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, 2017

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 No. 001-36876

BABCOCK & WILCOX ENTERPRISES, INC.

(Exact name of registrant as specified in its charter)

DELAWARE	47-2783641
(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  ¨    No  x

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  x

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.    Yes  x    No  ¨

Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files).    Yes  x    No  ¨

Indicate by check mark 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. ¨

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

Large accelerated filer	x	Accelerated filer	¨
Non-accelerated filer	¨  (Do not check if a smaller reporting company)	Smaller reporting company	¨
		Emerging growth company	¨

If an emerging growth company, indicate by check mark if the registrant has elected not to use the extension transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. ¨

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

Yes  ¨    No  x

The aggregate market value of the registrant's common stock held by non-affiliates 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 30, 2017) was approximately $570 million.

The number of shares of the registrant's common stock outstanding at January 31, 2018 was 44,084,680.

DOCUMENTS INCORPORATED BY REFERENCE

Portions of the registrant's proxy statement for the 2018 Annual Meeting of Stockholders are incorporated by reference

into Part III of this Form 10-K.

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BABCOCK & WILCOX ENTERPRISES, INC.

INDEX TO FORM 10-K

		PAGE
	PART I
Item 1.	Business	1
	Overview	1
	Going concern considerations	2
	Business Segments	2
	Joint Ventures	5
	Contracts	5
	Bookings and Backlog	6
	Foreign Operations	7
	Customers	7
	Competition	7
	Raw Materials and Suppliers	8
	Employees	8
	Patents and Licenses	8
	Research and Development Activities	8
	Permits and Licenses	9
	Environmental	9
	Executive Officers of Registrant	9
	Cautionary Statement Concerning Forward-Looking Information	9
	Available Information	10
Item 1A.	Risk Factors	10
	Risks Relating to Our Industry and Our Business	10
	Risks relating to Our 2015 Spin-Off From Our Former Parent	22
	Risks Relating to Ownership of Our Common Stock	25
Item 1B.	Unresolved Staff Comments	26
Item 2.	Properties	27
Item 3.	Legal Proceedings	27
	PART II
Item 5.	Market for Registrant's Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities	28
Item 6.	Selected Financial Data	30
Item 7.	Management's Discussion and Analysis of Financial Condition and Results of Operations	31
	Overview	31
	Results of Operations - Years Ended December 31, 2017, 2016 and 2015	34
	Liquidity and Capital Resources	44
	Effects of Inflation and Changing Prices	50
	Critical Accounting Policies and Estimates	51

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Item 7A.	Quantitative and Qualitative Disclosures about Market Risk	55
Item 8	Consolidated Financial Statements and Supplementary data	56
	Report of Independent Registered Public Accounting Firm	56
	Consolidated and Combined Statements of Operations for the Years Ended December 31, 2017, 2016 and 2015	57
	Consolidated and Combined Statements of Comprehensive Income for the Years Ended December 31, 2017, 2016 and 2015	58
	Consolidated Balance Sheets for the Years Ended December 31 2017 and 2016	59
	Consolidated and Combined Statement of Stockholders' Equity for the Years Ended December 31, 2017, 2016 and 2015	60
	Consolidated and Combined Statements of Cash Flows for the Years Ended December 31, 2017, 2016 and 2015	61
	Notes to Consolidated Financial Statements	63
Item 9.	Changes In and Disagreements With Accountants on Accounting and Financial Disclosure	114
Item 9A.	Controls and Procedures	114
	Disclosure Controls and Procedures	114
	Management's Report on Internal Control Over Financial Reporting	116
	Independent Auditor's Report on Internal Control over Financial Reporting	117
	Changes in Internal Control Over Financial Reporting	118
Item 9B.	Other Information	118
	PART III
Item 10.	Directors, Executive Officers and Corporate Governance	121
Item 11.	Executive Compensation	122
Item 12.	Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters	122
Item 13.	Certain Relationships and Related Transactions, and Director Independence	123
Item 14.	Principal Accountant Fees and Services	123
	PART IV
Item 15.	Exhibits and Financial Statement Schedules	124
Item 16.	Form 10-K Summary	127
Signatures		127

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PART 1

ITEM 1. Business

In this annual report on Form 10-K, unless the context otherwise indicates, "B&W," "we," "us," the "Company" and "our" mean Babcock & Wilcox Enterprises, Inc. and its consolidated subsidiaries.

B&W is a leading technology-based provider of advanced fossil and renewable power generation and environmental equipment that includes a broad suite of boiler products, environmental systems, and services for power and industrial uses. We specialize in technology and engineering for power generation and various other industries, including the procurement, erection and specialty manufacturing of related equipment, and services, including:

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

• environmental control systems for both power generation and industrial applications to incinerate, filter, capture, recover and/or purify air, liquid and vapor-phase effluents from a variety of power generation and specialty manufacturing processes;

• aftermarket support for the global installed base of operating plants with a wide variety of products and technical services including replacement parts, retrofit and upgrade capabilities, field engineering, construction, inspection, operations and maintenance, condition assessment and other technical support;

• custom-engineered comprehensive dry and wet cooling solutions;

• gas turbine inlet and exhaust systems, custom silencers, filters and custom enclosures; and

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

Our overall activity depends significantly on the capital expenditures and operations and maintenance expenditures of global electric power generating companies, other steam-using industries and industrial facilities with environmental compliance and noise abatement needs. Several factors influence these expenditures, including:

• prices for electricity, along with the cost of production and distribution including the cost of fuel within the United States or internationally;

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

• requirements for environmental and noise abatement improvements;

• expectation of future requirements to further limit or reduce greenhouse gas and other emissions in the United States and internationally;

• environmental policies which include waste-to-energy or biomass as options to meet legislative requirements and clean energy portfolio standards;

• level of capacity utilization at operating power plants and other industrial uses of steam production;

• requirements for maintenance and upkeep at operating power plants to combat the accumulated effects of usage;

• overall strength of the industrial industry; and

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

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Customer demand is heavily affected by the variations in our customers' business cycles and by the overall economies and energy, environmental and noise abatement needs of the countries in which they operate.

On June 8, 2015, the board of directors of The Babcock & Wilcox Company (now known as BWX Technologies, Inc.) ("BWC" or the "former Parent") approved the spin-off of B&W through the distribution of shares of B&W common stock to holders of BWC common stock. The distribution of B&W common stock was made on June 30, 2015, and consisted of one share of B&W common stock for every two shares of BWC common stock to holders of BWC common stock as of 5:00 p.m. New York City time on the record date, June 18, 2015. Cash was paid in lieu of any fractional shares of B&W common stock. On June 30, 2015, B&W became a separate publicly traded company, and BWC did not retain any ownership interest in B&W. We filed our Form 10 describing the spin-off with the Securities and Exchange Commission, which was declared effective on June 16, 2015. The spin-off is further described in Note 1 to the consolidated financial statements included in Item 8.

Going Concern Considerations

As a result of additional losses we recognized in the fourth quarter of 2017 related to an increase in structural steel repair costs on one of our European renewable energy contracts, we were not in compliance with certain financial covenants under our United States Revolving Credit Facility (“Revolver”) and our Second Lien Term Loan Facility agreement (“Second Lien”) as of December 31, 2017. On March 1, 2018, we obtained an agreement (the “March 1, 2018 Amendment”) to amend our Revolver. The March 1, 2018 Amendment temporarily waived the financial covenant defaults that existed at December 31, 2017 under the Revolver, consented to our planned Rights Offering (as discussed below), permitted up to $35 million of borrowings to be used in conjunction with the proceeds of the Rights Offering (described below) to be used to repay the principal portion of the Second Lien, and made certain other modifications. We face liquidity challenges, primarily related to our non-compliance with the financial covenants under our Second Lien as of December 31, 2017, which may be difficult to resolve in a timely manner. The Second Lien contains a 180 day standstill period beginning on March 1, 2018 to resolve the event of default or repay the loan. The March 1, 2018 Amendment and the Second Lien are further described in Note 19 and Note 20, respectively, to the consolidated financial statements included in Item 8.

On March 1, 2018, we entered into an equity commitment agreement (“Equity Commitment Agreement”) with a group of our existing stockholders to fully backstop our planned Rights Offering (“Rights Offering”) for the purpose of providing at least $182 million of new capital. We are proposing to undertake a rights offering pursuant to which all of our stockholders will have the ability, on a pro rata basis, to purchase up to at least $182 million of the Company’s common stock. The Equity Commitment Agreement provides for a backstop commitment from a group of our existing stockholders to purchase any unsold portion of the Rights Offering. We plan to use the net proceeds from the sale of the Company’s common stock in the Rights Offering and the permitted borrowing capacity provided by our Revolver to extinguish the outstanding balance of our Second Lien and terminate the associated borrowing agreement. Our plan is designed to provide us with adequate liquidity to meet our obligations for at least the twelve month period following March 1, 2018; however, our remediation plan includes raising additional capital through the Rights Offering and other sources before the end of the standstill period, which will depend on conditions in the capital markets and, with respect to the Rights Offering, an amendment to our existing shelf registration statement that we plan to file in early March 2018 being declared effective by the Securities and Exchange Commission (“SEC”), which are matters that are outside of our control. Accordingly, we cannot be certain of our ability to raise additional capital on terms acceptable to us which raises substantial doubt about our ability to continue as a going concern. Additionally, our ability to meet the amended covenants associated with our Revolver is dependent on our future financial operating results. While we believe that the actions summarized above and in Note 1 to our consolidated financial statements included in Item 8 are more likely than not to address the substantial doubt about the Company’s ability to continue as a going concern, we cannot assert that it is probable that our plans will fully mitigate the conditions identified. If we cannot continue as a going concern, material adjustments to the carrying values and classifications of our assets and liabilities and the reported amounts of income and expense could be required.

Business Segments

Our operations are assessed based on three reportable segments, which are summarized as follows:

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Power segment

Our Power segment focuses on the supply of, and aftermarket services for, steam-generating, environmental, and auxiliary equipment for power generation and other industrial applications. The segment provides a comprehensive mix of aftermarket products and services to support peak efficiency and availability of steam generating and associated environmental and auxiliary equipment, serving large steam generating utility and industrial customers globally. Our products and services include replacement parts, field technical services, retrofit and upgrades, fuel switching and repowering contracts, construction and maintenance services, start-up and commissioning, training programs and plant operations and maintenance for our full complement of boiler, environmental and auxiliary equipment. Our auxiliary equipment includes boiler cleaning equipment and material handling equipment.

Our worldwide new build boiler and environmental products businesses serve large steam generating and industrial customers. The segment provides a full suite of product and service offerings including engineering, procurement, specialty manufacturing, construction and commissioning. The segment's product suite includes utility boilers and industrial boilers fired with coal and natural gas. Our boiler products include advanced supercritical boilers, subcritical boilers, fluidized bed boilers, chemical recovery boilers, industrial power boilers, package boilers, heat recovery steam generators and waste heat boilers.

Our environmental systems offerings include air pollution control products and related equipment for the treatment of nitrogen oxides, sulfur dioxide, fine particulate, mercury, acid gases and other hazardous air emissions. These include wet and dry flue gas desulfurization systems, catalytic and non-catalytic nitrogen oxides reduction systems, low nitrogen oxides burners and overfire air systems, fabric filter baghouses, wet and dry electrostatic precipitators, mercury control systems and dry sorbent injection for acid gas mitigation.

The segment also receives license fees and royalty payments through licensing agreements of our proprietary technologies.

While opportunities to increase revenues in the segment are limited, we are striving to grow margins by:

• maintaining our strong service presence in support of our installed fleet of steam generation equipment and expanding support of other OEM equipment;

• selectively bidding contracts in emerging international markets needing state-of-the-art technology for fossil power generation and environmental systems;

• growing sales of industrial steam generation products in the petrochemical and pulp & paper markets, such as heat recovery, natural gas and oil fired package boilers, due in part to lower fuel prices; and

• reducing costs through a focus on operational efficiencies.

Our Power segment generated revenues of $821.1 million, $982.0 million and $1.23 billion in 2017, 2016 and 2015, respectively, which was 52.7%, 62.2% and 70.3% of our total revenues in those years, respectively.

Renewable segment

Our Renewable segment provides steam-generating systems, environmental and auxiliary equipment for the waste-to-energy and biomass power generation industries, and plant operations and maintenance services for our full complement of systems and equipment. We deliver these products and services to a large base of customers primarily in Europe through our extensive network of technical support personnel and global sourcing capabilities. Our customers consist of traditional, renewable and carbon neutral power utility companies that require steam generation and environmental control technologies to enable beneficial use of municipal waste and biomass. This segment's activity is dependent on the demand for electricity and reduced landfill use, and ultimately the capacity utilization and associated operations and maintenance expenditures of waste-to-energy power generating companies and other industries that use steam to generate energy.

In 2017, we redefined our approach to bidding on and executing renewable energy contracts. Under our new model, we are focusing on engineering and supplying our core waste-to-energy and renewable energy technologies - steam generation, combustion grate, environmental equipment, material handling, and cooling condensers - while partnering with other firms to execute the balance of plant and civil construction scope on contracts we pursue. We believe the new market approach is better aligned with our core competencies and risk-profile as a supplier of engineered equipment and technologies and aftermarket services.

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Globally, efforts to reduce the environmental impact of burning fossil fuels may create opportunities for us as existing generating capacity is replaced with cleaner technologies. We expect backlog growth in the future, primarily from renewable waste-to-energy contracts, as we continue to see numerous opportunities around the globe, although the rate of this growth is dependent on many external factors.

Our Renewable segment generated revenues of $347.2 million, $349.2 million and $338.6 million in 2017, 2016 and 2015, respectively, which was 22.3%, 22.1% and 19.3% of our total revenues in those years, respectively.

Industrial segment

At December 31, 2017, our Industrial segment was comprised of our MEGTEC, Universal and SPIG businesses, each as described below. The segment is focused on custom-engineered cooling, environmental, noise abatement and industrial equipment along with related aftermarket services.

Through MEGTEC, we provide environmental products and services to numerous industrial end markets. MEGTEC designs, engineers and manufactures products including oxidizers, solvent recovery and distillation systems, wet electrostatic precipitators, scrubbers and heat recovery systems. MEGTEC also provides specialized industrial process systems, coating lines and equipment. To this product mix, B&W recently added (synergy) technologies including dry electrostatic precipitators, pulse jet fabric filters, selective catalytic reduction systems, and dry and wet scrubbers. These complementary technologies enhance MEGTEC’s ability to offer a full line of environmental products and allow MEGTEC to strategically grow its business by selling solutions (comprehensive equipment trains) to new and existing customers and markets. MEGTEC serves a diverse set of industrial end markets globally with a current emphasis on the chemical, pharmaceutical, energy storage, metals and mining, and engineered wood panel board markets. MEGTEC's activity is dependent primarily on the capacity utilization of operating industrial plants and an increased emphasis on environmental emissions globally across a broad range of industries and markets.

We acquired SPIG S.p.A. ("SPIG") on July 1, 2016. SPIG provides custom-engineered cooling systems, services and aftermarket products. SPIG’s product offerings include air-cooled (dry) cooling systems, mechanical draft wet cooling towers and natural draft wet cooling hyperbolic towers. SPIG also provides end-to-end aftermarket services, including spare parts, upgrades and revamping of existing installations and remote monitoring. SPIG's comprehensive dry and wet cooling solutions and aftermarket products and services are primarily provided to the power generation industry, including natural gas-fired and renewable energy power plants, and downstream oil and gas, petrochemical and other industrial end markets in the Europe, the Middle East and the Americas. SPIG's activity is dependent primarily on global energy demand from utilities and other industrial plants, regulatory requirements, water scarcity and energy efficiency needs.

We acquired Universal Acoustic & Emissions Technology, Inc. ("Universal") on January 11, 2017. Universal provides custom-engineered acoustic, emission and filtration solutions to the natural gas power generation, mid-stream natural gas pipeline, locomotive and general industrial end-markets. Universal’s product offering includes gas turbine inlet and exhaust systems, custom silencers, filters and custom enclosures. Historically, almost all of Universal's activity has been in the United States. With the integration of Universal with the Industrial segment, we expect its business will grow globally with the benefit of B&W's global network of current and future customers and the evolving needs of noise abatement controls in the industrial market.

We see opportunities for growth in revenues in the Industrial segment relating to a variety of factors. Our new equipment customers make purchases as part of major capacity expansions, to replace existing equipment, or in response to regulatory initiatives. Additionally, our significant installed base provides a consistent and recurring aftermarket stream of parts, retrofits and services. Major investments in global industrial markets have strengthened demand for our industrial equipment, while tightening global environmental and noise abatement regulations are creating new opportunities. We foresee long-term trends toward increased environmental and noise abatement controls for industrial manufacturers around the world. Together, the companies that comprise the Industrial segment are well-positioned to capitalize on opportunities in these markets.

To enhance our financial flexibility, in November 2017 we also announced that we are evaluating strategic alternatives for our MEGTEC and Universal businesses. Though our outlook remains favorable for these businesses, we believe it is prudent to explore alternatives for these parts of our company, providing greater optionality if needed.

Our Industrial segment generated revenues of $397.8 million, $253.6 million and $183.7 million in 2017, 2016 and 2015, respectively, which was 25.5%, 16.1% and 10.4% of our total revenues in those years, respectively.

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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." We enter into joint ventures primarily for specific market access and to enhance our manufacturing, design and global production operations as well as reduce operating and financial risk profiles. We generally account for our investments in joint ventures under the equity method of accounting. Our unconsolidated joint ventures are described below.

• Babcock & Wilcox Beijing Company, Ltd. ("BWBC") Through December 31, 2017, we owned equal interests in this entity with Beijing Jingcheng Machinery Electric Holding Company, Ltd. BWBC was formed in 1986 and is located in Beijing, China. Its main activities include the design, manufacture, production and sale of various power plant steam generators including supercritical and ultra supercritical boilers and aftermarket services that include boiler upgrades and environmental equipment. BWBC also provides engineering services and manufacturing to support B&W's new power boiler business globally. In early 2018, we sold all of our joint venture interest in BWBC for approximately $21 million, resulting in a gain of approximately $4 million, which will be recognized in the first quarter of 2018. Although we will no longer have an equity interest in this joint venture, we will continue a relationship with BWBC through an expanded technology license.

• Thermax Babcock & Wilcox Energy Solutions Private Limited ("TBWES") 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 TBWES our technology for subcritical boilers 300 MW and larger, highly efficient supercritical boilers and coal pulverizers. In 2013, TBWES finalized construction of a facility in India designed to produce parts for up to 3,000 MW of utility boiler capacity per year. During the second quarter of 2017, both we and our joint venture partner decided to make a strategic change in the Indian joint venture due to the decline in forecasted market opportunities in India, which reduced the recoverable value of our investment in the joint venture. As a result of this strategic change, we recognized an $18.2 million other-than-temporary-impairment of our investment in TBWES in the second quarter of 2017. At December 31, 2017, our remaining investment in TBWES was $26.0 million.

• Other Project Related Ventures From time to time, we partner with other companies to better meet the needs of our customers, which can result in project-related joint venture entities. Examples of this include BWL Energy Ltd., which was formed to complete the construction of a waste wood fired boiler contract in the United Kingdom. This joint venture combines our expertise in the waste-to-energy power plant design, engineering, procurement and construction with our partner's civil construction capability to provide a full turnkey product to our customer.

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, technical capabilities of equipment and personnel, plant or equipment availability, 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 Related to Our Business – We are subject to risks associated with contractual pricing in our industry, 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" as detailed 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 regularly 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

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reduction or an elimination of previously reported profits with respect to a contract, we would recognize a charge against current earnings, which could be material.

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, which may involve significant amounts for contract security.

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.

Other sales, such as parts and certain aftermarket service activities, are not in the form of long-term contracts, and we recognize revenues as goods are delivered and work is performed.

Bookings and Backlog

Bookings and 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 contracts are awarded and completed within the same fiscal period.

Bookings and backlog are not measures defined by generally accepted accounting principles. It is possible that our methodology for determining bookings and backlog may not be comparable to methods used by other companies. Backlog may not be indicative of future operating results, and contracts in our backlog may be canceled, modified or otherwise altered by customers. Additionally, because we operate globally, our backlog is also affected by changes in foreign currencies.

We generally include expected revenue from contracts in our backlog when we receive written confirmation from our customers authorizing the performance of work and committing the customer to payment for work performed. Accordingly, we exclude from backlog orders or arrangements that have been awarded but that we have not been authorized to begin performance.

Bookings represent additions to our backlog. We believe comparing bookings on a quarterly basis or for periods less than one year is less meaningful than for longer periods, and that shorter term changes in bookings may not necessarily indicate a material trend.

We do not include the value of our unconsolidated joint venture contracts in backlog. See Note 7 to the consolidated financial statements included in Item 8 of this annual report for financial information on our equity method investments.

Our bookings during the years ended December 31, 2017 and 2016 were as follows:

(In millions)	2017			2016
Power	$	656		$	790
Renewable	115			135
Industrial	416			222
Other/eliminations	(48		)	(6		)
Bookings	$	1,139		$	1,141

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Our backlog at the end of the prior two years was as follows: 

(in approximate millions)	December 31, 2017			December 31, 2016
Power segment	$	453		$	618
Renewable segment	1,008			1,241
Industrial segment	258			216
Other/eliminations	(43		)	(3		)
Backlog	$	1,676		$	2,072

Of the December 31, 2017 backlog, we expect to recognize approximate revenues as follows:

(in approximate millions)	2018			2019		Thereafter			Total
Power segment	$	335		$	81	$	37		$	453
Renewable segment	293			111		604			1,008
Industrial segment	258			—		—			258
Other/eliminations	(3		)	—		(40		)	(43		)
Backlog	$	883		$	192	$	601		$	1,676

Foreign Operations

Our operations in Denmark provide comprehensive services to companies in the waste-to-energy and biomass energy sector of the power generation market, primarily in Europe. Our operations in Italy provide custom-engineered comprehensive dry and wet cooling solutions and aftermarket parts and services to the power generation industry including natural gas-fired and renewable energy power plants, as well as downstream oil and gas, petrochemical and other industrial end markets. Our operations in Scotland provideboiler cleaning technologies and systems (such as sootblowers).Our operations in Germany provide a variety of ash and material handling solutions, from completely dry bottom ash handling to fly ash and petroleum coke processing.Our Canadian operations serve the Canadian industrial power, oil production and electric utility markets. We also have manufacturing facilities in Mexico to serve global markets.

Historically, our joint ventures in China and India served the power generation needs of their local domestic and other utility markets, and both joint ventures participated as manufacturing partners on certain of our foreign contracts.

The functional currency of our foreign operating entities is not the United States dollar, and as a result, we are subject to exchange rate fluctuations that impact our financial position, results of operations and cash flows.

For additional information on the geographic distribution of our revenues, see Note 4 to our consolidated financial statements included in Item 8 of this annual report.

Customers

We provide our products and services to a diverse customer base that includes utilities and other power producers located around the world. We have no customers that individually accounted for more than 10% of our consolidated revenues in the years ended December 31, 2017, 2016 or 2015.

Competition

With 150 years of experience, we have supplied highly engineered energy and environmental equipment in over 90 countries. 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 around the globe also yields competitive advantages, although our markets are highly competitive and price sensitive. We compete with a number of domestic and foreign companies specializing in power generation, environmental, and cooling systems and services. Each segment's primary competitors are summarized as follows:

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Power segment	Renewable segment	Industrial segment
GE	CNIM Group	B&W MEGTEC primary competitors
Doosan	Hitachi Zosen	Durr, Dustex, CECO, Eisenmann
Babcock Power	Martin	B&W Universal primary competitors
Cleaver-Brooks	Keppel Seghers	CECO, Innova, Miratech, American Air Filter
Sumitomo SHI-FW	Valmet	B&W SPIG primary competitors
MH Power Systems	Andritz	Hamon, Enexio, Kelvion, Paharpur, Evapco, SPX Corporation

Across each of our segments, we also compete with a variety of engineering and construction companies related to installation of steam generating systems and environmental control equipment; specialized industrial equipment; and other suppliers of replacement parts, repair and alteration services and other services required to retrofit and maintain existing steam generating systems. The primary bases of competition are price, technical capabilities, quality, timeliness of performance, breadth of products and services and willingness to accept contract risks.

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. We do not depend on a single source of supply for any significant raw materials. Although shortages of some raw materials have existed from time to time, no serious shortage exists at the present time.

Employees

At December 31, 2017, we had approximately 4,800 employees worldwide, not including 2,200 joint venture employees. Of our hourly employees, approximately 1,300 are union-affiliated, covered by ten union agreements related to active facilities in Canada, China, Denmark, Great Britain, Mexico, and United States. Most of our union agreements expire in 2018 or 2019, and we are actively negotiating new agreements. We consider our relationships with our employees and unions to be in good standing.

Patents and Licenses

We currently hold a large number of United States 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 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. Historically, we focused our research dollars on improving our products for the markets we serve through: (i) cost reductions resulting in more competitive products in a highly competitive global market and margin improvement; (ii) reduced performance risk assuring our products meet our and our customers' expectations; and (iii) standards development and updates, which results in lower engineering hours consumed on projects and enable us to sublet engineering to low cost engineering centers of excellence. In the future, our research and development activities will be focused primarily on improvements in the reliability and efficiency of our products to meet our customers' needs and enhance our market opportunities and profitability. Research and development costs unrelated to specific contracts are expensed as incurred. Research and development expenses totaled $9.4 million, $10.4 million and $16.5 million in the years ended December 31, 2017, 2016 and 2015, respectively.

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Permits and Licenses

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 are not aware of any material noncompliance and believe our operations and certifications are currently in compliance with all relevant permits, licenses and certifications.

Environmental

We have been identified as a potentially responsible party at various cleanup sites under the Comprehensive Environmental Response, Compensation and Liability Act of 1980, 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.

Executive Officers of Registrant

For a listing of our executive officers, see Part III, Item 10 of this annual report, which information is incorporated herein by reference.

***** Cautionary Statement Concerning Forward-Looking Information *****

This annual report, including Management's Discussion and Analysis of Financial Condition and Results of Operations, contains forward-looking statements within the meaning of Section 27A of the Securities Act of 1933 and Section 21E of the Securities Exchange Act of 1934. You should not place undue reliance on these statements. Statements that include the words "expect," "intend," "plan," "believe," "project," "forecast," "estimate," "may," "should," "anticipate" and similar statements of a future or forward-looking nature identify forward-looking statements.

These forward-looking statements address matters that involve risks and uncertainties and include statements that reflect the current views of our senior management with respect to our financial performance and future events with respect to our business and industry in general. There are or will be important factors that could cause our actual results to differ materially from those indicated in these statements. If one or more events related to these or other risks or uncertainties materialize, or if our underlying assumptions prove to be incorrect, actual results may differ materially from what we anticipate. Differences between actual results and any future performance suggested in our forward-looking statements could result from a variety of factors, including the following: our ability to continue as a going concern; our ability to obtain and maintain sufficient financing to provide liquidity to meet our business objectives, surety bonds, letters of credit and similar financing, and to refinance our Second Lien through the Rights Offering, or otherwise; the highly competitive nature of our businesses; general economic and business conditions, including changes in interest rates and currency exchange rates; general developments in the industries in which we are involved; cancellations of and adjustments to backlog and the resulting impact from using backlog as an indicator of future earnings; our ability to perform contracts on time and on budget, in accordance with the schedules and terms established by the applicable contracts with customers; failure by third-party subcontractors or suppliers to perform their obligations on time and as specified; our ability to realize anticipated savings and operational benefits from our restructuring plans, and other cost-savings initiatives; our ability to successfully integrate and realize the expected synergies from acquisitions; our ability to successfully address productivity and schedule issues in our Renewable segment; willingness of customers to waive liquidated damages or agree to bonus opportunities; our ability to successfully partner with third parties to win and execute renewable projects; changes in our effective tax rate and tax positions; 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; our ability to protect our intellectual property and renew licenses to use intellectual property of third parties; our use of the percentage-of-completion method of accounting; the risks associated with integrating businesses we acquire; our ability to successfully manage research and development projects and costs, including our efforts to successfully develop and commercialize new technologies and products; the operating risks normally incident to our lines of business, including professional liability, product liability, warranty and other claims against us;

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changes in, or our failure or inability to comply with, laws and government regulations; difficulties we may encounter in obtaining regulatory or other necessary permits or approvals; changes in, and liabilities relating to, existing or future environmental regulatory matters; our limited ability to influence and direct the operations of our joint ventures; potential violations of the Foreign Corrupt Practices Act; our ability to successfully compete with current and future competitors; the loss of key personnel and the continued availability of qualified personnel; our ability to negotiate and maintain good relationships with labor unions; changes in pension and medical expenses associated with our retirement benefit programs; social, political, competitive and economic situations in foreign countries where we do business or seek new business; the possibilities of war, other armed conflicts or terrorist attacks; our ability to successfully consummate strategic alternatives for our MEGTEC and Universal businesses if we determine to pursue them; and the other risks set forth under Part I, Item 1A "Risk Factors" in this annual report.

These factors are not necessarily all the factors that could affect us. We assume no obligation to revise or update any forward-looking statement included in this annual report for any reason, except as required by law.

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, our proxy statement, 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 annual reports, 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; Amended and Restated By-laws; charters for the Audit & Finance, Governance, Compensation and Safety & Security Committees of our Board; and Modern Slavery Transparency Statement.

Item 1A. Risk Factors

You should carefully consider each of the following risks and all of the other information contained in this annual report. Some of these risks relate principally to our spin-off from our former Parent, while others relate principally to our business and the industry in which we operate or to the securities markets generally and ownership of our common stock. If any of these risks develop into actual events, our business, financial condition, results of operations or cash flows could be materially adversely affected by any of these risks, and, as a result, the trading price of our common stock could decline.

Risks Relating to Our Industry and Our Business

As a result of operating losses and negative cash flows from operations, together with other factors, including the possibility that a covenant default or other event of default could cause certain of our indebtedness to become immediately due and payable (after the expiration of any applicable grace period), we may not have sufficient liquidity to sustain operations and to continue as a going concern.

We have experienced losses from operations in each of the past two years, have negative operating cash flows during the year ended December 31, 2017 and are dependent on our ability to raise capital in the time frame required in our United States Revolving Credit Facility ("Revolver") in order to avoid an event of default under our lending agreements. As a result of additional losses we recognized in the fourth quarter of 2017 related to an increase in structural steel repair costs on one of our European renewable energy contracts, we were not in compliance with certain financial covenants under our Revolver and our Second Lien Term Loan Facility ("Second Lien") as of December 31, 2017. On March 1, 2018, we obtained an agreement (the “March 1, 2018 Amendment”) to amend our Revolver. The March 1, 2018 Amendment waived the financial covenant defaults that existed at December 31, 2017 under the Revolver, consented to our planned Rights Offering and made certain other modifications. The Second Lien contains a 180 day standstill period beginning on March 1, 2018 to resolve the event of default or repay the loan.

Absent additional waivers or cures, continued non-compliance with covenants contained in our Second Lien will constitute a

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default under the Second Lien following the expiration of the 180 day standstill period. As a result, all indebtedness under the Second Lien could be declared immediately due and payable upon the occurrence of an event of default after expiration of the 180 day standstill period. It is possible we could obtain waivers from our lenders; however, our current liquidity risks raise substantial doubt about whether we will meet our obligations as they become due within one year after the date of issuance of this report.

As a result of these factors, there exists substantial doubt whether we will be able to continue as a going concern. The accompanying consolidated financial statements are prepared on a going concern basis and do not include any adjustments that might result from uncertainty about our ability to continue as a going concern, other than the reclassification of certain long-term debt to current liabilities. The report from our independent registered public accounting firm on our consolidated financial statements for the year ended December 31, 2017 includes a paragraph that summarizes the salient facts and conditions that raise substantial doubt about our ability to continue as a going concern.

There can be no assurance that our plan to improve our operating performance and financial position will be successful or that we will be able to obtain additional financing on commercially reasonable terms or at all including, without limitation, our ability to successfully complete the Rights Offering and refinance our Second Lien. As a result, our liquidity and ability to timely pay our obligations when due could be adversely affected. Furthermore, our creditors may resist renegotiation or lengthening of payment and other terms through legal action or otherwise. If we are not able to timely, successfully or efficiently implement the strategies that we are pursuing to improve our operating performance and financial position, we may not have sufficient liquidity to sustain operations and to continue as a going concern.

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

The demand for power generation products and services depends primarily on the spending of electric power generating companies and other steam-using industries and expenditures by original equipment manufacturers. These 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 and other end products of steam-generating facilities;

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

• requirements of environmental legislation and regulations, 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 and associated operations and maintenance expenditures of power generating companies and other steam-using facilities;

• requirements for maintenance and upkeep at operating power plants and other steam-using facilities 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.

We estimate that 27%, 47% and 50% of our consolidated revenues in 2017, 2016 and 2015, respectively, was related to coal-fired power plants. A material decline in spending by electric power generating 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. 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 in the United States and elsewhere has caused many of our major customers, principally electric utilities, to delay making substantial expenditures for new plants, as well as upgrades to existing power plants.

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Demand for our products and services is vulnerable to economic downturns and industry conditions.

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. These factors include, but are not limited to: the cyclical nature of the industries we serve, inflation, geopolitical issues, the availability and cost of credit, volatile oil and natural gas prices, low business and consumer confidence, high unemployment and energy conservation measures.

Unfavorable economic conditions may lead customers to delay, curtail or cancel proposed or existing contracts, which may decrease the overall demand for our products and services and adversely affect our results of operations.

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 products and 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 receivable 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 contract cancellations or changes in scope and schedule, we cannot predict with certainty when or if backlog will be performed. In addition, even where a contract proceeds as scheduled, it is possible that contracted parties may default and fail to pay amounts owed to us or poor contract performance could increase the cost associated with a contract. Delays, suspensions, cancellations, payment defaults, scope changes and poor contract execution could materially reduce or eliminate the revenues and profits that we actually realize from contracts 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 contracts. 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. Contracts may remain in our backlog for extended periods of time. If we experience significant contract 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 industry, 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 a highly competitive industry, and we have priced a number of our contracts on a fixed-price basis. Our actual costs could exceed our projections, as was the case recently with several large contracts in the Renewable segment. 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 industry may result in actual revenues or costs being different from those we originally estimated and may result in reduced profitability or losses on contracts. Some of these risks include:

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

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

• 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 contract delays and cause us to incur additional costs.

Our contractual performance may be affected by third parties’ and subcontractors’ failure to meet schedule, quality and other requirements on our contracts, which could increase our costs, scope, technical difficulty or in extreme cases, our ability to meet contractual requirements.

We conduct significant portions of our business by engaging in long-term contracts related to highly complex, customized equipment or facilities for electrical generation, industrial processes, and/or environmental compliance. The complexity of these contracts generally necessitates the participation of others on this contract, including subcontractors, equipment or part manufacturers, partner companies, other companies with whom we do not have contractual relationships, customers, financing organizations, regulators and others. While we endeavor to limit our liability to matters within our control, not all scenarios can be foreseen and we may become subject to the risk of others’ performance that may or may not be within our control or influence. Delays, changes or failures of others, including subcontractors, could subject us to additional costs, delays, technical specification changes, contractual penalties or other matters for which we may be unable to obtain compensation, or compensation may not be sufficient. In extreme cases, the direct or indirect effects of such matters may cause us to be unable to fulfill our contractual requirements.

For example, we have contracts to construct several renewable energy plants in the United Kingdom. These contracts have suffered delays, additional cost and contractual penalties. The complexity of these contracts required us to subcontract matters, such as structural engineering, to other companies that have the appropriate technical expertise. In September 2017, a structural steel issue was discovered at one of these plants, which management believes is the result of an engineering error by a subcontractor. The failure resulted in work being stopped at the plant with the failure and at two other plants under construction where failure had not occurred, but had used a similar design by the same subcontractor. In each case, additional engineering analysis and remediation was required, resulting in additional costs, schedule delays and contractual penalties, all of which were significantly greater at the plant where failure occurred. Through December 31, 2017, $42 million of additional costs had been recorded related to the effects of this engineering error across the three plants. In each case, the engineering assessment, remediation and safety plans required approval of the subcontractor, customer, our contract partner and the respective analysis independent technical experts from each. In the case of the plant where structural failure occurred, this process to agree on the appropriate structural remediation and plan to implement the remediation was lengthy and resulted in a more significant delay. These contracts include rejection clauses that give the customers the option to reject the deliverable, recover all monies paid to us and our partner, and require us to restore the property to its original state if contractual milestones are not met by a certain date. While we expect to be able to accelerate our progress and take other remedial actions if necessary to avoid giving a customer the option to exercise its rejection clause, failure to do so could have a material adverse effect on our liquidity and our ability to satisfy obligations under other contracts or comply with our debt covenants. Any insurance coverage may be insufficient, or the timing of any insurance proceeds may not meet our liquidity requirements.

We are exposed to credit risk and may incur losses as a result of such exposure.

We conduct our business by obtaining orders that generate cash flows in the form of advances, contract progress payments and final balances in accordance with the underlying contractual terms. We are thus exposed to potential losses resulting from contractual counterparties' failure to meet their obligations. As a result, the failure by customers to meet their payment obligations, or a mere delay in making those payments, could reduce our liquidity and increase the need to resort to other sources of financing, with possible adverse effects on our business, financial condition, results of operations and cash flows. In some cases, we have joint and several liability with consortium partners in our projects, such as the renewable energy plants in the United Kingdom, and we may be subject to additional losses if our partners are unable to meet their contractual obligations.

In addition, the deterioration of economic conditions or negative trends in the credit markets could have a negative impact on relationships with customers and our ability to collect on trade receivables, with possible adverse effects on our business, financial condition, results of operations and cash flows.

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Our use of the 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 regularly 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 contract, 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 contracts, 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.

If our co-venturers fail to perform their contractual obligations on a contract 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 contract.

We often perform contracts jointly with third parties. For example, we enter into contracting consortia and other contractual arrangements to bid for and perform jointly on large contracts. Success on these joint contracts 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 contract, exposing us to legal liability, loss of reputation and reduced profit.

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.

We could be subject to changes in tax rates or tax law, adoption of new regulations or changing interpretations of existing law or exposure to additional tax liabilities in excess of accrued amounts.

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. Recently enacted tax reform legislation has made substantial changes to United States tax law, including a reduction in the corporate tax rate, a limitation on deductibility of interest expense, a limitation on the use of net operating losses to offset future taxable income, the allowance of immediate expensing of capital expenditures and deemed repatriation of foreign earnings. This legislation has resulted in, and may in the future result in additional effects on us, some of which may be adverse. For example, the reduction in the corporate tax rate has resulted in a revaluation of our existing deferred tax assets, and consequently an increase in our income tax expense for 2017. The magnitude of the net impact remains uncertain at this time and is subject to any other regulatory or administrative developments, including any regulations or other guidance promulgated by the United States Internal Revenue Service.

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, and we are regularly subject to 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 ability to use net operating losses and certain tax credits to reduce future tax payments could be limited if we experience an "ownership change".

Our NOL carryforwards and certain tax credits may become subject to annual limitation if we experience an "ownership change". In general, an "ownership change" occurs if 5% shareholders increase their collective ownership of our company by more than 50 percentage points during the relevant testing period. If an ownership change occurs, our ability to use NOL carryforwards and certain credits to reduce tax payments is generally limited to an annual amount based on (i) the fair market value of our stock immediately prior to the ownership change multiplied by the long-term tax-exempt interest rate.

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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, 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 are increasingly dependent on information technology networks and systems, including the Internet, to process, transmit and store electronic and financial information, to manage and support a variety of business processes and activities and to comply with regulatory, legal and tax requirements. We have been, and will likely continue to be, subject to cyber-based attacks and other attempts to threaten our information technology systems and the software we sell. A cyber-based attack could include attempts to gain unauthorized access to our proprietary information and attacks from malicious third parties using sophisticated, targeted methods to circumvent firewalls, encryption and other security defenses, including hacking, fraud, trickery or other forms of deception. If any of our significant information technology systems suffer severe damage, disruption, or shutdown and our business continuity plans do not effectively resolve the issues in a timely manner, the services we provide to customers, the value of our investment in research and development efforts and other intellectual property, our product sales, financial condition, results of operations and stock price may be materially and adversely affected, and we could experience delays in reporting our financial results. In addition, there is a risk of business interruption, litigation risks, and reputational damage from leakage of confidential information or the software we sell being compromised. The costs related to cyber or other security threats or disruptions may not be fully insured or indemnified by other means.

In order to address risks to our information systems, we continue to make investments in technologies and training of company personnel. 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 our financial condition, results of operations and stock price.

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, which could have a material adverse effect on our operations.

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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 contract and we are unable to obtain it due to insufficient liquidity or other reasons, we will not be able to pursue that contract. 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. 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 from sources outside of our contractually committed Credit Agreement will continue to be available to us on reasonable terms. The inclusion of a "going concern" explanatory paragraph in the auditor's report covering our audited consolidated financial statements contained herein may prevent us from obtaining bonding and letters of credit from sources outside of our contractually committed Credit Agreement on reasonable terms, or at all. 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, 2017, we had $269.1 million in letters of credit and bank guarantees and $378.8 million in surety bonds outstanding. Of these amounts, $7.4 million of financial letters of credit and $123.7 million of performance letters of credit were outstanding under the United States credit agreement.

Our amended United States credit facility could restrict our operations.

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

• flexibility in planning for, or reacting to, changes in our business or economic, regulatory and industry conditions;

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

• ability to sell assets;

• ability to pay dividends to our stockholders;

• ability to repurchase shares of our common stock; and

• ability to borrow additional funds.

In addition, our amended United States credit facility requires us to satisfy and maintain specified financial ratios. Our ability to meet those financial ratios can be affected by events beyond our control, and we cannot assure you that we will continue to meet the financial ratios.

During the covenant relief period under our amended United States credit facility, we are limited to $300.0 million of borrowings under that facility.

Our ability to comply with the covenants and restrictions contained in our amended United States credit facility may be affected by events beyond our control, including prevailing economic, financial and industry conditions. If market or other economic conditions deteriorate, our ability to comply with these covenants may be impaired. A breach of any of these covenants could result in an event of default under our amended United States credit facility, and we would not be able to access our credit facility for additional borrowings and letters of credit while any default exists. Upon the occurrence of such an event of default, all amounts outstanding under our amended United States credit facility could be declared to be immediately due and payable and all applicable commitments to extend further credit could be terminated. If indebtedness under our amended credit facility is accelerated, there can be no assurance that we will have sufficient assets to repay the indebtedness. The operating and financial restrictions and covenants in our amended credit facility and any future financing agreements may adversely affect our ability to finance future operations or capital needs or to engage in other business activities.

Our evaluation of strategic alternatives for certain businesses and non-core assets may not be successful.

We have initiated a process to evaluate strategic alternatives for business lines, such as MEGTEC and Universal, as well as certain non-core assets. These strategic alternatives are being evaluated as options to improve the company’s capital structure. There can be no assurance that these on-going strategic evaluations will result in the identification or consummation of any transaction. We may incur substantial expenses associated with identifying and evaluating potential strategic alternatives. The

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process of exploring strategic alternatives may be time consuming and disruptive to our business operations, and if we are unable to effectively manage the process, our business, financial condition and results of operations could be adversely affected. We also cannot assure that any potential transaction or other strategic alternative, if identified, evaluated and consummated, will prove to be beneficial to stockholders. Any potential transaction would be dependent upon a number of factors that may be beyond our control, including, among other factors, market conditions, industry trends, the interest of third parties in our business, the availability of financing to potential buyers on reasonable terms, and the consent of our lenders.

In addition, while this strategic evaluation is underway, we are exposed to risks and uncertainties, including potential difficulties in retaining and attracting key employees, distraction of our management from other important business activities, and potential difficulties in establishing and maintaining relationships with customers, suppliers, lenders, sureties and other third parties, all of which could harm our business.

Our business strategy includes development and commercialization of new technologies to support our growth, which requires significant investment and involves various risks and uncertainties. These new technologies may not achieve desired commercial or financial results.

Our future growth will depend, in part, 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, our ability to license or purchase new technologies from third parties, 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 revenues 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.

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 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 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, war and confiscation or seizure of property in some areas of the

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world, pollution liability, liabilities related to occupational health exposures (including asbestos), 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 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.

Our wholly owned captive insurance subsidiary provides workers' compensation, employer's liability, commercial general liability, professional 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 which 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 United States 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.

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;

• currency conversions and repatriation;

• clean air and other environmental protection legislation;

• taxation of foreign earnings;

• transactions in or with foreign countries or officials; 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 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.

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.

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Our business and our customers' businesses are required to obtain, and to comply with, national, state and local government permits and approvals.

Our business and our customers' 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 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 or our customers may be required to obtain additional operating permits or approvals. Our inability or our customers' inability to obtain, and to comply with, the permits and approvals required for our business could have a material adverse effect on us.

Our operations are subject to various environmental laws and legislation that may become more stringent in the future.

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.

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 financial condition as a result of future compliance with existing environmental laws and regulations. However, 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.

Our operations involve the handling, transportation and disposal of 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 hazardous materials. 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.

Governmental requirements relating to the protection of the environment, including solid waste management, air quality, water quality and cleanup of contaminated sites, have in the past 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

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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.

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 contamination 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 could be adversely affected by violations of the United States Foreign Corrupt Practices Act, the UK Anti-Bribery Act or other anti-bribery laws.

The United States Foreign Corrupt Practices Act (the "FCPA") generally prohibits companies and their intermediaries from making improper payments to non-United States government officials. Our training program, audit process and policies mandate compliance with the FCPA, the UK Anti-Bribery Act (the "UK Act") and other anti-bribery laws. We operate in some parts of the world that have experienced governmental corruption to some degree, and, in some 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, the UK Act or other anti-bribery laws (either due to our own acts or our inadvertence, or due to the acts or inadvertence of others, including agents, promoters or employees of our joint ventures), we could suffer from civil and criminal penalties or other sanctions.

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, which contributed income (losses) of $(9.9) million, $16.4 million and $(0.2) million to equity in income (loss) from investees for the years ended December 31, 2017, 2016 and 2015, respectively, and may enter into additional joint venture arrangements in the future. Our influence over some of these entities may be limited. Even in those joint ventures over which we do exercise significant influence, 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 contracts 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 business practices, contracts and internal controls relating to contracts. 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.

Our joint ventures located in countries outside of the United States are subject to various risks and uncertainties associated with emerging markets, including bribery and corruption, changes in laws, rules and regulations, fluctuations in demand, labor unrest, and the impact of regional and global business conditions generally. To the extent any of these factors has a material adverse impact on the joint venture or its future operations, our investment may become impaired. With respect to each joint venture, we, or our joint venture partner, may decide to change the strategic direction of the joint venture, which could adversely affect its sales, financial condition, and results of operations. In addition, our arrangements involving joint ventures may restrict us from gaining access to the cash flows or assets of these entities, including when we determine to exit a joint venture. In some cases, our joint ventures have governmentally imposed restrictions on their abilities to transfer funds

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to us. At December 31, 2017, our total investment in joint ventures was $43.3 million, which included $26.0 million related to a joint venture in India and $16.6 million related to a joint venture in China that was sold in the early part of 2018.

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 and in some cases are government supported. 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 other companies, which may impair our ability to compete against competitors or potential competitors.

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 or profits.

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, retirement or other reasons, 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. Additionally, we froze pension plan benefit accruals at the end of 2015, which could also result in incremental turnover in our workforce. If any of these events occurred for a significant period of time, our financial condition, results of operations and cash flows could be adversely impacted.

Negotiations with labor unions and possible work stoppages and other labor problems could divert management's attention and disrupt operations. In addition, new collective bargaining agreements or amendments to existing 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 from time to time, 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 could experience higher ongoing labor costs.

Pension and medical expenses associated with our retirement benefit plans may fluctuate significantly depending on a number of factors, and we may be required to contribute cash to meet underfunded pension obligations.

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, mortality assumptions and trends for future costs. Variances from these estimates could have a material adverse effect on us. Our policy to recognize these variances annually through mark to market accounting could result in volatility in our results of operations, which could be material. As of December 31, 2017, our defined benefit pension and postretirement benefit plans were underfunded by approximately $258.8 million. In addition, certain of these postretirement benefit plans were collectively bargained, and our ability to curtail or change the benefits provided may be impacted by contractual provisions set forth in the relevant union agreements and other plan documents. We also participate in various multi-employer pension plans in the United States and Canada under union and industry agreements that generally provide defined benefits to employees covered by collective bargaining agreements. Absent an applicable exemption, a contributor to a United States multi-employer plan is liable, upon termination or withdrawal from a plan, for its proportionate share of the plan's underfunded vested liability. Funding requirements for benefit obligations of these multi-employer pension plans are subject to certain regulatory requirements, and we may be required to make cash contributions which may be material to one or more of these plans to satisfy certain

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underfunded benefit obligations. See Note 18 to the consolidated financial statements included in Item 8 in this annual report for additional information regarding our pension and postretirement benefit plan obligations.

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, and we intend to continue to expand our international operations and customer base as part of our growth strategy. Our revenues from sales to customers located outside of the United States represented approximately 51%, 46% and 41% of total revenues for the years ended December 31, 2017, 2016 and 2015, respectively. Operating in international markets requires significant resources and management attention and subjects us to political, economic and regulatory risks that are not generally encountered in our United States 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. If we continue to expand our business globally, our success will depend, in part, on our ability to anticipate and effectively manage these and other risks. These and other factors may have a material impact on our international operations or our business as a whole.

International uncertainties and fluctuations in the value of foreign currencies could harm our profitability.

We have international operations primarily in Europe and Canada. For the year ended December 31, 2017, international operations accounted for approximately 51% of our total revenues. Our significant international subsidiaries may have sales and cost of sales in different currencies as well as other transactions that are denominated in currencies other than their functional currency. We do not currently engage in currency hedging activities to limit the risks of currency fluctuations. Consequently, fluctuations in foreign currencies could have a negative impact on the profitability of our global operations, which would harm our financial results and cash flows.

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

Natural disasters, such as earthquakes, tsunamis, hurricanes, floods, tornadoes, 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 tornadoes.

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

War, 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 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.

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Risks Relating to our 2015 Spin-Off from our Former Parent

We may be unable to achieve some or all of the benefits that we expect to achieve from our separation from BWC.

As an independent public company, we believe that we are able to more effectively focus on our operations and growth strategies than we could as a segment of BWC prior to the spin-off. However, following our separation from BWC in the spin-off, there is a risk that our results of operations and cash flows may be susceptible to greater volatility due to fluctuations in our business levels and other factors that may adversely affect our operating and financial performance. In addition, as a segment of BWC, we previously benefitted from BWC's financial resources. Because BWC's other operations will no longer be available to offset any volatility in our results of operations and cash flows and BWC's financial and other resources will no longer be available to us, we may not be able to achieve some or all of the benefits that we expect to achieve as an independent public company.

Our historical audited consolidated financial information is not necessarily indicative of our future financial condition, future results of operations or future cash flows nor does it reflect what our financial condition, results of operations or cash flows would have been as an independent public company during the periods presented.

The historical audited consolidated financial information included in this annual report for periods prior to July 1, 2015 does not necessarily reflect what our financial condition, results of operations or cash flows would have been as an independent public company during such periods and is not necessarily indicative of our future financial condition, future results of operations or future cash flows. This is primarily a result of the following factors:

• the historical audited consolidated financial results reflect allocations of expenses for services historically provided by BWC, and those allocations may be different than the comparable expenses we would have incurred as an independent company;

• our cost of debt and other capitalization may be different from that reflected in our historical audited consolidated financial statements;

• the historical audited consolidated financial information does not reflect the changes that will occur in our cost structure, management, financing arrangements and business operations as a result of our separation from BWC, including the costs related to being an independent company; and

• the historical audited consolidated financial information does not reflect the effects of some of the liabilities that have been assumed by B&W and does reflect the effects of some of the assets that have been transferred to, and liabilities that have been assumed by, BWC, including the assets and liabilities associated with BWC's Nuclear Energy segment, which were previously part of B&W and were transferred to BWC prior to the spin-off.

Please refer to "Management's Discussion and Analysis of Financial Condition and Results of Operations" included in Part II, Item 7, and the consolidated financial statements included in Item 8 of this annual report.

We are subject to continuing contingent liabilities of BWC following the spin-off.

As a result of the spin-off, there are several significant areas where the liabilities of BWC 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 BWC consolidated tax reporting group during any taxable period or portion of any taxable period ending on or before the completion of the spin-off is jointly and severally liable for the federal income tax liability of the entire consolidated tax reporting group for that taxable period. We entered into a tax sharing agreement with BWC in connection with the spin-off that allocates the responsibility for prior period taxes of BWC consolidated tax reporting group between us and BWC and its subsidiaries. However, if BWC were unable to pay, we could be required to pay the entire amount of such taxes. Other provisions of law establish similar liability for other matters, including laws governing tax-qualified pension plans as well as other contingent liabilities. The other contingent liabilities include personal injury claims or environmental liabilities related to BWC's historical nuclear operations. For example, BWC has agreed to indemnify us for personal injury claims and environmental liabilities associated with radioactive materials related to the operation, remediation, and/or decommissioning of two former nuclear fuel processing facilities located in the Borough of Apollo and Parks Township, Pennsylvania. To the extent insurance providers and third party indemnitors do not cover those liabilities, and BWC was unable to pay, we could be required to pay for them.

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The spin-off could result in substantial tax liability.

The spin-off was conditioned on BWC's receipt of an opinion of counsel, in form and substance satisfactory to BWC, substantially to the effect that, for United States federal income tax purposes, the spin-off qualifies under Section 355 of the Code, and certain transactions related to the spin-off qualify under Sections 355 and/or 368 of the Code. The opinion relied on, among other things, various assumptions and representations as to factual matters made by BWC and us which, if inaccurate or incomplete in any material respect, would jeopardize the conclusions reached by such counsel in its opinion. The opinion is not binding on the United States Internal Revenue Service ("IRS") or the courts, and there can be no assurance that the IRS or the courts will not challenge the conclusions stated in the opinion or that any such challenge would not prevail.

We are not aware of any facts or circumstances that would cause the assumptions or representations that were relied on in the opinion to be inaccurate or incomplete in any material respect. If, notwithstanding receipt of the opinion, the spin-off were determined not to qualify under Section 355 of the Code, each United States holder of BWC common stock who received shares of our common stock in the spin-off would generally be treated as receiving a taxable distribution of property in an amount equal to the fair market value of the shares of our common stock received. In addition, if certain related preparatory transactions were to fail to qualify for tax-free treatment, they would be treated as taxable asset sales and/or distributions.

Under the terms of the tax sharing agreement we entered into in connection with the spin-off, we and BWC generally share responsibility for any taxes imposed on us or BWC 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 us or BWC, we or BWC, respectively, 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 liabilities associated with obligations under the tax sharing agreement cannot be precisely quantified at this time.

Under the terms of the tax sharing agreement we entered into in connection with the spin-off, we are generally responsible for all taxes attributable to us or any of our subsidiaries, whether accruing before, on or after the date of the spin-off. We and BWC generally share responsibility for all taxes imposed on us or BWC and its subsidiaries in the event 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 us or BWC, we or BWC, respectively would be responsible for all such taxes. Our liabilities under the tax sharing agreement could have a material adverse effect on us. At this time, we cannot precisely quantify the amount of liabilities we may have under the tax sharing agreement and there can be no assurances as to their final amounts.

Under some circumstances, we could be liable for any resulting adverse tax consequences from engaging in significant strategic or capital raising transactions.

Even if the spin-off otherwise qualifies as a tax-free distribution under Section 355 of the Code, the spin-off and certain related transactions may result in significant United States federal income tax liabilities to us under Section 355(e) and other applicable provisions of the Code if 50% or more of BWC's stock or our stock (in each case, by vote or value) is treated as having been acquired, directly or indirectly, by one or more persons as part of a plan (or series of related transactions) that includes the spin-off. Any acquisitions of BWC stock or our stock (or similar acquisitions), or any understanding, arrangement or substantial negotiations regarding such an acquisition of BWC stock or our stock (or similar acquisitions), within two years before or after the spin-off are subject to special scrutiny. The process for determining whether an acquisition triggering those provisions has occurred is complex, inherently factual and subject to interpretation of the facts and circumstances of a particular case.

Under the terms of the tax sharing agreement we entered into in connection with the spin-off, BWC generally is liable for any such tax liabilities. However, we are required to indemnify BWC against any such tax liabilities that result from actions taken or failures to act by us. As a result of these rules and contractual provisions, we may be unable, within the two year period following the spin, to engage in strategic or capital raising transactions that our stockholders might consider favorable, or to structure potential transactions in the manner most favorable to us, without certain adverse tax consequences.

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Potential indemnification liabilities to BWC pursuant to the master separation agreement could materially adversely affect B&W.

The master separation agreement with BWC 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 B&W and BWC with respect to and resulting from the spin-off. Among other things, the master separation agreement provides for indemnification obligations designed to make B&W 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 BWC assumed by us pursuant to the master separation agreement. If we are required to indemnify BWC under the circumstances set forth in the master separation agreement, we may be subject to substantial liabilities.

In connection with our separation from BWC, BWC has agreed to 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 BWC's ability to satisfy its indemnification obligation will not be impaired in the future.

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

Several members of our board and management may have conflicts of interest because of their ownership of shares of common stock of BWC (now known as BWX Technologies, Inc.).

Several members of our board and management own shares of common stock of BWC and/or options to purchase common stock of BWC because of their current or prior relationships with BWC. In addition, six of the current members of our board of directors were members of the BWC board of directors. This share ownership by these six directors could create, or appear to create, potential conflicts of interest when our directors and executive officers are faced with decisions that could have different implications for B&W and BWC.

Risks Relating to Ownership of Our Common Stock

The market price and trading volume of our common stock may be volatile.

The market price of our common stock could fluctuate significantly in future periods due to a number of factors, many of which are beyond our control, including:

• fluctuations in our quarterly or annual earnings or those of other companies in our industry;

• failures of our operating results to meet the estimates of securities analysts or the expectations of our stockholders or changes by securities analysts in their estimates of our future earnings;

• announcements by us or our customers, suppliers or competitors;

• the depth and liquidity of the market for B&W common stock;

• changes in laws or regulations that adversely affect our industry or us;

• changes in accounting standards, policies, guidance, interpretations or principles;

• general economic, industry and stock market conditions;

• future sales of our common stock by our stockholders;

• the concentration of ownership of our common stock;

• future issuances of our common stock by us;

• our ability to pay dividends in the future; and

• the other factors described in these "Risk Factors" and other parts of this annual report.

Substantial sales of our common stock could cause our stock price to decline and issuances by us may dilute our common stockholders' ownership in B&W.

As of December 31, 2017, we have an aggregate of approximately 44.1 million shares of common stock outstanding. Any sales of substantial amounts of our common stock could lower the market price of our common stock and impede our ability to raise capital through the issuance of equity securities. Further, if we were to issue additional equity securities to raise

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additional capital, our stockholders' ownership interests in B&W will be diluted and the value of our common stock may be reduced.

We do not currently pay regular dividends on our common stock, so holders of our common stock may not receive funds without selling their shares of our common stock.

We have no current intent to pay a regular dividend, and dividend payments are restricted by our lending agreements. Our board of directors will determine the payment of future dividends on our common stock, if any, and the amount of any dividends in light of applicable law, contractual restrictions limiting our ability to pay dividends, our earnings and cash flows, our capital requirements, our financial condition, and other factors our board of directors deems relevant. Accordingly, our stockholders may have to sell some or all of their shares of our common stock in order to generate cash flow from their investment.

Provisions in our corporate documents and Delaware law could delay or prevent a change in control of B&W, 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 B&W that a stockholder may consider favorable.

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 B&W 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 B&W 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.

Item 1B. Unresolved Staff Comments

None

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Item 2. Properties

The following table provides the segment, location and general use of each of our principal properties that we own or lease at December 31, 2017.

Business Segment and Location	Principal Use	Owned/Leased (Lease Expiration)
Power segment
Barberton, Ohio	Administrative office / research and development	Owned(1)
Lancaster, Ohio	Manufacturing facility	Owned(1)
Copley, Ohio	Warehouse / service center	Owned(1)
Dumbarton, Scotland	Manufacturing facility	Owned
Guadalupe, NL, Mexico	Manufacturing facility	Leased (2024)
Cambridge, Ontario, Canada	Administrative office / warehouse	Leased (2018)
Jingshan, Hubei, China	Manufacturing facility	Owned
Renewable segment
Copenhagen, Denmark	Administrative office	Leased (2022)
Esbjerg, Denmark	Manufacturing facility / administrative office	Owned
Straubing, Germany	Manufacturing facility	Leased (2021)
Industrial segment
De Pere, Wisconsin	Manufacturing facility / administrative office	Owned(1)
Stoughton, Wisconsin	Administrative office	Owned(1)
Arona, Italy	Administrative offices / research and development	Leased (2022)
San Diego, California	Administrative office	Leased (2024)
Shanghai, China	Manufacturing facility	Owned
Ding Xiang, Xin Zhou, Shan Xi, China	Manufacturing facility	Leased (2019/2020)
Beloit, Wisconsin	Manufacturing facility	Leased (2026)
Muscoda, Wisconsin	Manufacturing facility	Owned(1)
San Luis Potosi, Mexico	Manufacturing facility	Owned
Corporate office
Charlotte, North Carolina	Administrative office	Leased (2019)

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

We believe that our major properties are adequate for our present needs and, as supplemented by planned improvements and construction, expect them to remain adequate for the foreseeable future.

Item 3. Legal Proceedings

For information regarding ongoing investigations and litigation, see Note 21 to the consolidated financial statements included in Item 8 of this annual report, which we incorporate by reference into this Item.

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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 BW. High and low common stock prices in the quarterly periods after our spin-off transaction through December 31, 2017 were as follows:

	Share Price				Dividends
Quarter ended	High		Low		Per Share
June 30, 2015	$	22.31	$	17.12	$	—
September 30, 2015	$	21.95	$	16.40	$	—
December 31, 2015	$	21.67	$	15.86	$	—
March 31, 2016	$	22.17	$	17.95	$	—
June 30, 2016	$	23.99	$	14.32	$	—
September 30, 2016	$	17.30	$	14.27	$	—
December 31, 2016	$	17.72	$	12.90	$	—
March 31, 2017	$	17.50	$	8.54	$	—
June 30, 2017	$	11.88	$	8.58	$	—
September 30, 2017	$	12.06	$	1.61	$	—
December 31, 2017	$	6.14	$	3.28	$	—

As of January 31, 2018, there were approximately 1,800 record holders of our common stock.

In August 2015, we announced that our Board of Directors authorized a share repurchase program. The following table provides information on our purchases of equity securities during the quarter ended December 31, 2017. 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.

Period	Total number of shares purchased (1)	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 thousands) (2)
October 1, 2017 - October 31, 2017	—	$—	—	$100,000
November 1, 2017 - November 30, 2017	2,345	$—	—	$100,000
December 1, 2017 - December 31, 2017	6,544	$—	—	$100,000
Total	8,889		—

(1)	The shares repurchased during November and December 2017 shown in the table above are those repurchased pursuant to the provisions of employee benefit plans that require us to repurchase shares to satisfy employee statutory income tax withholding obligations.
(2)	On August 4, 2016, we announced that our board of directors authorized the repurchase of an indeterminate number of our shares of common stock in the open market at an aggregate market value of up to $100 million over the next twenty-four months. As of March 1, 2018, we have not made any share repurchases under the August 4, 2016 share repurchase authorization.

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The following graph provides a comparison of our cumulative total shareholder return through December 31, 2017 to the return of the S&P 500, the Russell 2000 and our custom peer group.

(1) Assumes initial investment of $100 on June 30, 2015.

The peer group used for the comparison above is comprised of the following companies:

Actuant Corp.	Crane Co.	MasTec Inc.
AMETEK Inc.	Curtiss-Wright Corp.	Primoris Services Corp.
CECO Environmental Corp.	Dycom Industries Inc.	SPX Corp.
Chart Industries Inc.	Flowserve Corp.	Tetra Tech, Inc.
CIRCOR Int. Inc.	Harsco Corp.
Covanta Holding Corp.	Idex Corp.

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Item 6. Selected Financial Data

	For the Years Ended
(in thousands, except for per share amounts)	2017			2016			2015		2014			2013
Revenues	$	1,557,735		$	1,578,263		$	1,757,295	$	1,486,029		$	1,767,651
Income (loss) from continuing operations	(379,015		)	(115,082		)	16,534		(11,890		)	140,478
Net income attributable to Babcock & Wilcox Enterprises, Inc.	(379,824		)	(115,649		)	19,141		(26,528		)	174,527
Basic earnings per common share:
Income (loss) from continuing operations per common share	(8.09		)	(2.31		)	0.30		(0.23		)	2.49
Net income attributable to Babcock & Wilcox Enterprises, Inc.	(8.09		)	(2.31		)	0.36		(0.49		)	3.10
Total assets (as of year end)	$	1,322,229		$	1,529,143		$	1,663,045	$	1,516,554		$	1,290,228

Our Renewable segment's results in each of the past two years were significantly impacted by the performance of an operating unit within the segment which recognized $158.5 million and $141.1 million in charges in the years ended December 31, 2017 and 2016, respectively, related to net changes in the estimated revenues and costs to complete certain renewable energy contracts in Europe.

Our Power segment experienced a decline in sales volume in each of the past two years resulting from the decline in activity related to the coal-fired power and industrial steam generation markets in the United States. Because of our proactive restructuring activities and good contract execution in each of the prior two years, gross margin percentages in the Power segment have remained consistent over the past three years. Also, in each of the annual periods from 2013 through 2015, we recognized contract losses for additional estimated costs to complete our Power segment's Berlin Station project. This project experienced unforeseen worksite conditions and fuel specification issues that caused schedule delays, resulting in us filing suit against the customer in January 2014. The dispute was settled during the third quarter of 2015. The contract losses reduced pre-tax income (or increased pre-tax losses) from continuing operations by $9.6 million, $11.6 million and $35.6 million in 2015, 2014 and 2013, respectively.

Our Industrial segment benefited from the acquisition of Universal during 2017, which contributed $69.1 million of revenue and $14.5 million of gross profit to the Industrial segment. The Industrial segment also benefited from the July 1, 2016 acquisition of SPIG S.p.A., which contributed $181.5 million and $96.3 million of revenue and a gross profit (loss) of $(7.7) million and $7.8 million in the years ended December 31, 2017 and 2016, respectively. Our MEGTEC business, which was purchased on June 20, 2014, generated revenues of $147.2 million, $157.3 million, $183.7 million and $105.4 million and gross profit of $34.9 million, $42.9 million, $54.8 million and $30.4 million in the years ended December 31, 2017, 2016, 2015 and 2014, respectively.

Our 2017 results were also significantly impacted by the revaluation of our deferred taxes as a result of the December 2017 United States tax reform. This resulted in an increase in income tax expense of $64.8 million related primarily to the revaluation of our deferred income tax balances.

Other matters that significantly impacted our results over the past five years include the following:

• In 2017, we recorded goodwill impairment charges of $86.9 million ($85.8 million net of tax), which included a $50.0 million charge in the Renewable reporting unit and a $36.9 million charge in the SPIG reporting unit. The reasons for the charges and related assumptions made by management are described in Note 15 to the consolidated financial statements included in Item 8 of this annual report.

• Restructuring and spin costs were $15.4 million, $40.8 million, $14.9 million and $20.2 million in 2017, 2016, 2015, and 2014, respectively.

• In 2017, as a result of a strategic change in our Indian joint venture due to the decline in forecasted market opportunities in India, we recorded an $18.2 million other-than-temporary-impairment of our investment in TBWES.

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• In 2016, we sold all of our interest in our Australian joint venture, Halley & Mellowes Pty. Ltd., for $18.0 million, resulting in a gain of $8.3 million.

• In 2015, we recognized a $14.6 million impairment charge, primarily related to research and development facilities and equipment dedicated to activities that were determined not to be commercially viable.

• We recognize actuarial gains (losses) related to our pension and postretirement benefit plans in earnings as a component of net periodic benefit cost. The effect of these adjustments for 2017, 2016, 2015, 2014 and 2013 and on pre-tax income was a gain (loss) of $8.7 million, $(24.1) million, $(40.2) million, $(101.3) million and $92.1 million, respectively.

Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations

OVERVIEW OF RESULTS

In this annual report, unless the context otherwise indicates, "B&W," "we," "us," "our" and "the Company" mean Babcock & Wilcox Enterprises, Inc. and its consolidated subsidiaries. The presentation of the components of our revenues, gross profit and operating income on the following pages of this Management's Discussion and Analysis of Financial Condition and Results of Operations is consistent with the way our chief operating decision maker reviews the results of operations and makes strategic decisions about the business.

We obtained an Agreement to amend our United States Revolving Credit Facility (described further in Note 19 to the consolidated financial statements included in Item 8) on March 1, 2018 (the “March 1, 2018 Amendment”). The March 1, 2018 Amendment temporarily waived the financial covenant defaults associated with our United States Revolving Credit Facility ("Revolver") that existed at December 31, 2017, consented to the Company's planned Rights Offering and allows up to $35 million of borrowings to be used in conjunction with the proceeds of the Rights Offering to be used to repay the principal portion of the Second Lien Term Loan Facility ("Second Lien"). The events of default at December 31, 2017 were due primarily to additional losses we recognized in the fourth quarter of 2017 related to an increase in structural steel repair costs on one of our European renewable energy contracts.

On March 1, 2018, we entered into an equity commitment agreement (“Equity Commitment Agreement”) with a group of our existing stockholders to fully backstop our planned Rights Offering (“Rights Offering”) for the purpose of providing at least $182 million of new capital. We are proposing to undertake a rights offering pursuant to which all of our stockholders will have the ability, on a pro rata basis, to purchase up to at least $182 million of the Company’s common stock. The Equity Commitment Agreement provides for a backstop commitment from a group of our existing stockholders to purchase any unsold portion of the Rights Offering.

We plan to use the net proceeds from the sale of the Company’s common stock in the Rights Offering and the permitted borrowing capacity provided by our Revolver to extinguish the outstanding balance of our Second Lien and terminate the associated borrowing agreement. Our plan is designed to provide us with adequate liquidity to meet our obligations for at least the twelve month period following March 1, 2018; however, our remediation plan includes raising additional capital through the Rights Offering and other sources before the end of the standstill period, which will depend on conditions in the capital markets and, with respect to the Rights Offering, an amendment to our existing shelf registration statement that we plan to file in early March 2018 being declared effective by the Securities and Exchange Commission (“SEC”), which are matters that are outside of our control. Accordingly, we cannot be certain of our ability to raise additional capital on terms acceptable to us which raises substantial doubt about our ability to continue as a going concern. Additionally, our ability to meet the amended covenants associated with our Revolver is dependent on our future financial operating results. While we believe that the actions summarized above and in Note 1 to our consolidated financial statements included in Item 8 are more likely than not to address the substantial doubt about the Company’s ability to continue as a going concern, we cannot assert that it is probable that our plans will fully mitigate the conditions identified. If we cannot continue as a going concern, material adjustments to the carrying values and classifications of our assets and liabilities and the reported amounts of income and expense could be required.

We generally recognize revenues and related costs from long-term contracts on a percentage-of-completion basis. Accordingly, we review contract price and cost estimates regularly as work progresses and reflect adjustments in profit proportionate to the percentage of completion in the periods in which we revise estimates to complete the contract. To the

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extent that these adjustments result in a reduction of previously reported profits from a contract, we recognize a charge against current earnings. Changes in the estimated results of our percentage of completion contracts are necessarily based on information available at the time that the estimates are made and are based on judgments that are inherently uncertain as they are predictive in nature. As with all estimates to complete used to measure contract revenue and costs, actual results can and do differ from our estimates made over time.

Our Renewable segment continues to make progress towards completing its portfolio of European renewable energy projects. The segment has significant loss contracts that recognize additional profit or loss only to the extent there are changes in our estimates at completion. Our losses were primarily attributable to $158.5 million and $141.1 million in net losses in 2017 and 2016, respectively, from changes in the estimated cost to complete certain renewable energy contracts in Europe, partially offset by gross profit from our operations and maintenance services and aftermarket parts and services in each year. In 2017, we made substantial management and process changes in our Renewable segment in response to the loss contracts, including changes in top management and strengthening of project management controls and procedures. Although we believe the provisions we made for our six loss contracts at December 31, 2017 are adequate, given that among other things these loss positions are based on estimates of future activities, revenues and costs, there can be no assurance that unanticipated schedule delays in the future will not result in additional contract losses or liquidated damages. Going forward, our Renewable segment will focus primarily on its core technologies, with the balance of plant and civil construction scope being executed by a partner. We believe the new execution model lowers our execution risk and positions us for better profitability in the Renewable segment, and is more consistent with our company-wide strategy of being an industrial and power equipment technology and solutions provider.

Our Power segment continued to deliver gross margin percentages consistent with our expectations in 2017. As previously disclosed, we anticipated a decline in the coal power generation markets and proactively responded by restructuring the segment to help us maintain gross margins. Our restructuring activities in each of the past two years has been effective, and the Power segment's gross margin percentage has not significantly changed despite the 16.4% decline in revenues in 2017 compared 2016. The Power segment also continues to benefit from consistent, effective contract execution.

Industrial segment revenues grew in 2017 compared to 2016 primarily due to the $69.1 million contribution from Universal Acoustic & Emissions Technology, Inc. ("Universal"), which we acquired on January 11, 2017, and the $181.5 million increase from the full year contribution of SPIG S.p.A. ("SPIG"), which we acquired on July 1, 2016. The acquisitions benefited the Industrial segment's gross profit in 2017 by $6.8 million, which was lower than our expectations due to a change in the product mix and challenges related to completing several of the segment's cooling systems contracts. We expect the Industrial segment to benefit from improvements in international growth, increased capital spending in the United States, and the change in strategy in the SPIG business announced in the third quarter of 2017.

In the second half of 2017, we announced plans to implement restructuring actions to improve our global cost structure and increase our financial flexibility. The restructuring actions included a workforce reduction at both the business segment and corporate levels totaling approximately 9% of our global workforce, selling, general and administrative ("SG&A") expense reductions and new cost control measures, and office closures and consolidations in non-core geographies. These actions include reduction of approximately 30% of B&W Vølund's workforce, in order to right-size its workforce to operate under a new execution model focused on B&W's core boiler, grate and environmental equipment technologies, with the balance-of-plant and civil construction scope being executed by a partner. We believe the new B&W Vølund business model provides us with a lower risk profile and aligns with our strategy of being an industrial and power equipment technology and solutions provider. Other actions are focused on productivity and efficiency gains to enhance profitability and cash flows, and to mitigate the impact of lower demand in the global coal-fired power market. Total estimated costs associated with these restructuring actions are anticipated to be less than $20 million, $9.1 million of which was recognized in the fourth quarter of 2017. The estimated annual savings are expected to be at least $45 million in 2018.

The net decrease in cash in 2017 was $39.2 million. Net borrowings on our Revolver were $84.5 million, which included the repayment of $115.5 million of the revolving credit facility balance with a portion of the net proceeds from the issuance of $195.9 million of Second Lien. Our use of cash in 2017 was primarily to fund progress on our Renewable segment contracts, acquire Universal and repurchase shares of our common stock from a related party. We expect our operations to use cash through the first half of 2018, particularly in the Renewable segment, as we fund accrued contract losses and work down advanced bill positions. Our forecasted use of cash is expected to be funded in part through borrowings from our Revolver. Additional discussion is included in Liquidity and capital resources.

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Year-over-year comparisons of our results were also affected by:

• Goodwill impairment charges totaling $86.9 million were recorded in 2017, of which $50.0 million related to our Renewable reporting unit and $36.9 million related to our SPIG reporting unit in the Industrial segment.

• Intangible asset amortization expense was $18.3 million and $19.9 million in 2017 and 2016, respectively. We expect approximately $12.4 million of expense in the full year 2018.

• Restructuring expense totaled $14.2 million, $37.0 million, and $11.7 million in 2017, 2016 and 2015, respectively. Restructuring expense includes accelerated depreciation and other activities related to manufacturing facility consolidation and outsourcing as well as reduction in force, consulting and other costs. In addition to savings already realized, we expect to realize savings of approximately $45.0 million in 2018.

• Asset impairments in 2016 totaled $14.9 million and were associated with the long-lived assets at an owned coal-fired power plant. The non-cash impairment charge was classified in restructuring costs in 2016, and we sold the coal-fired power plant in 2017. B&W no longer owns any coal-fired power plants at December 31, 2017.

• Asset impairments in 2015 totaled $14.6 million and were primarily related to research and development facilities and equipment used for activities that were determined not to be commercially viable. The non-cash impairment charge was reflected in loss on disposal of assets in 2015.

• The outcome of the Arkansas River Power Authority ("ARPA") litigation on November 21, 2016 resulted in a net $3.2 million charge in our Power segment in the fourth quarter of 2016, which included a $4.2 million revenue reversal, a $2.3 million decrease in cost of operations and a $1.3 million increase in SG&A expenses. On July 21, 2017, the court awarded $3.7 million of pre-judgment interest, which we recorded as an increase in other accrued liabilities and interest expense in the second quarter of 2017. In December 2017, we reached an agreement in arbitration to settle all matters related to the ARPA litigation for $7.0 million. The arbitration agreement resulted in a $1.6 million reduction in our accrual, a $0.8 million increase in revenue and $0.8 million decrease in interest expense in the fourth quarter of 2017.

• Litigation settlement charges of $9.6 million were incurred in 2015, including $1.8 million of legal costs and a $7.8 million reversal of Power segment revenues associated with the release of an accrued claims receivable balance as part of the legal settlement related to the Berlin Station project.

• Expenses related to the spin-off from our former Parent were $1.2 million, $3.8 million and $3.3 million in 2017, 2016 and 2015, respectively. The costs were primarily attributable to employee retention awards.

• Acquisition and integration costs included in SG&A totaled $2.7 million and $5.1 million in 2017 and 2016, respectively, related to the SPIG and Universal acquisitions .

• Actuarially determined mark to market gains (losses) were $8.7 million, $(24.1) million and $(40.2) million in 2017, 2016 and 2015, respectively.

• An other-than-temporary-impairment of our investment in TBWES of $18.2 million in 2017 was included in Equity in income of investees, reducing our remaining investment in TBWES to $26.0 million at December 31, 2017.

• In 2016, we sold all of our joint venture interest in HMA for $18.0 million, resulting in a gain of $8.3 million that was included in Equity in income of investees.

• Enactment of new United States tax legislation in the fourth quarter of 2017 resulted in $62.4 million of income tax expense from the revaluation of deferred tax assets to the newly enacted United States federal income tax rates.

Our segment and other operating results are described in more detail below.

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RESULTS OF OPERATIONS – YEARS ENDED DECEMBER 31, 2017, 2016 and 2015

Consolidated results of operations

	Years ended December 31,
(In thousands)	2017			2016			2015
Revenues:
Power segment	$	821,062		$	981,978		$	1,234,997
Renewable segment	347,198			349,172			338,603
Industrial segment	397,791			253,613			183,695
Eliminations	(8,316		)	(6,500		)	—
	1,557,735			1,578,263			1,757,295
Gross profit (loss):
Power segment	191,999			233,550			247,632
Renewable segment	(128,204		)	(68,109		)	57,682
Industrial segment	41,383			50,726			54,826
Intangible amortization expense included in cost of operations	(14,272		)	(15,842		)	(7,676		)
Mark to market gain (loss) included in cost of operations	8,972			(21,208		)	(44,307		)
	99,878			179,117			308,157
SG&A expenses	(255,545		)	(240,166		)	(240,296		)
Goodwill impairment charges	(86,903		)	—			—
Restructuring activities and spin-off transaction costs	(15,447		)	(40,807		)	(14,946		)
Research and development costs	(9,412		)	(10,406		)	(16,543		)
Intangible amortization expense included in SG&A	(3,980		)	(4,081		)	(3,769		)
Mark to market gain (loss) included in SG&A	(274		)	(2,902		)	4,097
Equity in income of investees	8,326			16,440			(242		)
Impairment of equity method investment	(18,193		)	—			—
Gains (losses) on asset disposals, net	(15		)	32			(14,597		)
Operating income (loss)	$	(281,565	)	$	(102,773	)	$	21,861

The presentation of the components of our revenues and gross profit in the table above is consistent with the way our chief operating decision maker reviews the results of our operations and makes strategic decisions about our business.

2017 vs 2016 Consolidated results

Revenues decreased by $20.5 million to $1.56 billion in 2017 as compared to $1.58 billion in 2016, primarily due to the decline in the coal power generation market, which resulted in a $160.9 million decline in revenues in our Power segment. Partially offsetting the decline in Power segment revenues were increases in revenues of $144.2 million in the Industrial segment resulting from the acquisitions of Universal on January 11, 2017 and SPIG on July 1, 2016.

In 2017, we had consolidated gross profit of $99.9 million, which compares to consolidated gross profit of $179.1 million in 2016, a decrease of $79.2 million. The primary drivers of the decrease were the six uncompleted European loss contracts in the Renewable segment (see Note 6 in the consolidated financial statements included in Item 8), the volume impact of the decline in the Power segment's revenues and productivity issues on new build cooling system contracts in the Industrial segment, which were partially offset by the positive gross profit contribution from the Universal acquisition.

Our consolidated operating losses were $281.6 million and $102.8 million in 2017 and 2016, respectively. In addition to the decrease in gross profit discussed above, the primary drivers of the increase in our consolidated operating loss were $86.9 million of goodwill impairment charges in the third quarter of 2017, an $18.2 million other-than-temporary-impairment of our investment in TBWES (a joint venture in India), $15.4 million more SG&A expenses primarily related to acquired

34

businesses, and $8.1 million less income from equity method investees. Partially offsetting these declines were a $25.4 million reduction in restructuring expenses and related savings from these actions.

SG&A expenses, goodwill impairment charges, restructuring expenses, intangible asset amortization expense and income from equity method investees are discussed in further detail in the sections below.

2016 vs 2015 Consolidated results

Revenues decreased $179.0 million to $1.58 billion in 2016 compared to $1.76 billion in 2015 due to a $253.0 million decrease in Power segment revenues, partially offset by increases in revenues of $10.6 million and $69.9 million in our Renewable and Industrial segments, respectively. The SPIG acquisition, which was completed on July 1, 2016, contributed revenues of $96.3 million in 2016.

Consolidated gross profit decreased $129.0 million to $179.1 million in 2016 from $308.2 million in 2015. Excluding the mark to market charges, consolidated gross profit in 2016 decreased primarily due to the $125.8 million decline in our Renewable segment's gross profit, which was attributable to losses on four renewable energy projects during 2016.

Our consolidated operating income decreased $124.6 million to a consolidated operating loss of $102.8 million in 2016 compared to consolidated operating income of $21.9 million in 2015. In addition to the gross profit decrease discussed above, the primary drivers of the decrease in our consolidated operating income in 2016 were a $25.9 million increase in restructuring charges primarily related to our Power segment restructuring in June 2016, partially offset by a $14.6 million decrease in loss on asset disposals and impairments compared to 2015, $16.1 million lower mark to market charges compared to 2015 and a $8.3 million gain from the sale of all of our interest in our Australian joint venture in 2016.

SG&A expenses, restructuring expenses, intangible asset amortization expense and income from equity method investees are discussed in further detail in the sections below.

Segment descriptions

Our operations are assessed based on three reportable segments.

• Power: Focused on technologies and aftermarket services for steam-generating, environmental, and auxiliary equipment for power generation and other industrial applications.

• Renewable: Focused on the supply of steam-generating systems, environmental and auxiliary equipment for the waste-to-energy and biomass power generation industries.

• Industrial: Focused on custom-engineered cooling, environmental, acoustic, emission and filtration solutions, other industrial equipment and related aftermarket services.

Power segment

Our Power segment focuses on technologies and aftermarket services for steam-generating, environmental, and auxiliary equipment for power generation and other industrial applications. The segment provides a comprehensive mix of aftermarket products and services to support peak efficiency and availability of steam generating and associated environmental and auxiliary equipment, serving large steam generating utility and industrial customers globally. Our products and services include replacement parts, field technical services, retrofit and upgrades, fuel switching and repowering contracts, construction and maintenance services, start-up and commissioning, training programs and plant operations and maintenance for our full complement of boiler, environmental and auxiliary equipment. Our auxiliary equipment includes boiler cleaning equipment and material handling equipment.

Our worldwide new build boiler and environmental products businesses serve large steam generating and industrial customers. The segment provides a full suite of product and service offerings including engineering, procurement, specialty manufacturing, construction and commissioning. The segment's product suite includes utility boilers and industrial boilers fired with coal and natural gas. Our boiler products include advanced supercritical boilers, subcritical boilers, fluidized bed boilers, chemical recovery boilers, industrial power boilers, package boilers, heat recovery steam generators and waste heat boilers.

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Our environmental systems offerings include air pollution control products and related equipment for the treatment of nitrogen oxides, sulfur dioxide, fine particulate, mercury, acid gases and other hazardous air emissions. These include wet and dry flue gas desulfurization systems, catalytic and non-catalytic nitrogen oxides reduction systems, low nitrogen oxides burners and overfire air systems, fabric filter baghouses, wet and dry electrostatic precipitators, mercury control systems and dry sorbent injection for acid gas mitigation.

The segment also receives license fees and royalty payments through licensing agreements for our proprietary technologies.

While opportunities to increase revenues in the segment are limited, we are striving to grow margins by:

• maintaining our strong service presence in support of our installed fleet of steam generation equipment and expanding support of other OEM equipment;

• selectively bidding contracts in emerging international markets needing state-of-the-art technology for fossil power generation and environmental systems;

• growing sales of industrial steam generation products in the petrochemical and pulp & paper markets, such as heat recovery, natural gas and oil fired package boilers, due in part to lower fuel prices; and

• reducing costs through a focus on operational efficiencies.

Power segment results

	Year Ended December 31,									Year Ended December 31,
(In thousands)	2017			2016			$ Change			2016			2015			$ Change
Revenues	$	821,062		$	981,978		$	(160,916	)	$	981,978		$	1,234,997		$	(253,019	)
Gross profit	$	191,999		$	233,550		$	(41,551	)	$	233,550		$	247,632		$	(14,082	)
Gross margin %	23		%	24		%				24		%	20		%

2017 vs 2016 results

Revenues decreased 16%, or $160.9 million, to $821.1 million in 2017 from $982.0 million in 2016. The revenue decrease is attributable to the anticipated decline in the coal power generation market, which impacted our new build utility, retrofits and aftermarket parts and services businesses. The decline in coal power generation market activity is due primarily to a decrease in construction activity in the United States. We resized our business in anticipation of these declines with our restructuring actions in both 2017 and 2016. Partially offsetting the revenue decrease was an increase in revenues associated with our industrial steam generation repair and maintenance sales. We expect a low single-digit percentage decline in revenue in 2018.

Gross profit decreased 18%, or $41.6 million, to $192.0 million in 2017 from $233.6 million in 2016. We were able to largely maintain our gross margin percentage as a result of the 2017 and 2016 restructuring actions, which partially offset the gross profit effect of lower sales volumes. Compared to 2016, the primary decrease in gross profit in 2017 was attributable to the decrease in gross profit from a lower volume of construction activity associated with our new build utility and retrofits businesses. Also contributing to the decrease were fewer net improvements on contracts that were completed this year versus last year.

2016 vs 2015 results

Revenues decreased 20%, or $253.0 million, to $982.0 million in 2016 from $1.23 billion in 2015. The decrease in the segment's revenues reflect the accelerated decline in activities in the United States coal-fired generation market and a decline in sales of our industrial steam generation products to non-utility customers in North America. These declines resulted in lower revenues in all of our Power segment product lines.

Gross profit decreased $14.1 million to $233.6 million in 2016 from $247.6 million in 2015. While the 2016 decrease in gross profit was in-line with the 20% decrease in revenues, our Power segment's gross margin percentage improved in 2016 across all of our product lines as a result of the restructuring efforts in 2016. Also contributing to the increase in our gross margin percentage is a $41.5 million increase in the gross profit contribution from construction contracts in 2016 as a result of improved contract performance. In 2015, gross profit was negatively impacted by a loss of $11.6 million on the Berlin Station project.

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Effect of new accounting standard on Power segment results

In the first quarter of 2018, we will retrospectively adopt Financial Accounting Standards Board ("FASB") issued Accounting Standards Update 2017-07, Compensation - Retirement Benefits (Topic 715): Improving the Presentation of Net Periodic Benefit Cost and Net Periodic Postretirement Benefit Cost. The new guidance requires that we classify in our consolidated statement of operations the service cost component of net periodic retirement benefit costs in cost of operations, and all other costs associated with our retirement plans as a component of other income. This will affect not only how we present net periodic benefit cost, but also how we present segment gross profit and operating income upon adoption. Because almost all of our retirement benefit plans are in the Power segment, the reclassification of all of the net periodic retirement benefit components other than service cost from cost of operations to other income in the statement of operations will result in reclassification of $21.0 million, $20.0 million and $17.9 million of net periodic retirement benefit gains from the Power segment's gross profit for 2017, 2016 and 2015, respectively, which will result in restated gross margins of 21%, 22% and 19%, respectively. See Note 29 to the consolidated financial statements included in Item 8 for more information about the new accounting standard.

Renewable segment

Our Renewable segment provides steam-generating systems, environmental and auxiliary equipment for the waste-to-energy and biomass power generation industries, and plant operations and maintenance services for our full complement of systems and equipment. We deliver these products and services to a large base of customers primarily in Europe through our extensive network of technical support personnel and global sourcing capabilities. Our customers consist of traditional, renewable and carbon neutral power utility companies that require steam generation and environmental control technologies to enable beneficial use of municipal waste and biomass. This segment's activity is dependent on the demand for electricity and reduced landfill use, and ultimately the capacity utilization and associated operations and maintenance expenditures of waste-to-energy power generating companies and other industries that use steam to generate energy.

In 2017, we redefined our approach to bidding on and executing renewable energy contracts. Under our new model, we are focusing on engineering and supplying our core waste-to-energy and renewable energy technologies - steam generation, combustion grate, environmental equipment, material handling, and cooling condensers - while partnering with other firms to execute the balance of plant and civil construction scope on contracts we pursue. We also elected to limit bidding any additional Renewable contracts that involved our European resources during 2017 as we worked through our existing contracts.

Globally, efforts to reduce the environmental impact of burning fossil fuels may create opportunities for us as existing generating capacity is replaced with cleaner technologies. We expect backlog growth in the future, primarily from renewable waste-to-energy contracts, as we continue to see numerous opportunities around the globe, although the rate of this growth is dependent on many external factors.

Renewable segment results

	Year Ended December 31,									Year Ended December 31,
(in thousands, except percentages)	2017			2016			$ Change			2016			2015			$ Change
Revenues	$	347,198		$	349,172		$	(1,974	)	$	349,172		$	338,603		$	10,569
Gross profit (loss)	$	(128,204	)	$	(68,109	)	$	(60,095	)	$	(68,109	)	$	57,682		$	(125,791	)
% of revenues	(37		)%	(20		)%				(20		)%	17		%

2017 vs 2016 results

Revenues decreased 1%, or $2.0 million to $347.2 million in 2017 from $349.2 million in 2016. Our revenue is comparable in both years primarily due to the activities in our portfolio of renewable energy projects in Europe during both periods.

The segment had losses of $128.2 million and $68.1 million in 2017 and 2016, respectively. Our losses were attributable to $158.5 million and $141.1 million in net losses in 2017 and 2016, respectively, from changes in the estimated cost to complete certain renewable energy contracts in Europe, partially offset by gross profit from our operations and maintenance services and aftermarket parts and services in each year. These $158.5 million of losses in 2017 were primarily a result of scheduling delays, shortcomings in our subcontractors' estimated productivity and the cost of repairing a structural steel beam

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on one of our projects, which were partially offset by contractual bonus opportunities and reduced liquidated damages on certain projects. In September 2017, we identified the failure of a structural steel beam on one of our renewable energy contracts in Europe, which stopped work in the boiler building and other areas pending corrective actions to stabilize the structure that are expected to be complete in the first half of 2018. The engineering, design and manufacturing of the steel structure were the responsibility of our subcontractors. A similar design was also used on two of the other renewable energy contracts in Europe, and although no structural failure occurred on these two other projects, work was also stopped in certain restricted areas while we added reinforcement to the structures. The reinforcements at these two other projects are now complete. The total costs related to the structural steel issues on these three projects, including project delays, are estimated to be approximately $42 million, which is included in the December 31, 2017 estimated losses at completion for these three projects.

Also in the second half of 2017, we adjusted the design of three of our renewable energy projects to increase the guaranteed power output, which will allow us to achieve contractual bonus opportunities for the higher output, and also received contractual reductions in liquidated damages. The bonus opportunities and reduced liquidated damages increased the estimated selling price of the three contracts by approximately $19 million in total, which was recognized in the estimated revenues and costs to complete in 2017 because each were loss contracts.

During 2018, we expect construction will be completed and the units will be operational on each of the six renewable energy loss projects in Europe. We expect customers will take-over five of the facilities in 2018, and one in early 2019. See additional details in Note 6 to the consolidated financial statements included in Item 8 of this annual report.

2016 vs 2015 results

Revenues increased 3.1%, or $10.6 million to $349.2 million in 2016 from $338.6 million in 2015. The increase in revenue in 2016 is primarily attributable to an increase in the level of activity on our renewable energy contracts. Our operations and maintenance services also contributed $2.4 million more to the segment's revenues in 2016.

Gross profit (loss) decreased $125.8 million in 2016 from $57.7 million in 2015 to $(68.1) million in 2016. The decrease is attributable to $141.1 million in losses from changes in the estimated forecasted cost to complete certain renewable energy contracts in Europe, partially offset by an increase in gross profit from our operations and maintenance services. During 2016, four of the segment's renewable energy projects became loss contracts. See additional details in Note 6 to the consolidated financial statements included in Item 8 of this annual report.

Industrial segment

Through December 31, 2016, our Industrial segment was comprised of our MEGTEC and SPIG businesses. Beginning with the first quarter of 2017, Universal was added to the Industrial segment. The segment is focused on custom-engineered cooling, environmental, noise abatement and industrial equipment along with related aftermarket services.

We acquired MEGTEC in 2014. Through MEGTEC, we provide environmental products and services to numerous industrial end markets. MEGTEC designs, engineers and manufactures products including oxidizers, solvent recovery and distillation systems, wet electrostatic precipitators, scrubbers and heat recovery systems. MEGTEC also provides specialized industrial process systems, coating lines and equipment. To this product mix, B&W recently added (synergy) technologies including dry electrostatic precipitators, pulse jet fabric filters, selective catalytic reduction systems, and dry and wet scrubbers. These complementary technologies enhance MEGTEC’s ability to offer a full line of environmental products and allow MEGTEC to strategically grow its business by selling solutions (comprehensive equipment trains) to new and existing customers and markets. MEGTEC serves a diverse set of industrial end markets globally with a current emphasis on the chemical, pharmaceutical, energy storage, metals and mining, and engineered wood panel board markets. MEGTEC's activity is dependent primarily on the capacity utilization of operating industrial plants and an increased emphasis on environmental emissions globally across a broad range of industries and markets.

We acquired SPIG on July 1, 2016. It provides custom-engineered cooling systems, services and aftermarket products. SPIG’s product offerings include air-cooled (dry) cooling systems, mechanical draft wet cooling towers and natural draft wet cooling hyperbolic towers. SPIG also provides end-to-end aftermarket services, including spare parts, upgrades and revamping of existing installations and remote monitoring. SPIG's comprehensive dry and wet cooling solutions and aftermarket products and services are primarily provided to the power generation industry, including natural gas-fired and renewable energy power plants, and downstream oil and gas, petrochemical and other industrial end markets in the Europe,

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the Middle East and the Americas. SPIG's activity is dependent primarily on global energy demand from utilities and other industrial plants, regulatory requirements, water scarcity and energy efficiency needs.

We acquired Universal on January 11, 2017. The business complements the product and service offerings we are able to provide through our Industrial segment. Universal provides custom-engineered acoustic, emission and filtration solutions to the natural gas power generation, mid-stream natural gas pipeline, locomotive and general industrial end-markets. Universal's product offering includes gas turbine inlet and exhaust systems, custom silencers, filters and custom enclosures. Historically, almost all of Universal's activity has been in the United States; however, we expect its business to grow globally with the benefit of B&W's global network of current and future customers and the needs of noise abatement controls for natural gas power generation, natural gas pipelines and other industrial markets.

We see opportunities for growth in revenues in the Industrial segment relating to a variety of factors. Our new equipment customers make purchases as part of major capacity expansions, to replace existing equipment, or in response to regulatory initiatives. Additionally, our significant installed base provides a consistent and recurring aftermarket stream of parts, retrofits and services. Major investments in global industrial markets have strengthened demand for our industrial equipment, while tightening global environmental and noise abatement regulations are creating new opportunities. We foresee long-term trends toward increased environmental and noise abatement controls for industrial manufacturers around the world. Together, the companies that comprise the Industrial segment are well-positioned to capitalize on opportunities in these markets. Additionally, we will continue to seek acquisitions to expand our market presence and technology offerings in our Industrial segment.

In November 2017, we also announced that we are evaluating strategic alternatives for our MEGTEC and Universal businesses in order to enhance our financial flexibility. Though our outlook remains favorable for these businesses, we believe it is prudent to explore alternatives for these parts of our company, providing greater optionality if needed.

Industrial segment results

	Year Ended December 31,									Year Ended December 31,
(In thousands)	2017			2016			$ Change			2016			2015			$ Change
Revenues	$	397,791		$	253,613		$	144,178		$	253,613		$	183,695		$	69,918
Gross profit	$	41,383		$	50,726		$	(9,343	)	$	50,726		$	54,826		$	(4,100	)
Gross margin %	10		%	20		%				20		%	30		%

2017 vs 2016 results

Revenues increased 57%, or $144.2 million, to $397.8 million in 2017 from $253.6 million in 2016. The increase in revenues is primarily attributable to the July 1, 2016 acquisition of SPIG and the January 11, 2017 acquisition of Universal, which together comprised $250.6 million of revenue in 2017. In 2016, SPIG contributed $96.3 million of revenue to the Industrial segment. Partially offsetting the increase in revenue is a $9.0 million decline in revenues attributable to sales of engineered products, primarily in the first half of 2017.

Gross profit decreased 18%, or $9.3 million, to $41.4 million in the year ended December 31, 2017, compared to $50.7 million in 2016. In 2017, Universal contributed $14.5 million of gross profit. The net decrease in gross profit and the gross margin percentage reflects decreased revenues from our MEGTEC business and changes in product mix, particularly at our SPIG business as new build cooling systems generally have lower margins than other products and services in the segment. In addition, the gross profit in 2017 was negatively affected by productivity issues on new build cooling system contracts. The productivity issues increased estimated costs and resulted in deployment of additional resources to complete the contracts on time. We expect the Industrial segment's gross profit will normalize over the course of 2018 as these legacy new build cooling system contracts are completed and both our productivity and profitability increase.

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2016 vs 2015 results

Revenues increased 38.1%, or $69.9 million, to $253.6 million in 2016 from $183.7 million in 2015. The increase in revenues is primarily the result of our acquisition of SPIG on July 1, 2016, which contributed $96.3 million of revenue to the Industrial segment during the second half of 2016. Our MEGTEC business experienced a decline in revenues in 2016 across each of its product lines caused by the decline in demand in the United States.

Gross profit decreased 7.5%, or $4.1 million, to $50.7 million in the year ended December 31, 2016, compared to $54.8 million in 2015. The SPIG business contributed gross profit of $7.8 million in 2016, which was partially offset by lower gross profit from MEGTEC in-line with the decrease in revenues during 2016. MEGTEC was able to improve its gross margin percentage in 2016 due to its mix of product revenues despite the overall decline in revenues and gross profit for the business. In addition, SPIG's gross margins have been historically lower than MEGTEC's, resulting in a decline in the 2016 gross margin percentage in the segment.

Goodwill impairment

We recorded goodwill impairment charges of $86.9 million ($85.8 million net of tax) in the third quarter of 2017, which included a $50.0 million charge in the Renewable reporting unit and a $36.9 million charge in the SPIG reporting unit. The reasons for the charges and related assumptions made by management are described in Note 15 to the consolidated financial statements included in Item 8. The third quarter 2017 impairment charges eliminated all of the Renewable reporting unit's goodwill balance at September 30, 2017, and $38.3 million of the SPIG reporting unit's goodwill balance remains after the impairment charge; long-lived assets in the two reporting units were not impaired.

As a result of our annual goodwill impairment tests performed on the first day of the fourth quarter of 2017, 2016 and 2015, we did not record any goodwill impairment charges.

SG&A expenses

SG&A expenses, excluding intangible asset amortization expense and pension mark to market adjustments, increased by $15.4 million to $255.5 million in 2017 from $240.2 million in 2016. The primary reason for the increase is $24.3 million of combined SG&A expenses attributable to the recently acquired SPIG and Universal businesses. In addition, SG&A expenses in our Renewable segment increased by $17.5 million in 2017 to support ongoing renewable energy projects in Europe. These increases are partially offset by the savings from our restructuring initiatives, which provided $30.6 million of benefit to our Power segment in 2017, and reductions in incentive compensation accruals in both 2017 and 2016 based on the company's operating results. SG&A expenses in 2017 and 2016 also include $2.7 million and $5.1 million, respectively, of acquisition and integration related costs related to the acquisitions of Universal and SPIG.

SG&A expenses were $240.2 million in 2016 and $240.3 million in 2015, excluding intangible asset amortization expense and pension mark to market adjustments. SG&A expenses in 2016 were higher primarily due to $5.1 million of acquisition and integration related costs related to the acquisitions of SPIG, $1.3 million of litigation expenses associated with the ARPA trial and the addition of $8.2 million of SG&A expenses associated with SPIG. These 2016 increases were almost entirely offset by savings from our 2016 restructuring actions and reduced incentive compensation accruals.

Research and development expenses

Research and development expenses relate to the development and improvement of new and existing products and equipment, as well as conceptual and engineering evaluation for translation into practical applications. These expenses were $9.4 million, $10.4 million and $16.5 million in 2017, 2016 and 2015, respectively. We continuously evaluate each research and development project and collaborate with our business teams to ensure that we believe we are developing technology and products that are currently desired by the market and will result in future sales. In 2018, we expect our research and development expenses to continue to decline.

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Restructuring

2017 Restructuring activities

In the second half of 2017, we announced plans to implement restructuring actions to improve our global cost structure and increase our financial flexibility. The restructuring actions include a workforce reduction at both the business segment and corporate levels totaling approximately 9% of our global workforce, SG&A expense reductions and new cost control measures, and office closures and consolidations in non-core geographies. These actions include reduction of approximately 30% of B&W Vølund's workforce, which will right-size its workforce to operate under a new execution model focused on B&W's core boiler, grate and environmental equipment technologies, with the balance-of-plant and civil construction scope being executed by a partner. We believe the new B&W Vølund business model provides us with a lower risk profile and aligns with our strategy of being an industrial and power equipment technology and solutions provider. Other actions are focused on productivity and efficiency gains to enhance profitability and cash flows, and to mitigate the impact of lower demand in the global coal-fired power market. Total costs associated with these restructuring actions were $9.1 million, most of which was recognized in the fourth quarter of 2017, and the estimated annual savings are expected to be approximately $45 million in 2018.

Pre-2017 Restructuring activities

Our series of restructuring activities prior to 2017 were intended to help us maintain margins, make our costs more variable and allow our business to be more flexible. We made our manufacturing costs more volume-variable through the closure of manufacturing facilities and development of manufacturing arrangements with third parties. Also, we made our cost of engineering and supply chain more variable by creating a matrix organization capable of delivering products across multiple segments, and developing more volume-variable outsourcing arrangements with our joint venture partners and other third parties to meet fluctuating demand. This new matrix organization and operating model required different competencies and, in some cases, changes in leadership. While primarily applicable to our Power segment, our restructuring actions also benefit the Renewable and Industrial segments to a lesser degree. As demonstrated in our Power segment's gross margin percentages, we have achieved our objective of maintaining gross margins in the segment. Quantification of cost savings, however, is significantly dependent upon volume assumptions that have changed since the restructuring actions were initiated.

On June 28, 2016, we announced actions to restructure our power business in advance of lower projected demand for power generation from coal in the United States. These restructuring actions were primarily in the Power segment. Additionally, we announced leadership changes on December 6, 2016, which included the departure of members of management in our Renewable segment. The costs associated with these restructuring activities totaled $4.2 million and $31.4 million in the years ended December 31, 2017 and 2016, respectively. We do not expect additional restructuring charges related to these activities in 2018.

Other restructuring initiatives announced prior to 2016 were intended to better position us for growth and profitability. They have primarily been related to facility consolidation and organizational efficiency initiatives. Theses costs were $1.0 million, $5.6 million and $11.7 million in 2017, 2016, and 2015, respectively. We do not expect additional restructuring charges related to the pre-2017 restructuring activities in 2018.

Spin-off transaction costs

Spin-off costs were primarily attributable to employee retention awards directly related to the spin-off from our former parent, The Babcock & Wilcox Company (now known as BWX Technologies, Inc.). In the years ended December 31, 2017, 2016 and 2015, we recognized spin-off costs of $1.2 million, $3.8 million, $3.8 million, respectively. In 2017, we disbursed $1.9 million of the accrued retention awards. Approximately $0.3 million of such costs remain, which we expect will be recognized through June 30, 2018.

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Equity in income (loss) of investees

	Year Ended December 31,
	2017			2016		2015
B&W's share of income from equity method investees	$	8,326		$	8,116	$	(242	)
Gain on sale of HMA	—			8,324		—
Other than temporary impairment of TBWES	(18,193		)	—		—
	$	(9,867	)	$	16,440	$	(242	)

The 2017 increase in our share of income from equity-method investees compared to 2016 was primarily a result of improved performance and warranty experience at Babcock & Wilcox Beijing Company, Ltd. ("BWBC"), offset by no 2017 contribution from our former Australian joint venture, Halley & Mellowes Pty. Ltd. ("HMA"). Our share of HMA's income from its operations in 2016 and 2015 was $2.2 million and $3.1 million, respectively. At the end of 2016, we sold all of our interest in HMA, resulting in an $8.3 million gain, which was classified in equity income of investees in 2016.

The 2016 increase in contributions from equity-method investees compared to 2015 was primarily due to the performance of BWBC.

During the second quarter of 2017, both we and our joint venture partner decided to make a strategic change in the Indian joint venture due to the decline in forecasted market opportunities in India, which reduced the expected recoverable value of our investment in the joint venture. As a result of this strategic change, we recognized a $18.2 million other-than-temporary-impairment of our investment in TBWES in the second quarter of 2017. The impairment charge was based on the difference in the carrying value of our investment in TBWES and our share of the estimated fair value of TBWES's net assets. Our remaining investment in TBWES at December 31, 2017 was $26.0 million. The winding down of the TBWES joint venture in India is further described in Note 7 to the consolidated financial statements included in Item 8.

In the first quarter of 2018, we sold all of our interest in BWBC to our joint venture partner for approximately $21 million, which will result in a gain of approximately $4 million during the first quarter of 2018. The sale of our BWBC joint venture in China is further described in Note 7 to the consolidated financial statements included in Item 8. BWBC contributed equity in income of investees of $6.1 million, $4.5 million and $4.9 million from its operations in 2017, 2016 and 2015, respectively.

Excluding the gain on the sale of our BWBC joint venture, in 2018, our equity income is expected to relate only to any potential decreases in the recoverable value of our Indian joint venture and from various contract joint ventures, which are not expected to be material.

Intangible asset amortization expense

We recorded $18.3 million, $19.9 million and $11.4 million of expense during the years ended December 31, 2017, 2016 and 2015, respectively. The increase in amortization expense is attributable to our last two business combinations, which increased our intangible assets by $74.7 million. We expect intangible asset amortization expense will be approximately $12.4 million in 2018.

We acquired $55.2 million of intangible assets in the July 1, 2016 acquisition of SPIG. Amortization of the SPIG intangible assets resulted in $9.1 million and $13.3 million of expense during 2017 and 2016, respectively.

We acquired $19.5 million of intangible assets in the January 11, 2017 acquisition of Universal. Amortization of the Universal intangible assets resulted in $3.1 million of expense during 2017.

Mark to market adjustments

We recognize actuarial gains and losses for our pension and other postretirement benefit plans into earnings as a component of net periodic benefit cost, which affect both our cost of operations and SG&A. These mark to market ("MTM") adjustments for our pension and other postretirement plans resulted in net gains (losses) of $8.7 million, $(24.1) million, and $(40.2)

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million, in 2017, 2016 and 2015, respectively. The effect of the MTM adjustments on cost of operations and SG&A are detailed in Note 18 to the consolidated financial statements included in Item 8.

The MTM gain in 2017 was primarily related to actual returns on plan assets exceeding our expected long-term rate of return assumption, which more than offset the decrease in the discount rate used to measure the pension and other postretirement plan liabilities at December 31, 2017. The MTM gain in 2017 was partially offset by lump sum payments from our Canadian pension plan in the first quarter of 2017, which resulted in a plan settlement of $0.4 million and an interim mark to market remeasurement for the Canadian pension plan. The mark to market adjustment in the first quarter of 2017 was $0.7 million.

The MTM loss in 2016 was primarily related to a decrease in the discount rate used to measure our pension plan liabilities, and changes in the demographics of our pension plan participants, partially offset by actual return on assets that exceeded our expected return for the year. The MTM loss in 2016 was partially offset by a curtailment gain in one of our other postretirement benefit plans. We terminated the Babcock & Wilcox Retiree Medical Plan (the "Retiree OPEB plan") effective December 31, 2016. The Retiree OPEB plan was originally established to provide secondary medical insurance coverage for retirees that had reached the age of 65, up to a lifetime maximum cost. In exchange for terminating the Retiree OPEB plan, the participants had the option to enroll in a third-party health care exchange, which B&W agreed to contribute up to $750 a year for each of the next three years (beginning in 2017), provided the plan participant had not yet reached his or her lifetime maximum under the terminated Retiree OPEB plan. Based on the number of participants who did not enroll in the new benefit plan, we recognized a settlement gain of $7.2 million on December 31, 2016 (which is included as part of the MTM adjustment). Also, during the second and third quarters of 2016, we recorded adjustments to our benefit plan liabilities resulting from certain curtailment and settlement events. In April and September 2016, lump sum payments from our Canadian pension plan resulted in pension plan settlement charges of $1.1 million and $0.1 million, respectively. In May 2016, the closure of our West Point, Mississippi manufacturing facility resulted in a $1.8 million curtailment charge in our United States pension plan. These events resulted in interim mark to market accounting for the respective benefit plans in 2016, which totaled $27.5 million.

The net MTM loss in 2015 was primarily related to actual return on assets that fell short of the expected long-term rate of return assumption, offset by an increase in the discount rate used to measure our benefit plans liabilities.

Provision for income taxes

	Year Ended December 31,
(In thousands, except for percentages)	2017			2016			2015
Income (loss) before income taxes	$	(314,199	)	$	(108,139	)	$	20,205
Income tax expense (benefit)	$	64,816		$	6,943		$	3,671
Effective tax rate	(20.6		)%	(6.4		)%	18.2		%

We operate in numerous countries that have statutory tax rates below that of the United States federal statutory rate of 35% that was in effect through December 31, 2017. The most significant of these foreign operations are located in Canada, Denmark, Germany, Italy, Mexico, Sweden and the United Kingdom with effective tax rates ranging between 20% and approximately 30%. In addition, the jurisdictional mix of our income (loss) before tax can be significantly affected by mark to market adjustments related to our pension and postretirement plans, which have been primarily in the United States, and the impact of discrete items.

In 2017, we had a pretax loss in the United States after MTM adjustments as well as an aggregate pretax loss in our foreign jurisdictions. We had significant losses which were subject to a valuation allowance and therefore did not give rise to a tax benefit in 2017. These losses were primarily attributable to our Renewable Segment, as well as nondeductible goodwill impairment charges. The negative effective tax rate is a result of unfavorable discrete items recorded in 2017, largely attributable to the impact of the newly enacted United States tax legislation.

In 2016, we had a pretax profit in the United States after MTM adjustments as well as an aggregate pretax loss in our foreign jurisdictions. In addition, some of the foreign losses were subject to a valuation allowance and therefore did not give rise to a tax benefit in 2016. Because the jurisdictional mix of our pretax loss was heavily skewed toward relatively low tax jurisdictions, a lower effective tax rate resulted. This low effective tax rate applied against our pretax loss was further reduced due to the impact of unfavorable discrete items recorded in 2016.

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In 2015, the MTM adjustments resulted in a net loss in the United States, which was tax-effected at United States statutory tax rates. When these tax benefits, which are realized in a relatively high tax jurisdiction, are combined with the tax expense generated in foreign jurisdictions with relatively lower statutory tax rates, a low net effective tax rate resulted because we have income before the provision for income taxes.

Income (loss) before provision for income taxes generated in the United States and foreign locations for the years ended December 31, 2017, 2016 and 2015 is presented in the table below.

	Year Ended December 31,
(in thousands)	2017			2016			2015
United States	$	(44,835	)	$	1,280		$	(20,748	)
Other than the United States	(269,364		)	(109,419		)	40,953
Income (loss) before provision for (benefit from) income taxes	(314,199		)	(108,139		)	20,205

As described above, in addition to jurisdictional mix of earnings and the impact of MTM adjustments, our income tax provision and our effective tax rate can also be affected by discrete items that do not occur in each period or jurisdiction and recurring items like foreign tax and research credits, nondeductible expenses and manufacturing tax benefits.

In 2017, we had net unfavorable discrete items of approximately $70.7 million. With a pretax loss in 2017, unfavorable discrete items decreased the effective rate by 22.5%. Our discrete items primarily consist of unfavorable discrete items of $62.4 million related to the enactment of new United States tax legislation in the fourth quarter (see further discussion in Note 10 to the consolidated financial statements included in Item 8), an unfavorable discrete item for withholding tax of $4.5 million on a dividend distribution outside the United States, and unfavorable discrete items related to changes in state deferred taxes due to changes in tax rates and an increase in valuation allowances of $5.0 million.

In 2016, we had net unfavorable discrete items of approximately $32.2 million. With a pretax loss in 2016, unfavorable discrete items decreased the effective tax rate by 29.8%. Our discrete items primarily consist of a $15.7 million increase in the valuation allowance against deferred tax assets related to one of our foreign businesses that incurred pretax losses in the current year, a $10.8 million increase in the valuation allowance against the deferred tax asset related to our equity investment in a foreign joint venture and a $5.1 million charge related to changes in state deferred taxes due to changes in tax rates and an increase in valuation allowances.

In 2015, we had net unfavorable discrete items of approximately $2.7 million, primarily related to revaluing our state deferred taxes, which increased the effective tax rate in 2015 by approximately 14%. The recurring items largely offset each other.

Discrete items are dependent on future events that management is unable to reasonably forecast. Consequently, we cannot predict the amount or significance of such items on our effective tax rate in future periods.

See Note 10 to the consolidated financial statements included in Item 8 for explanation of differences between our effective income tax rate and our statutory rate and the impact of the United States Tax Cuts and Jobs Act of 2017.

Liquidity and capital resources

Additional losses we recognized in the fourth quarter of 2017 related to an increase in structural steel repair costs on one of our European renewable energy contracts led to us seeking amendment of our lending arrangement. The additional losses we recognized in the fourth quarter of 2017 caused us to be out of compliance with certain financial covenants in our lending arrangements at December 31, 2017. We obtained an amendment to our United States Revolving Credit Facility on March 1, 2018 that temporarily waived the financial covenant defaults that existed at December 31, 2017. We face liquidity challenges related to our non-compliance with the financial covenants associated with our second lien term loan facility at December 31, 2017, which may be difficult to resolve in a timely manner. Our second lien term loan agreement contains a 180-day standstill period beginning on March 1, 2018 to resolve the event of default or repay the loan as described in Note 20. Our financing plan includes raising additional capital through a rights offering and other sources before the end of the standstill period, which will depend on conditions in the capital markets and, with respect to the rights offering, an amendment to our existing shelf registration statement that we plan to file in early March 2018 being declared effective by the Securities and Exchange Commission ("SEC"), which are matters that are outside of our control.

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We have initiated steps to remedy the going concern uncertainty, which include, but are not limited to:

• secured an equity commitment agreement on March 1, 2018 with a group of our existing stockholders to fully backstop our planned rights offering for the purpose of providing approximately $182 million of new capital, in the form of new equity, that together with $35 million of borrowings permitted by our United States revolving credit facility we intend to use to extinguish the outstanding balance of our second lien term loan facility and terminate the associated borrowing agreement;

• mitigating, to the extent possible, the adverse impact of our net losses and financial covenant defaults over the past two years on our core operations, customers, vendors and banking relationships (e.g., providers of bank guarantees, letters of credit and surety bonds);

• entered into employee retention agreements with key members of management;

• dedicating project management resources to the performance, efficiency and timely completion of our existing and forecasted portfolio of contracts; and

• selling certain assets or exiting certain markets, if we believe the opportunity would improve stockholder value and our liquidity outlook.

While we believe that the actions summarized above are more likely than not to address the substantial doubt about our ability to continue as a going concern, we cannot assert that it is probable that our plans will fully mitigate the conditions identified. If we cannot continue as a going concern, material adjustments to the carrying values and classifications of our assets and liabilities and the reported amounts of income and expense could be required.

At December 31, 2017, our cash and cash equivalents totaled $56.7 million and we had $263.6 million of total borrowings ($299.3 million face value before debt discounts). In general, our foreign cash balances are not available to fund our United States operations unless the funds are repatriated or used to repay intercompany loans made from the United States to foreign entities, which could expose us to taxes we presently have not made a provision for in our results of operations. Our foreign business locations held $54.3 million of our $56.7 million of unrestricted cash and cash equivalents at December 31, 2017. We presently have no plans to repatriate these funds to the United States as we believe that our United States liquidity is sufficient to meet the anticipated cash requirements of our United States operations.

Historically, our primary sources of liquidity have been cash from operations, borrowings under our United States Revolving Credit Facility ("Revolver") and borrowings under foreign revolving credit facilities. Our borrowing capacity under our Revolver is primarily limited by the financial covenants, which are most significantly affected by our trailing 12 months EBITDA (as defined in the credit agreement governing the facility). The significant loss accruals we recorded in the second quarter and fourth quarters of 2017 reduced our trailing 12 months EBITDA and, in turn, our ability to comply with our financial covenants. Accordingly, we amended our Revolver on February 28, 2017, August 9, 2017 and March 1, 2018 to, among other things, provide covenant relief.

To provide additional liquidity, we entered into a Second Lien Term Loan Facility ("Second Lien") on August 9, 2017 with an affiliate of American Industrial Partners ("AIP"). The Second Lien consists of a second lien term loan in the principal amount of $175.9 million, all of which we borrowed on August 9, 2017, and a delayed draw term loan in the principal amount of $20.0 million, which was drawn in a single draw on December 13, 2017. On August 9, 2017, we used $125.0 million of the second lien term loan proceeds to repay borrowings outstanding under our Revolver and pay fees and expenses related to the Second Lien and the amendment of our Revolver, and the balance of the second lien term loan proceeds on August 9, 2017 were used to repurchase approximately 4.8 million shares of our common stock held by an affiliate of AIP for approximately $50.9 million, which was one of the conditions precedent for the Second Lien. As described in Note 20 to the consolidated financial statements included in Item 8, the difference between the price paid for the shares and the estimated fair value of the shares repurchased was treated as a debt discount together with the direct financing costs.

Additionally, to enhance our financial flexibility, we also announced in November 2017 that we are evaluating strategic alternatives for our MEGTEC and Universal businesses. Though our outlook remains favorable for these businesses, we believe it is prudent to explore alternatives for these parts of our company, providing greater optionality if needed.

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After giving effect to the March 1, 2018 amendment, we had approximately $137.4 million of availability under our Revolver as of December 31, 2017. Based on the amended Revolver, we believe we have adequate sources of liquidity at December 31, 2017. Our assessment is based on the Equity Commitment Agreement we entered into on March 1, 2018, our operating forecast, backlog, cash on-hand, borrowing capacity under the Revolver, potential asset sales, planned capital investments and ability to manage future discretionary cash outflows during the next 12 month period. We expect our operations to use cash over the first half of 2018 and generate cash flows that will cover our forecasted obligations during the second half of 2018. Our forecasted use of cash during 2018 will primarily be in the Renewable segment as we fund accrued contract losses and work down advanced bill positions. Our forecasted use of cash is expected to be funded in part through borrowings from our Revolver. Our Revolver allows for nearly immediate borrowing of available capacity to fund cash requirements in the normal course of business, meaning that United States cash on hand is minimized to reduce borrowing costs. After giving effect to the the $65.0 million of minimum liquidity required under our financial covenants, we expect to have between $25.0 million and $35.0 million of available borrowing capacity from our Revolver during the next 12 months based on our forecast of the trailing 12 month EBITDA calculation and forecasted borrowings. Our available borrowing capacity will increase if we complete assets sales. We expect cash and cash equivalents, cash flows from operations, and our borrowing capacity under our Revolver to be sufficient to meet our liquidity needs for at least 12 months from the date of this filing.

Our net cash provided by (used) in operations was $(189.8) million in 2017 and $2.3 million in 2016. The change is partially attributable to the $263.9 million increase in our net loss in the 2017 compared to 2016. Also, a $48.1 million net decrease in cash inflows associated with changes in accounts receivable, contracts in progress and advanced billings in 2017 compared to 2016 resulted primarily from the timing of billings and stage of completion of large, ongoing contracts in our Renewable segment. Generally, we try to structure contract milestones to mirror our expected cash outflows over the course of the contract; however, the timing of milestone receipts can greatly affect our overall cash position. Our portfolio of Renewable energy contracts at both December 31, 2017 and December 31, 2016 included milestone payments from our customers in advance of incurring the contract expenses, and as a result we are in an advance bill position on most of these contracts at both dates. Because of the advanced bill positions, combined with the increase in expected costs to complete the Renewable loss contracts, we expect the use of cash by the Renewable segment to continue during the first half of 2018 until these contracts are completed. Our operating cash outflows also increased by $56.8 million associated with changes in contract related accounts payable and accrued liabilities in 2017 compared to 2016.

Our net cash used in investing activities was $62.1 million in 2017 and $180.8 million in 2016. The net cash used in investing activities in 2017 was primarily attributable to the $52.5 million acquisition of Universal on January 11, 2017, net of $4.4 million cash acquired in the business combination (see Note 5 to the consolidated financial statements included in Item 8). The net cash used in investing activities in 2016 included $145.0 million acquisition of SPIG, net of $26.0 million cash acquired, and a $26.3 million contribution to increase our interest in TBWES, our joint venture in India. Capital expenditures were $14.3 million and $22.5 million in 2017 and 2016, respectively.

Our net cash provided by financing activities was $206.1 million in 2017, compared to $83.4 million of cash used in 2016. The cash provided by financing activities in 2017 was a result of net borrowings from our United States revolving credit facility of $84.5 million and proceeds from the issuance of the Second Lien of $161.7 million, which were used to repurchase $16.7 million of shares from a related party, fund debt issuance costs and repay a portion of our Revolver. The net cash used in financing activities in 2016 is primarily attributable to repurchases of $78.4 million of our common stock.

In 2017, we also experienced increased levels of cash paid for interest based on higher borrowing levels, which we expect to increase further in 2018.

United States Revolving Credit Facility ("Revolver")

On May 11, 2015, we entered into a credit agreement with a syndicate of lenders ("Credit Agreement") in connection with our spin-off from The Babcock & Wilcox Company. The Credit Agreement, which is scheduled to mature on June 30, 2020, provides for a senior secured revolving credit facility, initially in an aggregate amount of up to $600 million. The proceeds of loans under the Credit Agreement are available for working capital needs and other general corporate purposes, and the full amount is available to support the issuance of letters of credit.

On February 24, 2017, August 9, 2017 and March 1, 2018, we entered into amendments to the Credit Agreement (the "Amendments" and the Credit Agreement, as amended to date, the "Amended Credit Agreement") to, among other things: (1) permit us to incur the debt under the second lien term loan facility, (2) modify the definition of EBITDA in the Amended Credit Agreement to exclude: up to $98.1 million of charges for certain Renewable segment contracts for periods including

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the quarter ended December 31, 2016, up to $115.2 million of charges for certain Renewable segment contracts for periods including the quarter ended June 30, 2017, up to $30.1 million of charges for certain Renewable segment contracts for periods including the quarter ended September 30, 2017, up to $38.7 million of charges for certain Renewable segment contracts for periods including the quarter ended December 31, 2017, up to $4.0 million of aggregate restructuring expenses incurred during the period from July 1, 2017 through September 30, 2018 measured on a consecutive four-quarter basis, realized and unrealized foreign exchange losses resulting from the impact of foreign currency changes on the valuation of assets and liabilities, and fees and expenses incurred in connection with the August 9, 2017 and March 1, 2018 amendments, (3) replace the maximum leverage ratio with a maximum senior debt leverage ratio, (4) decrease the minimum consolidated interest coverage ratio, (5) limit our ability to borrow under the Amended Credit Agreement during the covenant relief period to $250.0 million in the aggregate, (6) reduce commitments under the revolving credit facility from $600.0 million to $450.0 million, (7) require us to maintain liquidity (as defined in the Amended Credit Agreement) of at least $75.0 million as of the last business day of any calendar month, (8) require us to repay outstanding borrowings under the revolving credit facility (without any reduction in commitments) with certain excess cash, (9) increase the pricing for borrowings and commitment fees under the Amended Credit Agreement, (10) limit our ability to incur debt and liens during the covenant relief period, (11) limit our ability to make acquisitions and investments in third parties during the covenant relief period, (12) prohibit us from paying dividends and undertaking stock repurchases during the covenant relief period (other than our share repurchase from an affiliate of AIP), (13) prohibit us from exercising the accordion described below during the covenant relief period, (14) limit our financial and commercial letters of credit outstanding under the Amended Credit Agreement, (15) require us to reduce commitments under the Amended Credit Agreement with the proceeds of certain debt issuances and asset sales, (16) beginning with the quarter ended March 31, 2018, limit to no more than $15.0 million any cumulative net income losses attributable to eight specified Vølund projects, (17) increase reporting obligations and require us to hire a third-party consultant and a chief implementation officer, (18) require us to pledge the equity of certain of our foreign subsidiaries to guarantee and provide collateral for our obligations under the United States credit facility, (19) require us to pay a deferred facility fee as more fully set forth in the March 1, 2018 Amendment, and (20) require us to sell at least $100 million of assets before March 31, 2019. The covenant relief period will end, at our election, when the conditions set forth in the Amended Credit Agreement are satisfied, but in no event earlier than the date on which we provide the compliance certificate for our fiscal quarter ended December 31, 2019.

Other than during the covenant relief period, the Amended Credit Agreement contains an accordion feature that allows us, subject to the satisfaction of certain conditions, including the receipt of increased commitments from existing lenders or new commitments from new lenders, to increase the amount of the commitments under the revolving credit facility in an aggregate amount not to exceed the sum of (1) $200.0 million plus (2) an unlimited amount, so long as for any commitment increase under this subclause (2) our senior leverage ratio (assuming the full amount of any commitment increase under this subclause (2) is drawn) is equal to or less than 2.0:1.0 after giving pro forma effect thereto. During the covenant relief period, our ability to exercise the accordion feature will be prohibited.

The March 1, 2018 Amendment temporarily waived certain defaults and events of default under our Revolver that were breached on December 31, 2017 or that may occur in the future, with certain amendments effective immediately and other amendments effective upon the completion of the Rights Offering and the repayment of the outstanding balance of our Second Lien. If the Rights Offering and the repayment of the outstanding balance of our Second Lien do not occur by April 15, 2018 (subject to extension in certain cases), the temporary waiver will end. The temporary waiver will also end if certain other conditions specified in the March 1, 2018 Amendment occur. Upon any such termination of the waiver, our ability to borrow funds under the Revolver will terminate.

After giving effect to the Amendments, loans outstanding under the Amended Credit Agreement bear interest at our option at either LIBOR rate plus 7.0% per annum or the Base Rate plus 6.0% per annum until we complete the Rights Offering and prepay the Second Lien Term Loan facility and thereafter at our option at either (1) the LIBOR rate plus 5.0% per annum during 2018, 6.0% per annum during 2019 and 7.0% per annum during 2020, or (2) the Base Rate plus 4.0% per annum during 2018, 5.0% per annum during 2019, and 6.0% per annum during 2020. The Base Rate is the highest of the Federal Funds rate plus 0.5%, the one month LIBOR rate plus 1.0%, or the administrative agent's prime rate. A commitment fee of 1.0% per annum is charged on the unused portions of the revolving credit facility. A letter of credit fee of 2.50% per annum is charged with respect to the amount of each financial letter of credit outstanding, and a letter of credit fee of 1.50% per annum is charged with respect to the amount of each performance and commercial letter of credit outstanding. Additionally, an annual facility fee of $1.5 million is payable on the first business day of 2018 and 2019, and a pro rated amount is payable on the first business day of 2020.

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The Amended Credit Agreement includes financial covenants that are tested on a quarterly basis, based on the rolling four-quarter period that ends on the last day of each fiscal quarter. After we complete the Rights Offering and the repayment of the outstanding balance of our Second Lien within the time period required by the March 1, 2018 Amendment, the maximum permitted senior debt leverage ratio as defined in the Amended Credit Agreement is:

• 8.50:1.0 for the quarter ended December 31, 2017,

• 7.00:1.0 for the quarter ending March 31, 2018,

• 6.50:1.0 for the quarters ending June 30, 2018 and September 30, 2018,

• 4.75:1.0 for the quarter ending December 31, 2018,

• 3.00:1.0 for the quarter ending March 31, 2019,

• 2.75:1.0 for the quarters ending June 30, 2019 and September 30, 2019, and

• 2.50:1.0 for the quarter ending December 31, 2019 and each quarter thereafter.

After we complete the Rights Offering and the repayment of the outstanding balance of our Second Lien within the time period required by the March 1, 2018 Amendment, the minimum consolidated interest coverage ratio as defined in the Credit Agreement is:

• 1.25:1.0 for the quarter ended December 31, 2017,

• 1.15:1.0 for the quarter ending March 31, 2018,

• 1.00:1.0 for the quarter ending June 30, 2018,

• 0.85:1.0 for the quarter ending September 30, 2018,

• 1.25:1.0 for the quarter ending December 31, 2018,

• 1.50:1.0 for the quarter ending March 31, 2019 and

• 2.00:1.0 for the quarters ending June 30, 2019 and each quarter thereafter.

Beginning with September 30, 2017, consolidated capital expenditures in each fiscal year are limited to $27.5 million.

At December 31, 2017, borrowings under the Amended Credit Agreement and foreign facilities totaled $103.5 million at an effective interest rate of 6.89%. Usage under the Amended Credit Agreement consisted of $94.3 million of borrowings, $7.4 million of financial letters of credit and $123.7 million of performance letters of credit. After giving effect to the March 1, 2018 amendment, at December 31, 2017 we had approximately $221.4 million available for borrowings or to meet letter of credit requirements primarily based on trailing 12 month EBITDA (as defined in the Amended Credit Agreement), and our leverage and interest coverage ratios (as defined in the Amended Credit Agreement) were 2.59 and 2.50, respectively. We expect to be closest to the minimum financial covenant thresholds at September 30, 2018.

We plan to execute the actions necessary to enable us to maintain compliance with the financial and other covenants described above. We believe we will accomplish our plans to maintain compliance with our financial and other covenants, and believe our cash on hand, proceeds from potential future asset sales, cash flows from operations and amounts available under our Revolver will be adequate to enable us to fund our operations. However, there can be no assurance that we will be successful. Our ability to generate cash flows from operations, access funding under reasonable terms, contract business with reasonable terms and conditions and comply with our financial and other covenants may be impacted by a variety of business, economic, regulatory and other factors, which may be outside of our control. Such factors include, but are not limited to: our ability to access capital markets and complete asset dispositions, delay or cancellation of contracts, decreased profitability on our contracts due to matters not reasonably forecasted, changes in the timing of cash flows on our contracts due to the timing of receipts and required payments of liabilities and funding of our loss projects, the timing of approval or settlement of change orders and claims, changes in foreign currency exchange or interest rates, performance of pension plan assets or changes in actuarially determined liabilities. In addition, we could be impacted if our customers experience a material change in their ability to pay us or if the banks associated with our lending facilities were to cease or reduce operations. Also, we have what we believe is adequate capacity to provide letters of credit and secure surety bonds in support of current and future contracts, but there can be no assurance that these will be renewed or available at reasonable commercial terms in the future.

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Second Lien Term Loan ("Second Lien")

On August 9, 2017, we entered into a second lien credit agreement (the "Second Lien Credit Agreement") with an affiliate of AIP governing a second lien term loan facility. The Second Lien consists of a second lien term loan in the principal amount of $175.9 million, all of which we borrowed on August 9, 2017, and a delayed draw term loan facility in the principal amount of up to $20.0 million, which was drawn in a single draw on December 13, 2017. Borrowings under the second lien term loan, other than the delayed draw term loan, bear interest at 10% per annum, and borrowings under the delayed draw term loan bear interest at 12% per annum, in each case payable quarterly. Delayed draw borrowings and the second lien term loan have scheduled maturities of December 30, 2020. In connection with our entry into the second lien term loan facility, we used a portion of the proceeds from the second lien term loan to repurchase approximately 4.8 million shares of our common stock (approximately 10% of our shares outstanding) held by an affiliate of AIP for approximately $50.9 million, which was one of the conditions precedent for the second lien term loan facility.

Borrowings under the Second Lien Credit Agreement are (1) guaranteed by substantially all of our wholly owned domestic subsidiaries, but excluding our captive insurance subsidiary, and (2) secured by second-priority liens on certain assets owned by us and the guarantors. The Second Lien Credit Agreement requires interest payments on loans on a quarterly basis until maturity. Voluntary prepayments made during the first year after closing are subject to a make-whole premium, voluntary prepayments made during the second year after closing are subject to a a 3.0% premium and voluntary prepayments made during the third year after closing are subject to a 2.0% premium. The Second Lien Credit Agreement requires us to make certain prepayments on any outstanding loans after receipt of cash proceeds from certain asset sales or other events, subject to certain exceptions and a right to reinvest such proceeds in certain circumstances, and subject to certain restrictions contained in an intercreditor agreement among the lenders under the Amended Credit Agreement and the Second Lien Credit Agreement.

The Second Lien Credit Agreement contains representations and warranties, affirmative and restrictive covenants, financial covenants and events of default substantially similar to those contained in the Amended Credit Agreement, subject to appropriate cushions. The Second Lien Credit Agreement is generally less restrictive than the Amended Credit Agreement.

Foreign revolving credit facilities

Outside of the United States, we have revolving credit facilities in Turkey and India that are used to provide working capital to our operations in each country. These foreign revolving credit facilities allow us to borrow up to $9.2 million in aggregate and each have a one year term. At December 31, 2017, we had $9.2 million in borrowings outstanding under these foreign revolving credit facilities at an effective weighted-average interest rate of 6.07%.

Letters of credit, bank guarantees and surety bonds

Certain subsidiaries have credit arrangements with various commercial banks and other financial institutions for the issuance of letters of credit and bank guarantees associated with contracting activity. The aggregate value of all such letters of credit and bank guarantees not secured by the United States credit facility as of December 31, 2017 and December 31, 2016 was $269.1 million and $255.2 million, respectively. The aggregate value of all such letters of credit and bank guarantees that are partially secured by the Revolver as of December 31, 2017 was $114.2 million. The aggregate value of the letters of credit provided by the Revolver in support of letters of credit outside of the United States was $40.4 million as of December 31, 2017.

We have posted surety bonds to support contractual obligations to customers relating to certain contracts. 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 contract 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, 2017, bonds issued and outstanding under these arrangements in support of contracts totaled approximately $378.8 million.

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Long-term benefit obligations

Our unfunded pension and postretirement benefit obligations totaled $258.8 million at December 31, 2017. For the year ended December 31, 2017, we made required contributions to our pension plans totaling $17.3 million and to our postretirement plans of $1.2 million. In 2018, we expect to make $21 million to $23 million of contributions to our benefit plans. See additional information on our long-term benefit obligations in Note 18 to our consolidated financial statements included in Item 8 of this annual report.

Contractual obligations

Our cash requirements as of December 31, 2017 under current contractual obligations were as follows:

(in thousands)	Total		Less than 1 Year		1-3 Years		3-5 Years		After 5 Years
Operating lease payments	$	23,803	$	6,814	$	8,653	$	4,999	$	3,337
United States revolving credit facility	$	94,300	$	—	$	94,300	$	—	$	—
Second lien notes facility	$	195,884	$	—	$	195,884	$	—	$	—
Foreign revolving credit facility	$	9,173	$	9,173	$	—	$	—	$	—
ARPA litigation settlement	$	7,000	$	2,500	$	4,500	$	—	$	—

The table above excludes cash payments for self-insured claims, litigation (other than the ARPA settlement) and funding of our pension and postretirement benefit plans because we are uncertain as to the timing and amount of any associated cash payments that will be required. For example, pension contributions may be subject to potential required contributions in connection with dispositions or plan mergers. Also, estimated pension and other postretirement benefit payments are based on actuarial estimates using current assumptions for, among other things, discount rates, expected long-term rates of return on plan assets and health care costs. Additionally, the table above excludes deferred income taxes recorded on our balance sheets because cash payments for income taxes are determined primarily on future taxable income.

Our contingent commitments under letters of credit, bank guarantees and surety bonds outstanding at December 31, 2017 expire as follows (in thousands):

Total	Less than 1 Year	1-3 Years	3-5 Years	Thereafter
$779,082	$368,357	$374,566	$35,072	$1,088

We do not expect significant cash payments associated with the contingent commitments included in the table above because we expect to fulfill the performance commitments related to the underlying contracts.

Off-balance sheet arrangements

There were no significant off-balance sheet arrangements at December 31, 2017.

EFFECTS OF INFLATION AND CHANGING PRICES

Our consolidated financial statements included in Item 8 are prepared in accordance with generally accepted accounting principles in the United States, using historical United States 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 United States dollar, especially during times of significant and continued inflation.

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.

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CRITICAL ACCOUNTING POLICIES AND ESTIMATES

The consolidated financial statements included in Item 8 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 consolidated 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 begins. We generally recognize contract revenues and related costs on a percentage-of-completion ("POC") method for individual contracts or combinations of contracts based on a cost-to-cost method, as applicable to the product or activity involved. We recognize estimated contract revenues and resulting income based on costs incurred to date as a percentage of total estimated costs. 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. 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. We routinely review estimates related to our contracts, and revisions to profitability are reflected in the quarterly and annual earnings we report. For parts orders and certain aftermarket services activities, we recognize revenues as goods are delivered and work is performed.

In the years ended December 31, 2017, 2016 and 2015, we recognized net changes in estimates related to long-term contracts accounted for on the POC basis which increased (decreased) operating income by $(153.3) million, $(106.8) million and $0.4 million, respectively. As of December 31, 2017, we have estimated the costs to complete all of our in-process contracts in order to estimate revenues in accordance with the percentage-of-completion method of accounting. However, it is possible that current estimates could change due to contract performance or unforeseen events, which could result in adjustments to overall contract costs. Variations from estimated contract performance could result in material adjustments to operating results for any fiscal quarter or year.

We recognize income from contract change orders or claims when agreed with the customer. We regularly assess the collectability of contract revenues and receivables from customers. We recognize accrued claims in contract revenues for extra work or changes in scope of work to the extent of costs incurred when we believe the following accounting criteria have been met:

a) The contract or other evidence provides a legal basis for the claim; or a legal opinion has been obtained, stating that under the circumstances there is a reasonable basis to support the claim.

b) Additional costs are caused by circumstances that were unforeseen at the contract date and are not the result of deficiencies in the contractor's performance.

c) Costs associated with the claim are identifiable or otherwise determinable and are reasonable in view of the work performed.

d) The evidence supporting the claim is objective and verifiable, not based on unsupported representations.

In our consolidated balance sheets, we had no accrued claims receivable at December 31, 2017 and at December 31, 2016.

Business combinations

We account for acquisitions in accordance with Financial Accounting Standards Board ("FASB") Topic Business Combinations. This topic requires us to estimate the fair value 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.

Several valuation methods are used to determine the fair value of the assets acquired and liabilities assumed. For intangible assets, we used the income method, which required us to forecast the expected future net cash flows for each intangible asset. These cash flows were then adjusted to present value by applying an appropriate discount rate that reflects the risk factors associated with the projected cash flows. Some of the more significant estimates and assumptions inherent in the income method include the amount and timing of projected future cash flows, the discount rate selected to measure the risks inherent

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in the future cash flows and the assessment of the asset's economic life and the competitive trends impacting the asset, including consideration of any technical, legal, regulatory or economic barriers to entry. Determining the useful life of an intangible asset also require judgment as different types of intangible assets will have different useful lives, or indefinite useful lives.

We accounted for the acquisitions of SPIG and Universal using the acquisition method. All of the assets acquired and liabilities assumed were recognized at their fair value on the acquisition date. Any excess of the purchase price over the estimated fair values of the net assets acquired was recorded as goodwill. Acquisition-related costs were recorded as selling, general and administrative expenses in our consolidated financial statements.

Pension and other postretirement benefit plans

We utilize actuarial and other assumptions in calculating the cost and benefit obligations of our pension and postretirement benefits. The assumptions utilized in the determination of our benefit cost and obligations include assumptions regarding discount rates, expected returns on plan assets, mortality and health care cost trends. The assumptions utilized represent our best estimates based on historical experience and other factors.

Actual experience that differs from these assumptions or future changes in assumptions will affect our recognized benefit obligations and related costs. We recognize net actuarial gains and losses into earnings in the fourth quarter of each year, or as interim remeasurements are required, as a component of net periodic benefit cost. Net actuarial gains and losses occur when actual experience differs from any of the various assumptions used to value our pension and postretirement benefit plans or when assumptions, which are revisited annually through our update of our actuarial valuations, change due to current market conditions or underlying demographic changes. The primary factors contributing to net actuarial gains and losses are changes in the discount rate used to value the obligations as of the measurement date each year, the difference between the actual and expected return on plan assets and changes in health care cost trends. The effect of changes in the discount rate and expected rate of return on plan assets in combination with the actual return on plan assets can result in significant changes in our estimated pension and postretirement benefit cost and our consolidated financial condition.

In 2016, we changed our approach to setting the discount rate from a single equivalent discount rate to an alternative spot rate method. This change in estimate was applied prospectively in developing our annual discount rate, which resulted in $6.8 million lower interest and service cost in 2016. The impact of the change in estimate did not change our pension and other postretirement benefits liability as of December 31, 2016, because any change was completely offset in the net actuarial gain (loss) recorded in the annual mark to market adjustment. This new method was adopted because it more accurately applies each year’s spot rates to the projected cash flows.

The following sensitivity analysis shows the impact of a 25 basis point change in the assumed discount rate and return on assets on our pension plan obligations and expense for the year ended December 31, 2017:

(In millions)	0.25% increase			0.25% decrease
Discount rate:
Effect on ongoing net periodic benefit cost(1)	$	(31.1	)	$	32.4
Effect on projected benefit obligation	(32.7		)	34.2
Return on assets:
Effect on ongoing net periodic benefit cost	$	(2.2	)	$	2.2

⁽¹⁾ Excludes effect of annual MTM adjustment.

A 25 basis point change in the assumed discount rate, return on assets and health care cost trend rate would have no meaningful impact on our other postretirement benefit plan obligations and expense for the year ended December 31, 2017 individually or in the aggregate, excluding the impact of any annual MTM adjustments we record annually.

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. See Note 21 to the consolidated financial statements included in Item 8 for a discussion of this litigation. As

52

disclosed, we have accrued estimates of the probable losses associated with these matters; however, these matters 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 and long-lived asset impairment

Each year, or as circumstances indicate, we evaluate goodwill at each reporting unit to assess recoverability, and impairments, if any, are recognized in earnings. We perform a qualitative analysis when we believe that there is sufficient excess fair value over carrying value based on our most recent quantitative assessment, adjusted for relevant facts and circumstances that could affect fair value. Deterioration in macroeconomic, industry and market conditions, cost factors, overall financial performance, share price decline or entity and reporting unit specific events could cause us to believe a qualitative test is no longer appropriate.

When we determine that it is appropriate to test goodwill for impairment utilizing a quantitative test, the first step of the test compares the fair value of a reporting unit to its carrying amount, including goodwill. We utilize both the income and market valuation approaches to 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 materially from our projections. Some assumptions, such as future revenues, costs and changes in working capital are company driven and could be affected by a loss of one or more significant contracts or customers; failure to control costs on certain contracts; or a decline in demand based on changing economic, industry or regulatory conditions. Changes in external market conditions may affect certain other assumptions, such as the cost of capital. Market conditions can be volatile and are outside of our control.

Under the market valuation approach, we employ both the guideline publicly traded company method and the similar transactions method. The guideline publicly traded company method indicates the fair value of the equity of each reporting unit by comparing it to publicly traded companies in similar lines of business. The similar transactions method considers recent prices paid for business in our industry or related industries. After identifying and selecting guideline companies and similar transactions, 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. Assumptions include the selection of our peer companies and use of market multiples, which could deteriorate or increase based on the profitability of our competitors and performance of their stock, which is often dependent on the performance of the stock market and general economy as a whole.

Adverse changes in these assumptions utilized within the first step of our impairment test could cause a reduction or elimination of excess fair value over carrying value, resulting in potential recognition of impairment. 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.

Our annual goodwill impairment assessment is performed on October 1 of each year (the "annual assessment" date); however, events during 2017 have required two interim assessments of all six of our reporting units. In the second quarter of 2017, significant charges in our Renewable segment were considered to be a triggering event for the interim assessment as of June 30, 2017, which did not indicate impairment. In the third quarter of 2017, our market capitalization significantly decreased to below our equity value, which was considered to be a trigger for a second interim assessment. Additionally, the forecast was reduced for our SPIG reporting unit based on a change in the market strategy implemented by the new segment management to focus on core geographies and products.

The goodwill impairment test associated with our SPIG reporting unit is the most sensitive to a change in future valuation assumptions. The reporting unit has $38.3 million of goodwill remaining after the $36.9 million impairment charge we recorded at September 30, 2017. Even a marginal increase in the discount rate we use to estimate the fair value of the SPIG reporting unit in the income valuation approach could result in an impairment, assuming no significant change in the

53

forecasted cash flows. Additionally, a decline in SPIG's forecasted cash flows would result in an impairment, assuming no significant change in the discount rate.

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 asset 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 and result in future asset impairments.

In the year ended December 31, 2016, we recognized a $14.9 million impairment charge related primarily to the impairment of long-lived assets at B&W’s one coal-fired power plant located in Ebensburg, Pennsylvania. The impairment charge was determined as the difference between the fair value of the power plant's long-lived assets less the estimated cost to sell and the carrying value of the assets before recording the impairment charge.

In the year ended December 31, 2015, we recognized a $14.6 million impairment charge primarily related to research and development facilities and equipment dedicated to activities that were determined not to be commercially viable. The impairment is included in losses on asset disposals and impairments, net in our consolidated financial statements included in Item 8 of this annual report.

Income taxes

Income tax expense for federal, foreign, state and local income taxes is calculated on pre-tax income based on current tax law and includes 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. Should we conclude in the future that any or all of our deferred tax assets are not more likely than not to be realized, we would establish additional valuation allowances and any changes to our estimated valuation allowance could be material to our consolidated financial statements. 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 consolidated financial statements. We record interest and penalties (net of any applicable tax benefit) related to income taxes as a component of the provision for income taxes in our consolidated statements of operations.

On December 22, 2017, the Tax Cuts and Jobs Act of 2017 (the “Tax Act”) was signed into law making significant changes to the United States Federal Internal Revenue Code. Changes include: (1) reduction of the United States federal corporate tax rate from 35% to 21%; (2) elimination of the corporate alternative minimum tax; (3) the creation of the base erosion anti-abuse tax, a new minimum tax; (4) a general elimination of United States federal income taxes on dividends from foreign subsidiaries; (5) a new provision designed to tax global intangible low-taxed income ("GILTI"), (6) the creation of an export incentive for United States companies on foreign-derived intangible income; (7) a new limitation on deductible interest expense; (8) the repeal of the domestic production activity deduction; (9) limitations on the deductibility of certain executive compensation; (10) limitations on the use of foreign tax credits to reduce the United States income tax liability; and (11) limitations on net operating losses generated after December 31, 2017, to 80 percent of taxable income, while changing to an unlimited carryforward period. In connection with our initial analysis of the impact of the Tax Act, we have recorded an increase in tax expense in the period ending December 31, 2017; however, we have not completed our accounting for the income tax effects of certain elements of the Tax Act. If we were able to make reasonable estimates of the effects of elements for which our analysis is not yet complete, we recorded provisional adjustments. If we were not yet able to make reasonable estimates of the impact of certain elements, we have not recorded any adjustments related to those elements and have continued accounting for them in accordance with ASC 740 on the basis of the tax laws in effect before the Tax Act. Our accounting for the following elements of the Tax Act is complete: cost recovery and GILTI. Our accounting for the following elements of the Tax Act is incomplete; however, we were able to make reasonable estimates of certain effects and, therefore,

54

recorded provisional adjustments: reduction of United States federal corporate tax rate, deemed repatriation transition tax, valuation allowances, and decrease in deferred taxes related to performance-based compensation. We believe the assumptions and estimates related to the provision for income taxes are critical to our results of operations, and are described in greater detail in Note 10 to the consolidated financial statements included in Item 8.

On December 22, 2017, Staff Accounting Bulletin No. 118 ("SAB 118") was issued to address situations when a registrant does not have the necessary information available, prepared, or analyzed (including computations) in reasonable detail to complete the accounting for certain income tax effects of the Act. In accordance with SAB 118, we have determined that the deferred tax expense recorded in connection with the remeasurement of certain deferred tax assets was provisional, and a reasonable estimate at December 31, 2017. Additional work is necessary for a more detailed analysis of our deferred tax assets and liabilities. Any subsequent adjustment will be recorded to current tax expense in the quarter of 2018 when the analysis is complete.

Warranty

We accrue estimated expense included in cost of operations on our consolidated statements of operations to satisfy contractual warranty requirements when we recognize the associated revenues on the related contracts. In addition, we record specific provisions or reductions when 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. Such changes could have a material effect on our consolidated financial condition, results of operations and cash flows.

Item 7A. Quantitative and Qualitative Disclosures About Market Risk

Our exposures to market risks could change materially from those disclosed under "Quantitative and Qualitative Disclosures About Market Risk" in our Annual Report. 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 United States Government obligations and highly liquid money market instruments denominated in United States 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. Our investments are classified as available-for-sale.

Although the consolidated balance sheets do not present debt at fair value, our second lien term loan facility is fixed-rate debt, the fair value of which could fluctuate as a result of changes in prevailing market rates. On December 31, 2017, its principal balance was $195.9 million. Our United States revolving credit facility is variable-rate debt, so its fair value would not be significantly affected by changes in prevailing market rates. On December 31, 2017, its principal balance was $94.3 million.

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 ("FX") rates or weak economic conditions in those foreign markets. Our primary foreign currency exposures are Danish kroner, Great British pound, Euro, Canadian dollar, and Chinese yuan. In order to manage the risks associated with FX rate fluctuations, we attempt to hedge those risks with FX derivative instruments, but there can be no assurance that such instruments will be available to us on reasonable terms. Historically, we have hedged those risks with FX forward contracts. We do not enter into speculative derivative positions. During the third quarter of 2017, our hedge counterparties removed the lines of credit supporting new FX forward contracts. Subsequently, we have not entered into any new FX forward contracts.

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ITEM 8. Consolidated Financial Statements and Supplemental Data

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

To the Stockholders and Board of Directors of Babcock & Wilcox Enterprises, Inc.:

Opinion on the Financial Statements

We have audited the accompanying consolidated balance sheets of Babcock & Wilcox Enterprises, Inc. (the “Company”) as of December 31, 2017 and 2016, the related consolidated and combined statements of operations, comprehensive income (loss), stockholders' equity, and cash flows, for each of the three years in the period ended December 31, 2017, and the related notes (collectively referred to as the “financial statements”). In our opinion, the financial statements present fairly, in all material respects, the financial position of the Company as of December 31, 2017 and 2016, and the results of its operations and its cash flows for each of the three years in the period ended December 31, 2017, in conformity with accounting principles generally accepted in the United States.

We have also audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States) (“PCAOB”), the Company's internal control over financial reporting as of December 31, 2017, based on the criteria established in Internal Control - Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission and our report dated March 1, 2018, expressed an unqualified opinion on the Company's internal control over financial reporting.

The Company’s Ability to Continue as a Going Concern

The accompanying financial statements have been prepared assuming the Company will continue as a going concern. As discussed in Note 1 to the financial statements, the Company recognized additional losses in the fourth quarter of 2017 that led to covenant violations associated with its second lien credit facility and does not have sufficient capital to repay such loans. Management's plans in regard to these matters are also described in Note 1. These matters raise substantial doubt about the Company’s ability to continue as a going concern. The accompanying financial statements do not include any adjustments that might result from the outcome of this uncertainty.

Spin-Off

The Board of Directors of The Babcock & Wilcox Company (“BWC”) approved the spin-off of the Company through the distribution of common stock of the Company on June 30, 2015 to existing shareholders of BWC. See Note 1 to the consolidated financial statements.

Basis for Opinion

These financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on the Company’s financial statements based on our audits. We are a public accounting firm registered with the PCAOB and are required to be independent with respect to the Company in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.

We conducted our audits in accordance with the standards of the PCAOB. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement, whether due to error or fraud. Our audits included performing procedures to assess the risks of material misstatement of the financial statements, whether due to error or fraud, and performing procedures that respond to those risks. Such procedures included examining, on a test basis, evidence regarding the amounts and disclosures in the financial statements. Our audits also included evaluating the accounting principles used and significant estimates made by management, as well as evaluating the overall presentation of the financial statements. We believe that our audits provide a reasonable basis for our opinion.

/S/ DELOITTE & TOUCHE LLP

Charlotte, North Carolina

March 1, 2018

We have served as the Company’s auditor since 2014.

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BABCOCK & WILCOX ENTERPRISES, INC.

CONSOLIDATED AND COMBINED STATEMENTS OF OPERATIONS

	Year Ended December 31,
(in thousands, except per share amounts)	2017			2016			2015
Revenues	$	1,557,735		$	1,578,263		$	1,757,295
Costs and expenses:
Cost of operations	1,457,857			1,399,146			1,449,138
Selling, general and administrative expenses	259,799			247,149			239,968
Goodwill impairment charges	86,903			—			—
Restructuring activities and spin-off transaction costs	15,447			40,807			14,946
Research and development costs	9,412			10,406			16,543
Losses (gains) on asset disposals, net	15			(32		)	14,597
Total costs and expenses	1,829,433			1,697,476			1,735,192
Equity in income (loss) and impairment of investees	(9,867		)	16,440			(242		)
Operating income (loss)	(281,565		)	(102,773		)	21,861
Other income (expense):
Interest income	510			810			618
Interest expense	(26,305		)	(3,796		)	(2,338		)
Other – net	(6,839		)	(2,380		)	64
Total other income (expense)	(32,634		)	(5,366		)	(1,656		)
Income (loss) before income tax expense	(314,199		)	(108,139		)	20,205
Income tax expense	64,816			6,943			3,671
Income (loss) from continuing operations	(379,015		)	(115,082		)	16,534
Income (loss) from discontinued operations, net of tax	—			—			2,803
Net income (loss)	(379,015		)	(115,082		)	19,337
Net income attributable to noncontrolling interest	(809		)	(567		)	(196		)
Net income (loss) attributable to stockholders	$	(379,824	)	$	(115,649	)	$	19,141
Basic earnings (loss) per share - continuing operations	$	(8.09	)	$	(2.31	)	$	0.31
Basic earnings (loss) per share - discontinued operations	—			—			0.05
Basic earnings (loss) per share	$	(8.09	)	$	(2.31	)	$	0.36
Diluted earnings (loss) per share - continuing operations	$	(8.09	)	$	(2.31	)	$	0.30
Diluted earnings per share - discontinued operations	—			—			0.06
Diluted earnings (loss) per share	$	(8.09	)	$	(2.31	)	$	0.36
Shares used in the computation of earnings per share:
Basic	46,935			50,129			53,487
Diluted	46,935			50,129			53,709

See accompanying notes to consolidated financial statements.

57

BABCOCK & WILCOX ENTERPRISES, INC.

CONSOLIDATED AND COMBINED STATEMENTS OF COMPREHENSIVE INCOME (LOSS)

	Year Ended December 31,
(in thousands)	2017			2016			2015
Net income (loss)	$	(379,015	)	$	(115,082	)	$	19,337
Other comprehensive income (loss):
Currency translation adjustments, net of taxes	16,150			(24,494		)	(19,459		)
Derivative financial instruments:
Unrealized gains on derivative financial instruments	3,346			2,208			282
Income taxes	142			162			(57		)
Unrealized gains on derivative financial instruments, net of taxes	3,204			2,046			339
Derivative financial instrument (gains) losses reclassified into net income	(2,503		)	(3,598		)	1,557
Income taxes	(234		)	(568		)	424
Reclassification adjustment for (gains) losses included in net income, net of taxes	(2,269		)	(3,030		)	1,133
Benefit obligations:
Unrealized gains (losses) on benefit obligations	(152		)	12,202			462
Income taxes	—			4,510			(57		)
Unrealized gains (losses) on benefit obligations, net of taxes	(152		)	7,692			519
Amortization of benefit plan costs (benefits)	(2,912		)	(254		)	1,042
Income taxes	43			(404		)	1,237
Amortization of benefit plan costs (benefits), net of taxes	(2,955		)	150			(195		)
Other:	75			7			(22		)
Other comprehensive income (loss)	14,053			(17,629		)	(17,685		)
Total comprehensive income (loss)	(364,962		)	(132,711		)	1,652
Comprehensive loss attributable to noncontrolling interest	(778		)	(575		)	(183		)
Comprehensive income (loss) attributable to stockholders	$	(365,740	)	$	(133,286	)	$	1,469

See accompanying notes to consolidated financial statements.

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BABCOCK & WILCOX ENTERPRISES, INC.

CONSOLIDATED BALANCE SHEETS

(in thousands, except per share amount)	December 31, 2017			December 31, 2016
Cash and cash equivalents	$	56,667		$	95,887
Restricted cash and cash equivalents	25,980			27,770
Accounts receivable – trade, net	291,704			282,347
Accounts receivable – other	78,970			73,756
Contracts in progress	161,220			166,010
Inventories	82,162			85,807
Other current assets	35,554			45,957
Total current assets	732,257			777,534
Net property, plant and equipment	141,931			133,637
Goodwill	204,398			267,395
Deferred income taxes	97,826			163,388
Investments in unconsolidated affiliates	43,278			98,682
Intangible assets	76,780			71,039
Other assets	25,759			17,468
Total assets	$	1,322,229		$	1,529,143
Foreign revolving credit facilities	$	9,173		$	14,241
Second lien term loan facility	160,141			—
Accounts payable	225,234			220,737
Accrued employee benefits	30,153			35,497
Advance billings on contracts	181,070			210,642
Accrued warranty expense	39,020			40,467
Other accrued liabilities	99,536			95,954
Total current liabilities	744,327			617,538
United States revolving credit facility	94,300			9,800
Pension and other accumulated postretirement benefit liabilities	256,390			301,259
Other noncurrent liabilities	36,509			39,595
Total liabilities	1,131,526			968,192
Commitments and contingencies
Stockholders' equity:
Common stock, par value $0.01 per share, authorized 200,000 shares; issued and outstanding 44,065 and 48,688 shares at December 31, 2017 and 2016, respectively	499			544
Capital in excess of par value	800,968			806,589
Treasury stock at cost, 5,681 and 5,592 shares at December 31, 2017 and December 31, 2016, respectively	(104,785		)	(103,818		)
Retained deficit	(492,150		)	(114,684		)
Accumulated other comprehensive loss	(22,429		)	(36,482		)
Stockholders' equity attributable to shareholders	182,103			552,149
Noncontrolling interest	8,600			8,802
Total stockholders' equity	190,703			560,951
Total liabilities and stockholders' equity	$	1,322,229		$	1,529,143

See accompanying notes to consolidated financial statements.

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BABCOCK & WILCOX ENTERPRISES, INC.

CONSOLIDATED AND COMBINED STATEMENT OF STOCKHOLDERS' EQUITY

	Common Stock					Capital In Excess of Par Value			Treasury Stock			Retained Earnings			Accumulated Other Comprehensive Income (Loss)			Former Parent Investment			Noncontrolling Interest			Total Stockholders’ Equity
	Shares		Par Value
			(in thousands, except share and per share amounts)
December 31, 2014 Balance	—		$	—		$	—		$	—		$	—		$	10,374		$	676,036		$	1,027		$	687,437
Net income	—		—			—			—			965			—			18,176			196			19,337
Currency translation adjustments	—		—			—			—			—			(19,446		)	—			(13		)	(19,459		)
Derivative financial instruments	—		—			—			—			—			1,472			—			—			1,472
Defined benefit obligations	—		—			—			—			—			324			—			—			324
Available-for-sale investments	—		—			—			—			—			(22		)	—			—			(22		)
Stock-based compensation	137		17			7,772			(1,143		)	—			—			6			—			6,652
Repurchased shares	(1,376	)	(14		)				(24,265		)	—			—			—			—			(24,279		)
Dividends to noncontrolling interests	—		—			—			—			—			—			—			(491		)	(491		)
Net transfers from Parent	—		—			—			—			—			—			125,295			—			125,295
Distribution of Nuclear Energy segment to former Parent	—		—			—			—			—			(11,555		)	(36,284		)	—			(47,839		)
Reclassification of former Parent investment to capital in excess of par value and common stock	53,720		537			782,692			—			—			—			(783,229		)	—			—
December 31, 2015 Balance	52,481		$	540		$	790,464		$	(25,408	)	$	965		$	(18,853	)	$	—		$	719		$	748,427
Net income	—		$	—		$	—		$	—		$	(115,649	)	$	—		$	—		$	567		$	(115,082	)
Currency translation adjustments	—		—			—			—			—			(24,494		)	—			8			(24,486		)
Derivative financial instruments	—		—			—			—			—			(984		)	—			—			(984		)
Defined benefit obligations	—		—			—			—			—			7,842			—			—			7,842
SPIG Acquisition	—		—			—			—			—			—			—			7,754			7,754
Available-for-sale investments	—		—			—			—			—			7			—			—			7
Stock-based compensation charges	423		46			16,125			(2,731		)	—			—			—			—			13,440
Repurchased shares	(4,216	)	(42		)	—			(75,679		)	—			—			—			—			(75,721		)
Dividends to noncontrolling interests	—		—			—			—			—			—			—			(246		)	(246		)
December 31, 2016 Balance	48,688		$	544		$	806,589		$	(103,818	)	$	(114,684	)	$	(36,482	)	$	—		$	8,802		$	560,951
Net income	—		$	—		$	—		$	—		$	(379,824	)	$	—		$	—		$	809		$	(379,015	)
Currency translation adjustments	—		—			—			—			—			16,150			—			(31		)	16,119
Derivative financial instruments	—		—			—			—			—			935			—			—			935
Defined benefit obligations	—		—			—			—			—			(3,107		)	—			—			(3,107		)
Available-for-sale investments	—		—			—			—			—			75			—			—			75
Stock-based compensation charges	212		3			11,005			(967		)	2,358			—			—			—			12,399
Common stock retirement	(4,835	)	(48		)	(16,626		)	—			—			—			—			—			(16,674		)
Dividends to noncontrolling interests	—		—			—			—			—			—			—			(980		)	(980		)
December 31, 2017 Balance	44,065		$	499		$	800,968		$	(104,785	)	$	(492,150	)	$	(22,429	)	$	—		$	8,600		$	190,703

See accompanying notes to consolidated financial statements.

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BABCOCK & WILCOX ENTERPRISES, INC.

CONSOLIDATED AND COMBINED STATEMENTS OF CASH FLOWS

	Year Ended December 31,
(in thousands)	2017			2016			2015
Cash flows from operating activities:
Net income (loss)	$	(379,015	)	$	(115,082	)	$	19,337
Non-cash items included in net income (loss):
Depreciation and amortization of long-lived assets	40,138			39,583			34,932
Amortization of debt issuance costs and debt discount	6,407			1,244			622
(Income) loss from equity method investees	(8,326		)	(16,440		)	242
Goodwill impairment charges	86,903			—			—
Other than temporary impairment of equity method investment in TBWES	18,193			—			—
Losses on asset disposals and impairments	807			14,938			16,881
Write-off of accrued claims receivable, net	—			—			7,832
Provision for (benefit from) deferred income taxes	50,304			(9,000		)	(32,121		)
Mark to market losses (gains) and prior service cost amortization for pension and postretirement plans	(11,608		)	36,346			40,611
Stock-based compensation, net of associated income taxes	11,813			16,129			7,773
Changes in assets and liabilities, net of effects of acquisitions:
Accounts receivable	9,414			46,755			(54,807		)
Dividends from equity method investees	50,134			12,160			20,830
Accrued insurance receivable	—			(15,000		)	—
Contracts in progress and advance billings on contracts	(24,001		)	(13,259		)	62,971
Inventories	11,874			2,869			6,060
Income taxes	26,618			22,593			9,275
Accounts payable	(14,664		)	4,542			17,863
Accrued and other current liabilities	(12,450		)	25,110			11,464
Pension liabilities, accrued postretirement benefits and employee benefits	(44,584		)	(46,973		)	(2,336		)
Other, net	(7,790		)	(4,242		)	2,970
Net cash from operating activities	(189,833		)	2,273			170,399
Cash flows from investing activities:
Decrease in restricted cash and cash equivalents	(2,259		)	9,374			6,298
Investment in equity method investees	—			(26,256		)	(7,424		)
Purchase of property, plant and equipment	(14,278		)	(22,450		)	(35,397		)
Acquisition of business, net of cash acquired	(52,547		)	(144,780		)	—
Proceeds from sale of equity method investment in a joint venture	—			17,995			—
Purchases of available-for-sale securities	(29,252		)	(45,217		)	(14,008		)
Sales and maturities of available-for-sale securities	35,484			29,846			5,266
Other, net	708			646			(587		)
Net cash from investing activities	$	(62,144	)	$	(180,842	)	$	(45,852	)

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BABCOCK & WILCOX ENTERPRISES, INC. CONSOLIDATED AND COMBINED STATEMENTS OF CASH FLOWS (CONTINUED)
	Year Ended December 31,
(in thousands)	2017			2016			2015
Cash flows from financing activities:
Borrowings under our United States revolving credit facility	$	629,722		$	205,600		$	—
Repayments of our United States revolving credit facility	(545,222		)	(195,800		)	—
Proceeds from our second lien term loan facility, net of $34.2 million discount	161,674			—			—
Borrowings under our foreign revolving credit facilities	273			5,674			—
Repayments of our foreign revolving credit facilities	(6,597		)	(20,248		)	(1,080		)
Common stock repurchase from related party	(16,674		)	—			—
Net transfers from our former Parent	—			—			80,589
Shares of our common stock returned to treasury stock	(967		)	(78,410		)	(25,408		)
Debt issuance costs	(15,002		)	—			—
Other	(1,082		)	(246		)	(491		)
Net cash from financing activities	206,125			(83,430		)	53,610
Effects of exchange rate changes on cash	6,632			(7,306		)	(6,407		)
Cash flow from continuing operations	(39,220		)	(269,305		)	171,750
Cash flows from discontinued operations:
Operating cash flows from discontinued operations, net	—			—			(25,194		)
Investing cash flows from discontinued operations, net	—			—			(23		)
Net cash flows from discontinued operations	—			—			(25,217		)
Net increase (decrease) in cash and equivalents	(39,220		)	(269,305		)	146,533
Cash and equivalents, beginning of period	95,887			365,192			218,659
Cash and equivalents, end of period	$	56,667		$	95,887		$	365,192

See accompanying notes to consolidated financial statements.

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BABCOCK & WILCOX ENTERPRISES, INC.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

DECEMBER 31,2017

NOTE 1 – BASIS OF PRESENTATION AND GOING CONCERN CONSIDERATIONS

Basis of presentation

Babcock & Wilcox Enterprises, Inc. ("B&W", "we", "us" or "our") operates in three business segments and was wholly owned by The Babcock & Wilcox Company ("BWC" or the "former Parent") until June 30, 2015 when BWC distributed 100% of our outstanding common stock to the BWC shareholders through a tax-free spin-off transaction (the "spin-off"). BWC is now known as BWX Technologies, Inc.

We have presented our 2017 and 2016 consolidated financial statements and our 2015 consolidated and combined financial statements (collectively referred to herein as the "consolidated financial statements") in United States dollars in accordance with accounting principles generally accepted in the United States ("GAAP"). 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. We present the notes to our consolidated financial statements on the basis of continuing operations, unless otherwise stated.

On June 8, 2015, BWC's board of directors approved the spin-off of B&W through the distribution of shares of B&W common stock to holders of BWC common stock (the "spin-off"). On June 30, 2015, B&W became a separate publicly-traded company, and BWC did not retain any ownership interest in B&W. On and prior to June 30, 2015 our operating results and cash flows consisted of The Power Generation Operations of BWC ("BW PGG"), which represented a combined reporting entity comprised of the assets and liabilities in managing and operating the Power Generation segment of BWC, combined with related captive insurance operations that were contributed in connection with the spin-off by BWC to B&W. In addition, BW PGG also included certain assets and liabilities of BWC's Nuclear Energy ("NE") segment that were transferred to BWC. We have treated the assets, liabilities, operating results and cash flows of the NE business as a discontinued operation in our consolidated financial statements. See Note 26 for further information.

Through June 30, 2015, certain corporate and general and administrative expenses, including those related to executive management, tax, accounting, legal, information technology, treasury services, and certain employee benefits, have been allocated by BWC to us to reflect all costs of doing business related to these operations in the financial statements, including expenses incurred by related entities on our behalf. The majority of these allocations of management and support services costs are based on specific identification methods such as direct usage and level of effort. The remainder is allocated on the basis of a three-factor formula that considered proportional revenue generated, payroll and fixed assets. Management believes such allocations are reasonable. However, the associated expenses reflected in the accompanying 2015 consolidated and combined statements of operations may not be indicative of the actual expenses that would have been incurred had we been operating as an independent public company for the periods presented. Following the spin-off from BWC, we have performed these functions using internal resources or purchased services, certain of which were provided by BWC pursuant to a transition services agreement. Refer to Note 25 for a detailed description of transactions with other affiliates of BWC.

Going concern considerations

The accompanying consolidated financial statements have been prepared on a going concern basis, which contemplates the realization of assets and the discharge of liabilities in the normal course of business for the foreseeable future. The consolidated financial statements do not include any adjustments that might result from the outcome of the going concern uncertainty other than the reclassification of our second lien term loan facility to current liabilities.

Additional losses we recognized in the fourth quarter of 2017 related to an increase in structural steel repair costs on one of our European renewable energy contracts led to us seek an amendment of our lending arrangement. The additional losses we recognized in the fourth quarter of 2017 caused us to be out of compliance with certain financial covenants in our lending arrangements at December 31, 2017. We obtained an amendment to our United States Revolving Credit Facility on March 1, 2018 that temporarily waived the financial covenant defaults that existed at December 31, 2017. We face liquidity challenges related to our non-compliance with the financial covenants associated with our Second Lien Term Loan Facility at December 31, 2017, which may be difficult to resolve in a timely manner. Our Second Lien Term Loan Agreement contains a 180-day standstill period beginning on March 1, 2018 to resolve the event of default or repay the loan as described in Note

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20. Our financing plan includes raising additional capital through a rights offering and other sources before the end of the standstill period, which will depend on conditions in the capital markets and, with respect to the rights offering, an amendment to our existing shelf registration statement that we plan to file in early March 2018 being declared effective by the Securities and Exchange Commission ("SEC"), which are matters that are outside of our control.

We have initiated steps to remedy the going concern uncertainty, which include, but are not limited to:

• secured an equity commitment agreement on March 1, 2018 with a group of our existing stockholders to fully backstop our planned rights offering for the purpose of providing approximately $182 million of new capital, in the form of new equity, that together with $35 million of borrowings permitted by our United States revolving credit facility we intend to use to extinguish the outstanding balance of our second lien term loan facility and terminate the associated borrowing agreement;

• mitigating, to the extent possible, the adverse impact of our net losses and financial covenant defaults over the past two years on our core operations, customers, vendors and banking relationships (e.g., providers of bank guarantees, letters of credit and surety bonds);

• entered into employee retention agreements with key members of management;

• dedicating project management resources to the performance, efficiency and timely completion of our existing and forecasted portfolio of contracts; and

• selling certain assets or exiting certain markets, if we believe the opportunity would improve stockholder value and our liquidity outlook.

While we believe that the actions summarized above are more likely than not to address the substantial doubt about our ability to continue as a going concern, we cannot assert that it is probable that our plans will fully mitigate the conditions identified. If we cannot continue as a going concern, material adjustments to the carrying values and classifications of our assets and liabilities and the reported amounts of income and expense could be required.

NOTE 2 – SIGNIFICANT ACCOUNTING POLICIES

Reportable segments

We operate in three reportable segments. Our reportable segments are as follows:

•

• Power: Focused on technologies and aftermarket services for steam-generating, environmental, and auxiliary equipment for power generation and other industrial applications.

• Renewable: Focused on the supply of steam-generating systems, environmental and auxiliary equipment for the waste-to-energy and biomass power generation industries.

• Industrial: Focused on custom-engineered cooling, environmental, acoustic, emission and filtration solutions, other industrial equipment and related aftermarket services.

For financial information about our segments see Note 4 to our consolidated financial statements.

Use of estimates

We use estimates and assumptions to prepare our consolidated financial statements in conformity with GAAP. Some of our more significant estimates include our estimate of costs to complete long-term construction contracts, estimates associated with assessing whether goodwill and other long-lived assets are impaired, estimates of costs to be incurred to satisfy contractual warranty requirements, estimates of the value of acquired intangible and tangible assets, estimates associated with the realizability of deferred tax assets, estimates associated with determining the fair value of the transactions with American Industrial Partners (see Note 20) and estimates we make in selecting assumptions related to the valuations of our pension and postretirement plans, including the selection of our discount rates, mortality and expected rates of return on our pension plan assets. These estimates and assumptions affect the amounts we report in our consolidated 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. We have a number of forms of stock-based

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compensation, including incentive and non-qualified stock options, restricted stock, restricted stock units, performance shares and performance units, subject to satisfaction of specific performance goals. We include the shares applicable to these plans in dilutive earnings per share when related performance criteria have been met.

Investments

Our investments, primarily 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 (loss). 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 - net in our consolidated statements of operations. 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 United States dollars at current exchange rates, and we translate items in our statement of operations 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 (loss). We report foreign currency transaction gains and losses in income. We have included in other - net transaction gains (losses) of $2.9 million, $(5.4) million and $(0.1) million in the years ended December 31, 2017, 2016 and 2015, 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 contract. 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 invoices that exceed accumulated contract costs and revenues and costs recognized under the percentage-of-completion method. Contracts in progress and advance billings on contracts balances are classified as current assets and liabilities, respectively, in our consolidated balance sheets based on the life cycle of the associated contracts. 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 contract loss is recognized in full in the statement of operations and an accrual for the estimated loss on the uncompleted contract is included in other current liabilities in the balance sheet. In addition, when we determine that an uncompleted contract will not be completed on-time and the contract has liquidated damages provisions, we recognize the estimated liquidated damages we will incur and record them as a reduction of the estimated selling price in the period the change in estimate occurs.

For contracts that 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.

As of December 31, 2017, we have estimated the costs to complete all of our in-process contracts in order to estimate revenues in accordance with the percentage-of-completion method of accounting. 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, transportation, fluctuations in foreign exchange rates 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

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and cash flows. Alternatively, reductions in overall contract costs at completion could materially improve our consolidated financial condition, results of operations and cash flows. Variations from estimated contract performance could result in material adjustments to operating results for any fiscal quarter or year.

We recognize accrued claims in contract revenues for extra work or changes in scope of work to the extent of costs incurred when we believe the following accounting criteria have been met:

a) The contract or other evidence provides a legal basis for the claim; or a legal opinion has been obtained, stating that under the circumstances there is a reasonable basis to support the claim.

b) Additional costs are caused by circumstances that were unforeseen at the contract date and are not the result of deficiencies in the contractor's performance.

c) Costs associated with the claim are identifiable or otherwise determinable and are reasonable in view of the work performed.

d) The evidence supporting the claim is objective and verifiable, not based on unsupported representations.

Warranty expense

We accrue estimated expense included in cost of operations on our consolidated statements of operations to satisfy contractual warranty requirements when we recognize the associated revenues on the related contracts. In addition, we record 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.

Research and development

Our research and development activities are related to the development and improvement of new and existing products, services and equipment. Research and development activities totaled $9.4 million, $10.4 million and $16.5 million in the years ended December 31, 2017, 2016 and 2015, respectively.

In the twelve months ended December 31, 2015, we recognized a $14.6 million impairment charge primarily related to research and development facilities and equipment dedicated to activities that were determined not to be commercially viable. The impairment is included in losses on asset disposals and impairments in the consolidated statements of operations.

Pension plans and postretirement benefits

We sponsor various defined benefit pension and postretirement plans covering certain employees of our United States and international subsidiaries. We use actuarial valuations to calculate the cost and benefit obligations of our pension and postretirement benefits. The actuarial valuations use significant assumptions in the determination of our benefit cost and obligations, including assumptions regarding discount rates, expected returns on plan assets, mortality and health care cost trends.

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 and postretirement plan obligations. In 2016, we changed our approach to developing the discount rate from a single equivalent discount rate to an alternative spot rate method. This new method was adopted because it more accurately applies each year's spot rates to the projected cash flows. This change in estimate was applied prospectively in developing our annual discount rate, which resulted in a lower interest and service cost during 2016.

The components of benefit cost related to service cost, interest cost, expected return on plan assets and prior service cost amortization are recorded on a quarterly basis based on actuarial assumptions. In the fourth quarter of each year, or as interim remeasurements are required, we recognize net actuarial gains and losses into earnings as a component of net periodic benefit cost (mark to market adjustment). Recognized net actuarial gains and losses consist primarily of our reported actuarial gains and losses and the difference between the actual return on plan assets and the expected return on plan assets.

We recognize the funded status of each plan as either an asset or a liability in the consolidated balance sheets. The funded status is the difference between the fair value of plan assets and the present value of its benefit obligation, determined on a plan-by-plan basis. See Note 18 for a detailed description of our plan assets.

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Income taxes

Income tax expense for federal, foreign, state and local income taxes are calculated on pre-tax income based on the income tax law in effect at the latest balance sheet date, and includes 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 our consolidated 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 statements of operations.

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.

Trade accounts receivable and allowance for doubtful accounts

Our trade accounts receivable balance is stated at the amount owed by our customers, net of allowances for estimated uncollectible balances. We maintain allowances for doubtful accounts for estimated losses expected to result from the inability of our customers to make required payments. These estimates are based on management’s evaluation of the ability of customers to make payments, with emphasis on historical remittance experience, known customer financial difficulties and the age of receivable balances. Accounts receivable are charged to the allowance when it is determined they are no longer collectible. Our allowance for doubtful accounts was $11.0 million and $9.4 million at December 31, 2017 and 2016, respectively. Amounts charged to selling, general and administrative expenses or deducted from the allowance were not significant to our statement of operations in the years ended December 31, 2017, 2016 and 2015.

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 segment, for which we use the last-in, first-out ("LIFO") method. We determined the cost of approximately 16% and 18% of our total inventories using the LIFO method at December 31, 2017 and 2016, respectively, and our total LIFO reserve at December 31, 2017 and 2016 was approximately $7.0 million and $7.0 million, respectively. The components of inventories can be found in Note 13.

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 33 years for buildings and three to 28 years for machinery and equipment. Our depreciation expense was $21.9 million, $19.7 million and $23.5 million for the years ended December 31, 2017, 2016 and 2015, 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.

Investments in unconsolidated joint ventures

We use the equity method of accounting for investments in joint ventures in which we are able to exert significant influence, but not control. Joint ventures in which our investment ownership is less than 20% and where we are unable to exert significant influence are carried at cost. We assess our investments in unconsolidated joint ventures for other-than-temporary-impairment when significant changes occur in the investee's business or our investment philosophy. Such changes might include a series of operating losses incurred by the investee that are deemed other than temporary, the inability of the investee to sustain an earnings capacity that would justify the carrying amount of the investment or a change in the strategic reasons that were important when we originally entered into the joint venture. If an other-than-temporary-impairment were to occur, we would measure our investment in the unconsolidated joint venture at fair value.

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Goodwill

Goodwill represents the excess of the cost of our acquired businesses over the fair value of the net assets acquired. We perform testing of goodwill for impairment annually. We may elect to perform a qualitative test when we believe that there is sufficient excess fair value over carrying value based on our most recent quantitative assessment, adjusted for relevant events and circumstances that could affect fair value during the current year. If we conclude based on this assessment that it is more likely than not that the reporting unit is not impaired, we do not perform a quantitative impairment test. In all other circumstances, we utilize a two-step quantitative impairment test to identify potential goodwill impairment and measure the amount of any goodwill impairment. 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.

Intangible assets

Intangible assets are recognized at fair value when acquired. Intangible assets with definite lives are amortized to operating expense using the straight-line method over their estimated useful lives and tested for impairment when events or changes in circumstances indicate that their carrying amounts may not be recoverable. Intangible assets with indefinite lives are not amortized and are subject to annual impairment testing. We may elect to perform a qualitative assessment when testing indefinite lived intangible assets for impairment to determine whether events or circumstances affecting significant inputs related to the most recent quantitative evaluation have occurred, indicating that it is more likely than not that the indefinite lived intangible asset is impaired. Otherwise, we test indefinite lived intangible assets for impairment by quantitatively determining the fair value of the indefinite lived intangible asset and comparing the fair value of the intangible asset to its carrying amount. If the carrying amount of the intangible asset exceeds its fair value, we recognize impairment for the amount of the difference.

Derivative financial instruments

Our global operations expose us to changes in foreign currency exchange ("FX") rates. We use derivative financial instruments, primarily 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 derivative financial instruments for trading or other speculative purposes.

We enter into derivative financial instruments primarily as hedges of certain firm purchase and sale commitments and certain intercompany loans denominated in foreign currencies. We record these contracts at fair value on our consolidated balance sheets and defer the related gains and losses in stockholders' equity as a component of accumulated other comprehensive income (loss) until the hedged item is recognized in earnings. Any ineffective portion of a derivative's change in fair value and any portion excluded from the assessment of effectiveness is immediately recognized in other – net on our consolidated statements of operations. 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 – net in our consolidated statements of operations.

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 $23.1 million and $24.1 million at the years ended December 31, 2017 and 2016, respectively.

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

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litigation, as discussed in Note 21. 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 Financial Accounting Standards Board ("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"). For performance shares or units granted in the years ended December 31, 2017 and 2016 that contain a Relative Total Shareholder Return vesting criteria, we utilize a Monte Carlo simulation to determine the grant date fair value, which determines the probability of satisfying the market condition included in the award. The determination of the fair value of a share-based payment award using an option-pricing model requires the input of significant assumptions, such as the expected life of the award and stock price volatility.

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

During the year ended December 31, 2017, the Company adopted ASU 2016-09, Compensation - Stock Compensation (Topic 718): Improvements to Employee Share-based Payment Accounting. This new accounting standard has affected how we account for share-based payments, with the most significant impact being the impact of income taxes associated with share-based compensation. Subsequent to adoption, the income tax effects related to share-based payments will be recorded as a component of income tax expense (or benefit) as they occur, rather than being classified as a component of additional paid-in capital. In addition, the effect of excess tax benefits will now be presented in the cash flow statement as an operating activity. We prospectively adopted the new accounting standard. See Note 10 for the effect on the statement of operations for the twelve months ended December 31, 2017.

During the year ended December 31, 2017, the Company prospectively adopted ASU 2015-11, Inventory (Topic 330): Simplifying the Measurement of Inventory. This new accounting standard requires that first-in, first-out inventory be measured at the lower of cost or net realizable value. Under GAAP prior to the adoption of this new accounting standard, inventory was measured at the lower of cost or market, where market was defined as replacement cost, with a ceiling of net realizable value and a floor of net realizable value minus a normal profit margin. Although this new accounting standard raises the threshold on when charges against inventory can occur, it did not significantly impact our consolidated financial statements upon adoption and we do not expect it will significantly impact our operating results in future periods because we have not had significant inventory charges in the past.

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NOTE 3 – EARNINGS PER SHARE

The following table sets forth the computation of basic and diluted earnings per share of our common stock, net of noncontrolling interest:

	Year Ended December 31,
(in thousands, except per share amounts)	2017			2016			2015
Income (loss) from continuing operations	$	(379,824	)	(115,649		)	$	16,338
Income (loss) from discontinued operations, net of tax	—			—			2,803
Net income (loss) attributable to shareholders	$	(379,824	)	$	(115,649	)	$	19,141
Weighted average shares used to calculate basic earnings per share	46,935			50,129			53,487
Dilutive effect of stock options, restricted stock and performance shares	—			—			222
Weighted average shares used to calculate diluted earnings per share	46,935			50,129			53,709
Basic earnings (loss) per share:
Continuing operations	$	(8.09	)	$	(2.31	)	$	0.31
Discontinued operations	—			—			0.05
Basic earnings (loss) per share:	$	(8.09	)	$	(2.31	)	$	0.36
Diluted earnings (loss) per share:
Continuing operations	(8.09		)	(2.31		)	0.30
Discontinued operations	—			—			0.06
Diluted earnings (loss) per share:	$	(8.09	)	$	(2.31	)	$	0.36

Because we incurred a net loss in the years ended December 31, 2017 and 2016, basic and diluted shares are the same.

If we had net income in the years ended December 31, 2017 and 2016, diluted shares would include an additional 0.4 million and 0.5 million shares, respectively.

We excluded 2.0 million, 3.4 million and 1.3 million shares related to stock options from the diluted share calculation for the years ended December 31, 2017, 2016 and 2015, respectively, because their effect would have been anti-dilutive.

NOTE 4 – SEGMENT REPORTING

Our operations are assessed based on three reportable segments, which are summarized as follows:

• Power segment: focused on the supply of and aftermarket services for steam-generating, environmental and auxiliary equipment for power generation and other industrial applications.

• Renewable segment: focused on the supply of steam-generating systems, environmental and auxiliary equipment for the waste-to-energy and biomass power generation industries.

• Industrial segment: focused on custom-engineered cooling, environmental and other industrial equipment along with related aftermarket services.

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An analysis of our operations by segment is as follows:

	Year Ended December 31,
(in thousands)	2017			2016			2015
REVENUES
Power segment
Retrofits & continuous emissions monitoring systems	$	306,758		$	392,854		$	427,378
New build utility and environmental	155,886			292,302			403,981
Aftermarket parts and field engineering services	277,129			292,535			304,923
Industrial steam generation	123,127			107,267			219,379
Eliminations	(41,838		)	(102,980		)	(120,664		)
	821,062			981,978			1,234,997
Renewable segment
Renewable new build and services	282,228			284,684			277,326
Operations and maintenance	64,970			65,814			63,437
Eliminations	—			(1,326		)	(2,160		)
	347,198			349,172			338,603
Industrial segment
Aftermarket parts and services	117,970			81,690			61,350
Environmental solutions	138,722			74,726			90,343
Cooling systems	126,683			73,797			—
Engineered products	14,416			23,400			32,002
	397,791			253,613			183,695
Eliminations	(8,316		)	(6,500		)	—
	$	1,557,735		$	1,578,263		$	1,757,295

The segment information presented in the table above reflects the product line revenues that are reviewed by each segment's manager. These gross product line revenues exclude eliminations of revenues generated from sales to other segments or to other product lines within the segment. The primary component of the Power segment elimination is revenue associated with construction services.

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	Year Ended December 31,
(in thousands)	2017			2016			2015
GROSS PROFIT (LOSS)
Power segment	$	191,999		$	233,550		$	247,632
Renewable segment	(128,204		)	(68,109		)	57,682
Industrial segment	41,383			50,726			54,826
Intangible amortization expense included in cost of operations	(14,272		)	(15,842		)	(7,676		)
Mark to market gain (loss) included in cost of operations	8,972			(21,208		)	(44,307		)
	99,878			179,117			308,157
Selling, general and administrative ("SG&A") expenses	(255,545		)	(240,166		)	(240,296		)
Goodwill impairment charges	(86,903		)	—			—
Restructuring activities and spin-off transaction costs	(15,447		)	(40,807		)	(14,946		)
Research and development costs	(9,412		)	(10,406		)	(16,543		)
Intangible amortization expense included in SG&A	(3,980		)	(4,081		)	(3,769		)
Mark to market gain (loss) included in SG&A	(274		)	(2,902		)	4,097
Equity in income of investees	8,326			16,440			(242		)
Impairment of equity method investment	(18,193		)	—			—
Gains (losses) on asset disposals, net	(15		)	32			(14,597		)
Operating income (loss)	$	(281,565	)	$	(102,773	)	$	21,861

	Year Ended December 31,
(in thousands)	2017		2016		2015
DEPRECIATION AND AMORTIZATION
Power segment	$	9,222	$	11,231	$	18,532
Renewable segment	3,208		2,711		2,567
Industrial segment	20,293		19,073		10,345
Segment depreciation and amortization	32,723		33,015		31,444
Corporate	7,415		6,568		3,488
Total depreciation and amortization	$	40,138	$	39,583	$	34,932

We do not separately identify or report our Company's assets by segment as the majority of our assets are shared by the Power and Renewable segments. Additionally, our chief operating decision maker does not consider assets by segment to be a critical measure by which performance is measured.

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Information about our consolidated operations in different geographic areas

	Year Ended December 31,
(in thousands)	2017		2016		2015
REVENUES(1)
United States	$	757,159	$	851,955	$	1,034,653
United Kingdom	194,456		201,221		126,285
Canada	108,045		74,629		134,276
Denmark	82,843		54,722		116,064
China	54,883		33,898		41,921
Egypt	43,148		35,878		—
South Korea	41,217		44,660		4,358
Sweden	39,891		24,809		18,302
Germany	28,333		29,559		19,233
Vietnam	15,771		55,265		46,803
Dominican Republic	15,144		21,366		82,916
Saudi Arabia	13,978		2,408		4,220
South Africa	12,453		4,097		4,486
Italy	11,663		7,862		4,671
Netherlands	8,989		3,348		4,651
Finland	8,713		5,756		6,113
Bolivia	8,694		—		—
Oman	7,683		—		—
Indonesia	6,909		6,723		1,730
Nigeria	6,766		—		—
India	6,441		6,856		13,108
Aggregate of all other countries, each with less than $5 million in revenues	84,556		113,251		93,505
	$	1,557,735	$	1,578,263	$	1,757,295

⁽¹⁾ We allocate geographic revenues based on the location of the customer's operations.

	Year Ended December 31,
(in thousands)	2017		2016		2015
NET PROPERTY, PLANT AND EQUIPMENT
United States	$	79,681	$	75,368	$	88,840
Mexico	26,503		22,594		24,643
China	13,373		13,460		13,956
United Kingdom	6,604		6,337		8,070
Denmark	7,953		6,749		6,265
Aggregate of all other countries, each with less than $5 million of net property, plant and equipment	7,817		9,129		3,943
	$	141,931	$	133,637	$	145,717

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NOTE 5 – ACQUISITIONS

Universal Acoustic & Emission Technologies, Inc.

On January 11, 2017, we acquired Universal Acoustic & Emission Technologies, Inc. ("Universal") for approximately $52.5 million in cash, funded primarily by borrowings under our United States revolving credit facility, net of $4.4 million cash acquired in the business combination. Transaction costs included in the purchase price were approximately $0.2 million. We accounted for the Universal acquisition using the acquisition method, whereby all of the assets acquired and liabilities assumed were recognized at their fair value on the acquisition date, with any excess of the purchase price over the estimated fair value recorded as goodwill. In order to purchase Universal on January 11, 2017, we borrowed approximately $55.0 million under the United States revolving credit facility in 2017.

Universal provides custom-engineered acoustic, emission and filtration solutions to the natural gas power generation, mid-stream natural gas pipeline, locomotive and general industrial end-markets. Universal's product offering includes gas turbine inlet and exhaust systems, silencers, filters and enclosures. At the acquisition date, Universal employed approximately 460 people, mainly in the United States and Mexico. During 2017, we integrated Universal with our Industrial segment. Universal contributed $69.1 million of revenue and $14.5 million of gross profit to our operating results in the year ended December 31, 2017.

The allocation of the purchase price based on the fair value of assets acquired and liabilities assumed is set forth below. We finalized the purchase price allocation associated with the valuation of certain intangible assets and deferred tax balances at December 31, 2017; as a result, the provisional measurements of intangible assets, goodwill and deferred income tax balances did not change.

(in thousands)	Acquisition date fair values
Cash	$	4,379
Accounts receivable	11,270
Contracts in progress	3,167
Inventories	4,585
Other assets	579
Property, plant and equipment	16,692
Goodwill	14,413
Identifiable intangible assets	19,500
Deferred income tax assets	935
Current liabilities	(10,833		)
Other noncurrent liabilities	(1,423		)
Deferred income tax liabilities	(6,338		)
Net acquisition cost	$	56,926

The intangible assets included above consist of the following:

	Fair value (in thousands)		Weighted average estimated useful life (in years)
Customer relationships	$	10,800	15
Backlog	1,700		1
Trade names / trademarks	3,000		20
Technology	4,000		7
Total amortizable intangible assets	$	19,500

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The acquisition of Universal resulted in an increase in our intangible asset amortization expense during the year ended December 31, 2017 of $3.1 million, which is included in cost of operations in our consolidated statement of operations. Amortization of intangible assets is not allocated to segment results.

Approximately $1.7 million of acquisition and integration related costs of Universal was recorded as a component of our SG&A expenses in the consolidated statement of operations in the year ended December 31, 2017.

The following unaudited pro forma financial information below represents our results of operations for year ended December 31, 2016 had the Universal acquisition occurred on January 1, 2016. The unaudited pro forma financial information below is not intended to represent or be indicative of our actual consolidated results had we completed the acquisition at January 1, 2016. This information should not be taken as representative of our future consolidated results of operations.

	Year Ended
(in thousands)	December 31, 2016
Revenues	$	1,660,986
Net income (loss) attributable to B&W	(113,940		)
Basic earnings per common share	(2.27		)
Diluted earnings per common share	(2.27		)

The unaudited pro forma results included in the table above reflect the following pre-tax adjustments to our historical results:

• A net increase in amortization expense related to timing of amortization of the fair value of identifiable intangible assets acquired of $2.8 million in the year ended December 31, 2016.

• Elimination of the historical interest expense recognized by Universal of $0.4 million in the year ended December 31, 2016.

• Elimination of $2.1 million in transaction related costs recognized in the year ended December 31, 2016.

SPIG S.p.A.

On July 1, 2016, we acquired all of the outstanding stock of SPIG S.p.A. ("SPIG") for €155.0 million (approximately $172.1 million) in an all-cash transaction, which wassubject to post-closing adjustments. During September 2016, €2.6 million (approximately $2.9 million) of the transaction price was returned to B&W based on the difference between the actual working capital and pre-close estimates. Transaction costs included in the purchase price associated with closing the acquisition of SPIG on July 1, 2016 were approximately $0.3 million.

Based in Arona, Italy, SPIG is a global provider of custom-engineered comprehensive dry and wet cooling solutions and aftermarket services to the power generation industry including natural gas-fired and renewable energy power plants, as well as downstream oil and gas, petrochemical and other industrial end markets. The acquisition of SPIG was consistent with B&W's goal to grow and diversify its technology-based offerings with new products and services in the industrial markets that are complementary to our core businesses.In the year ended December 31, 2016, SPIG contributed $96.3 million of revenue and $7.8 million of gross profit to the Industrial segment.

We accounted for the SPIG acquisition using the acquisition method. All of the assets acquired and liabilities assumed were recognized at their estimated fair value as of the acquisition date. Any excess of the purchase price over the estimated fair values of the net assets acquired was recorded as goodwill. Several valuation methods were used to determine the fair value of the assets acquired and liabilities assumed. For intangible assets, we used the income method, which required us to forecast the expected future net cash flows for each intangible asset. These cash flows were then adjusted to present value by applying an appropriate discount rate that reflects the risk factors associated with the projected cash flows. Some of the more significant estimates and assumptions inherent in the income method include the amount and timing of projected future cash flows, the discount rate selected to measure the risks inherent in the future cash flows and the assessment of the asset's economic life and the competitive trends impacting the asset, including consideration of any technical, legal, regulatory or economic barriers to entry. Determining the useful life of an intangible asset also required judgment as different types of intangible assets will have different useful lives, or indefinite useful lives.

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The allocation of the purchase price, based on the fair value of assets acquired and liabilities assumed, is detailed below.

(in thousands)	Acquisition date fair values
Cash	$	25,994
Accounts receivable	58,843
Contracts in progress	61,155
Inventories	2,554
Other assets	7,341
Property, plant and equipment	6,104
Goodwill	72,401
Identifiable intangible assets	55,164
Deferred income tax assets	5,550
Revolving debt	(27,530		)
Current liabilities	(56,323		)
Advance billings on contracts	(15,226		)
Other noncurrent liabilities	(379		)
Deferred income tax liabilities	(17,120		)
Noncontrolling interest in joint venture	(7,754		)
Net acquisition cost	$	170,774

We finalized the purchase price allocation as of December 31, 2016, which resulted in a $2.5 million increase in goodwill. The goodwill arising from the purchase price allocation of the SPIG acquisition is believed to be a result of the synergies created from combining its operations with B&W's, and the growth it canprovide from its wide scope of engineered cooling and service offerings and customer base.Noneof this goodwill is expected to be deductible for tax purposes. Also, seeNote 15for the results of our subsequent goodwill impairment assessments

The intangible assets included above consist of the following:

(in thousands)	Fair value (in thousands)		Weighted average estimated useful life (in years)
Customer relationships	$	12,217	9
Backlog	17,769		2
Trade names / trademarks	8,885		20
Technology	14,438		10
Non-compete agreements	1,666		3
Internally-developed software	189		3
Total amortizable intangible assets	$	55,164

The acquisition of SPIG added $9.1 million and $13.3 million of intangible asset amortization expense in the years ended December 31, 2017 and 2016, respectively. Amortization of intangible assets is not allocated to segment results.

Approximately $1.6 million and $3.5 million of acquisition and integration related costs of SPIG was recorded as selling, general and administrative expenses in the consolidated statement of operations for the years ended December 31, 2017 and 2016, respectively.

The following unaudited pro forma financial information below represents our results of operations for years endedDecember 31, 2016and2015had the SPIG acquisition occurred on January 1, 2015. The unaudited pro forma financial information below is not intended to represent or be indicative of our actual consolidated results had we completed the acquisition at January 1, 2015. This information should not be taken as representative of our future consolidated results of operations.

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	Year Ended December 31,
(in thousands)	2016			2015
Revenues	$	1,663,126		$	1,941,987
Net income (loss) attributable to B&W	(111,500		)	12,047
Basic earnings per common share	(2.22		)	0.23
Diluted earnings per common share	(2.22		)	0.22

The unaudited pro forma results included in the table above reflect the following pre-tax adjustments to our historical results:

• A net increase (decrease) in amortization expense related to timing of amortization of the fair value of identifiable intangible assets acquired of $6.5 million and $18.6 million in the years ended December 31, 2016 and 2015, respectively.

• Elimination of the historical interest expense recognized by SPIG of $0.5 million and $0.7 million in the years ended ended December 31, 2016 and 2015, respectively.

• Elimination of $3.5 million and $0.2 million in transaction related costs recognized in the years ended December 31, 2016 and 2015, respectively.

NOTE 6 – CONTRACTS AND REVENUE RECOGNITION

We generally recognize revenues and related costs from long-term contracts on a percentage-of-completion basis. Accordingly, we review contract price and cost estimates regularly as work progresses and reflect adjustments in profit proportionate to the percentage of completion in the periods in which we revise estimates to complete the contract. To the extent that these adjustments result in a reduction of previously reported profits from a contract, we recognize a charge against current earnings. If a contract is estimated to result in a loss, that loss is recognized in the current period as a charge to earnings and the full loss is accrued on our balance sheet, which results in no expected gross profit from the loss contract in the future unless there are revisions to our estimated revenues or costs at completion in periods following the accrual of the contract loss. Changes in the estimated results of our percentage-of-completion contracts are necessarily based on information available at the time that the estimates are made and are based on judgments that are inherently uncertain as they are predictive in nature. As with all estimates to complete used to measure contract revenue and costs, actual results can and do differ from our estimates made over time.

In the years ended December 31, 2017 and 2016 and 2015, we recognized changes in estimated gross profit related to long-term contracts accounted for on the percentage-of-completion basis, which are summarized as follows:

	Year Ended December 31,
(in thousands)	2017			2016			2015
Increases in estimates for percentage-of-completion contracts	$	21,638		$	42,368		$	36,653
Decreases in estimates for percentage-of-completion contracts	(174,906		)	(149,169		)	(36,235		)
Net changes in estimates for percentage-of-completion contracts	$	(153,268	)	$	(106,801	)	$	418

We had four renewable energy projects in Europe that were loss contracts at December 31, 2016. During 2017, two additional renewable energy projects in Europe became loss contracts. In the years ended December 31, 2017 and December 31, 2016, we recorded $158.5 million and $141.1 million, respectively, in net losses resulting from changes in the estimated revenues and costs to complete certain European renewable energy contracts, of which $34.7 million and $98.1 million were recorded in the three months ended December 31, 2017 and 2016, respectively. These changes in estimates in the years ended December 31, 2017 and December 31, 2016 included an increase in our estimate of anticipated liquidated damages that reduced revenue associated with these six projects of $41.3 million and $35.8 million, respectively, of which $14.3 million and $35.8 million were recorded in the three months ended December 31, 2017 and December 31, 2016, respectively. The total anticipated liquidated damages associated with these six projects was $77.1 million and $35.8 million at December 31, 2017 and December 31, 2016, respectively.

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The charges recorded in the twelve months ended December 31, 2017 were due to revisions in the estimated revenues and costs at completion during the period, primarily as a result of (a) structural steel design issues on the second, fourth and fifth projects (discussed further below) including the anticipated schedule impact, (b) scheduling delays and (c) shortcomings in our subcontractors' estimated productivity. Also included in the charges recorded in the twelve months ended December 31, 2017 were corrections that reduced (increased) estimated contract losses at completion by $1.0 million relating to the three months ended December 31, 2016. Management determined this amount was immaterial to the consolidated financial statements in the previous year. As of December 31, 2017, the status of these six loss contracts was as follows:

The first project became a loss contract in the second quarter of 2016. As of December 31, 2017, this project is approximately 98% complete and construction activities are complete as of the date of this report. The unit became operational during the second quarter of 2017, and turnover activities linked to the customer's operation of the facility are expected to be completed during the second quarter of 2018. During the year ended December 31, 2017, we recognized additional contract losses of $20.8 million on the project as a result of differences in actual and estimated costs and schedule delays, $5.8 million of which was recorded in the three months ended December 31, 2017. Our estimate at completion as of December 31, 2017 includes $9.6 million of total expected liquidated damages. As of December 31, 2017, the reserve for estimated contract losses recorded in "other accrued liabilities" in our consolidated balance sheet was $1.6 million. In the year ended December 31, 2016, we recognized charges of $50.3 million (net of accrued insurance proceeds), and as of December 31, 2016, this project had $6.4 million of accrued losses and was 88% complete.

The second project became a loss contract in the fourth quarter of 2016. As of December 31, 2017, this contract was approximately 81% complete, and we expect construction will be completed on this project in mid 2018. During the year ended December 31, 2017, we recognized contract losses of $47.8 million on this project as a result of changes in construction cost estimates and schedule delays, $12.4 million of which was recorded in the three months ended December 31, 2017. Our estimate at completion as of December 31, 2017 includes $20.1 million of total expected liquidated damages due to schedule delays. Our estimate at completion as of December 31, 2017 also includes contractual bonus opportunities for guaranteed higher power output (discussed further below). As of December 31, 2017, the reserve for estimated contract losses recorded in "other accrued liabilities" in our consolidated balance sheet was $12.8 million. In the year ended December 31, 2016, we recognized charges of $28.1 million, and as of December 31, 2016, this project had $5.1 million of accrued losses and was 67% complete.

The third project became a loss contract in the fourth quarter of 2016. As of December 31, 2017, this contract was approximately 98% complete and construction activities are complete as of the date of this report. The unit became operational during the second quarter of 2017, and turnover activities linked to the customer's operation of the facility are expected to be completed during the first quarter of 2018. During the year ended December 31, 2017, we recognized additional contract losses of $10.2 million as a result of changes in the estimated costs at completion, $3.0 million of which was recorded in the three months ended December 31, 2017. Our estimate at completion as of December 31, 2017 includes $7.1 million of total expected liquidated damages due to schedule delays. As of December 31, 2017, the reserve for estimated contract losses recorded in "other accrued liabilities" in our consolidated balance sheet was $0.7 million. In the year ended December 31, 2016, we recognized charges of $30.1 million, and as of December 31, 2016, this project had $3.9 million of accrued losses and was 82% complete.

The fourth project became a loss contract in the fourth quarter of 2016. As of December 31, 2017, this contract was approximately 85% complete, and we expect construction will be completed on this project in mid 2018. During the year ended December 31, 2017, we revised our estimated revenue and costs at completion for this loss contract, which resulted in contract losses of $26.0 million, $8.6 million of which was recorded in the three months ended December 31, 2017. Our estimate at completion as of December 31, 2017 includes $13.7 million of total expected liquidated damages due to schedule delays. Our estimate at completion as of December 31, 2017 also includes contractual bonus opportunities for guaranteed higher power output (discussed further below). The changes in the status of this project in 2017 were primarily attributable to changes in the estimated costs at completion and an increase estimated liquidated damages. As of December 31, 2017, the reserve for estimated contract losses recorded in "other accrued liabilities" in our consolidated balance sheet was $4.7 million. In the year ended December 31, 2016, we recognized charges of $16.4 million, and as of December 31, 2016, this project had $1.6 million of accrued losses and was 61% complete.

The fifth project became a loss contract in the second quarter of 2017. As of December 31, 2017, this contract was approximately 64% complete, and we expect construction will be completed on this project in late 2018. During the year ended December 31, 2017, we revised our estimated revenue and costs at completion for this loss contract, which resulted in additional contract losses of $40.2 million, $4.9 million of which was recorded in the three months ended December 31, 2017. The change in the status of this project in 2017 was primarily attributable to changes in the estimated costs at completion and schedule delays. Our estimate at completion as of December 31, 2017 includes $20.0 million of

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total expected liquidated damages due to schedule delays. As of December 31, 2017, the reserve for estimated contract losses recorded in "other accrued liabilities" in our consolidated balance sheet was $14.3 million. Further, in late February 2018, we became aware that our partner responsible for civil works on this project would be filing for administration in the United Kingdom (similar to bankruptcy protection in the United States). While we are still evaluating the effect on us, we may assume all of their remaining scope on this project. Our preliminary estimate of costs to complete their remaining scope is up to $10 million. We will pursue multiple paths to recover any additional costs we incur as a result of our partner filing for administration, including a performance bond posted by our partner.

The sixth project became a loss contract in the second quarter of 2017. As of December 31, 2017, this contract was approximately 76% complete, and we expect construction will be completed on this project in the second half of 2018. During the year ended December 31, 2017, we revised our estimated revenue and costs at completion for this loss contract, which resulted in additional contract losses of $18.5 million. There was no significant change in estimated revenue of costs at completion on this project in the three months ended December 31, 2017. Our estimate at completion as of December 31, 2017 includes $6.7 million of total expected liquidated damages due to schedule delays. The change in the status of this project in 2017 was primarily attributable to changes in the estimated costs at completion and schedule delays. As of December 31, 2017, the reserve for estimated contract losses recorded in "other accrued liabilities" in our consolidated balance sheet was $2.5 million.

In September 2017, we identified the failure of a structural steel beam on the fifth project, which stopped work in the boiler building and other areas pending corrective actions to stabilize the structure that are expected to be complete in the first half of 2018. The engineering, design and manufacturing of the steel structure were the responsibility of our subcontractors. A similar design was also used on the second and fourth projects, and although no structural failure occurred on these two other projects, work was also stopped in certain restricted areas while we added reinforcement to the structures, which also resulted in delays that lasted until late January 2018. The total costs related to the structural steel issues on these three projects, including project delays, are estimated to be approximately $42 million, which is included in the December 31, 2017 estimated losses at completion for these three projects.

Also during the third quarter of 2017, we adjusted the design of three renewable facilities to increase the guaranteed power output, which will allow us to achieve contractual bonus opportunities for the higher output. In the fourth quarter of 2017, we obtained agreement from certain customers to increase the value of these bonus opportunities and to provide partial relief on liquidated damages. The bonus opportunities and liquidated damages relief increased the estimated selling price of the three contracts by approximately $19 million in total ($4 million in the three months ended December 31, 2017), and this positive change in estimated cost to complete was fully recognized in 2017 because each were loss projects.

During the years ended December 31, 2017 and 2016, we recognized losses of $2.5 million and $14.2 million, respectively, on our other renewable energy projects that are not loss contracts. Accrued liquidated damages associated with these projects was $9.0 million at December 31, 2016.

During the third quarter of 2016, we determined it was probable that we would receive a $15.0 million insurance recovery for a portion of the losses on the first European renewable energy project discussed above. There was no change in the accrued probable insurance recovery at December 31, 2017. The insurance recovery represents the full amount available under the insurance policy, and is recorded in accounts receivable - other in our consolidated balance sheet at December 31, 2017 and 2016.

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

	December 31,
(in thousands)	2017		2016
Included in contracts in progress:
Costs incurred less costs of revenue recognized	$	80,645	$	96,210
Revenues recognized less billings to customers	80,575		69,800
Contracts in progress	$	161,220	$	166,010
Included in advance billings on contracts:
Billings to customers less revenues recognized	$	177,953	$	199,480
Costs of revenue recognized less cost incurred	3,117		11,162
Advance billings on contracts	$	181,070	$	210,642

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The following amounts represent retainage on contracts:

	December 31,
(in thousands)	2017		2016
Retainage expected to be collected within one year	$	14,572	$	18,843
Retainage expected to be collected after one year	6,112		4,583
Total retainage	$	20,684	$	23,426

We have included retainage expected to be collected in 2018 in "accounts receivable – trade, net." Retainage expected to be collected after one year are included in "other assets." Of the long-term retainage at December 31, 2017, we anticipate collecting $4.3 million, $1.6 million and $0.2 million in 2019, 2020 and 2021, respectively.

NOTE 7 – EQUITY METHOD INVESTMENTS

Our equity method investment in Babcock & Wilcox Beijing Company, Ltd. ("BWBC") contributed $6.1 million, $4.5 million and $4.9 million in income to our results from operations in the years ended December 31, 2017, 2016 and 2015, respectively. BWBC has a manufacturing facility that designs, manufactures, produces and sells various power plant and industrial boilers primarily in China. Our investment in BWBC at December 31, 2017 and 2016 was $16.6 million and $55.5 million, respectively. During the first quarter of 2018, we sold our interest in BWBC to our joint venture partner in China for approximately $21.0 million, resulting in a gain of approximately $4.4 million.

Our equity method investment in Thermax Babcock & Wilcox Energy Solutions Private Limited ("TBWES"), a joint venture in India, contributed $2.2 million, $1.5 million and $(8.2) million in income (losses) to our results from operations (excluding the impairment charge discussed below) in the years ended December 31, 2017, 2016 and 2015, respectively. TBWES has a manufacturing facility that produces boiler parts and equipment intended primarily for new build coal boiler contracts in India. During the second quarter of 2017, both we and our joint venture partner decided to make a strategic change in the Indian joint venture due to the decline in forecasted market opportunities in India, which reduced the expected recoverable value of our investment in the joint venture. As a result of this strategic change, we recognized a $18.2 million other-than-temporary-impairment of our investment in TBWES in the second quarter of 2017, which was classified in in equity income of investees. The impairment charge was based on the difference in the carrying value of our investment in TBWES and our share of the estimated fair value of TBWES's net assets. Our investment in TBWES at December 31, 2017 and 2016 was $26.0 million and $40.6 million, respectively. The TBWES joint venture is now idle as we and our joint venture partner explore strategic alternatives for its assets.

On December 22, 2016, we sold all of our interest in our former Australian joint venture, Halley & Mellowes Pty. Ltd. ("HMA") for $18.0 million. The sale of HMA resulted in an $8.3 million gain, which was classified in equity income of investees in 2016. HMA contributed income of $2.2 million and $3.1 million to our results from operations in the years ended December 31, 2016 and 2015.

Our investment in equity method investees was not significantly different from our underlying equity in the net assets of those investees based on stated ownership percentages at December 31, 2017. All of our investments in equity method investees are included in our Power segment.

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The undistributed earnings of our equity method investees were $7.9 million and $59.6 million at December 31, 2017 and 2016, respectively. Summarized below is consolidated balance sheet and statement of operations information for investments accounted for under the equity method:

	December 31,
(in thousands)	2017		2016
Current assets	$	322,956	$	335,577
Noncurrent assets	137,081		126,958
Total assets	460,037		462,535
Current liabilities	342,178		231,150
Noncurrent liabilities	24,474		40,537
Owners' equity	93,385		190,848
Total liabilities and equity	$	460,037	$	462,535

	Year Ended December 31,
(in thousands)	2017			2016		2015
Revenues	$	346,459		$	488,101	$	475,459
Gross profit	32,682			76,986		69,021
Income before provision for income taxes	(10,626		)	19,529		3,072
Provision for income taxes	1,907			3,715		4,500
Net income	$	(12,533	)	$	15,814	$	(1,428	)

The provision for income taxes is based on the tax laws and rates in the countries in which our investees operate. The taxation regimes vary not only by their nominal rates, but also by allowable deductions, credits and other benefits. For some of our United States investees, United States income taxes are the responsibility of the respective owners, which is primarily the reason for the provision for income taxes being low in relation to income before provision for income taxes.

Reconciliation of net income in the statement of operations of our investees to equity in income of investees in our consolidated statements of operations is as follows:

	Year Ended December 31,
(in thousands)	2017			2016		2015
Equity income based on stated ownership percentages	$	7,530		$	7,898	$	(542	)
TBWES other than temporary impairment	(18,193		)	—		—
Gain on sale of our interest in HMA	—			8,324		—
All other adjustments due to amortization of basis differences, timing of GAAP adjustments and other adjustments	796			218		300
Equity in income of investees	$	(9,867	)	$	16,440	$	(242	)

Our transactions with unconsolidated affiliates were as follows:

	Year Ended December 31,
(in thousands)	2017		2016		2015
Sales to	$	7,143	$	17,220	$	18,014
Purchases from	12,470		32,490		45,397
Dividends received (1)	50,134		12,160		20,830
Capital contributions (2)	—		26,256		7,424

⁽¹⁾ includes $48.1 million, $6.0 million and $18.2 million in dividends received from BWBC in 2017, 2016 and 2015, respectively, before taxes.

⁽²⁾ includes a $26.3 million contribution we made in April 2016 to increase our ownership interest in TBWES for the purpose of extinguishing the joint venture's high-interest third-party debt and avoiding the associated future interest cost (our joint venture partner contributed the same amount to TBWES).

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Our accounts receivable-other includes receivables from these unconsolidated affiliates of $5.8 million and $8.7 million at December 31, 2017 and 2016, respectively.

NOTE 8 – RESTRUCTURING ACTIVITIES AND SPIN-OFF TRANSACTION COSTS

Restructuring liabilities

Restructuring liabilities are included in other accrued liabilities on our consolidated balance sheets. Activity related to the restructuring liabilities is as follows:

	Year ended December 31,
(in thousands)	2017			2016
Balance at beginning of period	$	2,253		$	740
Restructuring expense	13,923			21,939
Payments	(13,857		)	(20,426		)
Balance at December 31	$	2,319		$	2,253

Accrued restructuring liabilities at December 31, 2017 and 2016 relate primarily to employee termination benefits.

Excluded from restructuring expense in the table above are non-cash restructuring charges that did not impact the accrued restructuring liability. In the years ended December 31, 2017 and 2016, we recognized $0.3 million and $15.0 million, respectively, in non-cash restructuring expense related to losses (gains) on the disposals of long-lived assets.

Spin-off transaction costs

Spin-off costs were primarily attributable to employee retention awards directly related to the spin-off from our former parent, The Babcock & Wilcox Company (now known as BWX Technologies, Inc.). In the years ended December 31, 2017 and 2016, we recognized spin-off costs of $1.2 million and $3.8 million, respectively. During 2017, we disbursed $1.9 million of the accrued retention awards.

NOTE 9 – STOCK-BASED COMPENSATION

2015 Long-Term Incentive Plan of Babcock & Wilcox Enterprises, Inc.

Prior to the spin-off, executive officers, key employees, members of the board of directors and consultants of B&W were eligible to participate in the 2010 Long-Term Incentive Plan of The Babcock & Wilcox Company (the "BWC Plan"). Effective June 30, 2015, executive officers, key employees, members of the board of directors and consultants of B&W are eligible to participate in the 2015 Long-Term Incentive Plan of Babcock & Wilcox Enterprises, Inc. (the "Plan"). The Plan permits grants of nonqualified stock options, incentive stock options, appreciation rights, restricted stock, restricted stock units, performance shares, performance units, and cash incentive awards. The Plan was amended and restated in 2016 to increase the number of shares available for issuance by 2.5 million shares. The number of shares available for award grants under the Plan, as amended and restated, is 8.3 million, of which 0.2 million remain available as of December 31, 2017.

In connection with the spin-off, outstanding stock options and restricted stock units granted under the BWC Plan prior to 2015 were replaced with both an adjusted BWC award and a new B&W stock award. These awards, when combined, had terms that were intended to preserve the values of the original awards. Outstanding performance share awards originally issued under the BWC Plan granted prior to 2015 were generally converted into unvested rights to receive the value of deemed target performance in unrestricted shares of a combination of BWC common stock and B&W common stock, determined by reference to the ratio of one share of B&W common stock being distributed for every two shares of BWC common stock in the spin-off, in each case with the same vesting terms as the original awards.

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Company stock options

There were no stock options awarded in 2017. The fair value of each option grant awarded in 2016 and 2015 was estimated at the date of grant using Black-Scholes, with the following weighted-average assumptions:

	Year Ended December 31,
	2016		2015
Risk-free interest rate	1.14	%	1.38	%
Expected volatility	25	%	28	%
Expected life of the option in years	3.95		3.96
Expected dividend yield	—	%	—	%

The risk-free interest rate is based on the implied yield on a United States 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 is zero in 2016 and 2015 because we did not expect to pay dividends on the dates the 2016 and 2015 stock options were awarded.

The following table summarizes activity for our stock options the year ending December 31, 2017:

(share data in thousands)	Number of Shares		Weighted-Average Exercise Price		Weighted-Average Remaining Contractual Term (in years)	Aggregate Intrinsic Value (in thousands)
Outstanding at beginning of period	2,652		$	18.27
Granted	—		—
Exercised	(24	)	15.04
Cancelled/expired/forfeited	(150	)	18.50
Outstanding at end of period	2,478		$	18.28	5.46	$	—
Exercisable at end of period	1,844		$	18.14	4.69	$	—

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, 2017. 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, 2016 and 2015, was $4.03 and $4.80, respectively.

During the years ended December 31, 2017, 2016 and 2015, the total intrinsic value of stock options exercised was not significant, $0.7 million and $2.3 million, respectively. The actual tax benefits realized related to the stock options exercised during the years ended December 31, 2017 and 2016 were not significant and $0.3 million, respectively.

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Company restricted stock units

Nonvested restricted stock units activity for the year ending December 31, 2017 was as follows:

(share data in thousands)	Number of Shares		Weighted-Average Grant Date Fair Value
Nonvested at beginning of period	712		$	19.14
Granted	1,902		5.35
Vested	(282	)	18.48
Cancelled/forfeited	(105	)	15.00
Nonvested at end of period	2,227		$	7.63

The actual tax benefits realized related to the restricted stock units vested during the year ended December 31, 2017 and 2016 were $1.1 million and $2.7 million, respectively.

Company performance-based restricted stock units

During 2017 and 2016, we granted certain B&W employees performance-based restricted stock units ("PSUs") under the Plan, which include both performance and service conditions. PSU awards vest upon satisfying certain service requirements and B&W financial metrics, including return on invested capital (ROIC), earnings per share (EPS) and total shareholder return (TSR), established by the board of directors. The fair value of the TSR portion of each PSU granted was estimated at the date of grant using a Monte Carlo methodology based on market prices and the following weighted-average assumptions:

	Year Ended December 31,		Year Ended December 31,
	2017		2016
Risk-free interest rate	1.54	%	0.96	%
Expected volatility	42	%	25	%
Expected life of the option in years	2.83		2.83
Expected dividend yield	—	%	—	%

PSU activity for the year ending December 31, 2017 was as follows:

(share data in thousands)	Number of Shares		Weighted-Average Grant Date Fair Value
Nonvested at beginning of period	451		$	19.29
Granted	828		9.74
Vested	(3	)	9.67
Cancelled/forfeited	(141	)	14.07
Nonvested at end of period	1,135		$	12.75

Company performance-based, cash settled units

In 2017, we granted certain B&W employees cash-settled performance units under the Plan, the value of which is tied to the fair market value of our common stock on the vesting dates, subject to a ceiling of 150% of the grant date share value. The activity for the cash-settled performance units for the year ending December 31, 2017 was as follows:

(share data in thousands)	Number of Shares		Weighted-Average Grant Date Fair Value
Nonvested at beginning of period	32		$	18.53
Granted	1,908		2.90
Vested	(7	)	—
Cancelled/forfeited	(134	)	3.93
Nonvested at end of period	1,799		$	4.53

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NOTE 10 – PROVISION FOR INCOME TAXES

We are subject to federal income tax in the United States 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 both nominal rates and the basis on which these rates are applied. Our consolidated effective income tax rate can vary significantly from period to period due to these variations, changes in jurisdictional mix of our income and valuation allowances in certain jurisdictions that can offset income tax expense or benefit.

We are currently under audit by various domestic and international authorities. With few exceptions, we do not have any returns under examination for years prior to 2013. The United States Internal Revenue Service has completed examinations of the federal tax returns of BWC through 2014, and all matters arising from such examinations have been resolved.

We recognize the effect of income tax positions only if it is more-likely-than-not that those positions will be sustained. Recognized income tax positions are measured at the largest amount that is greater than 50% likely of being realized. Changes in recognition or measurement are reflected in the period in which the change in judgment occurs. Unrecognized tax benefits are as follows:

(in thousands)	2017			2016			2015
Balance at beginning of period	$	884		$	1,141		$	3,321
Increases based on tax positions taken in the current year	277			178			88
Increases based on tax positions taken in the prior years	56			230			248
Decreases based on tax positions taken in the prior years	(13		)	—			(1,161		)
Decreases due to settlements with tax authorities	—			(665		)	(1,355		)
Decreases due to lapse of applicable statute of limitation	—			—			—
Balance at end of period	$	1,204		$	884		$	1,141

The $1.2 million balance of unrecognized tax benefits at December 31, 2017 would decrease expense if recognized. We do not expect any of our unrecognized income tax benefits to be resolved in the next twelve months. We recognize interest and penalties related to unrecognized tax benefits in our provision for income taxes; however, such amounts are not significant to any period presented.

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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, 2017 and 2016 were as follows:

	December 31,
(in thousands)	2017			2016
Deferred tax assets:
Pension liability	$	58,810		$	105,426
Accrued warranty expense	5,262			11,628
Accrued vacation pay	996			4,792
Accrued liabilities for self-insurance (including postretirement health care benefits)	3,910			6,596
Accrued liabilities for executive and employee incentive compensation	4,950			8,334
Investments in joint ventures and affiliated companies	10,422			10,742
Long-term contracts	6,801			10,318
Accrued Legal Fees	1,579			2,110
Inventory Reserve	1,842			2,445
Property, plant and equipment	—			1,587
Net operating loss carryforward	95,715			33,187
State tax net operating loss carryforward	21,658			15,372
Foreign tax credit carryforward	7,150			3,870
Other tax credits	5,678			737
Other	4,980			7,852
Total deferred tax assets	229,753			224,996
Valuation allowance for deferred tax assets	(108,105		)	(40,484		)
Net, total deferred tax assets	121,648			184,512
Deferred tax liabilities:
Long-term contracts	569			3,601
Intangibles	21,215			21,892
Property, plant and equipment	2,835			—
Undistributed foreign earnings	1,314			500
Goodwill	—			1,125
Other	2,445			2,885
Total deferred tax liabilities	28,378			30,003
Net deferred tax assets	$	93,270		$	154,509

At December 31, 2017, we had a valuation allowance of $108.1 million for deferred tax assets, which we expect may not be realized through carrybacks, future reversals of existing taxable temporary differences and estimates 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 estimates of future taxable income. Should we conclude in the future that any or all of our deferred tax assets are not more likely than not to be realized, we would establish additional valuation allowances and 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:

(in thousands)	Beginning balance			Charges to costs and expenses			Charged to other accounts			Ending balance
Year Ended December 31, 2017	$	(40,484	)	$	(61,021	)	$	(6,600	)	$	(108,105	)
Year Ended December 31, 2016	(10,077		)	(29,307		)	(1,100		)	(40,484		)
Year Ended December 31, 2015	(9,216		)	(861		)	—			(10,077		)

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We operate in numerous countries that have statutory tax rates below that of the 35% federal statutory rate that has been applicable to the United States through December 31, 2017. The most significant of these foreign operations are located in Canada, Denmark, Germany, Italy, Mexico, Sweden and the United Kingdom with effective tax rates ranging between 20% and approximately 30%. Income before the provision for income taxes was as follows:

	Year Ended December 31,
(in thousands)	2017			2016			2015
United States	$	(44,835	)	$	1,280		$	(20,748	)
Other than the United States	(269,364		)	(109,419		)	40,953
Income before provision for income taxes	$	(314,199	)	$	(108,139	)	$	20,205

The provision for income taxes consisted of:

	Year Ended December 31,
(in thousands)	2017			2016			2015
Current:
United States – federal	$	100		$	284		$	24,084
United States – state and local	397			(415		)	3,458
Other than in the United States	8,612			4,504			8,250
Total current	9,109			4,373			35,792
Deferred:
United States – Federal	58,203			11,512			(35,888		)
United States – state and local	2,546			6,365			(111		)
Other than in the United States	(5,042		)	(15,307		)	3,878
Total deferred (benefit) provision	55,707			2,570			(32,121		)
Provision for income taxes	$	64,816		$	6,943		$	3,671

The following is a reconciliation of the United States statutory federal tax rate (35%) to the consolidated effective tax rate:

	Year Ended December 31,
	2017		2016		2015
United States federal statutory rate	35.0	%	35.0	%	35.0	%
State and local income taxes	0.2		(3.5	)	13.8
Foreign rate differential	(9.5	)	(12.8	)	(13.1	)
Deferred Taxes - Change in Tax Rate	(19.9	)	—		—
Tax credits	0.9		3.0		(14.7	)
Dividends and deemed dividends from affiliates	(1.8	)	(0.2	)	1.7
Valuation allowances	(17.9	)	(28.1	)	4.3
Goodwill impairment	(7.0	)	—		—
Uncertain tax positions	—		0.3		(6.6	)
Non-deductible expenses	0.2		(1.8	)	2.4
Manufacturing deduction	—		—		(2.5	)
Other	(0.8	)	1.7		(2.1	)
Effective tax rate	(20.6	)%	(6.4	)%	18.2	%

We have foreign net operating loss benefits after tax of $75.0 million available to offset future taxable income in certain foreign jurisdictions. Of the foreign net operating loss benefits, $1.7 million is scheduled to expire in 2019 to 2026. The remaining net operating loss benefits have unlimited lives. We are carrying a valuation allowance of $66.0 million against the deferred tax asset related to the foreign loss carryforwards.

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At December 31, 2017, we have a tax effected United States federal net operating loss of $20.7 million. The United States federal operating loss will begin to expire in 2037, and we expect to fully utilize this net operating loss in future periods. At December 31, 2017, we have foreign tax credit carryovers of $7.2 million, against which we have a full valuation allowance. At December 31, 2017, we have state net operating loss benefits after tax of $21.7 million available to offset future taxable income in various states, against which we have $21.6 million of valuation allowance. Our state net operating loss carryforwards begin to expire in the year 2018.

It has been our practice to reinvest indefinitely, the earnings of our foreign subsidiaries and that position has not changed as a result of the enactment of the U.S. Tax Cuts and Jobs Act. If we were to distribute earnings from certain foreign subsidiaries, we would be subject to withholding taxes of approximately $4.4 million but U.S. income taxes would generally not be imposed upon such distributions. We have not established deferred taxes for these withholding taxes.

During the twelve months ended December 31, 2017, we prospectively adopted Financial Accounting Standards Board ("FASB") Accounting Standards Update ("ASU") 2016-09, Compensation - Stock Compensation (Topic 718): Improvements to Employee Share-based Payment Accounting. Adopting the new accounting standard resulted in a net $0.1 million income tax expense and $1.6 million income tax benefit in the three and twelve months ending December 31, 2017, respectively, associated with the income tax effects of vested and exercised share-based compensation awards.

New Tax Act

The United States Tax Cuts and Jobs Act (the “Tax Act”) was enacted on December 22, 2017 and introduces significant changes to the United States income tax law. Beginning in 2018, the Tax Act reduces the United States statutory corporate income tax rate from 35% to 21% and creates a modified territorial system that will generally allow United States companies a full dividend received deduction for any future dividends from non-U.S. subsidiaries. In connection with the transition to a modified territorial system, the Tax Act also establishes a mandatory one-time deemed repatriation transition tax on currently deferred foreign earnings.

The SEC staff issued Staff Accounting Bulletin ("SAB 118"), which provides guidance on accounting for the tax effects of the Tax Act. SAB 118 provides a measurement period that should not extend beyond one year from the Tax Act enactment date for companies to complete the accounting under Accounting Standards Codification 740 ("ASC 740"). In accordance with SAB 118, we have made reasonable estimates of the effects of the Tax Act and recorded provisional amounts in our financial statements as of December 31, 2017. We will finalize our estimates in 2018 as we collect and analyze necessary data, and interpret additional guidance that becomes available.

Provisional amounts for the following income tax effects of the Tax Act have been recorded as of December 31, 2017:

Deferred tax effects

We remeasured our deferred taxes and recorded a deferred tax expense of $62.4 million. This amount consists of an expense for the corporate rate reduction of $54.4 million, expense of $0.8 million based on a change in our deferred taxes related to executive compensation and an expense of $7.2 million to record a valuation allowance on foreign tax credit carryforwards that are now expected to expire unused. While we are able to make a reasonable estimate of the deferred tax effects, our continued analysis of other aspects of the Tax Act could impact our estimate.

One-time transition tax

The Deemed Repatriation Transition Tax (Transition Tax) is a tax on previously untaxed accumulated and current earnings and profits (E&P) of certain of our foreign subsidiaries. To determine the amount of the Transition Tax, we must determine, in addition to other factors, the amount of post-1986 E&P of the relevant subsidiaries, as well as the amount of non-United States income taxes paid on such earnings. We are able to make a reasonable estimate of the Transition Tax and because we have estimated an E&P deficit, we have not recorded a Transition Tax. We are continuing to gather additional information to more precisely compute final E&P, including the computation of 2017 current year E&P which we will finalize with the 2017 tax return.

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NOTE 11 – COMPREHENSIVE INCOME

Gains and losses deferred in accumulated other comprehensive income (loss) ("AOCI") are reclassified and recognized in the consolidated statements of operations once they are realized. The changes in the components of AOCI, net of tax, for the years ended 2017, 2016 and 2015 were as follows:

(in thousands)	Currency translation gain (loss) (net of tax)			Net unrealized gain (loss) on investments (net of tax)			Net unrealized gain (loss) on derivative instruments (net of tax)			Net unrecognized gain (loss) related to benefit plans (net of tax)			Total
Balance at December 31, 2014	$	11,551		$	(22	)	$	(123	)	$	(1,032	)	$	10,374
Other comprehensive income (loss) before reclassifications	(19,459		)	(49		)	339			519			(18,650		)
Amounts reclassified from AOCI to net income (loss)	—			27			1,133			(195		)	965
Net transfers from Parent	(11,585		)	—			437			(394		)	(11,542		)
Net current-period other comprehensive income (loss)	(31,044		)	(22		)	1,909			(70		)	(29,227		)
Balance at December 31, 2015	$	(19,493	)	$	(44	)	$	1,786		$	(1,102	)	$	(18,853	)
Other comprehensive income (loss) before reclassifications	(24,494		)	7			2,046			7,692			(14,749		)
Amounts reclassified from AOCI to net income (loss)	—			—			(3,030		)	150			(2,880		)
Net current-period other comprehensive income (loss)	(24,494		)	7			(984		)	7,842			(17,629		)
Balance at December 31, 2016	(43,987		)	(37		)	802			6,740			(36,482		)
Other comprehensive income (loss) before reclassifications	16,150			99			3,204			(152		)	19,301
Amounts reclassified from AOCI to net income (loss)	—			(24		)	(2,269		)	(2,955		)	(5,248		)
Net current-period other comprehensive income (loss)	16,150			75			935			(3,107		)	14,053
Balance at December 31, 2017	$	(27,837	)	$	38		$	1,737		$	3,633		$	(22,429	)

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The amounts reclassified out of AOCI by component and the affected consolidated statements of operations line items are as follows (in thousands):

AOCI component	Line items in the Consolidated Statements of Operations affected by reclassifications from AOCI	Year Ended December 31,
		2017			2016			2015
Derivative financial instruments	Revenues	$	10,059		$	4,624		$	546
	Cost of operations	(118		)	195			155
	Other-net	(7,438		)	(1,221		)	(24		)
	Total before tax	2,503			3,598			677
	Provision for income taxes	234			568			149
	Net income	$	2,269		$	3,030		$	528
Amortization of prior service cost on benefit obligations	Cost of operations	$	2,912		$	254		$	(1,475	)
	Provision for income taxes	(43		)	404			(1,168		)
	Net income (loss)	$	2,955		$	(150	)	$	(307	)
Realized gain on investments	Other-net	$	38		$	—		$	(42	)
	Provision for income taxes	14			—			(15		)
	Net income (loss)	$	24		$	—		$	(27	)

NOTE 12 – CASH AND CASH EQUIVALENTS

The components of cash and cash equivalents are as follows:

(in thousands)	December 31, 2017		December 31, 2016
Held by foreign entities	$	54,274	$	94,415
Held by United States entities	2,393		1,472
Cash and cash equivalents	$	56,667	$	95,887
Reinsurance reserve requirements	$	21,061	$	21,189
Restricted foreign accounts	4,919		6,581
Restricted cash and cash equivalents	$	25,980	$	27,770

Our United States revolving credit facility described in Note 19 allows for nearly immediate borrowing of available capacity to fund cash requirements in the normal course of business, meaning that the minimum United States cash on hand is maintained to minimize borrowing costs.

NOTE 13 – INVENTORIES

The components of inventories are as follows:

(in thousands)	December 31, 2017		December 31, 2016
Raw materials and supplies	$	60,708	$	61,630
Work in progress	7,867		6,803
Finished goods	13,587		17,374
Total inventories	$	82,162	$	85,807

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NOTE 14– INTANGIBLE ASSETS

Our intangible assets are as follows:

(in thousands)	December 31, 2017			December 31, 2016
Definite-lived intangible assets
Customer relationships	$	59,794		$	47,892
Unpatented technology	20,160			18,461
Patented technology	6,542			2,499
Tradename	22,951			18,774
Backlog	30,160			28,170
All other	7,611			7,430
Gross value of definite-lived intangible assets	147,218			123,226
Customer relationships amortization	(23,434		)	(17,519		)
Unpatented technology amortization	(5,013		)	(2,864		)
Patented technology amortization	(2,213		)	(1,532		)
Tradename amortization	(5,097		)	(3,826		)
Acquired backlog amortization	(28,695		)	(21,776		)
All other amortization	(7,291		)	(5,974		)
Accumulated amortization	(71,743		)	(53,491		)
Net definite-lived intangible assets	$	75,475		$	69,735
Indefinite-lived intangible assets:
Trademarks and trade names	$	1,305		$	1,305
Total indefinite-lived intangible assets	$	1,305		$	1,305

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

	Twelve months ended December 31,
(in thousands)	2017			2016
Balance at beginning of period	$	71,039		$	37,844
Business acquisitions	19,500			55,438
Amortization expense	(18,252		)	(19,923		)
Currency translation adjustments and other	4,493			(2,320		)
Balance at end of the period	$	76,780		$	71,039

The January 11, 2017 acquisition of Universal resulted in an increase in our intangible asset amortization expense during the year ended December 31, 2017 of $3.1 million.

The July 1, 2016 acquisition of SPIG, S.p.A. resulted in a $9.1 million and $13.3 million increase in our intangible asset amortization expense during the year ended December 31, 2017 and six months ended December 31, 2016, respectively.

Amortization of intangible assets is included in cost of operations in our consolidated statement of operations, but it is not allocated to segment results.

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Estimated future intangible asset amortization expense is as follows (in thousands):

Year ending	Amortization expense
December 31, 2018	$	12,423
December 31, 2019	$	10,371
December 31, 2020	$	9,077
December 31, 2021	$	8,817
December 31, 2022	$	7,244
Thereafter	$	27,543

NOTE 15 – GOODWILL

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

(in thousands)	Power			Renewable			Industrial			Total
Balance at December 31, 2015	$	47,137		$	49,624		$	104,308		$	201,069
Increase resulting from SPIG acquisition	—			—			69,862			69,862
Purchase price adjustment - SPIG acquisition	—			—			2,539			2,539
Currency translation adjustments	(917		)	(1,189		)	(3,969		)	(6,075		)
Balance at December 31, 2016	46,220			48,435			172,740			267,395
Increase resulting from Universal acquisition	—			—			14,413			14,413
Impairment charges(1)	—			(49,965		)	(36,938		)	(86,903		)
Currency translation adjustments	1,150			1,530			6,813			9,493
Balance at December 31, 2017	$	47,370		$	—		$	157,028		$	204,398

⁽¹⁾ Prior to September 30, 2017, we had not recorded any goodwill impairment charges.

Our annual goodwill impairment assessment is performed on October 1 of each year (the "annual assessment" date); however, events during 2017 have required two interim assessments of all six of our reporting units. In the second quarter of 2017, significant charges in our Renewable segment were considered to be a triggering event for the interim assessment as of June 30, 2017, which did not indicate impairment. During the third quarter of 2017, our market capitalization significantly decreased to below our equity value, which was considered to be a trigger for a second interim assessment. Additionally, the forecast was reduced for our SPIG reporting unit based on a change in the market strategy implemented by the new segment management to focus on core geographies and products, which we considered to be another triggering event for an interim assessment during the third quarter of 2017. The second interim assessment as of September 30, 2017 indicated impairment for our Renewable and SPIG reporting units as described below. Our 2017 annual goodwill impairment test as of October 1, 2017 did not indicate additional impairment.

Assessing goodwill for impairment involves a two step test. Step 1 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 test is performed to measure the amount of the impairment loss, if any. Step 2 of the test compares the implied fair value of the reporting unit's goodwill with the carrying amount of that goodwill, and impairment is measured as the excess of the carrying value over the implied value of goodwill. Estimating the fair value of a reporting unit requires significant judgment. The fair value of each reporting unit determined under Step 1 of the goodwill impairment test was based on a 50% weighting of an income approach using a discounted cash flow analysis using forward-looking projections of future operating results, a 30% to 40% weighting of a market approach using multiples of revenue and earnings before interest, taxes, depreciation and amortization ("EBITDA") of guideline companies and a 20% to 10% weighting of a market approach using multiples of revenue and EBITDA from recent, similar business combinations.

We primarily attributed the significant decline in our market capitalization in the third quarter of 2017 to the announcement of significant charges in the Renewable reporting unit. Accordingly, we increased the discount rate applied to future projected cash flows from 15.0% at June 30, 2017 to 23.5% at September 30, 2017. As a result of the increase in the discount rate and an increase in the carrying value of the reporting unit, impairment was indicated at September 30, 2017, which measured

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$50.0 million ($48.9 million net of tax), the full carrying value. Other long-lived assets in the reporting unit were not impaired.

For our SPIG reporting unit, which is included in our Industrial segment, the Step 1 also indicated impairment at September 30, 2017. At June 30, 2017 and October 1, 2016, the fair value exceeded the carrying value by less than 1% and 5%, respectively. At September 30, 2017, the independently obtained fair value estimates decreased under both the income and market valuation approaches due to a short-term decrease in profitability attributable to specific current contracts and changes in SPIG's market strategy introduced by segment management during the third quarter. The discount rate applied to future projected cash flows was 14.0% and 12.5% at each of the September 30, 2017 and June 30, 2017 interim tests, respectively. Step 2 of the impairment test at September 30, 2017 measured $36.9 million of impairment (with no income tax impact). The SPIG reporting unit has $38.3 million of goodwill remaining after the September 30, 2017 impairment charge. Our 2017 annual goodwill impairment test as of October 1, 2017 utilized the same assumptions and inputs as the test we performed at September 30, 2017, and it did not indicate additional impairment. Other long-lived assets in the reporting unit were not impaired.

For the remaining four reporting units where impairment was not indicated at September 30, 2017, the goodwill balances at September 30, 2017 (and October 1, 2017) and the Step 1 goodwill impairment test headroom (the estimated fair value less the carrying value) are as follows:

	Power Segment		Industrial Segment
(in millions)	Power	Construction	MEGTEC	Universal
Reporting unit headroom	60%	98%	12%	18%
Goodwill balance	$38.5	$8.9	$104.3	$14.4

NOTE 16 – PROPERTY, PLANT & EQUIPMENT

Property, plant and equipment is stated at cost. The composition of our property, plant and equipment less accumulated depreciation is set forth below:

(in thousands)	December 31, 2017		December 31, 2016
Land	$	8,859	$	6,348
Buildings	122,369		114,322
Machinery and equipment	217,791		189,489
Property under construction	6,486		22,378
	355,505		332,537
Less accumulated depreciation	213,574		198,900
Net property, plant and equipment	$	141,931	$	133,637

NOTE 17 – WARRANTY EXPENSE

Changes in the carrying amount of our accrued warranty expense are as follows:

	Year Ended December 31,
(in thousands)	2017			2016			2015
Balance at beginning of period	$	40,467		$	39,847		$	37,735
Additions	23,161			22,472			19,310
Expirations and other changes	(13,887		)	(10,855		)	(982		)
Increases attributable to business combinations	1,060			918			—
Payments	(14,110		)	(11,089		)	(15,215		)
Translation and other	2,329			(826		)	(1,001		)
Balance at end of period	$	39,020		$	40,467		$	39,847

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During the years ended December 31, 2017 and 2016, our Power segment reduced its accrued warranty expense by $9.1 million and $4.4 million, respectively, to reflect the expiration of warranties, and updated its estimated warranty accrual rate to reflect its warranty claims experience and current contractual warranty obligations. Additions to the warranty accrual include specific provisions on industrial steam contracts totaling $7.9 million and $2.1 million during the years ended December 31, 2017 and 2016, respectively.

NOTE 18 – PENSION PLANS AND OTHER POSTRETIREMENT BENEFITS

We have historically provided defined benefit retirement benefits to domestic employees under the Retirement Plan for Employees of Babcock & Wilcox Commercial Operations (the "Company Plan"), a noncontributory plan. As of 2006, the Company Plan was closed to new salaried plan entrants. Effective December 31, 2015, benefit accruals for those salaried employees covered by, and continuing to accrue service and salary adjusted benefits under the Company Plan will cease. Furthermore, beginning on January 1, 2016, we began making service-based, cash contributions to a defined contribution 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 6 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. In 2014, benefit accruals under certain hourly Canadian pension plans were ceased with an effective date of January 1, 2015. As part of the spin-off transaction, we split the Canadian defined benefit plans from BWC, which was completed in 2017. We did not present these plans as multi-employer plans because our portion was separately identifiable and we were able to assess the assets, liabilities and periodic expense in the same manner as if it were a separate plan in each period.

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. Funding provisions under the Pension Protection Act accelerate funding requirements to ensure full funding of benefits accrued.

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, and on a limited basis, to future retirees.

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Obligations and funded status

	Pension Benefits Year Ended December 31,						Other Postretirement Benefits  Year Ended December 31,
(in thousands)	2017			2016			2017			2016
Change in benefit obligation:
Benefit obligation at beginning of period	$	1,211,720		$	1,205,163		$	11,907		$	31,889
Service cost	789			1,680			15			23
Interest cost	41,113			40,875			319			897
Plan participants’ contributions	—			—			219			574
Curtailments	—			266			—			—
Settlements	509			1,453			—			—
Amendments	—			231			—			(10,801		)
Actuarial loss (gain)	73,403			41,957			(141		)	(7,162		)
Loss (gain) due to transfer	—			3,641			—			—
Foreign currency exchange rate changes	6,222			(5,099		)	126			50
Benefits paid	(78,954		)	(78,447		)	(1,416		)	(3,563		)
Benefit obligation at end of period	$	1,254,802		$	1,211,720		$	11,029		$	11,907
Change in plan assets:
Fair value of plan assets at beginning of period	$	922,868		$	923,030		$	—		$	—
Actual return on plan assets	149,449			76,570			—			—
Employer contribution	17,307			3,986			1,197			2,989
Plan participants' contributions	—			—			219			574
Transfers	—			2,744			—			—
Foreign currency exchange rate changes	(3,668		)	(5,015		)	—			—
Benefits paid	(78,954		)	(78,447		)	(1,416		)	(3,563		)
Fair value of plan assets at the end of period	1,007,002			922,868			—			—
Funded status	$	(247,800	)	$	(288,852	)	$	(11,029	)	$	(11,907	)
Amounts recognized in the balance sheet consist of:
Accrued employee benefits	$	(1,930	)	$	(1,099	)	$	(1,615	)	$	(1,722	)
Accumulated postretirement benefit obligation	—			—			(9,414		)	(10,185		)
Pension liability	(245,870		)	(287,753		)	—			—
Prepaid pension	—			—			—			—
Accrued benefit liability, net	$	(247,800	)	$	(288,852	)	$	(11,029	)	$	(11,907	)
Amount recognized in accumulated comprehensive income (before taxes):
Prior service cost (credit)	$	324		$	432		$	(7,792	)	$	(10,801	)
Supplemental information:
Plans with accumulated benefit obligation in excess of plan assets
Projected benefit obligation	$	1,254,802		$	1,183,345		$	—		$	—
Accumulated benefit obligation	$	1,272,010		$	1,206,056		$	11,029		$	11,907
Fair value of plan assets	$	1,007,002		$	894,105		$	—		$	—
Plans with plan assets in excess of accumulated benefit obligation
Projected benefit obligation	$	—		$	28,375		$	—		$	—
Accumulated benefit obligation	$	—		$	28,375		$	—		$	—
Fair value of plan assets	$	—		$	28,763		$	—		$	—

Components of net periodic benefit cost (benefit) included in net income (loss) are as follows:

	Pension Benefits									Other Benefits
(in thousands)	2017			2016			2015			2017			2016			2015
Service cost	$	789		$	1,680		$	13,677		$	15		$	23		$	24
Interest cost	41,113			40,875			49,501			319			897			1,143
Expected return on plan assets	(59,409		)	(61,939		)	(68,709		)	—			—			—
Amortization of prior service cost	103			250			307			(3,009		)	—			—
Recognized net actuarial loss (gain)	(8,191		)	31,932			41,574			(505		)	(7,822		)	(1,364		)
Net periodic benefit cost (benefit)	$	(25,595	)	$	12,798		$	36,350		$	(3,180	)	$	(6,902	)	$	(197	)

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During the first quarter of 2017, lump sum payments from our Canadian pension plan resulted in a plan settlement of $0.4 million, which also resulted in interim mark to market accounting for the pension plan. The mark to market adjustment in the first quarter of 2017 was $0.7 million. The effect of these charges and mark to market adjustments are reflected in the "Recognized net actuarial loss (gain)" in the table above. There were no significant plan settlements or interim mark to market adjustments after the first quarter of 2017.

We terminated the Babcock & Wilcox Retiree Medical Plan (the "Retiree OPEB plan") effective December 31, 2016. The Retiree OPEB plan was originally established to provide secondary medical insurance coverage for retirees that had reached the age of 65, up to a lifetime maximum cost. The Retiree OPEB plan had no plan assets, no accumulated other comprehensive income balance and no active participants as of the termination date. In exchange for terminating the Retiree OPEB plan, the participants had the option to enroll in a third-party health care exchange, which B&W agreed to contribute up to $750 a year for each of the next three years (beginning in 2017), provided the plan participant had not yet reached their lifetime maximum under the terminated Retiree OPEB plan. Based on the number of participants who did not enroll in the new benefit plan, we recognized a settlement gain of $7.2 million on December 31, 2016. Based on the number of participants who did enroll in the new benefit plan, we recognized a curtailment gain of $10.8 million on December 31, 2016 for the actuarially determined difference in the liability for these participants in the Retiree OPEB plan and the new plan. The settlement gain is reported in the "Recognized net actuarial loss" in the table above, and the curtailment gain was deferred in accumulated other comprehensive income and $3.0 million was recognized in 2017, and we expect to recognize the remainder during the periods of 2018 through 2020.

During 2016, we recorded adjustments to our benefit plan liabilities from pension curtailment and settlement events. Lump sum payments from our Canadian pension plan during 2016 resulted in interim pension plan settlement charges totaling $1.2 million in 2016. Also, in May 2016, the closure of our West Point, Mississippi manufacturing facility resulted in a $1.8 million curtailment charge in the Company Plan. These events also resulted in$27.5 millionin interim MTM losses for these pension plans, the effects of which are reflected in the 2016 "Recognized net actuarial loss (gain)" in the table above along with a$1.4 million loss for the annual MTM adjustment of our pension plans at December 31, 2016.

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. Total net mark to market adjustments for our pension and other postretirement benefit plans were (gains) losses of $(8.7) million, $24.1 million and $40.2 million in the years ended, December 31, 2017, 2016 and 2015, respectively. We have excluded the recognized net actuarial loss from our reportable segments and such amount has been reflected in Note 4 as the mark to market adjustment in the reconciliation of reportable segment income (loss) to consolidated operating losses. The recognized net actuarial (gain) loss was recorded in our consolidated statements of operations in the following line items:

(in thousands)	2017			2016		2015
Cost of operations	$	(8,972	)	$	21,208	$	44,307
Selling, general and administrative expenses	274			2,902		(4,097		)
Other	2			—		—
Total	$	(8,696	)	$	24,110	$	40,210

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Assumptions

	Pension Benefits		Other Benefits
	2017	2016	2017	2016
Weighted average assumptions used to determine net periodic benefit obligations at December 31:
Discount rate	3.65%	4.13%	3.33%	3.66%
Rate of compensation increase	0.10%	2.40%	—	—
Weighted average assumptions used to determine net periodic benefit cost for the years ended December 31:
Discount rate	4.11%	4.25%	3.33%	3.66%
Expected return on plan assets	6.64%	6.70%	—%	—%
Rate of compensation increase	0.10%	2.40%	—%	—%

The expected rate of return on plan assets 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 asset class. These rates are then adjusted for anticipated future inflation to determine estimated nominal rates of return for each asset 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 asset classes within the total asset portfolio. We use an expected return on plan assets assumption of 6.89% for the majority of our pension plan assets (approximately 93% of our total pension assets at December 31, 2017).

	2016
Assumed health care cost trend rates at December 31
Health care cost trend rate assumed for next year	8.50	%
Rates to which the cost trend rate is assumed to decline (ultimate trend rate)	4.50	%
Year that the rate reaches ultimate trend rate	2024

During the year ended December 31, 2017, we did not utilize health care cost assumptions as a result of our termination of the Babcock & Wilcox Retiree Medical Plan (the "Retiree OPEB plan") effective December 31, 2016.

Investment goals

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 plans' 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 Company Plan, which is a domestic defined benefit plan. The assets of this plan are held by the Trustee in The Babcock & Wilcox Company Master Trust (the "Master Trust"). For the years ended December 31, 2017

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and 2016, the investment return on domestic plan assets of the Master Trust (net of deductions for management fees) was approximately 17% and 9%, respectively.

The following is a summary of the asset allocations for the Master Trust at December 31, 2017 and 2016 by asset category:

	2017		2016
Asset Category:
Fixed Income (excluding United States Government Securities)	33	%	32	%
Commingled and Mutual Funds	41	%	38	%
United States Government Securities	21	%	20	%
Equity Securities	3	%	7	%
Derivatives	1	%	1	%
Other	1	%	2	%

The target asset allocation for the domestic defined benefit plan is 55% fixed income and 45% equities.

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 United Kingdom Plan").

The combined weighted average asset allocations of these plans at December 31, 2017 and 2016 by asset category were as follows:

	2017		2016
Asset Category:
Equity Securities and Commingled Mutual Funds	41	%	44	%
Fixed Income	58	%	55	%
Other	1	%	1	%

The target allocation for 2017 for the foreign plans, by asset class, is as follows:

	Canadian Plans		Diamond UK Plan
Asset Class:
United States Equity	27	%	10	%
Global Equity	23	%	12	%
Fixed Income	50	%	78	%

Fair value of plan assets

See Note 23 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, 2017:

(in thousands)	12/31/2017		Level 1		Level 2
Fixed income	$	352,484	$	—	$	352,484
Equities	33,525		33,525		—
Commingled and mutual funds	413,166		—		413,166
United States government securities	193,249		193,249		—
Cash and accrued items	14,578		12,585		1,993
Total pension and other postretirement benefit assets	$	1,007,002	$	239,359	$	767,643

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The following is a summary of total investments for our plans measured at fair value at December 31, 2016:

(in thousands)	12/31/2016		Level 1		Level 2
Fixed income	$	321,847	$	—	$	321,847
Equities	83,441		78,268		5,173
Commingled and mutual funds	349,348		4,609		344,739
United States government securities	156,599		156,599		—
Cash and accrued items	11,633		9,394		2,239
Total pension and other postretirement benefit assets	$	922,868	$	248,870	$	673,998

Expected cash flows

	Domestic Plans				Foreign Plans
(in thousands)	Pension Benefits 1		Other Benefits		Pension Benefits 1		Other Benefits
Expected employer contributions to trusts of defined benefit plans:
2018	$	16,798	$	1,400	$	3,126	$	167
Expected benefit payments:
2018	$	71,881	$	1,463	$	3,003	$	167
2019	72,537		1,342		3,095		167
2020	73,104		854		3,175		169
2021	73,331		802		3,252		163
2022	73,434		746		3,318		146
2023-2027	359,308		2,975		18,576		611

¹ Pension benefit payments are made from their respective plan's trust.

Defined contribution plans

We provide benefits under The B&W Thrift Plan (the "Thrift Plan"). The Thrift Plan generally provides for matching employer contributions of 50% of participants' contributions up to 6% of compensation. These matching employer contributions are typically made in cash. 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 totaled approximately $14.4 million, $13.4 million and $8.9 million in the years ended December 31, 2017, 2016 and 2015, respectively.

We also provide benefits under the MEGTEC Union Plan, a defined contribution plan. The total employer contribution expense for the Union plan was approximately $0.2 million, $0.3 million and $0.3 million in the years ended December 31, 2017, 2016 and 2015, respectively. Matching employer contributions are made in cash.

We also provide benefits under the Universal Defined Contribution Plan (the "Universal Plan"). The total employer contribution expense for the Universal Plan was approximately $0.5 million in the year ended December 31, 2017. Matching employer contributions are made in cash.

Effective December 31, 2016, we merged the MEGTEC Non-union Plan and SPIG 401(k) defined contribution plans into the Thrift Plan. For the MEGTEC Non-union Plan, amounts charged to expense for our contributions were approximately $1.1 million and $1.1 million in the years ended December 31, 2016 and 2015, respectively. Matching employer contributions were made in cash. The SPIG 401(k) plan contributions were also made in cash, and were not material to our consolidated financial statements in 2016.

Also, our salaried Canadian employees are provided with a defined contribution plan. As of and in the periods following January 1, 2012, we made cash, service-based contributions under this arrangement. The amount charged to expense for

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employer contributions was approximately $0.3 million, $0.4 million and $0.1 million in the years ended December 31, 2017, 2016 and 2015, respectively.

Multi-employer plans

One of our subsidiaries in the Power segment contributes to various multi-employer plans. The plans generally provide defined benefits to substantially all unionized workers in this subsidiary. The following table summarizes our contributions to multi-employer plans for the years covered by this report:

Pension Fund	EIN/PIN	Pension Protection Act Zone Status		FIP/RP  Status Pending/ Implemented	Contributions						Surcharge Imposed	Expiration Date Of Collective Bargaining Agreement
					2017		2016		2015
		2017	2016		(in millions)
Boilermaker-Blacksmith National Pension Trust	48-6168020/ 001	Yellow	Yellow	Yes	$	7.9	$	17.8	$	20.3	No	Described Below
All Other					2.0		3.2		4.6
					$	9.9	$	21.0	$	24.9

Our collective bargaining agreements with the Boilermaker-Blacksmith National Pension Trust (the "Boilermaker Plan") is 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 Boilermaker 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.

See Note 29 for the future expected effect of FASB ASU 2017-07 on the presentation of benefit and expense related to our pension and post retirement plans.

NOTE 19 – REVOLVING DEBT

The components of our revolving debt are comprised of separate revolving credit facilities in the following locations:

(in thousands)	December 31, 2017		December 31, 2016
United States	$	94,300	$	9,800
Foreign	9,173		14,241
Total revolving debt	$	103,473	$	24,041

United States revolving credit facility

On May 11, 2015, we entered into a credit agreement with a syndicate of lenders ("Credit Agreement") in connection with our spin-off from The Babcock & Wilcox Company. The Credit Agreement, which is scheduled to mature on June 30, 2020, provides for a senior secured revolving credit facility, initially in an aggregate amount of up to $600.0 million. The proceeds from loans under the Credit Agreement are available for working capital needs and other general corporate purposes, and the full amount is available to support the issuance of letters of credit.

On February 24, 2017, August 9, 2017 and March 1, 2018, we entered into amendments to the Credit Agreement (the "Amendments" and the Credit Agreement, as amended to date, the "Amended Credit Agreement") to, among other things: (1) permit us to incur the debt under the second lien term loan facility (discussed further in Note 20), (2) modify the definition of EBITDA in the Amended Credit Agreement to exclude: up to $98.1 million of charges for certain Renewable segment contracts for periods including the quarter ended December 31, 2016, up to $115.2 million of charges for certain Renewable segment contracts for periods including the quarter ended June 30, 2017, up to $30.1 million of charges for certain Renewable segment contracts for periods including the quarter ended September 30, 2017, up to $38.7 million of charges for certain Renewable segment contracts for periods including the quarter ended December 31, 2017, up to $4.0 million of aggregate restructuring expenses incurred during the period from July 1, 2017 through September 30, 2018 measured on a consecutive four-quarter basis, realized and unrealized foreign exchange losses resulting from the impact of foreign currency

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changes on the valuation of assets and liabilities, and fees and expenses incurred in connection with the August 9, 2017 and March 1, 2018 amendments, (3) replace the maximum leverage ratio with a maximum senior debt leverage ratio, (4) decrease the minimum consolidated interest coverage ratio, (5) limit our ability to borrow under the Amended Credit Agreement during the covenant relief period to $250.0 million in the aggregate, (6) reduce commitments under the revolving credit facility from $600.0 million to $450.0 million, (7) require us to maintain liquidity (as defined in the Amended Credit Agreement) of at least $75.0 million as of the last business day of any calendar month, (8) require us to repay outstanding borrowings under the revolving credit facility (without any reduction in commitments) with certain excess cash, (9) increase the pricing for borrowings and commitment fees under the Amended Credit Agreement, (10) limit our ability to incur debt and liens during the covenant relief period, (11) limit our ability to make acquisitions and investments in third parties during the covenant relief period, (12) prohibit us from paying dividends and undertaking stock repurchases during the covenant relief period (other than our share repurchase from an affiliate of AIP (discussed further in Note 20)), (13) prohibit us from exercising the accordion described below during the covenant relief period, (14) limit our financial and commercial letters of credit outstanding under the Amended Credit Agreement to $30.0 million, (15) require us to reduce commitments under the Amended Credit Agreement with the proceeds of certain debt issuances and asset sales, (16) beginning with the quarter ended March 31, 2018, limit to no more than $15.0 million any cumulative net income losses attributable to eight specified Vølund projects, (17) increase reporting obligations and require us to hire a third-party consultant and a chief implementation officer, (18) require us to pledge the equity of certain of our foreign subsidiaries to guarantee and provide collateral for our obligations under the United States credit facility, (19) require us to pay a deferred facility fee as more fully set forth in the March 1, 2018 Amendment, and (20) require us to sell at least $100 million of assets before March 31, 2019. The covenant relief period will end, at our election, when the conditions set forth in the Amended Credit Agreement are satisfied, but in no event earlier than the date on which we provide the compliance certificate for our fiscal quarter ended December 31, 2019.

Other than during the covenant relief period, the Amended Credit Agreement contains an accordion feature that allows us, subject to the satisfaction of certain conditions, including the receipt of increased commitments from existing lenders or new commitments from new lenders, to increase the amount of the commitments under the revolving credit facility in an aggregate amount not to exceed the sum of (1) $200.0 million plus (2) an unlimited amount, so long as for any commitment increase under this subclause (2) our senior leverage ratio (assuming the full amount of any commitment increase under this subclause (2) is drawn) is equal to or less than 2.00:1.0 after giving pro forma effect thereto. During the covenant relief period, our ability to exercise the accordion feature will be prohibited.

The Amended Credit Agreement and our obligations under certain hedging agreements and cash management agreements with our lenders and their affiliates are (1) guaranteed by substantially all of our wholly owned domestic subsidiaries, but excluding our captive insurance subsidiary, and (2) secured by first-priority liens on certain assets owned by us and the guarantors. The Amended Credit Agreement requires interest payments on revolving loans on a periodic basis until maturity. We may prepay all loans at any time without premium or penalty (other than customary LIBOR breakage costs), subject to notice requirements. The Amended Credit Agreement requires us to make certain prepayments on any outstanding revolving loans after receipt of cash proceeds from certain asset sales or other events, subject to certain exceptions and a right to reinvest such proceeds in certain circumstances. During the covenant relief period, such prepayments may require us to reduce the commitments under the Amended Credit Agreement by a corresponding amount of such prepayments. Following the covenant relief period, such prepayments will not require us to reduce the commitments under the Amended Credit Agreement.

The March 1, 2018 Amendment temporarily waived certain defaults and events of default under our United States credit facility that were breached on December 31, 2017 or that may occur in the future, with certain amendments effective immediately and other amendments effective upon the completion of the Rights Offering and the repayment of the outstanding balance of our Second Lien Notes Offering. If the Rights Offering and the repayment of the outstanding balance of our Second Lien Notes Offering do not occur by April 15, 2018 (subject to extension in certain cases), the temporary waiver will end. The temporary waiver will also end if certain other conditions specified in the March 1, 2018 Amendment occur. Upon any such termination of the waiver, our ability to borrow funds under the United States credit facility will terminate.

After giving effect to the Amendments, loans outstanding under the Amended Credit Agreement bear interest at our option at either LIBOR rate plus 7.0% per annum or the Base Rate plus 6.0% per annum until we complete the Rights Offering and prepay the Second Lien Term Loan facility and thereafter at our option at either (1) the LIBOR rate plus 5.0% per annum during 2018, 6.0% per annum during 2019 and 7.0% per annum during 2020, or (2) the Base Rate plus 4.0% per annum during 2018, 5.0% per annum during 2019, and 6.0% per annum during 2020. The Base Rate is the highest of the Federal Funds rate plus 0.5%, the one month LIBOR rate plus 1.0%, or the administrative agent's prime rate. Interest expense

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associated with our United States revolving credit facility loans for the year ended December 31, 2017 was $11.3 million, respectively. Included in interest expense was $6.3 million of non-cash amortization of direct financing costs for the year ended December 31, 2017. A commitment fee of 1.0% per annum is charged on the unused portions of the revolving credit facility. A letter of credit fee of 2.50% per annum is charged with respect to the amount of each financial letter of credit outstanding, and a letter of credit fee of 1.50% per annum is charged with respect to the amount of each performance and commercial letter of credit outstanding. Additionally, an annual facility fee of $1.5 million is payable on the first business day of 2018 and 2019, and a pro rated amount is payable on the first business day of 2020.

The Amended Credit Agreement includes financial covenants that are tested on a quarterly basis, based on the rolling four-quarter period that ends on the last day of each fiscal quarter. After we complete the Rights Offering and the repayment of the outstanding balance of our Second Lien Notes Offering within the time period required by the March 1, 2018 Amendment, the maximum permitted senior debt leverage ratio as defined in the Amended Credit Agreement is:

• 8.50:1.0 for the quarter ended December 31, 2017,

• 7.00:1.0 for the quarter ending March 31, 2018,

• 6.50:1.0 for the quarters ending June 30, 2018 and September 30, 2018,

• 4.75:1.0 for the quarter ending December 31, 2018,

• 3.00:1.0 for the quarter ending March 31, 2019,

• 2.75:1.0 for the quarters ending June 30, 2019 and September 30, 2019 and

• 2.50:1.0 for the quarter ending December 31, 2019 and each quarter thereafter.

After we complete the Rights Offering and the repayment of the outstanding balance of our Second Lien Notes Offering within the time period required by the March 1, 2018 Amendment, the minimum consolidated interest coverage ratio as defined in the Credit Agreement is:

• 1.25:1.0 for the quarter ended December 31, 2017,

• 1.15:1.0 for the quarter ending March 31, 2018,

• 1.00:1.0 for the quarter ending June 30, 2018,

• 0.85:1.0 for the quarter ending September 30, 2018,

• 1.25:1.0 for the quarter ending December 31, 2018,

• 1.50:1.0 for the quarter ending March 31, 2019 and

• 2.00:1.0 for the quarters ending June 30, 2019 and each quarter thereafter.

Beginning with September 30, 2017, consolidated capital expenditures in each fiscal year are limited to $27.5 million.

At December 31, 2017, borrowings under the Amended Credit Agreement and foreign facilities consisted of $103.5 million at an effective interest rate of 6.89%. Usage under the Amended Credit Agreement consisted of $94.3 million of borrowings, $7.4 million of financial letters of credit and $123.7 million of performance letters of credit. After giving effect to the March 1, 2018 amendment, at December 31, 2017, we had approximately $221.4 million available for borrowings or to meet letter of credit requirements primarily based on trailing 12 month EBITDA (as defined in the Amended Credit Agreement), and our leverage and interest coverage ratios (as defined in the Amended Credit Agreement) were 2.59 and 2.50, respectively. We expect to be closest to the minimum financial covenant thresholds at September 30, 2018.

Foreign revolving credit facilities

Outside of the United States, we have revolving credit facilities in Turkey and India that are used to provide working capital to our operations in each country. These foreign revolving credit facilities allow us to borrow up to $9.2 million in aggregate and each have a one year term. At December 31, 2017, we had $9.2 million in borrowings outstanding under these foreign revolving credit facilities at an effective weighted-average interest rate of 6.07%. Subsequent to December 31, 2017, the foreign facilities were repaid and extinguished.

Letters of credit, bank guarantees and surety bonds

Certain subsidiaries primarily outside of the United States have credit arrangements with various commercial banks and other financial institutions for the issuance of letters of credit and bank guarantees in association with contracting activity. The aggregate value of all such letters of credit and bank guarantees not secured by the United States revolving credit facility as of December 31, 2017 and 2016 was $269.1 million and $255.2 million, respectively. The aggregate value of all such letters of credit and bank guarantees that are partially secured by the United States revolving credit facility as of December 31, 2017

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was $114.2 million. The aggregate value of the letters of credit provided by the Company's United States revolving credit facility in support of letters of credit outside of the United States was $40.4 million as of December 31, 2017.

We have posted surety bonds to support contractual obligations to customers relating to certain contracts. 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 adequate to support our existing contract requirements for the next 12 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, 2017, bonds issued and outstanding under these arrangements in support of contracts totaled approximately $378.8 million.

NOTE 20 – SECOND LIEN TERM LOAN FACILITY

On August 9, 2017, we entered into a second lien credit agreement (the "Second Lien Credit Agreement") with an affiliate of American Industrial Partners ("AIP"), governing a second lien term loan facility. The second lien term loan facility consists of a second lien term loan in the principal amount of $175.9 million, all of which was borrowed on August 9, 2017, and a delayed draw term loan facility in the principal amount of up to $20.0 million, which was drawn in a single draw on December 13, 2017.

Borrowings under the second lien term loan, other than the delayed draw term loan, have a coupon interest rate of 10% per annum, and borrowings under the delayed draw term loan have a coupon interest rate of 12% per annum, in each case payable quarterly. Undrawn amounts under the delayed draw term loan accrue a commitment fee at a rate of 0.50%, which was paid at closing. The second lien term loan and the delayed draw term loan have a scheduled maturity of December 30, 2020.

In connection with our entry into the second lien term loan facility, we used $50.9 million of the proceeds to repurchase and retire approximately 4.8 million shares of our common stock (approximately 10% of our shares outstanding) held by an affiliate of AIP, which was one of the conditions precedent for the second lien term loan facility. Based on observable and unobservable market data, we determined the fair value of the shares we repurchased from the related party on August 9, 2017 was $16.7 million. We utilized a discounted cash flow model and estimates of our weighted average cost of capital on the transaction date to derive the estimated fair value of the share repurchase. The $34.2 million difference between the share repurchase price and the fair value of the repurchased shares was recorded as a discount on the second lien term facility borrowing. Non-cash amortization of the debt discount and direct financing costs will be accreted to the carrying value of the loan through interest expense over the term of the second lien term loan facility utilizing the effective interest method and an effective interest rate of 18.11%.

The carrying value of the second lien term loan facility at December 31, 2017 was as follows (in thousands):

Face value	Unamortized debt discount and direct financing costs	Net carrying value
$195,884	$35,743	$160,141

Interest expense associated with our second lien credit agreement is comprised of the following:

(in thousands)	Coupon Interest	Accretion of debt discount and amortization of financing costs	Total Interest Expense
For the three months ended September 30, 2017	$2,554	$1,095	$3,649
For the three months ended December 31, 2017	$4,657	$2,131	$6,788
Forecasted for the year ending December 31, 2018	$20,266	$9,838	$30,104

Borrowings under the Second Lien Credit Agreement are (1) guaranteed by substantially all of our wholly owned domestic subsidiaries, but excluding our captive insurance subsidiary, and (2) secured by second-priority liens on certain assets owned by us and the guarantors. The Second Lien Credit Agreement requires interest payments on loans on a quarterly basis until maturity. Voluntary prepayments made during the first year after closing are subject to a make-whole premium, voluntary

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prepayments made during the second year after closing are subject to a 3.0% premium and voluntary prepayments made during the third year after closing are subject to a 2.0% premium. The Second Lien Credit Agreement requires us to make certain prepayments on any outstanding loans after receipt of cash proceeds from certain asset sales or other events, subject to certain exceptions and a right to reinvest such proceeds in certain circumstances, and subject to certain restrictions contained in an intercreditor agreement among the lenders under the Amended Credit Agreement and the Second Lien Credit Agreement.

The Second Lien Credit Agreement contains representations and warranties, affirmative and restrictive covenants, financial covenants and events of default substantially similar to those contained in the Amended Credit Agreement, subject to certain cushions. The Second Lien Credit Agreement is generally less restrictive than the Amended Credit Agreement. At December 31, 2017, we were in default of several financial covenants associated in the Second Lien Credit Agreement, which resulted in our classification of all of the $160.1 million net carrying value as a current liability in our consolidated balance sheet. Under the terms of the intercreditor agreement among the lenders under the United States Revolving Credit Agreement and the Second Lien Credit Agreement, we have a 180 day standstill period after March 1, 2018 to remedy the event of default under the Second Lien Credit Agreement. See Note 1 for our remediation plan.

The March 1, 2018 United States Revolving Credit Facility amendment temporarily waived all events of default, including cross-default provisions, which resulted in the outstanding balance being classified as noncurrent in our consolidated balance sheet at December 31, 2017.

NOTE 21 – CONTINGENCIES

ARPA litigation

On February 28, 2014, the Arkansas River Power Authority ("ARPA") filed suit against Babcock & Wilcox Power Generation Group, Inc. (now known as The Babcock & Wilcox Company and referred to herein as "BW PGG") in the United States District Court for the District of Colorado (Case No. 14-cv-00638-CMA-NYW) alleging breach of contract, negligence, fraud and other claims arising out of BW PGG's delivery of a circulating fluidized bed boiler and related equipment used in the Lamar Repowering Project pursuant to a 2005 contract.

A jury trial took place in mid-November 2016. Some of ARPA's claims were dismissed by the judge during the trial. The jury's verdict on the remaining claims was rendered on November 21, 2016. The jury found in favor of B&W with respect to ARPA's claims of fraudulent concealment and negligent misrepresentation and on one of ARPA's claims of breach of contract. The jury found in favor of ARPA on the three remaining claims for breach of contract and awarded damages totaling $4.2 million, which exceeded the previous $2.3 million accrual we established in 2012 by $1.9 million. Accordingly, we increased our accrual by $1.9 million in the fourth quarter of 2016.

ARPA also requested that pre-judgment interest of $4.1 million plus post-judgment interest at a rate of 0.77% compounded annually be added to the judgment, together with certain litigation costs. The court granted ARPA $3.7 million of pre-judgment interest on July 21, 2017, which we recorded in our June 30, 2017 consolidated financial statements in other accrued liabilities and interest expense. B&W commenced an appeal of the judgment on August 18, 2017, and ARPA filed a notice of cross appeal on August 31, 2017.

In December 2017, we reached an agreement in principle to settle all matters related to the ARPA litigation for $7.0 million. The agreement requires us to make payments of $2.5 million, $2.5 million and $2.0 million on July 1, 2018, 2019 and 2020, respectively. We discounted the liability by approximately $0.6 million at December 31, 2017, and $2.5 million and $3.9 million was included in other current accrued liabilities and other noncurrent accrued liabilities, respectively, in our consolidated balance sheets at December 31, 2017. The settlement resulted in a $1.6 million reduction in our accrual in December 2017.

Stockholder litigation

On March 3, 2017 and March 13, 2017, the Company and certain of its officers were named as defendants in two separate but largely identical complaints alleging violations of the federal securities laws. The complaints were brought on behalf of a putative class of investors who purchased the Company's common stock between July 1, 2015 and February 28, 2017 and were filed in the United States District Court for the Western District of North Carolina (collectively, the "Stockholder Litigation"). During the second quarter of 2017, the Stockholder Litigation was consolidated into a single action and a lead

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plaintiff was selected by the Court. During the third quarter of 2017, the plaintiff further amended its complaint. As amended, the complaint now purports to cover investors who purchased shares between June 17, 2015 and August 9, 2017. We filed a motion to dismiss in late 2017; the court denied the motion in early 2018.

The plaintiff in the Stockholder Litigation alleges fraud, misrepresentation and a course of conduct relating to the facts surrounding certain projects underway in the Company's Renewable segment, which, according to the plaintiff, had the effect of artificially inflating the price of the Company's common stock. The plaintiff further alleges that stockholders were harmed when the Company later disclosed that it would incur losses on these projects. The plaintiff seeks an unspecified amount of damages.

On February 16, 2018 and February 22, 2018, the Company and certain of its officers and directors were named as defendants in three separate but substantially similar derivative lawsuits filed in the United States District Court for the District of Delaware (the “Derivative Litigation”). The allegations and claims against defendants are largely the same. Plaintiffs assert a variety of claims against defendants including alleged violations of the federal securities laws, gross mismanagement, waste, breach of fiduciary duties and unjust enrichment. Plaintiffs, who all purport to be current shareholders of the Company's common stock, are suing on behalf of the Company to recover costs and unspecified damages, and force implementation of corporate governance changes.

We believe the allegations in the Stockholder Litigation and the Derivative Litigation are without merit, and that the respective outcomes of the Stockholder Litigation and the Derivative Litigation will not have a material adverse impact on our consolidated financial condition, results of operations or cash flows, net of any insurance coverage.

Other

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, premises liability and other claims. Based on 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.

NOTE 22 – DERIVATIVE FINANCIAL INSTRUMENTS

Our foreign currency exchange ("FX") forward contracts that qualify for hedge accounting are designated as cash flow hedges. The hedged risk is the risk of changes in functional-currency-equivalent cash flows attributable to changes in FX spot rates of forecasted transactions related to long-term contracts. We exclude from our assessment of effectiveness the portion of the fair value of the FX forward contracts attributable to the difference between FX spot rates and FX forward rates. At December 31, 2017 and 2016, we had deferred approximately $1.8 million and $0.8 million, respectively, of net gains on these derivative financial instruments in accumulated other comprehensive income ("AOCI").

At December 31, 2017, our derivative financial instruments consisted solely of FX forward contracts. The notional value of our FX forward contracts totaled $63.0 million at December 31, 2017 with maturities extending to November 2019. These instruments consist primarily of contracts to purchase or sell euros and British pounds sterling. 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 party to our United States revolving credit facility. Our hedge counterparties have the benefit of the same collateral arrangements and covenants as described under our United States revolving credit facility. During the third quarter of 2017, our hedge counterparties removed the lines of credit supporting new FX forward contracts. Subsequently, we have not entered into any new FX forward contracts.

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The following tables summarize our derivative financial instruments:

	Asset and Liability Derivative
(in thousands)	December 31, 2017		December 31, 2016
Derivatives designated as hedges:
Foreign exchange contracts:
Location of FX forward contracts designated as hedges:
Accounts receivable-other	$	1,088	$	3,805
Other assets	312		665
Accounts payable	105		1,012
Other liabilities	—		213
Derivatives not designated as hedges:
Foreign exchange contracts:
Location of FX forward contracts not designated as hedges:
Accounts receivable-other	$	7	$	105
Accounts payable	1,722		403
Other liabilities	12		7

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

	Year Ended December 31,
(in thousands)	2017			2016
Derivatives designated as hedges:
Cash flow hedges
Foreign exchange contracts
Amount of gain (loss) recognized in other comprehensive income	$	3,346		2,208
Effective portion of gain (loss) reclassified from AOCI into earnings by location:
Revenues	10,059			4,624
Cost of operations	(118		)	195
Other-net	(7,438		)	(1,221		)
Portion of gain (loss) recognized in income that is excluded from effectiveness testing by location:
Other-net	(5,277		)	4,518
Derivatives not designated as hedges:
Forward contracts
Loss recognized in income by location:
Other-net	$	(3,436	)	$	(872	)

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NOTE 23 – FAIR VALUE MEASUREMENTS

The following tables summarize our financial assets and liabilities carried at fair value, all of which were valued from readily available prices or using inputs based upon quoted prices for similar instruments in active markets (known as "Level 1" and "Level 2" inputs, respectively, in the fair value hierarchy established by the FASB Topic Fair Value Measurements and Disclosures).

(in thousands)
Available-for-sale securities	December 31, 2017		Level 1		Level 2		Level 3
Commercial paper	$	1,895	$	—	$	1,895	$	—
Certificates of deposit	2,398		—		2,398		—
Mutual funds	1,331		—		1,331		—
Corporate notes and bonds	4,447		4,447		—		—
United States Government and agency securities	5,738		5,738		—		—
Total fair value of available-for-sale securities	$	15,809	$	10,185	$	5,624	$	—

(in thousands)
Available-for-sale securities	December 31, 2016		Level 1		Level 2		Level 3
Commercial paper	$	6,734	$	—	$	6,734	$	—
Certificates of deposit	2,251		—		2,251		—
Mutual funds	1,152		—		1,152		—
Corporate notes and bonds	750		750		—		—
United States Government and agency securities	7,104		7,104		—		—
Total fair value of available-for-sale securities	$	17,991	$	7,854	$	10,137	$	—

Derivatives	December 31, 2017			December 31, 2016
Forward contracts to purchase/sell foreign currencies	$	(432	)	$	2,940

Available-for-sale securities

We estimate the fair value of available-for-sale securities based on quoted market prices. Our investments in available-for-sale securities are presented in "other assets" on our consolidated balance sheets.

Derivatives

Derivative assets and liabilities currently consist of FX forward contracts. 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.

Other financial instruments

We used the following methods and assumptions in estimating our fair value disclosures for our other financial instruments:

• 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 and restricted cash and cash equivalents approximate their fair values due to their highly liquid nature.

• Revolving 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, 2017 and December 31, 2016.

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Non-recurring fair value measurements

The purchase price allocation associated with the January 11, 2017 acquisition of Universal required significant fair value measurements using unobservable inputs ("Level 3" inputs as defined in the fair value hierarchy established by FASB Topic Fair Value Measurements and Disclosures). The fair value of the acquired intangible assets was determined using the income approach (see Note 5).

The other-than-temporary impairment of our equity method investment in TBWES (see Note 7) required significant fair value measurements using unobservable inputs. We determined the impairment charge by first determining an estimate of the price that could be received to sell the assets and transfer the liabilities held by TBWES in an orderly transaction between market participants at June 30, 2017. The fair value of TBWES's net assets was determined through a combination of the cost approach, a market approach and an income approach.

Our interim goodwill impairment tests and third quarter impairment charges required significant fair value measurements using unobservable inputs (see Note 15). The fair value of each reporting unit determined under Step 1 of the goodwill impairment test was based on an income approach using a discounted cash flow analysis, a market approach using multiples of revenue and EBITDA of guideline companies, and a market approach using multiples of revenue and EBITDA from recent, similar business combinations. The fair value of the assets and liabilities for the Renewable and SPIG reporting units determined under Step 2 of the goodwill impairment test were based on either an income or market approach.

The measurement of the net actuarial gain or loss associated with our pension and other postretirement plans was determined using unobservable inputs (see Note 18). These inputs included the estimated discount rate, expected return on plan assets and other actuarial inputs associated with the plan participants.

The determination of the estimated fair value of the related party share repurchase required significant fair value measurements using unobservable inputs (see Note 20). We utilized a discounted cash flow model and estimates of our weighted average cost of capital on the transaction date to derive the estimated fair value of the share repurchase.

NOTE 24 – SUPPLEMENTAL INFORMATION

During the twelve months ended December 31, 2017, 2016 and 2015, we recognized the following non-cash activity in our consolidated financial statements:

(in thousands)	2017		2016		2015
Accrued capital expenditures in accounts payable	$	1,383	$	2,751	$	568
Accreted interest expense on our second lien term loan facility	$	3,226	$	—	$	—

During the years ended December 31, 2017, 2016 and 2015 we recognized the following cash activity in our consolidated financial statements:

(in thousands)	2017			2016		2015
Income tax payments (refunds), net	$	(10,889	)	$	10,781	$	15,008
Interest payments on our United States revolving credit facility	$	4,909		$	425	$	—
Interest payments on our second lien term loan facility	$	7,044		$	—	$	—

During the years ended December 31, 2017, 2016 and 2015, interest expense in our consolidated financial statements consisted of the following components:

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(in thousands)	2017		2016		2015
Components associated with borrowings from:
United States revolving credit facility	$	5,051	$	1,669	$	1,059
Second lien term loan facility	7,211		—		—
Foreign revolving credit facilities	1,021		847		148
	13,283		2,516		1,207
Components associated with amortization or accretion of:
United States revolving credit facility deferred financing fees	6,270		1,244		1,131
Second lien term loan facility deferred financing fees and discount	3,226		—		—
	9,496		1,244		1,131
Other interest expense	3,526		36		—
Total interest expense	$	26,305	$	3,796	$	2,338

In the year ended December 31, 2017, other interest expense in the table above is primarily attributable to the $3.0 million of interest expense associated with the ARPA litigation settlement (see Note 21). Interest expense included in our consolidated and combined statement of operations for the year ended December 31, 2015 has been corrected to reclassify $1.3 million of interest expense from "other - net" to "interest expense."

NOTE 25 – RELATED PARTY TRANSACTIONS

Prior to June 30, 2015, we were a party to transactions with our former Parent and its subsidiaries in the normal course of operations. After the spin-off, we no longer consider the former Parent to be a related party. Transactions with our former Parent prior to the spin-off included the following:

(in thousands)	Year Ended December 31, 2015
Sales to our former Parent	$	911
Corporate administrative expenses	35,343

Guarantees

Our former Parent had outstanding performance guarantees for various contracts executed by us in the normal course of business. As of April 21, 2016, these guarantees had all been terminated.

Net transfers from former Parent

Net transfers from former Parent represent the change in our former Parent's historical investment in us. It primarily includes the net effect of cost allocations from transactions with our former Parent, sales to our former Parent, and the net transfers of cash and assets to our former Parent prior to the spin-off. After the spin-off transaction on June 30, 2015, there have been no significant transfers to or from our former Parent. These transactions included the following:

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(in thousands)	Year Ended December 31 2015
Sales to former Parent	$	911
Corporate administrative expenses	35,343
Income tax allocation	11,872
Acquisition of business, net of cash acquired	—
Cash pooling and general financing activities	(91,015		)
Cash contribution received at spin-off	125,300
Net transfer from former Parent per statement of cash flows	$	80,589
Non-cash items:
Net transfer of assets and liabilities	$	44,706
Distribution of Nuclear Energy segment	$	(47,839	)
Net transfer from former Parent per statement of shareholders' equity	$	77,456

Transactions with AIP

The second lien term loan and related repurchase of shares of our common stock described in Note 20 was a related party transaction.

NOTE 26 – DISCONTINUED OPERATIONS

We received corporate allocations from our former Parent as described in Note 1, which totaled $2.7 million for the year ended December 31, 2015. Though these allocations relate to our discontinued NE segment, they are included as part of continuing operations because allocations are not eligible for inclusion in discontinued operations.

The following table presents selected financial information regarding the results of operations of our former NE segment through June 30, 2015, the date it was discontinued:

	Six Months Ended June 30,
(in thousands)	2015
Revenues	$	53,064
Income (loss) before income tax expense	3,358
Income tax expense (benefit)	555
Income (loss) from discontinued operations, net of tax	$	2,803

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NOTE 27 – FUTURE MINIMUM PAYMENTS

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, 2017 are as follows (in thousands):

Fiscal Year Ending December 31,	Amount
2018	$	6,814
2019	$	5,100
2020	$	3,553
2021	$	2,741
2022	$	2,258
Thereafter	$	3,337

Total rental expense for the years ended December 31, 2017, 2016 and 2015, was $10.5 million, $8.3 million and $13.5 million, respectively.

Long-term borrowings

Maturities of our long-term borrowings in the five years succeeding December 31, 2017 are as follows (in thousands):

Fiscal year ending December 31,	Amount
2018	$	9,173
2019	$	—
2020	$	290,184
2021	$	—
2022	$	—
Thereafter	$	—

NOTE 28 – QUARTERLY FINANCIAL DATA

The following tables set forth selected unaudited quarterly financial information for the years ended December 31, 2017 and 2016:

(in thousands, except per share amounts)	Quarter ended
	March 31, 2017			June 30, 2017			Sept. 30, 2017			Dec. 31, 2017
Revenues	$	391,104		$	349,829		$	408,703		$	408,099
Gross profit	$	62,900		$	(55,822	)	$	47,287		$	45,513
Operating income (loss) (1)	$	(8,798	)	$	(144,646	)	$	(104,748	)	$	(23,373	)
Equity in income (loss) of investees	$	618		$	(15,232	)	$	1,234		$	3,513
Net income (loss) attributable to shareholders	$	(7,045	)	$	(150,999	)	$	(114,302	)	$	(107,478	)
Earnings per common share
Basic	$	(0.14	)	$	(3.09	)	$	(2.48	)	$	(2.44	)
Diluted	$	(0.14	)	$	(3.09	)	$	(2.48	)	$	(2.44	)

⁽¹⁾  Includes equity in income of investees.

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(in thousands, except per share amounts)	Quarter ended
	March 31, 2016		June 30, 2016			Sept. 30, 2016		Dec. 31, 2016
Revenues	$	404,116	$	383,208		$	410,955	$	379,984
Gross profit	$	80,156	$	26,052		$	73,757	$	(848	)
Operating income (loss) (1)	$	17,266	$	(72,585	)	$	11,133	$	(58,587	)
Equity in income (loss) of investees	$	2,676	$	(616	)	$	2,827	$	11,553
Net income (loss) attributable to shareholders	$	10,507	$	(63,490	)	$	8,894	$	(71,560	)
Earnings per common share
Basic	$	0.20	$	(1.25	)	$	0.18	$	(1.47	)
Diluted	$	0.20	$	(1.25	)	$	0.18	$	(1.47	)

⁽¹⁾  Includes equity in income of investees.

Our quarterly results include the following items that significant affect comparability across periods:

• Actuarial gains and losses from marking to market our pension and postretirement benefit plan assets and liabilities (see Note 18). Such mark to market adjustments resulted in (charges) gains of: $9.8 million in the fourth quarter of 2017, $(1.1) million in the first quarter of 2017, $6.4 million in the fourth quarter of 2016, $(0.5) million in the third quarter of 2016, and $(30.0) million in the second quarter of 2016.

• In the third quarter of 2017, $86.9 million of goodwill impairment charges (see Note 15).

• In the second and fourth quarters of both 2017 and 2016, significant losses related to changes in the estimates of the forecasted revenues and costs to complete six renewable energy contracts (see Note 6).

• In the fourth quarter of 2017, $62.4 million of additional income tax expense resulting from the enactment of new tax legislation in the United States on December 22, 2017 (see Note 10).

NOTE 29 – NEW ACCOUNTING STANDARDS

New accounting standards that could affect our consolidated financial statements in the future are summarized as follows:

In May 2014, the FASB issued ASU 2014-09, Revenue from Contracts with Customers. The new accounting standard provides a comprehensive model to use in accounting for revenue from contracts with customers and will replace most existing revenue recognition guidance when it becomes effective. In 2016, the FASB issued accounting standards updates to address implementation issues and to clarify the guidance for identifying performance obligations, licenses; determining if an entity is the principal or agent in a revenue arrangement; and technical corrections and improvements on topics including: contract costs, loss provisions on construction and production contracts and disclosures for remaining and prior-period performance obligations. The new accounting standard also requires more detailed disclosures to enable financial statement users to understand the nature, amount, timing, and uncertainty of revenue and cash flows arising from contracts with customers. The new accounting standard is effective for interim and annual reporting periods beginning after December 15, 2017, and permits retrospectively applying the guidance to each prior reporting period presented (full retrospective method) or prospectively applying the guidance and providing additional disclosures comparing results to previous guidance, with the cumulative effect of initially applying the guidance recognized in beginning retained earnings at the date of initial application (modified retrospective method). We will adopt the new accounting standard under the modified retrospective method. We have developed a cross-functional team of B&W professionals from across each of our reportable segments and an implementation plan to adopt the new accounting standard during the first quarter of 2018. We have analyzed our primary revenue streams and performed a detailed review of a sample of key contracts representative of our products and services in order to assess potential changes in our processes, systems, internal controls and the timing and method of revenue recognition and related disclosures. Our evaluation included the existing, uncompleted contracts at January 1, 2018. Based on our assessment, we do not expect the timing of revenue recognition to change significantly upon adoption of the new accounting standard, but we do expect our revenue recognition disclosures will be expanded.

In January 2016, the FASB issued ASU 2016-01, Financial Instruments-Overall: Recognition and Measurement of Financial Assets and Financial Liabilities. The new accounting standard is effective for us beginning in 2018, but early adoption is

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permitted. The new accounting standard requires investments such as available-for-sale securities to be measured at fair value through earnings each reporting period as opposed to changes in fair value being reported in other comprehensive income. We do not expect the new accounting standard to have a significant impact on our financial results when adopted.

In February 2016, the FASB issued ASU 2016-02, Leases (Topic 842). With adoption of this standard, lessees will have to recognize almost all leases as a right-of-use asset and a lease liability on their balance sheet. For income statement purposes, the FASB retained a dual model, requiring leases to be classified as either operating or finance. Classification will be based on criteria that are similar to those applied in current lease accounting, but without explicit bright lines. The new accounting standard is effective for us beginning in 2019. We do not expect the new accounting standard to have a significant impact on our financial results when adopted, but will result in new balances in the consolidated balance sheets and new disclosures in the Notes.

In August 2016, the FASB issued ASU 2016-15, Statement of Cash Flows (Topic 230): Classification of Certain Cash Receipts and Cash Payments. The new guidance is intended to reduce diversity in practice in how certain transactions are classified in the statement of cash flows. Of the eight classification-related changes this new standard will require in the statement of cash flows, only two of the classification requirements are relevant to our historical cash flow statement presentation (presentation of debt prepayments and presentation of distributions from equity method investees). However, the new classification requirements would not have changed our historical statement of cash flows. The new standard is effective for us beginning in 2018. We do not plan to early adopt the new accounting standard because the impact is not expected to be material to our consolidated statement of cash flows when adopted.

In January 2017, the FASB issued ASU 2017-01, Business Combinations (Topic 805): Clarifying the Definition of a Business. The new guidance clarifies the definition of a business in an effort to make the guidance more consistent. The guidance provides a test for determining when a group of assets and business activities is not a business, specifically, when substantially all of the fair value of the gross assets acquired or disposed of are concentrated in a single identifiable asset or group of assets, and if inputs and substantive processes that significantly contribute to the ability to create outputs is not present. The new accounting standard is effective for us beginning in 2018. We do not expect the new accounting standard to have a significant impact on our financial results when we adopted.

In January 2017, the FASB issued ASU 2017-04, Intangibles - Goodwill and Other (Topic 350): Simplifying the Test for Goodwill Impairment. The new guidance removes the requirement to compare implied fair value of goodwill with the carrying amount, therefore impairment charges would be recognized immediately by the amount which carrying value exceeds fair value. The new accounting standard is effective beginning in 2020. We are currently assessing the impact that adopting this new accounting standard will have on our consolidated financial statements.

In March 2017, the FASB issued ASU 2017-07, Compensation - Retirement Benefits (Topic 715): Improving the Presentation of Net Periodic Benefit Cost and Net Periodic Postretirement Benefit Cost. The new guidance classifies service cost as the only component of net periodic benefit cost presented in cost of operations, whereas the other components will be presented in other income. This will affect not only how we present net periodic benefit cost, but also how we present segment gross profit and operating income upon adoption. The new accounting standard is effective for us beginning in 2018, and we will retrospectively apply the guidance to each prior reporting period presented. We have assessed the impact of adopting the new standard on our consolidated statement of operations and determined the required reclassifications will primarily impact our Power segment's gross profit. The changes in the classification of the historical components of net periodic benefit costs are summarized in the following table:

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Pension & other postretirement benefit costs (benefits)
(in thousands)	December 31, 2017			December 31, 2016			December 31, 2015			Current classification	Future classification
Service cost	$	804		$	1,703		$	13,701		Cost of operations	Cost of operations
Interest cost	41,432			41,772			50,644			Cost of operations	Other income (expense)
Expected return on plan assets	(59,409		)	(61,939		)	(68,709		)	Cost of operations	Other income (expense)
Amortization of prior service cost	(2,906		)	250			307			Cost of operations	Other income (expense)
Recognized net actuarial losses and mark to market adjustments	(8,696		)	24,110			40,210			Cost of operations or SG&A expense	Other income (expense)
Net periodic benefit cost (benefit)	$	(28,775	)	$	5,896		$	36,153

Item 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND FINANCIAL DISCLOSURE

None

Item 9A. Controls and Procedures

Disclosure controls and procedures

As of the end of the period covered by this report, the Company's management, with the participation of our Chief Executive Officer and the Chief Financial Officer, evaluated the effectiveness of the design and operation of our disclosure controls and procedures as defined in Rules 13a-15(e) and 15d-15(e) of the Securities Exchange Act of 1934, as amended (the "Exchange Act"). Disclosure controls and procedures are the controls and processes that are designed to ensure 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 SEC's rules and forms. Disclosure controls and procedures include, without limitation, controls and procedures designed to ensure that information required to be disclosed in the reports that the Company files or submits under the Exchange Act is accumulated and communicated to management, as appropriate, to allow timely decisions regarding required disclosures. 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. 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 provide absolute assurance 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, management of B&W concluded that as of December 31, 2017 the design and operation of our disclosure controls and procedures are effective 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.

On January 11, 2017, we acquired Universal, which would have represented approximately which represented approximately 6% of our consolidated total assets and 4% of our consolidated revenues as of and for the year ended December 31, 2017, respectively. As the acquisition occurred during the last 12 months, the scope of our assessment of the effectiveness of disclosure controls and procedures does not include internal control over financial reporting related to Universal. This exclusion is in accordance with the SEC's general guidance that an assessment of a recently acquired business may be omitted from our internal control over financial reporting scope in the year of acquisition.

Remediation of prior material weakness

The Company's management has concluded the the material weakness in internal control over financial reporting associated with the completeness and accuracy of the information used in the percentage of completion accounting at Vølund, a business

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unit within our Renewable segment, was remediated as of December 31, 2017. As of September 30, 2017, management fully implemented the remediation plan, and we determined through testing that the internal controls at Volund were effective at December 31, 2017.

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Management's Report on Internal Control Over Financial Reporting

B&W's management is responsible for establishing and maintaining adequate internal control over financial reporting (as defined in Rules 13a-15(f) and 15d-15(f) under the Securities Exchange Act of 1934, as amended). Our internal control over financial reporting includes, among other things, policies and procedures for conducting business, information systems for processing transactions and an internal audit department. Mechanisms are in place to monitor the effectiveness of our internal control over financial reporting and actions are taken to remediate identified internal control deficiencies. Our procedures for financial reporting include the involvement of senior management, our Audit and Finance Committee and our staff of financial and legal professionals. Our financial reporting process and associated internal controls were designed to provide reasonable assurance to management and the Board of Directors regarding the reliability of financial reporting and the preparation of our consolidated financial statements for external reporting in accordance with accounting principles generally accepted in the United States of America.

Management, with the participation of our principal executive and financial officers, assessed the effectiveness of our internal control over financial reporting as of December 31, 2017. Management based its assessment on criteria established in Internal Control–Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission (2013 framework). Because of its inherent limitations, a system of internal control over financial reporting can provide only reasonable assurance as to its effectiveness, and may not prevent or detect misstatements. Further, because of changing conditions, effectiveness of internal control over financial reporting may vary over time. Based on our assessment, management has concluded that B&W's internal control over financial reporting was effective at the reasonable assurance level described above as of December 31, 2017.

On January 11, 2017, we acquired Universal Acoustic & Emission Technologies, Inc. ("Universal"), which represented approximately 6% of our consolidated total assets and 4% of our consolidated revenues as of and for the year ended December 31, 2017, respectively. As permitted by the Securities and Exchange Commission, management has elected to exclude Universal from its assessment of internal control over financial reporting as of December 31, 2017.

The effectiveness of our internal control over financial reporting as of December 31, 2017 has been audited by Deloitte & Touche LLP, the independent registered public accounting firm who also audited our consolidated financial statements included in this Annual Report on Form 10-K. Deloitte & Touche LLP’s report on our internal control over financial reporting is included in this Annual Report on Form 10-K.

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REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

To the Stockholders and Board of Directors of Babcock & Wilcox Enterprises, Inc.:

Opinion on Internal Control over Financial Reporting

We have audited the internal control over financial reporting of Babcock & Wilcox Enterprises, Inc. and subsidiaries (the “Company”) as of December 31, 2017, based on criteria established in Internal Control - Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission (COSO). In our opinion, the Company maintained, in all material respects, effective internal control over financial reporting as of December 31, 2017, based on criteria established in Internal Control - Integrated Framework (2013) issued by COSO.

We have also audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States) (PCAOB), the consolidated and combined financial statements as of and for the year ended December 31, 2017 of the Company and our report dated March 1, 2018 expressed an unqualified opinion on those financial statements and includes an explanatory paragraph related to the completion of the spin-off of the Company effective June 30, 2015 by The Babcock and Wilcox Company and an explanatory paragraph related to the Company’s ability to continue as a going concern.

As described in Management’s Report on Internal Control Over Financial Reporting, management excluded from its assessment the internal control over financial reporting at Universal Acoustic & Emission Technologies, Inc. ("Universal"), which was acquired on January 11, 2017 and whose financial statements constitute approximately 6% of total assets and approximately 4% of revenues of the consolidated financial statement amounts as of and for the year ended December 31, 2017. Accordingly, our audit did not include the internal control over financial reporting at Universal.

Basis for Opinion

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 are a public accounting firm registered with the PCAOB and are required to be independent with respect to the Company in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.

We conducted our audit in accordance with the standards of the PCAOB. 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.

Definition and Limitations of Internal Control over Financial Reporting

A company’s internal control over financial reporting is a process designed 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 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.

/S/ DELOITTE & TOUCHE LLP

Charlotte, North Carolina

March 1, 2018

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Changes in internal control over financial reporting

There were no changes in our internal control over financial reporting during the quarter ended December 31, 2017 that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

Item 9B.    OTHER INFORMATION

Amended credit agreement

On May 11, 2015, we entered into a credit agreement with a syndicate of lenders ("Credit Agreement") in connection with our spin-off from The Babcock & Wilcox Company. The Credit Agreement, which is scheduled to mature on June 30, 2020, provides for a senior secured revolving credit facility, initially in an aggregate amount of up to $600.0 million. The proceeds from loans under the Credit Agreement are available for working capital needs and other general corporate purposes, and the full amount is available to support the issuance of letters of credit.

On February 24, 2017, August 9, 2017 and March 1, 2018, we entered into amendments to the Credit Agreement (the "Amendments" and the Credit Agreement, as amended to date, the "Amended Credit Agreement") to, among other things: (1) permit us to incur the debt under the second lien term loan facility (discussed further in Note 20), (2) modify the definition of EBITDA in the Amended Credit Agreement to exclude: up to $98.1 million of charges for certain Renewable segment contracts for periods including the quarter ended December 31, 2016, up to $115.2 million of charges for certain Renewable segment contracts for periods including the quarter ended June 30, 2017, up to $30.1 million of charges for certain Renewable segment contracts for periods including the quarter ended September 30, 2017, up to $38.7 million of charges for certain Renewable segment contracts for periods including the quarter ended December 31, 2017, up to $4.0 million of aggregate restructuring expenses incurred during the period from July 1, 2017 through September 30, 2018 measured on a consecutive four-quarter basis, realized and unrealized foreign exchange losses resulting from the impact of foreign currency changes on the valuation of assets and liabilities, and fees and expenses incurred in connection with the August 9, 2017 and March 1, 2018 amendments, (3) replace the maximum leverage ratio with a maximum senior debt leverage ratio, (4) decrease the minimum consolidated interest coverage ratio, (5) limit our ability to borrow under the Amended Credit Agreement during the covenant relief period to $250.0 million in the aggregate, (6) reduce commitments under the revolving credit facility from $600.0 million to $450.0 million, (7) require us to maintain liquidity (as defined in the Amended Credit Agreement) of at least $75.0 million as of the last business day of any calendar month, (8) require us to repay outstanding borrowings under the revolving credit facility (without any reduction in commitments) with certain excess cash, (9) increase the pricing for borrowings and commitment fees under the Amended Credit Agreement, (10) limit our ability to incur debt and liens during the covenant relief period, (11) limit our ability to make acquisitions and investments in third parties during the covenant relief period, (12) prohibit us from paying dividends and undertaking stock repurchases during the covenant relief period (other than our share repurchase from an affiliate of AIP (discussed further in Note 20)), (13) prohibit us from exercising the accordion described below during the covenant relief period, (14) limit our financial and commercial letters of credit outstanding under the Amended Credit Agreement to $30.0 million, (15) require us to reduce commitments under the Amended Credit Agreement with the proceeds of certain debt issuances and asset sales, (16) beginning with the quarter ended March 31, 2018, limit to no more than $15.0 million any cumulative net income losses attributable to eight specified Vølund projects, (17) increase reporting obligations and require us to hire a third-party consultant and a chief implementation officer, (18) require us to pledge the equity of certain of our foreign subsidiaries to guarantee and provide collateral for our obligations under the United States credit facility, (19) require us to pay a deferred facility fee as more fully set forth in the March 1, 2018 Amendment, and (20) require us to sell at least $100 million of assets before March 31, 2019. The covenant relief period will end, at our election, when the conditions set forth in the Amended Credit Agreement are satisfied, but in no event earlier than the date on which we provide the compliance certificate for our fiscal quarter ended December 31, 2019.

Other than during the covenant relief period, the Amended Credit Agreement contains an accordion feature that allows us, subject to the satisfaction of certain conditions, including the receipt of increased commitments from existing lenders or new commitments from new lenders, to increase the amount of the commitments under the revolving credit facility in an aggregate amount not to exceed the sum of (1) $200.0 million plus (2) an unlimited amount, so long as for any commitment increase under this subclause (2) our senior leverage ratio (assuming the full amount of any commitment increase under this subclause (2) is drawn) is equal to or less than 2.00:1.0 after giving pro forma effect thereto. During the covenant relief period, our ability to exercise the accordion feature will be prohibited.

The Amended Credit Agreement and our obligations under certain hedging agreements and cash management agreements with our lenders and their affiliates are (1) guaranteed by substantially all of our wholly owned domestic subsidiaries, but

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excluding our captive insurance subsidiary, and (2) secured by first-priority liens on certain assets owned by us and the guarantors. The Amended Credit Agreement requires interest payments on revolving loans on a periodic basis until maturity. We may prepay all loans at any time without premium or penalty (other than customary LIBOR breakage costs), subject to notice requirements. The Amended Credit Agreement requires us to make certain prepayments on any outstanding revolving loans after receipt of cash proceeds from certain asset sales or other events, subject to certain exceptions and a right to reinvest such proceeds in certain circumstances. During the covenant relief period, such prepayments may require us to reduce the commitments under the Amended Credit Agreement by a corresponding amount of such prepayments. Following the covenant relief period, such prepayments will not require us to reduce the commitments under the Amended Credit Agreement.

The March 1, 2018 Amendment temporarily waived certain defaults and events of default under our United States credit facility that were breached on December 31, 2017 or that may occur in the future, with certain amendments effective immediately and other amendments effective upon the completion of the Rights Offering and the repayment of the outstanding balance of our Second Lien Notes Offering. If the Rights Offering and the repayment of the outstanding balance of our Second Lien Notes Offering do not occur by April 15, 2018 (subject to extension in certain cases), the temporary waiver will end. The temporary waiver will also end if certain other conditions specified in the March 1, 2018 Amendment occur. Upon any such termination of the waiver, our ability to borrow funds under the United States credit facility will terminate.

After giving effect to the Amendments, loans outstanding under the Amended Credit Agreement bear interest at our option at either LIBOR rate plus 7.0% per annum or the Base Rate plus 6.0% per annum until we complete the Rights Offering and prepay the Second Lien Term Loan facility and thereafter at our option at either (1) the LIBOR rate plus 5.0% per annum during 2018, 6.0% per annum during 2019 and 7.0% per annum during 2020, or (2) the Base Rate plus 4.0% per annum during 2018, 5.0% per annum during 2019, and 6.0% per annum during 2020. The Base Rate is the highest of the Federal Funds rate plus 0.5%, the one month LIBOR rate plus 1.0%, or the administrative agent's prime rate. Interest expense associated with our United States revolving credit facility loans for the year ended December 31, 2017 was $11.3 million, respectively. Included in interest expense was $6.3 million of non-cash amortization of direct financing costs for the year ended December 31, 2017. A commitment fee of 1.0% per annum is charged on the unused portions of the revolving credit facility. A letter of credit fee of 2.50% per annum is charged with respect to the amount of each financial letter of credit outstanding, and a letter of credit fee of 1.50% per annum is charged with respect to the amount of each performance and commercial letter of credit outstanding. Additionally, an annual facility fee of $1.5 million is payable on the first business day of 2018 and 2019, and a pro rated amount is payable on the first business day of 2020.

The Amended Credit Agreement includes financial covenants that are tested on a quarterly basis, based on the rolling four-quarter period that ends on the last day of each fiscal quarter. After we complete the Rights Offering and the repayment of the outstanding balance of our Second Lien Notes Offering within the time period required by the March 1, 2018 Amendment, the maximum permitted senior debt leverage ratio as defined in the Amended Credit Agreement is:

• 8.50:1.0 for the quarter ended December 31, 2017,

• 7.00:1.0 for the quarter ending March 31, 2018,

• 6.50:1.0 for the quarters ending June 30, 2018 and September 30, 2018,

• 4.75:1.0 for the quarter ending December 31, 2018,

• 3.00:1.0 for the quarter ending March 31, 2019,

• 2.75:1.0 for the quarters ending June 30, 2019 and September 30, 2019 and

• 2.50:1.0 for the quarter ending December 31, 2019 and each quarter thereafter.

After we complete the Rights Offering and the repayment of the outstanding balance of our Second Lien Notes Offering within the time period required by the March 1, 2018 Amendment, the minimum consolidated interest coverage ratio as defined in the Credit Agreement is:

• 1.25:1.0 for the quarter ended December 31, 2017,

• 1.15:1.0 for the quarter ending March 31, 2018,

• 1.00:1.0 for the quarter ending June 30, 2018,

• 0.85:1.0 for the quarter ending September 30, 2018,

• 1.25:1.0 for the quarter ending December 31, 2018,

• 1.50:1.0 for the quarter ending March 31, 2019 and

• 2.00:1.0 for the quarters ending June 30, 2019 and each quarter thereafter.

Beginning with September 30, 2017, consolidated capital expenditures in each fiscal year are limited to $27.5 million.

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At December 31, 2017, borrowings under the Amended Credit Agreement and foreign facilities consisted of $103.5 million at an effective interest rate of 6.89%. Usage under the Amended Credit Agreement consisted of $94.3 million of borrowings, $7.4 million of financial letters of credit and $123.7 million of performance letters of credit. After giving effect to the March 1, 2018 amendment, at December 31, 2017, we had approximately $221.4 million available for borrowings or to meet letter of credit requirements primarily based on trailing 12 month EBITDA (as defined in the Amended Credit Agreement), and our leverage and interest coverage ratios (as defined in the Amended Credit Agreement) were 2.59 and 2.50, respectively. We expect to be closest to the minimum financial covenant thresholds at September 30, 2018.

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PART III

Item 10.    DIRECTORS, EXECUTIVE OFFICERS AND CORPORATE GOVERNANCE

The information required by this item with respect to directors is incorporated by reference to the material appearing under the heading "Election of Directors" in the Proxy Statement for our 2018 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 2018 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 2018 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." We intend to disclose promptly on our website any amendments to, or waivers of, the code covering our chief executive officer, chief financial officer and chief accounting officer.

EXECUTIVE OFFICERS

Our executive officers and their ages as of March 1, 2018, are as follows:

Name	Age	Position
Jenny L. Apker	60	Senior Vice President and Chief Financial Officer
Mark A. Carano	48	Senior Vice President, Industrial and Corporate Development
J. André Hall	52	Senior Vice President, General Counsel and Corporate Secretary
Daniel W. Hoehn	39	Vice President, Controller and Chief Accounting Officer
Mark S. Low	61	Senior Vice President, Power
Jimmy B. Morgan	49	Senior Vice President, Renewable
Leslie C. Kass	47	President and Chief Executive Officer
James J. Muckley	59	Senior Vice President, Operations

Jenny L. Apker serves as our Senior Vice President and Chief Financial Officer. Prior to the spin-off, Ms. Apker served as Vice President, Treasurer and Investor Relations of BWC since August 2012 and, prior to that time, served as Vice President and Treasurer since joining BWC in June 2010. Previously, Ms. Apker served as Vice President and Treasurer with Dex One Corporation (formerly R.H. Donnelley Corporation), a marketing services company, from May 2003 until June 2010.

Mark A. Carano serves as our Senior Vice President, Industrial and Corporate Development. Prior to the spin-off, Mr. Carano served as Senior Vice President and Chief Corporate Development Officer of BWC since August 2013. Prior to joining BWC in June 2013, Mr. Carano served as a Managing Director in the Investment Banking Group of Bank of America Merrill Lynch since 2006. Mr. Carano also previously held positions with the Investment Banking Group of Deutsche Bank.

J. André Hall serves as our Senior Vice President, General Counsel and Corporate Secretary. Prior to the spin-off, Mr. Hall served as Assistant General Counsel, Transactions and Compliance of BWC since August 2013. Prior to joining BWC, Mr. Hall served in various roles of increasing responsibility with Goodrich Corporation, an aerospace manufacturing company, most recently as Vice President of Business Conduct and Chief Ethics Officer from October 2009 until July 2012 when it was acquired by United Technologies Corporation. For the five years prior to becoming Chief Ethics Officer, Mr. Hall served as the segment general counsel for one of Goodrich Corporation’s multi-billion dollar operating segments.

Daniel W. Hoehn serves as our Vice President, Controller and Chief Accounting Officer. Mr. Hoehn joined BWC in March 2015. From 2013 to 2015, Mr. Hoehn was Vice President and Controller at Chiquita Brands International, Inc., a producer

121

and distributor of bananas and other produce, responsible for financial reporting for Chiquita's operations across three continents. From 2010 to 2013, he was Assistant Corporate Controller, after serving as Manager, Financial Reporting, from 2007 to 2010. Prior to joining Chiquita, Mr. Hoehn was a senior manager in the audit practice at KPMG, LLP.

Mark S. Low serves as our Senior Vice President, Power. From July 2015 to June 2016, he served as Senior Vice President, Global Services. Prior to the spinoff, Mr. Low was Vice President and General Manager of BWC’s Global Services Division from 2013 to March 2015. Previously, from 2012 to 2013, he was Vice President and General Manager of BWC’s Environmental Products and Services Division, responsible for all aspects of our environmental products and services business. From 2007 to 2012, he served as BWC's Vice President, Service Projects, in which he led all technical and commercial aspects of our service projects business including project management, forecasting, costing, cost forecasting, and warranty resolution.

Jimmy B. Morgan serves as our Senior Vice President, Renewable since December 2016. He is responsible for the company's renewable energy business, including its Babcock & Wilcox Volund subsidiary and Babcock & Wilcox's operations and maintenance services businesses. From August 2016 to December 2016, he served as Senior Vice President, Operations. He was Vice President, Operations from May 2016 to August 2016 and was Vice President and General Manager of Babcock & Wilcox Construction Co., Inc. from February 2016 to May 2016. Before joining Babcock & Wilcox, he was President for Allied Technical Resources, Inc., a technical staffing company, from September 2013 to January 2016. Previous positions included serving as Chief Operating Officer with BHI Energy, Vice President of Installation and Modification Services with Westinghouse Electric Company, and as Managing Director for AREVA T&D. He began his career with Duke Energy.

Leslie C. Kass was appointed as our President and Chief Executive Officer on January 31, 2018. She previously served in a variety of roles at the Company or its predecessor, including as the Senior Vice-President of our Industrial segment from May 2017 until January 2018, Vice President of Retrofits and Continuous Emissions Monitoring for the Power segment from August 2016 to May 2017, Vice President, Investor Relations & Communications from June 2015 to August 2016, and as Vice President of Regulatory Affairs from January 2013 to June 2015. Before joining the Company, Ms. Kass held a number of engineering and project management-related positions of increasing responsibility with Westinghouse Electric Company, Entergy Corporation and Duke Energy Corporation.

James J. Muckley has served as our Senior Vice President, Operations since December 2016 and is responsible for the Company's manufacturing operations, Global Project Management, Quality and Environmental, Health, Safety & Security functions. He is also responsible for Babcock & Wilcox Construction Co., LLC. From June 2016 to December 2016, he was Vice President, Global Parts and Field Engineering Services in the Company's Power segment. Prior to that, he was Vice President, Parts from January 2016 to May 2016, General Manager, Replacement Parts from November 2012 to December 2015, and Operations/Alliance Manager, Replacement Parts from March 2002 to October 2012.

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 2018 Annual Meeting of Stockholders.

Item 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT AND RELATED STOCKHOLDER MATTERS

The following table provides information on our equity compensation plans as of December 31, 2017:

Equity Compensation Plan Information

Plan Category:	Equity compensation plans approved by security holders
Number of securities to be issued upon exercise of outstanding options and rights	5,839,265
Weighted-average exercise price of outstanding options and rights	$	13.15
Number of securities remaining available for future issuance	247,310

122

The other information required by this item is incorporated by reference to 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 2017 Annual Meeting of Stockholders.

Item 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS, AND DIRECTOR INDEPENDENCE

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 2018 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, 2018" in the Proxy Statement for our 2018 Annual Meeting of Stockholders.

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PART IV

Item 15. Exhibits

2.1*	Master Separation Agreement, dated as of June 8, 2015, between The Babcock & Wilcox Company and Babcock & Wilcox Enterprises, Inc. (incorporated by reference to Exhibit 2.1 to the Babcock & Wilcox Enterprises, Inc. Quarterly Report on Form 10-Q for the quarter ended June 30, 2015 (File No. 001-36876))
3.1	Amended and Restated Certificate of Incorporation (incorporated by reference to Exhibit 3.1 to the Babcock & Wilcox Enterprises, Inc. Quarterly Report on Form 10-Q for the quarter ended June 30, 2015 (File No. 001-36876))
3.2	Amended and Restated Bylaws (incorporate by reference to Exhibit 3.1 to the Babcock & Wilcox Enterprises, Inc. Quarterly Report on Form 10-Q for the quarter ended March 31, 2017 (File No. 001-36876))
10.1	Tax Sharing Agreement, dated as of June 8, 2015, by and between The Babcock & Wilcox Company and Babcock & Wilcox Enterprises, Inc. (incorporated by reference to Exhibit 10.1 to the Babcock & Wilcox Enterprises, Inc. Quarterly Report on Form 10-Q for the quarter ended June 30, 2015 (File No. 001-36876))
10.2	Employee Matters Agreement, dated as of June 8, 2015, by and between The Babcock & Wilcox Company and Babcock & Wilcox Enterprises, Inc. (incorporated by reference to Exhibit 10.2 to the Babcock & Wilcox Enterprises, Inc. Quarterly Report on Form 10-Q for the quarter ended June 30, 2015 (File No. 001-36876))
10.3	Transition Services Agreement, dated as of June 8, 2015, between The Babcock & Wilcox Company, as service provider, and Babcock & Wilcox Enterprises, Inc., as service receiver (incorporated by reference to Exhibit 10.3 to the Babcock & Wilcox Enterprises, Inc. Quarterly Report on Form 10-Q for the quarter ended June 30, 2015 (File No. 001-36876))
10.4	Transition Services Agreement, dated as of June 8, 2015, between Babcock & Wilcox Enterprises, Inc., as service provider, and The Babcock & Wilcox Company, as service receiver (incorporated by reference to Exhibit 10.4 to the Babcock & Wilcox Enterprises, Inc. Quarterly Report on Form 10-Q for the quarter ended June 30, 2015 (File No. 001-36876))
10.5	Assumption and Loss Allocation Agreement, dated as of June 19, 2015, by and among ACE American Insurance Company and the Ace Affiliates (as defined therein), Babcock & Wilcox Enterprises, Inc. and The Babcock & Wilcox Company (incorporated by reference to Exhibit 10.5 to the Babcock & Wilcox Enterprises, Inc. Quarterly Report on Form 10-Q for the quarter ended June 30, 2015 (File No. 001-36876))
10.6	Reinsurance Novation and Assumption Agreement, dated as of June 19, 2015, by and among ACE American Insurance Company and the Ace Affiliates (as defined therein), Creole Insurance Company and Dampkraft Insurance Company (incorporated by reference to Exhibit 10.6 to the Babcock & Wilcox Enterprises, Inc. Quarterly Report on Form 10-Q for the quarter ended June 30, 2015 (File No. 001-36876))
10.7	Novation and Assumption Agreement, dated as of June 19, 2015, by and among The Babcock & Wilcox Company, Babcock & Wilcox Enterprises, Inc., Dampkraft Insurance Company and Creole Insurance Company (incorporated by reference to Exhibit 10.7 to the Babcock & Wilcox Enterprises, Inc. Quarterly Report on Form 10-Q for the quarter ended June 30, 2015 (File No. 001-36876))
10.8†	Amended and Restated 2015 Long-Term Incentive Plan of Babcock & Wilcox Enterprises, Inc. (incorporated by reference to the Babcock & Wilcox Enterprises, Inc. current Report on Form 8-K filed May 6, 2016 (File No. 001-36876))
10.9†	Babcock & Wilcox Enterprises, Inc. Executive Incentive Compensation Plan (incorporated by reference to Exhibit 10.9 to the Babcock & Wilcox Enterprises, Inc. Quarterly Report on Form 10-Q for the quarter ended June 30, 2015 (File No. 001-36876))
10.10†	Babcock & Wilcox Enterprises, Inc. Management Incentive Compensation Plan (incorporated by reference to Exhibit 10.10 to the Babcock & Wilcox Enterprises, Inc. Quarterly Report on Form 10-Q for the quarter ended June 30, 2015 (File No. 001-36876))

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10.11†	Supplemental Executive Retirement Plan of Babcock & Wilcox Enterprises, Inc. (incorporated by reference to Exhibit 10.11 to the Babcock & Wilcox Enterprises, Inc. Quarterly Report on Form 10-Q for the quarter ended June 30, 2015 (File No. 001-36876))
10.12†	Babcock & Wilcox Enterprises, Inc. Defined Contribution Restoration Plan (incorporated by reference to Exhibit 10.12 to the Babcock & Wilcox Enterprises, Inc. Quarterly Report on Form 10-Q for the quarter ended June 30, 2015 (File No. 001-36876))
10.13	Intellectual Property Agreement, dated as of June 26, 2015, between Babcock & Wilcox Power Generation Group, Inc. and BWXT Foreign Holdings, LLC (incorporated by reference to Exhibit 10.13 to the Babcock & Wilcox Enterprises, Inc. Quarterly Report on Form 10-Q for the quarter ended June 30, 2015 (File No. 001-36876))
10.14	Intellectual Property Agreement, dated as of June 27, 2015, between Babcock & Wilcox Technology, Inc. and Babcock & Wilcox Investment Company (incorporated by reference to Exhibit 10.14 to the Babcock & Wilcox Enterprises, Inc. Quarterly Report on Form 10-Q for the quarter ended June 30, 2015 (File No. 001-36876))
10.15	Intellectual Property Agreement, dated as of May 29, 2015, between Babcock & Wilcox Canada Ltd. and B&W PGG Canada Corp. (incorporated by reference to Exhibit 10.15 to the Babcock & Wilcox Enterprises, Inc. Quarterly Report on Form 10-Q for the quarter ended June 30, 2015 (File No. 001-36876))
10.16	Intellectual Property Agreement, dated as of May 29, 2015, between Babcock & Wilcox mPower, Inc. and Babcock & Wilcox Power Generation Group, Inc. (incorporated by reference to Exhibit 10.16 to the Babcock & Wilcox Enterprises, Inc. Quarterly Report on Form 10-Q for the quarter ended June 30, 2015 (File No. 001-36876))
10.17	Intellectual Property Agreement, dated as of June 26, 2015, between The Babcock & Wilcox Company and Babcock & Wilcox Enterprises, Inc. (incorporated by reference to Exhibit 10.17 to the Babcock & Wilcox Enterprises, Inc. Quarterly Report on Form 10-Q for the quarter ended June 30, 2015 (File No. 001-36876))
10.18	Credit Agreement, dated as of May 11, 2015, among Babcock & Wilcox Enterprises, Inc., as the borrower, Bank of America, N.A., as Administrative Agent, and the Other Lenders Party Thereto (incorporated by reference to Exhibit 10.18 to the Babcock & Wilcox Enterprises, Inc. Quarterly Report on Form 10-Q for the quarter ended June 30, 2015 (File No. 001-36876))
10.19†	Form of Change-in-Control Agreement, by and between Babcock & Wilcox Enterprises, Inc. and certain officers for officers elected prior to August 4, 2016 (incorporated by reference to Exhibit 10.1 to the Babcock & Wilcox Enterprises, Inc. Quarterly Report on Form 10-Q for the quarter ended September 30, 2016 (File No. 001-36876))
10.20†	Form of Restricted Stock Grant Agreement (Spin-off Award) (incorporated by reference to Exhibit 10.1 to the Babcock & Wilcox Enterprises, Inc. Quarterly Report on Form 10-Q for the quarter ended September 30, 2015 (File No. 001-36876))
10.21†	Form of Restricted Stock Units Grant Agreement (incorporated by reference to Exhibit 10.2 to the Babcock & Wilcox Enterprises, Inc. Quarterly Report on Form 10-Q for the quarter ended September 30, 2015 (File No. 001-36876))
10.22†	Form of Stock Option Grant Agreement (incorporated by reference to Exhibit 10.3 to the Babcock & Wilcox Enterprises, Inc. Quarterly Report on Form 10-Q for the quarter ended September 30, 2015 (File No. 001-36876))
10.23†	Form of Performance Restricted Stock Unit Agreement (incorporated by reference to Exhibit 10.23 to the Babcock & Wilcox Enterprises, Inc. Annual Report on Form 10-K for the year ended December 31, 2015 (File No. 001-36876))
10.24	Form of Director and Officer Indemnification Agreement (incorporated by reference to Exhibit 10.24 to the Babcock & Wilcox Enterprises, Inc. Annual Report on Form 10-K for the year ended December 31, 2015 (File No. 001-36876))

125

10.25†	Form of Change-in-Control Agreement, by and between Babcock & Wilcox Enterprises, Inc. and certain officers for officers elected on or after August 4, 2016 (incorporated by reference to Exhibit 10.2 to the Babcock & Wilcox Enterprises, Inc. Quarterly Report on Form 10-Q for the quarter ended September 30, 2016 (File No. 001-36876))
10.26	Amendment No. 1 dated June 10, 2016 to Credit Agreement, dated May 11, 2015, among Babcock & Wilcox Enterprises, Inc., as the Borrower, Bank of America, N.A., as Administrative Agent, and the other Lenders party thereto (incorporated by reference to Exhibit 10.1 to the Babcock & Wilcox Enterprises, Inc. Quarterly Report on Form 10-Q for the quarter ended June 30, 2016 (File No. 001-36876))
10.27	Amendment No. 2 dated February 24, 2017 to Credit Agreement, dated May 11, 2015, among Babcock & Wilcox Enterprises, Inc., as the Borrower, Bank of America, N.A., as Administrative Agent, and the other Lenders party thereto.
10.28†	Form of Performance Unit Award Grant Agreement (Cash Settled) (incorporated by reference to Exhibit 10.1 to the Babcock & Wilcox Enterprises, Inc. Quarterly Report on Form 10-Q for the quarter ended June 30, 2017 (File No. 001-36876))
10.29†	Form of Special Restricted Stock Unit Award Grant Agreement (incorporated by reference to Exhibit 10.2 to the Babcock & Wilcox Enterprises, Inc. Quarterly Report on Form 10-Q for the quarter ended June 30, 2017 (File No. 001-36876))
10.30	Amendment No. 3 dated August 9, 2017, to Credit Agreement dated May 11, 2015, among Babcock & Wilcox Enterprises, Inc., as the Borrower, Bank of America, N.A., as administrative Agent and Lender, and the other Lenders party thereto (incorporated by reference to Exhibit 10.1 to the Babcock & Wilcox Enterprises, Inc. Quarterly Report on Form 10-Q for the quarter ended September 30, 2017 (File No. 001-36876))
10.31	Second Lien Credit Agreement, dated August 9, 2017, among Babcock & Wilcox Enterprises, Inc., as the Borrower, Lightship Capital LLC, as administrative Agent and Lender, and the other Lenders party thereto (incorporated by reference to Exhibit 10.2 to the Babcock & Wilcox Enterprises, Inc. Quarterly Report on Form 10-Q for the quarter ended September 30, 2017 (File No. 001-36876))
10.32	Amendment No. 4 dated September 30, 2017, to Credit Agreement dated May 11, 2015, among Babcock & Wilcox Enterprises, Inc., as the Borrower, Bank of America, N.A., as administrative Agent and Lender, and the other Lenders party thereto (incorporated by reference to Exhibit 10.3 to the Babcock & Wilcox Enterprises, Inc. Quarterly Report on Form 10-Q for the quarter ended September 30, 2017 (File No. 001-36876))
10.33	Agreement, dated as of January 3, 2018, among Babcock & Wilcox Enterprises, Inc., Vintage Capital Management, LLC, Kahn Capital Management, LLC, and Brian R. Kahn (incorporated by reference to Exhibit 10.1 to the Babcock & Wilcox Enterprises, Inc. Current Report on Form 8-K filed January 3, 2018 (File No. 001-36876))
10.34	Form of Joinder Agreement (incorporated by reference to Exhibit 10.2 to the Babcock & Wilcox Enterprises, Inc. Current Report on Form 8-K filed January 3, 2018 (File No. 001-36876))
10.35†	Offer Letter, by and between Babcock & Wilcox Enterprises, Inc. and Leslie C. Kass dated as of January 31, 2018 (incorporated by reference to Exhibit 10.1 to the Babcock & Wilcox Enterprises, Inc. Current Report on Form 8-K filed February 1, 2018 (file no. 001-36876)
10.36†	Supplement to Employment Agreement, by and between Babcock & Wilcox Enterprises, Inc. and E. James Ferland dated as of January 31, 2018 (incorporated by reference to Exhibit 10.2 to the Babcock & Wilcox Enterprises, Inc. Current Report on Form 8-K filed February 1, 2018 (file no. 001-36876)
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

126

32.2	Section 1350 certification of Chief Financial Officer
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

*    Certain schedules and exhibits to this agreement have been omitted pursuant to Item 601(b)(2) of Regulation S-K. A copy of any omitted schedule and/or exhibit will be furnished to the SEC upon request.

†    Management contract or compensatory plan or arrangement.

Item 16.        Form 10-K Summary

None.

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.

		BABCOCK & WILCOX ENTERPRISES, INC.
		/s/ Leslie C. Kass
March 1, 2018	By:	Leslie C. Kass
		President and Chief Executive Officer

127

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/ Leslie C. Kass	President, Chief Executive Officer and Director (Principal Executive Officer)
Leslie C. Kass
/s/ Jenny L. Apker	Senior Vice President and Chief Financial Officer (Principal Financial Officer and Duly Authorized Representative)
Jenny L. Apker
/s/ Daniel W. Hoehn	Vice President, Controller and Chief Accounting Officer (Principal Accounting Officer and Duly Authorized Representative)
Daniel W. Hoehn
/s/ E. James Ferland	Executive Chairman
E. James Ferland
/s/ Matthew E. Avril	Director
Matthew E. Avril
/s/ Henry E. Bartoli	Director
Henry E. Bartoli
/s/ Thomas A. Christopher	Director
Thomas A. Christopher
/s/ Cynthia S. Dubin	Director
Cynthia S. Dubin
/s/ Brian K. Ferraioli	Director
Brian K. Ferraioli
/s/ Stephen G. Hanks	Director
Stephen G. Hanks
/s/ Brian R. Kahn	Director
Brian R. Kahn
/s/ Anne R. Pramaggiore	Director
Anne R. Pramaggiore
/s/ Larry L. Weyers	Director
Larry L. Weyers

March 1, 2018

128

EX-21.1

Exhibit 21.1

BABCOCK & WILCOX ENTERPRISES, INC.

SIGNIFICANT SUBSIDIARIES OF THE REGISTRANT

YEAR ENDED DECEMBER 31, 2017

Name of Company	Jurisdiction of Organization	Percentage of Ownership Interest
Americon Equipment Services, Inc.	Delaware	100
Americon, LLC	Delaware	100
B&W de Panama, Inc.	Panama	100
B&W PGG Luxembourg Canada Holdings SARL	Luxembourg	100
B&W PGG Luxembourg Finance SARL	Luxembourg	100
B&W PGG Luxembourg Holdings SARL	Luxembourg	100
B and W SPIG South Africa	South Africa	100
Babcock & Wilcox Beijing Company, Ltd.	China	50
Babcock & Wilcox Construction Co., LLC	Delaware	100
Babcock & Wilcox de Monterrey, S.A. de C.V.	Mexico	100
Babcock & Wilcox Ebensburg Power, LLC	Delaware	100
Babcock & Wilcox Equity Investments, LLC	Delaware	100
Babcock & Wilcox Global Sales and Services Brazil Ltda.	Brazil	100
Babcock & Wilcox Global Sales & Services - Chile SpA	Chile	100
Babcock & Wilcox Global Sales and Service Pte. Ltd.	Singapore	100
Babcock & Wilcox Global Sales & Services SARL	Luxembourg	100
Babcock & Wilcox Holdings, LLC	Delaware	100
Babcock & Wilcox India Holdings, Inc.	Delaware	100
Babcock & Wilcox India Private Limited	India	100
Babcock & Wilcox International Investments Co., Inc.	Panama	100
Babcock & Wilcox International Sales and Service Corporation	Delaware	100
Babcock & Wilcox International, Inc.	Delaware	100
Babcock & Wilcox Loibl GmbH	Germany	100
Babcock & Wilcox MEGTEC Holdings, Inc.	Delaware	100
Babcock & Wilcox MEGTEC, LLC	Delaware	100
Babcock & Wilcox Monterrey Finance SARL	Luxembourg	100
Babcock & Wilcox Power Generation Group Canada Corp.	Nova Scotia	100
Babcock & Wilcox Singapore Pte. Ltd.	Singapore	100
Babcock & Wilcox Slovakia s.r.o.	Slovakia	100
Babcock & Wilcox SPIG, Inc.	New Jersey	100
Babcock & Wilcox Technology, LLC	Delaware	100
Babcock & Wilcox Universal Europe Ltd.	United Kingdom	100
Babcock & Wilcox Universal, Inc.	Wisconsin	100
Babcock & Wilcox Universal, S. de R.L. de C.V.	Mexico	100
Babcock & Wilcox Volund Limited	United Kingdom	100
Babcock & Wilcox Volund AB	Sweden	100
Babcock & Wilcox Volund A/S	Denmark	100
BWL Energy (Teesside) Ltd.	Northern Ireland	50
BWL Energy (Rye House) Ltd.	Northern Ireland	50

Name of Company	Jurisdiction of Organization	Percentage of Ownership Interest
Dampkraft Insurance Company	South Carolina	100
D.C.S. Dry Cooling Services S.r.l.	Italy	100
Delta Power Services, LLC	Delaware	100
Diamond Operating Co., Inc.	Delaware	100
Diamond Power Australia Holdings, Inc.	Delaware	100
Diamond Power Central & Eastern Europe s.r.o.	Czech Republic	100
Diamond Power China Holdings, Inc.	Delaware	100
Diamond Power do Brasil Limitada	Brazil	100
Diamond Power Equity Investments, Inc.	Delaware	100
Diamond Power Finland OY	Finland	100
Diamond Power Germany GmbH	Germany	95
Diamond Power International, LLC	Delaware	100
Diamond Power Machine (Hubei) Co., Inc.	China	50
Diamond Power Services S.E.A. Ltd.	Thailand	50
Diamond Power Specialty (Proprietary) Limited	Republic of South Africa	100
Diamond Power Specialty Limited	United Kingdom	100
Diamond Power Sweden AB	Sweden	100
DPS Anson, LLC	Delaware	100
DPS Berlin, LLC	Delaware	100
DPS Cadillac, LLC	Delaware	100
DPS Florida, LLC	Delaware	100
DPS Gregory, LLC	Delaware	100
DPS Mecklenburg, LLC	Delaware	100
DPS Piedmont, LLC	Delaware	100
Ebensburg Energy, LLC	Delaware	100
Ebensburg Investors Limited Partnership	Pennsylvania	100
MEGTEC Energy & Environmental LLC	Delaware	100
MEGTEC Environmental Limited	United Kingdom	100
MEGTEC IEPG BV	Netherlands	100
MEGTEC India Holdings, LLC	Delaware	100
MEGTEC Systems AB	Sweden	100
MEGTEC Systems Amal AB	Sweden	100
MEGTEC Systems Australia, Inc.	Delaware	100
MEGTEC Systems India Private Ltd.	India	100
MEGTEC Systems Limited	United Kingdom	100
MEGTEC Systems S.A.S.	France	100
MEGTEC Systems Shanghai Ltd.	China	100
MEGTEC Systems, Inc.	Delaware	100
MEGTEC Thermal Energy & Environmental Technology (Shanghai), LTD.	China	100
MEGTEC TurboSonic Inc.	Ontario	100
MEGTEC TurboSonic Technologies, Inc.	Delaware	100
MTS Asia, Inc.	Delaware	100
MTS Environmental GmbH	Germany	100
O&M Holding Company	Delaware	100

Name of Company	Jurisdiction of Organization	Percentage of Ownership Interest
P. T. Babcock & Wilcox Asia	Indonesia	100
Palm Beach Resource Recovery Corporation	Florida	100
Power Systems Operations, Inc.	Delaware	100
Servicios de Fabricacion de Valle Soleado, S.A. de C.V.	Mexico	100
Servicios Profesionales de Valle Soleado, S.A. de C.V.	Mexico	100
SOFCo - EFS Holdings LLC	Delaware	100
SPIG S.p.A.	Italy	100
SPIG S.p.A.	Ecuador	100
SPIG Kuhlturmtechnologien GmbH	Germany	100
SPIG Turn Apa de Racine	Romania	100
SPIG Vostock	Russia	95
SPIG Sogutma Sistemleri Tlc Ldt	Turkey	100
SPIG Cooling Towers India Private Limited	India	100
SPIG Torres de Resfriamento Ltda.	Brazil	100
SPIG (Shanxi) Cooling System Co., Ltd.	China	100
SPIG (Shanxi) Cooling Technology Company, Ltd.	China	60
SPIG KOREA LTD.	Korea	100
The Babcock & Wilcox Company	Delaware	100
Thermax Babcock & Wilcox Energy Solutions Private Limited	India	49
Universal Acoustic & Emission Technologies Pvt. Ltd.	India	100
Universal AET Holdings, LLC	Wisconsin	100
Universal Asia Pacific Pte. Ltd.	Singapore	100
Universal Silencer Mexico, LLC	Wisconsin	100
Universal Silencer Mexico II, LLC	Wisconsin	100
Universal Silencer (Shanghai) Co., Ltd.	China	100

EX-23.1

Exhibit 23.1

CONSENT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

We consent to the incorporation by reference in the Registration Statement No. 333-204812 on Form S-1, the incorporation by reference in the Registration Statement No. 333-205333 on Form S-8, and the incorporation by reference in Registration Statements No. 333-216316 and No. 333-216399 on Forms S-3 ASR of our reports dated March 1, 2018, relating to the consolidated and combined financial statements of Babcock & Wilcox Enterprises, Inc., (which report expresses an unqualified opinion and includes an explanatory paragraph related to the completion of the spin-off of the Company effective June 30, 2015 by The Babcock and Wilcox Company and an explanatory paragraph related to the Company’s ability to continue as a going concern) and the effectiveness of Babcock & Wilcox Enterprises, Inc.’s internal control over financial reporting appearing in this Annual Report on Form 10-K for the year ended December 31, 2017.

/S/ DELOITTE & TOUCHE LLP

Charlotte, North Carolina

March 1, 2018

EX-31.1

EXHIBIT 31.1

CERTIFICATION

I, Leslie C. Kass, certify that:

1. I have reviewed this annual report on Form 10-K of Babcock & Wilcox Enterprises, Inc.;

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 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)) 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 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 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.

March 1, 2018	/s/ Leslie C. Kass
	Leslie C. Kass
	President and Chief Executive Officer

EX-31.2

EXHIBIT 31.2

CERTIFICATION

I, Jenny L. Apker, certify that:

1. I have reviewed this annual report on Form 10-K of Babcock & Wilcox Enterprises, Inc.;

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 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)) 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 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 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.

March 1, 2018	/s/ Jenny L. Apker
	Jenny L. Apker
	Senior Vice President and Chief Financial Officer

EX-32.1

EXHIBIT 32.1

BABCOCK & WILCOX ENTERPRISES, INC.

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, Leslie C. Kass, President and Chief Executive Officer of Babcock & Wilcox Enterprises, Inc., 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, 2017 (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 B&W as of the dates and for the periods expressed in the Report.

Dated: March 1, 2018	/s/ Leslie C. Kass
	Leslie C. Kass
	President and Chief Executive Officer

EX-32.2

EXHIBIT 32.2

BABCOCK & WILCOX ENTERPRISES, INC.

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, Jenny L. Apker, Senior Vice President and Chief Financial Officer of Babcock & Wilcox Enterprises, Inc., 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, 2017 (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 B&W as of the dates and for the periods expressed in the Report.

Dated: March 1, 2018	/s/ Jenny L. Apker
	Jenny L. Apker
	Senior Vice President and Chief Financial Officer

XML

Document and Entity Information - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Jan. 31, 2018
Document And Entity Information [Abstract]
Document Type	10-K
Amendment Flag	false
Document Period End Date	Dec. 31, 2017
Document Fiscal Year Focus	2017
Document Fiscal Period Focus	Q4
Trading Symbol	BW
Entity Registrant Name	BABCOCK & WILCOX ENTERPRISES, INC.
Entity Central Index Key	0001630805
Current Fiscal Year End Date	--12-31
Entity Filer Category	Accelerated Filer
Entity Common Stock, Shares Outstanding		44,084,680
Entity Well-known Seasoned Issuer	Yes
Entity Current Reporting Status	Yes
Entity Voluntary Filers	No
Entity Public Float	$ 570

XML

Condensed Consolidated and Combined Statements of Operations - USD ($) shares in Thousands, $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Revenues	$ 1,557,735	$ 1,578,263	$ 1,757,295
Costs and expenses:
Cost of operations	1,457,857	1,399,146	1,449,138
Selling, general and administrative expenses	259,799	247,149	239,968
Goodwill impairment charges	86,903	0	0
Restructuring charge	15,447	40,807	14,946
Research and development costs	9,400	10,400	16,500
Losses (gains) on asset disposals, net	15	(32)	14,597
Total costs and expenses	1,829,433	1,697,476	1,735,192
Equity in income (loss) and impairment of investees	(9,867)	16,440	(242)
Operating income (loss)	(281,565)	(102,773)	21,861
Other income (expense):
Interest income	510	810	618
Interest expense	(26,305)	(3,796)	(2,338)
Other – net	(6,839)	(2,380)	64
Total other income (expense)	(32,634)	(5,366)	(1,656)
Income (loss) before income tax expense	(314,199)	(108,139)	20,205
Income tax expense	64,816	6,943	3,671
Income (loss) from continuing operations	(379,015)	(115,082)	16,534
Income (loss) from discontinued operations, net of tax	0	0	2,803
Net income (loss)	(379,015)	(115,082)	19,337
Net income attributable to noncontrolling interest	809	(567)	(196)
Net income (loss) attributable to stockholders	(379,824)	(115,649)	19,141
Amounts attributable to shareholders:
Net income (loss) attributable to stockholders	$ (379,824)	$ (115,649)	$ 19,141
Basic earnings per common share:
Basic earnings (loss) per share - continuing operations	$ (8.09)	$ (2.31)	$ 0.31
Basic earnings (loss) per share - discontinued operations	0.00	0.00	0.05
Basic earnings (loss) per share	(8.09)	(2.31)	0.36
Basic earnings (loss) per share - discontinued operations
Diluted earnings (loss) per share - continuing operations	(8.09)	(2.31)	0.30
Diluted earnings per share - discontinued operations	0.00	0.00	0.06
Diluted earnings (loss) per share	$ (8.09)	$ (2.31)	$ 0.36
Shares used in the computation of earnings per share:
Basic	46,935	50,129	53,487
Diluted	46,935	50,129	53,709

XML

Condensed Consolidated and Combined Statements of Comprehensive Income - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Statement of Comprehensive Income [Abstract]
Net income (loss)	$ (379,015)	$ (115,082)	$ 19,337
Other comprehensive income (loss):
Currency translation adjustments, net of taxes	16,150	(24,494)	(19,459)
Derivative financial instruments:
Unrealized gains on derivative financial instruments	3,346	2,208	282
Income taxes	142	162	(57)
Unrealized gains on derivative financial instruments, net of taxes	3,204	2,046	339
Derivative financial instrument (gains) losses reclassified into net income	2,503	(3,598)	1,557
Income taxes	234	(568)	424
Reclassification adjustment for (gains) losses included in net income, net of taxes	(2,269)	(3,030)	1,133
Benefit obligations:
Unrealized gains (losses) on benefit obligations	(152)	12,202	462
Income taxes	0	4,510	(57)
Unrealized gains (losses) on benefit obligations, net of taxes	(152)	7,692	519
Amortization of benefit plan costs (benefits)	(2,912)	(254)	1,042
Income taxes	43	(404)	1,237
Amortization of benefit plan costs (benefits), net of taxes	(2,955)	150	(195)
Other:
Reclassification adjustments for (gains) losses included in net income, net of taxes	75	7	(22)
Other comprehensive income (loss)	14,053	(17,629)	(17,685)
Total comprehensive income (loss)	(364,962)	(132,711)	1,652
Comprehensive loss attributable to noncontrolling interest	(778)	(575)	(183)
Comprehensive income (loss) attributable to stockholders	$ (365,740)	$ (133,286)	$ 1,469

XML

Condensed Consolidated and Combined Statements of Cash Flows - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Cash flows from operating activities:
Net income (loss)	$ (379,015)	$ (115,082)	$ 19,337
Non-cash items included in net income (loss):
Depreciation and amortization of long-lived assets	40,138	39,583	34,932
Amortization of debt issuance costs and debt discount	6,407	1,244	622
(Income) loss from equity method investees	(8,326)	(16,440)	242
Goodwill impairment charges	(86,903)	0	0
Other than temporary impairment of equity method investment in TBWES	18,193	0	0
Losses on asset disposals and impairments	807	14,938	16,881
Write-off of accrued claims receivable, net	0	0	7,832
Provision for (benefit from) deferred income taxes	50,304	(9,000)	(32,121)
Mark to market losses (gains) and prior service cost amortization for pension and postretirement plans	(11,608)	36,346	40,611
Stock-based compensation, net of associated income taxes	11,813	16,129	7,773
Changes in assets and liabilities, net of effects of acquisitions:
Accounts receivable	9,414	46,755	(54,807)
Dividends from equity method investees	50,134	12,160	20,830
Accrued Insurance Receivable	0	(15,000)	0
Contracts in progress and advance billings on contracts	(24,001)	(13,259)	62,971
Inventories	11,874	2,869	6,060
Income taxes	26,618	22,593	9,275
Accounts payable	(14,664)	4,542	17,863
Accrued and other current liabilities	(12,450)	25,110	11,464
Pension liabilities, accrued postretirement benefits and employee benefits	(44,584)	(46,973)	(2,336)
Other, net	(7,790)	(4,242)	2,970
Net cash from operating activities	(189,833)	2,273	170,399
CASH FLOWS FROM INVESTING ACTIVITIES:
Decrease in restricted cash and cash equivalents	2,259	9,374	6,298
Investment in equity method investees	0	(26,256)	(7,424)
Purchase of property, plant and equipment	(14,278)	(22,450)	(35,397)
Acquisition of business, net of cash acquired	(52,547)	(144,780)	0
Proceeds from sale of equity method investment in a joint venture	0
Purchases of available-for-sale securities	(29,252)	(45,217)	(14,008)
Sales and maturities of available-for-sale securities	35,484	29,846	5,266
Other, net	708	646	(587)
Net cash from investing activities	(62,144)	(180,842)	(45,852)
Cash flows from financing activities:
Common Stock Repurchase from Related Party	(16,674)	0	0
Net transfers from our former Parent			80,589
Shares of our common stock returned to treasury stock	(967)	(78,410)	(25,408)
Debt issuance costs	(15,002)	0	0
Other	(1,082)	(246)	(491)
Net cash from financing activities	206,125	(83,430)	53,610
Effects of exchange rate changes on cash	6,632	(7,306)	(6,407)
Cash flow from continuing operations	(39,220)	(269,305)	171,750
Cash flows from discontinued operations:
Operating cash flows from discontinued operations, net	0	0	(25,194)
Investing cash flows from discontinued operations, net	0	0	(23)
Net cash flows from discontinued operations	0	0	(25,217)
Cash flow from continuing operations	(39,220)	(269,305)	146,533
Cash and equivalents, beginning of period	95,887	365,192	218,659
Cash and equivalents, end of period	56,667	95,887	365,192
US Revolving Credit Facility [Member]
Cash flows from financing activities:
Borrowings under our revolving credit facilities	629,722	205,600	0
Proceeds from (Repayments of) Lines of Credit	(545,222)	(195,800)	0
Second Lien Term Loan [Member]
Cash flows from financing activities:
Proceeds from (Repayments of) Lines of Credit	161,674	0	0
Foreign Revolvers [Member]
Cash flows from financing activities:
Borrowings under our revolving credit facilities	273	5,674	0
Proceeds from (Repayments of) Lines of Credit	$ (6,597)	(20,248)	(1,080)
HMA [Domain]
CASH FLOWS FROM INVESTING ACTIVITIES:
Proceeds from sale of equity method investment in a joint venture		$ 18,000	$ 0

XML

Condensed Consolidated and Combined Balance Sheet Statement - USD ($) $ in Thousands	Dec. 31, 2017	Dec. 31, 2016
CURRENT ASSETS
Cash and cash equivalents	$ 56,667	$ 95,887
Restricted cash and cash equivalents	25,980	27,770
Accounts receivable - trade, net	291,704	282,347
Accounts receivable - other	78,970	73,756
Contracts in progress	161,220	166,010
Inventories	82,162	85,807
Other current assets	35,554	45,957
Total current assets	732,257	777,534
NONCURRENT ASSETS
Property, plant and equipment - gross	355,505	332,537
Accumulated depreciation	213,574	198,900
Net property, plant and equipment	141,931	133,637
Goodwill	204,398	267,395
Deferred income taxes	97,826	163,388
Investments in unconsolidated affiliates	43,278	98,682
Intangible assets	76,780	71,039
Other assets	25,759	17,468
Total assets	1,322,229	1,529,143
CURRENT LIABILITIES
Foreign revolving credit facilities	9,173	14,241
Revolving debt	103,473	24,041
Accounts payable	225,234	220,737
Accrued employee benefits	30,153	35,497
Advance billings on contracts	181,070	210,642
Accrued warranty expense	39,020	40,467
Other accrued liabilities	99,536	95,954
Total current liabilities	744,327	617,538
NONCURRENT LIABILITIES
United States revolving credit facility	94,300	9,800
Pension and other accumulated postretirement benefit liabilities	256,390	301,259
Other noncurrent liabilities	36,509	39,595
Total liabilities	1,131,526	968,192
Common stock, par value $0.01 per share, authorized 200,000 shares; issued 44,065 and 48,688 shares at December 31, 2017 and 2016, respectively	499	544
Capital in excess of par value	800,968	806,589
Treasury Stock	(104,785)	(103,818)
Retained deficit	(492,150)	(114,684)
Accumulated other comprehensive loss	(22,429)	(36,482)
Stockholders' equity attributable to shareholders	182,103	552,149
Noncontrolling interest	8,600	8,802
Total stockholders' equity	190,703	560,951
Total liabilities and stockholders' equity	1,322,229	1,529,143
Second Lien Term Loan [Member]
CURRENT LIABILITIES
Revolving debt	$ 160,141	$ 0

XML

Condensed Consolidated and Combined Balance Sheet Equity Section - $ / shares	Dec. 31, 2017	Dec. 31, 2016
Common Stock, Par Value	$ 0.01	$ 0.01
Common Stock, Shares Authorized	200,000,000	200,000,000
Common Stock, Shares Issued and Outstanding	48,871,997	48,698,385
Treasury Stock, Shares	5,674,564	5,594,147

XML

Condensed Consolidated and Combined Statement of Stockholders' Equity Statement - USD ($) $ in Thousands	Total	Common Stock [Member]	Additional Paid-in Capital [Member]	Treasury Stock [Member]	Retained Earnings [Member]	AOCI Attributable to Parent [Member]	Former Parent Investment [Member]	Noncontrolling Interest [Member]
Common Stock, Shares, Issued		0
Shareholder's Equity	$ 687,437	$ 0	$ 0	$ 0	$ 0	$ 10,374	$ 676,036	$ 1,027
Shareholder's Equity	748,427	$ 540	790,464	(25,408)	965	(18,853)	0	719
Net income (loss)	19,337				965		18,176	196
Currency translation adjustments, net of taxes	(19,459)					(19,446)		(13)
Currency translation adjustment	(19,459)
Derivative financial instruments	1,472					1,472
Defined benefit obligation	324					324
Available-for-sale investments	(22)					(22)
Stock-based compensation		137,000
Stock Granted, Value, Share-based Compensation, Net of Forfeitures	6,652	$ 17	7,772	(1,143)			6
Repurchased shares		(1,376,000)
Repurchased shares, value	(24,279)	$ (14)		(24,265)
Dividends to noncontrolling interests	(491)							(491)
Net transfers from Parent	125,295						125,295
Distribution of Nuclear Energy segment to former Parent	(47,839)					(11,555)	(36,284)
Reclassification of former Parent investment to capital in excess of par value and common stock		53,720,000
Reclassification of former Parent investment to capital ine xcess of par value and common stock, value	0	$ 537	782,692				(783,229)
Shareholder's Equity - Ending Balance at Dec. 31, 2015	748,427	$ 540	790,464	(25,408)	965	(18,853)	0	719
Common Stock, Shares, Issued		52,481,000
Shareholder's Equity	748,427	$ 540	790,464	(25,408)	965	(18,853)	0	719
Shareholder's Equity	560,951	$ 544	806,589	(103,818)	(114,684)	(36,482)	0	8,802
Net income (loss)	(115,082)				(115,649)			567
Currency translation adjustments, net of taxes	(24,494)					(24,494)		8
Currency translation adjustment	(24,486)
Derivative financial instruments	(984)					(984)
SPIG Acquisition	7,754							7,754
Defined benefit obligation	7,842					7,842
Available-for-sale investments	7					7
Stock-based compensation		423,000
Stock Granted, Value, Share-based Compensation, Net of Forfeitures	13,440	$ 46	16,125	(2,731)
Repurchased shares		(4,216,000)
Repurchased shares, value	(75,721)	$ (42)		(75,679)
Dividends to noncontrolling interests	(246)							(246)
Shareholder's Equity - Ending Balance at Dec. 31, 2016	$ 560,951	$ 544	806,589	(103,818)	(114,684)	(36,482)	0	8,802
Common Stock, Shares, Issued	48,698,385	48,688,000
Shareholder's Equity	$ 560,951	$ 544	806,589	(103,818)	(114,684)	(36,482)	0	8,802
Shareholder's Equity	190,703	$ 499	800,968	(104,785)	(492,150)	(22,429)	0	8,600
Net income (loss)	(379,015)				(379,824)			809
Currency translation adjustments, net of taxes	16,150							(31)
Currency translation adjustment	16,119
Derivative financial instruments	935					935
Defined benefit obligation	(3,107)					(3,107)
Available-for-sale investments	75					75
Stock-based compensation		212,000
Stock Granted, Value, Share-based Compensation, Net of Forfeitures	12,399	$ 3	11,005	(967)	2,358
Repurchased shares		(4,834,822)
Repurchased shares, value	(16,674)	$ (48)	16,626	0
Dividends to noncontrolling interests	(980)							(980)
Shareholder's Equity - Ending Balance at Dec. 31, 2017	$ 190,703	$ 499	800,968	(104,785)	(492,150)	(22,429)	0	8,600
Common Stock, Shares, Issued	48,871,997	44,065,000
Shareholder's Equity	$ 190,703	$ 499	$ 800,968	$ (104,785)	$ (492,150)	$ (22,429)	$ 0	$ 8,600

XML

Second Lien Term Loan Facility Statement - USD ($) shares in Millions	3 Months Ended		12 Months Ended
	Dec. 31, 2017	Sep. 30, 2017	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015	Aug. 07, 2017
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Effective Percentage	6.90%		6.90%			18.00%
Common Stock Repurchase from Related Party			$ (16,674,000)	$ 0	$ 0
Debt Instrument, Unamortized Discount						$ 35,743,000
Debt Instrument, Unamortized Discount (Premium), Net						34,000,000
Second Lien Term Loan [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	465700000.00%	255400000.00%	465700000.00%
Amortization of Debt Issuance Costs and Discounts	$ 2,131,000	$ 1,095,000
Second Lien Term Loan Facility [Member]
Debt Instrument [Line Items]
Line of Credit Facility, Current Borrowing Capacity						$ 175,900,000
Debt Instrument, Interest Rate, Effective Percentage	0.00%		0.00%			12.00%
Treasury Stock, Common, Shares						4.8
Repurchased shares percentage						0.00%
Term Loan Facility, Additional Borrowings						$ 20,000,000
Treasury Stock, Common, Value						$ 50,900,000

XML

Second Lien Term Loan Facility Narrative (Details) $ in Thousands, shares in Millions	12 Months Ended
	Dec. 31, 2017 USD ($)
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Effective Percentage	6.90%
Common Stock Repurchase from Related Party	$ (16,674)
Revolving debt	$ 103,473
Second Lien Term Loan Facility [Member]
Debt Instrument [Line Items]
Premium on voluntary prepayments made in the second year	0.00%
Debt Instrument, Interest Rate, Effective Percentage	0.00%
Debt Instrument, Fee	.005
Premium on voluntary prepayments in the third year	0.00%
Second Lien Term Loan [Member]
Debt Instrument [Line Items]
Revolving debt	$ 160,141

XML

Second Lien Term Loan Facility Carrying value of Second Lien Term Loan Facility $ in Thousands	Aug. 07, 2017 USD ($)
Debt Instrument [Line Items]
Debt Instrument, Unamortized Discount	$ 35,743
Second Lien Term Loan Facility [Member]
Debt Instrument [Line Items]
Line of Credit Facility, Current Borrowing Capacity	$ 195,884

XML

Leases and Debt Obligations Statement - USD ($) $ in Thousands	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Operating Leased Assets [Line Items]
Operating Leases, Future Minimum Payments Due	$ 2,258	$ 2,741	$ 3,553	$ 5,100	$ 6,814	$ 3,337

XML

Leases and Debt Obligations Operating leases (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Leases [Abstract]
Operating Leases, Rent Expense, Net	$ 10.5	$ 8.3	$ 13.5

XML

Leases and Debt Obligations Debt obligations $ in Thousands	Dec. 31, 2017 USD ($)
Debt Instrument [Line Items]
Long-term Debt, Maturities, Repayments of Principal in Next Twelve Months	$ 9,173
Long-term Debt, Maturities, Repayments of Principal in Year Three	$ 290,184

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Earnings Per Share

12 Months Ended

Dec. 31, 2017

Earnings Per Share [Abstract]

Earnings Per Share

EARNINGS PER SHARE

The following table sets forth the computation of basic and diluted earnings per share of our common stock, net of noncontrolling interest:

	Year Ended December 31,
(in thousands, except per share amounts)	2017			2016			2015
Income (loss) from continuing operations	$	(379,824	)	(115,649		)	$	16,338
Income (loss) from discontinued operations, net of tax	—			—			2,803
Net income (loss) attributable to shareholders	$	(379,824	)	$	(115,649	)	$	19,141
Weighted average shares used to calculate basic earnings per share	46,935			50,129			53,487
Dilutive effect of stock options, restricted stock and performance shares	—			—			222
Weighted average shares used to calculate diluted earnings per share	46,935			50,129			53,709
Basic earnings (loss) per share:
Continuing operations	$	(8.09	)	$	(2.31	)	$	0.31
Discontinued operations	—			—			0.05
Basic earnings (loss) per share:	$	(8.09	)	$	(2.31	)	$	0.36
Diluted earnings (loss) per share:
Continuing operations	(8.09		)	(2.31		)	0.30
Discontinued operations	—			—			0.06
Diluted earnings (loss) per share:	$	(8.09	)	$	(2.31	)	$	0.36

Because we incurred a net loss in the years ended December 31, 2017 and 2016, basic and diluted shares are the same.

If we had net income in the years ended December 31, 2017 and 2016, diluted shares would include an additional 0.4 million and 0.5 million shares, respectively.

We excluded 2.0 million, 3.4 million and 1.3 million shares related to stock options from the diluted share calculation for the years ended December 31, 2017, 2016 and 2015, respectively, because their effect would have been anti-dilutive.

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Segment Reporting

12 Months Ended

Dec. 31, 2017

Segment Reporting, Disclosure of Entity's Reportable Segments [Abstract]

Segment Reporting Disclosure [Text Block]

	Year Ended December 31,
(in thousands)	2017			2016			2015
GROSS PROFIT (LOSS)
Power segment	$	191,999		$	233,550		$	247,632
Renewable segment	(128,204		)	(68,109		)	57,682
Industrial segment	41,383			50,726			54,826
Intangible amortization expense included in cost of operations	(14,272		)	(15,842		)	(7,676		)
Mark to market gain (loss) included in cost of operations	8,972			(21,208		)	(44,307		)
	99,878			179,117			308,157
Selling, general and administrative ("SG&A") expenses	(255,545		)	(240,166		)	(240,296		)
Goodwill impairment charges	(86,903		)	—			—
Restructuring activities and spin-off transaction costs	(15,447		)	(40,807		)	(14,946		)
Research and development costs	(9,412		)	(10,406		)	(16,543		)
Intangible amortization expense included in SG&A	(3,980		)	(4,081		)	(3,769		)
Mark to market gain (loss) included in SG&A	(274		)	(2,902		)	4,097
Equity in income of investees	8,326			16,440			(242		)
Impairment of equity method investment	(18,193		)	—			—
Gains (losses) on asset disposals, net	(15		)	32			(14,597		)
Operating income (loss)	$	(281,565	)	$	(102,773	)	$	21,861

SEGMENT REPORTING

Our operations are assessed based on three reportable segments, which are summarized as follows:

• Power segment: focused on the supply of and aftermarket services for steam-generating, environmental and auxiliary equipment for power generation and other industrial applications.

• Renewable segment: focused on the supply of steam-generating systems, environmental and auxiliary equipment for the waste-to-energy and biomass power generation industries.

• Industrial segment: focused on custom-engineered cooling, environmental and other industrial equipment along with related aftermarket services.

An analysis of our operations by segment is as follows:

	Year Ended December 31,
(in thousands)	2017			2016			2015
REVENUES
Power segment
Retrofits & continuous emissions monitoring systems	$	306,758		$	392,854		$	427,378
New build utility and environmental	155,886			292,302			403,981
Aftermarket parts and field engineering services	277,129			292,535			304,923
Industrial steam generation	123,127			107,267			219,379
Eliminations	(41,838		)	(102,980		)	(120,664		)
	821,062			981,978			1,234,997
Renewable segment
Renewable new build and services	282,228			284,684			277,326
Operations and maintenance	64,970			65,814			63,437
Eliminations	—			(1,326		)	(2,160		)
	347,198			349,172			338,603
Industrial segment
Aftermarket parts and services	117,970			81,690			61,350
Environmental solutions	138,722			74,726			90,343
Cooling systems	126,683			73,797			—
Engineered products	14,416			23,400			32,002
	397,791			253,613			183,695
Eliminations	(8,316		)	(6,500		)	—
	$	1,557,735		$	1,578,263		$	1,757,295

The segment information presented in the table above reflects the product line revenues that are reviewed by each segment's manager. These gross product line revenues exclude eliminations of revenues generated from sales to other segments or to other product lines within the segment. The primary component of the Power segment elimination is revenue associated with construction services.

	Year Ended December 31,
(in thousands)	2017			2016			2015
GROSS PROFIT (LOSS)
Power segment	$	191,999		$	233,550		$	247,632
Renewable segment	(128,204		)	(68,109		)	57,682
Industrial segment	41,383			50,726			54,826
Intangible amortization expense included in cost of operations	(14,272		)	(15,842		)	(7,676		)
Mark to market gain (loss) included in cost of operations	8,972			(21,208		)	(44,307		)
	99,878			179,117			308,157
Selling, general and administrative ("SG&A") expenses	(255,545		)	(240,166		)	(240,296		)
Goodwill impairment charges	(86,903		)	—			—
Restructuring activities and spin-off transaction costs	(15,447		)	(40,807		)	(14,946		)
Research and development costs	(9,412		)	(10,406		)	(16,543		)
Intangible amortization expense included in SG&A	(3,980		)	(4,081		)	(3,769		)
Mark to market gain (loss) included in SG&A	(274		)	(2,902		)	4,097
Equity in income of investees	8,326			16,440			(242		)
Impairment of equity method investment	(18,193		)	—			—
Gains (losses) on asset disposals, net	(15		)	32			(14,597		)
Operating income (loss)	$	(281,565	)	$	(102,773	)	$	21,861

	Year Ended December 31,
(in thousands)	2017		2016		2015
DEPRECIATION AND AMORTIZATION
Power segment	$	9,222	$	11,231	$	18,532
Renewable segment	3,208		2,711		2,567
Industrial segment	20,293		19,073		10,345
Segment depreciation and amortization	32,723		33,015		31,444
Corporate	7,415		6,568		3,488
Total depreciation and amortization	$	40,138	$	39,583	$	34,932

We do not separately identify or report our Company's assets by segment as the majority of our assets are shared by the Power and Renewable segments. Additionally, our chief operating decision maker does not consider assets by segment to be a critical measure by which performance is measured.

Information about our consolidated operations in different geographic areas

	Year Ended December 31,
(in thousands)	2017		2016		2015
REVENUES(1)
United States	$	757,159	$	851,955	$	1,034,653
United Kingdom	194,456		201,221		126,285
Canada	108,045		74,629		134,276
Denmark	82,843		54,722		116,064
China	54,883		33,898		41,921
Egypt	43,148		35,878		—
South Korea	41,217		44,660		4,358
Sweden	39,891		24,809		18,302
Germany	28,333		29,559		19,233
Vietnam	15,771		55,265		46,803
Dominican Republic	15,144		21,366		82,916
Saudi Arabia	13,978		2,408		4,220
South Africa	12,453		4,097		4,486
Italy	11,663		7,862		4,671
Netherlands	8,989		3,348		4,651
Finland	8,713		5,756		6,113
Bolivia	8,694		—		—
Oman	7,683		—		—
Indonesia	6,909		6,723		1,730
Nigeria	6,766		—		—
India	6,441		6,856		13,108
Aggregate of all other countries, each with less than $5 million in revenues	84,556		113,251		93,505
	$	1,557,735	$	1,578,263	$	1,757,295

⁽¹⁾ We allocate geographic revenues based on the location of the customer's operations.

	Year Ended December 31,
(in thousands)	2017		2016		2015
NET PROPERTY, PLANT AND EQUIPMENT
United States	$	79,681	$	75,368	$	88,840
Mexico	26,503		22,594		24,643
China	13,373		13,460		13,956
United Kingdom	6,604		6,337		8,070
Denmark	7,953		6,749		6,265
Aggregate of all other countries, each with less than $5 million of net property, plant and equipment	7,817		9,129		3,943
	$	141,931	$	133,637	$	145,717

	Year Ended December 31,
(in thousands)	2017		2016		2015
DEPRECIATION AND AMORTIZATION
Power segment	$	9,222	$	11,231	$	18,532
Renewable segment	3,208		2,711		2,567
Industrial segment	20,293		19,073		10,345
Segment depreciation and amortization	32,723		33,015		31,444
Corporate	7,415		6,568		3,488
Total depreciation and amortization	$	40,138	$	39,583	$	34,932

Information about our consolidated operations in different geographic areas

	Year Ended December 31,
(in thousands)	2017		2016		2015
REVENUES(1)
United States	$	757,159	$	851,955	$	1,034,653
United Kingdom	194,456		201,221		126,285
Canada	108,045		74,629		134,276
Denmark	82,843		54,722		116,064
China	54,883		33,898		41,921
Egypt	43,148		35,878		—
South Korea	41,217		44,660		4,358
Sweden	39,891		24,809		18,302
Germany	28,333		29,559		19,233
Vietnam	15,771		55,265		46,803
Dominican Republic	15,144		21,366		82,916
Saudi Arabia	13,978		2,408		4,220
South Africa	12,453		4,097		4,486
Italy	11,663		7,862		4,671
Netherlands	8,989		3,348		4,651
Finland	8,713		5,756		6,113
Bolivia	8,694		—		—
Oman	7,683		—		—
Indonesia	6,909		6,723		1,730
Nigeria	6,766		—		—
India	6,441		6,856		13,108
Aggregate of all other countries, each with less than $5 million in revenues	84,556		113,251		93,505
	$	1,557,735	$	1,578,263	$	1,757,295

	Year Ended December 31,
(in thousands)	2017			2016			2015
REVENUES
Power segment
Retrofits & continuous emissions monitoring systems	$	306,758		$	392,854		$	427,378
New build utility and environmental	155,886			292,302			403,981
Aftermarket parts and field engineering services	277,129			292,535			304,923
Industrial steam generation	123,127			107,267			219,379
Eliminations	(41,838		)	(102,980		)	(120,664		)
	821,062			981,978			1,234,997
Renewable segment
Renewable new build and services	282,228			284,684			277,326
Operations and maintenance	64,970			65,814			63,437
Eliminations	—			(1,326		)	(2,160		)
	347,198			349,172			338,603
Industrial segment
Aftermarket parts and services	117,970			81,690			61,350
Environmental solutions	138,722			74,726			90,343
Cooling systems	126,683			73,797			—
Engineered products	14,416			23,400			32,002
	397,791			253,613			183,695
Eliminations	(8,316		)	(6,500		)	—
	$	1,557,735		$	1,578,263		$	1,757,295

NOTE 4 – SEGMENT REPORTING

Our operations are assessed based on three reportable segments, which are summarized as follows:

• Power segment: focused on the supply of and aftermarket services for steam-generating, environmental and auxiliary equipment for power generation and other industrial applications.

• Renewable segment: focused on the supply of steam-generating systems, environmental and auxiliary equipment for the waste-to-energy and biomass power generation industries.

• Industrial segment: focused on custom-engineered cooling, environmental and other industrial equipment along with related aftermarket services.

An analysis of our operations by segment is as follows:

	Year Ended December 31,
(in thousands)	2017			2016			2015
REVENUES
Power segment
Retrofits & continuous emissions monitoring systems	$	306,758		$	392,854		$	427,378
New build utility and environmental	155,886			292,302			403,981
Aftermarket parts and field engineering services	277,129			292,535			304,923
Industrial steam generation	123,127			107,267			219,379
Eliminations	(41,838		)	(102,980		)	(120,664		)
	821,062			981,978			1,234,997
Renewable segment
Renewable new build and services	282,228			284,684			277,326
Operations and maintenance	64,970			65,814			63,437
Eliminations	—			(1,326		)	(2,160		)
	347,198			349,172			338,603
Industrial segment
Aftermarket parts and services	117,970			81,690			61,350
Environmental solutions	138,722			74,726			90,343
Cooling systems	126,683			73,797			—
Engineered products	14,416			23,400			32,002
	397,791			253,613			183,695
Eliminations	(8,316		)	(6,500		)	—
	$	1,557,735		$	1,578,263		$	1,757,295

The segment information presented in the table above reflects the product line revenues that are reviewed by each segment's manager. These gross product line revenues exclude eliminations of revenues generated from sales to other segments or to other product lines within the segment. The primary component of the Power segment elimination is revenue associated with construction services.

	Year Ended December 31,
(in thousands)	2017			2016			2015
GROSS PROFIT (LOSS)
Power segment	$	191,999		$	233,550		$	247,632
Renewable segment	(128,204		)	(68,109		)	57,682
Industrial segment	41,383			50,726			54,826
Intangible amortization expense included in cost of operations	(14,272		)	(15,842		)	(7,676		)
Mark to market gain (loss) included in cost of operations	8,972			(21,208		)	(44,307		)
	99,878			179,117			308,157
Selling, general and administrative ("SG&A") expenses	(255,545		)	(240,166		)	(240,296		)
Goodwill impairment charges	(86,903		)	—			—
Restructuring activities and spin-off transaction costs	(15,447		)	(40,807		)	(14,946		)
Research and development costs	(9,412		)	(10,406		)	(16,543		)
Intangible amortization expense included in SG&A	(3,980		)	(4,081		)	(3,769		)
Mark to market gain (loss) included in SG&A	(274		)	(2,902		)	4,097
Equity in income of investees	8,326			16,440			(242		)
Impairment of equity method investment	(18,193		)	—			—
Gains (losses) on asset disposals, net	(15		)	32			(14,597		)
Operating income (loss)	$	(281,565	)	$	(102,773	)	$	21,861

	Year Ended December 31,
(in thousands)	2017		2016		2015
DEPRECIATION AND AMORTIZATION
Power segment	$	9,222	$	11,231	$	18,532
Renewable segment	3,208		2,711		2,567
Industrial segment	20,293		19,073		10,345
Segment depreciation and amortization	32,723		33,015		31,444
Corporate	7,415		6,568		3,488
Total depreciation and amortization	$	40,138	$	39,583	$	34,932

We do not separately identify or report our Company's assets by segment as the majority of our assets are shared by the Power and Renewable segments. Additionally, our chief operating decision maker does not consider assets by segment to be a critical measure by which performance is measured.

Information about our consolidated operations in different geographic areas

	Year Ended December 31,
(in thousands)	2017		2016		2015
REVENUES(1)
United States	$	757,159	$	851,955	$	1,034,653
United Kingdom	194,456		201,221		126,285
Canada	108,045		74,629		134,276
Denmark	82,843		54,722		116,064
China	54,883		33,898		41,921
Egypt	43,148		35,878		—
South Korea	41,217		44,660		4,358
Sweden	39,891		24,809		18,302
Germany	28,333		29,559		19,233
Vietnam	15,771		55,265		46,803
Dominican Republic	15,144		21,366		82,916
Saudi Arabia	13,978		2,408		4,220
South Africa	12,453		4,097		4,486
Italy	11,663		7,862		4,671
Netherlands	8,989		3,348		4,651
Finland	8,713		5,756		6,113
Bolivia	8,694		—		—
Oman	7,683		—		—
Indonesia	6,909		6,723		1,730
Nigeria	6,766		—		—
India	6,441		6,856		13,108
Aggregate of all other countries, each with less than $5 million in revenues	84,556		113,251		93,505
	$	1,557,735	$	1,578,263	$	1,757,295

⁽¹⁾ We allocate geographic revenues based on the location of the customer's operations.

	Year Ended December 31,
(in thousands)	2017		2016		2015
NET PROPERTY, PLANT AND EQUIPMENT
United States	$	79,681	$	75,368	$	88,840
Mexico	26,503		22,594		24,643
China	13,373		13,460		13,956
United Kingdom	6,604		6,337		8,070
Denmark	7,953		6,749		6,265
Aggregate of all other countries, each with less than $5 million of net property, plant and equipment	7,817		9,129		3,943
	$	141,931	$	133,637	$	145,717

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Restructuring Activities and Spin Transaction Costs Restructuring Activities and Spin-Off Transaction Costs (Notes)

12 Months Ended

Dec. 31, 2017

Restructuring Activities and Spin-Off Transaction Costs [Abstract]

Restructuring and Related Activities Disclosure [Text Block]

Restructuring liabilities

Restructuring liabilities are included in other accrued liabilities on our consolidated balance sheets. Activity related to the restructuring liabilities is as follows:

	Year ended December 31,
(in thousands)	2017			2016
Balance at beginning of period	$	2,253		$	740
Restructuring expense	13,923			21,939
Payments	(13,857		)	(20,426		)
Balance at December 31	$	2,319		$	2,253

Restructuring liabilities are included in other accrued liabilities on our consolidated balance sheets. Activity related to the restructuring liabilities is as follows:

	Year ended December 31,
(in thousands)	2017			2016
Balance at beginning of period	$	2,253		$	740
Restructuring expense	13,923			21,939
Payments	(13,857		)	(20,426		)
Balance at December 31	$	2,319		$	2,253

Accrued restructuring liabilities at December 31, 2017 and 2016 relate primarily to employee termination benefits.

Excluded from restructuring expense in the table above are non-cash restructuring charges that did not impact the accrued restructuring liability. In the years ended December 31, 2017 and 2016, we recognized $0.3 million and $15.0 million, respectively, in non-cash restructuring expense related to losses (gains) on the disposals of long-lived assets.

Spin-off transaction costs

Spin-off costs were primarily attributable to employee retention awards directly related to the spin-off from our former parent, The Babcock & Wilcox Company (now known as BWX Technologies, Inc.). In the years ended December 31, 2017 and 2016, we recognized spin-off costs of $1.2 million and $3.8 million, respectively. During 2017, we disbursed $1.9 million of the accrued retention awards.

Spin-off transaction costs

Spin-off costs were primarily attributable to employee retention awards directly related to the spin-off from our former parent, The Babcock & Wilcox Company (now known as BWX Technologies, Inc.). In the years ended December 31, 2017 and 2016, we recognized spin-off costs of $1.2 million and $3.8 million, respectively. During 2017, we disbursed $1.9 million of the accrued retention awards.

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Contracts and Revenue Recognition (Notes)

12 Months Ended

Dec. 31, 2017

Contracts and Revenue Recognition [Abstract]

Revenue Recognition, Multiple-deliverable Arrangements [Table Text Block]

– CONTRACTS AND REVENUE RECOGNITION

We generally recognize revenues and related costs from long-term contracts on a percentage-of-completion basis. Accordingly, we review contract price and cost estimates regularly as work progresses and reflect adjustments in profit proportionate to the percentage of completion in the periods in which we revise estimates to complete the contract. To the extent that these adjustments result in a reduction of previously reported profits from a contract, we recognize a charge against current earnings. If a contract is estimated to result in a loss, that loss is recognized in the current period as a charge to earnings and the full loss is accrued on our balance sheet, which results in no expected gross profit from the loss contract in the future unless there are revisions to our estimated revenues or costs at completion in periods following the accrual of the contract loss. Changes in the estimated results of our percentage-of-completion contracts are necessarily based on information available at the time that the estimates are made and are based on judgments that are inherently uncertain as they are predictive in nature. As with all estimates to complete used to measure contract revenue and costs, actual results can and do differ from our estimates made over time.

In the years ended December 31, 2017 and 2016 and 2015, we recognized changes in estimated gross profit related to long-term contracts accounted for on the percentage-of-completion basis, which are summarized as follows:

	Year Ended December 31,
(in thousands)	2017			2016			2015
Increases in estimates for percentage-of-completion contracts	$	21,638		$	42,368		$	36,653
Decreases in estimates for percentage-of-completion contracts	(174,906		)	(149,169		)	(36,235		)
Net changes in estimates for percentage-of-completion contracts	$	(153,268	)	$	(106,801	)	$	418

We had four renewable energy projects in Europe that were loss contracts at December 31, 2016. During 2017, two additional renewable energy projects in Europe became loss contracts. In the years ended December 31, 2017 and December 31, 2016, we recorded $158.5 million and $141.1 million, respectively, in net losses resulting from changes in the estimated revenues and costs to complete certain European renewable energy contracts, of which $34.7 million and $98.1 million were recorded in the three months ended December 31, 2017 and 2016, respectively. These changes in estimates in the years ended December 31, 2017 and December 31, 2016 included an increase in our estimate of anticipated liquidated damages that reduced revenue associated with these six projects of $41.3 million and $35.8 million, respectively, of which $14.3 million and $35.8 million were recorded in the three months ended December 31, 2017 and December 31, 2016, respectively. The total anticipated liquidated damages associated with these six projects was $77.1 million and $35.8 million at December 31, 2017 and December 31, 2016, respectively.

The charges recorded in the twelve months ended December 31, 2017 were due to revisions in the estimated revenues and costs at completion during the period, primarily as a result of (a) structural steel design issues on the second, fourth and fifth projects (discussed further below) including the anticipated schedule impact, (b) scheduling delays and (c) shortcomings in our subcontractors' estimated productivity. Also included in the charges recorded in the twelve months ended December 31, 2017 were corrections that reduced (increased) estimated contract losses at completion by $1.0 million relating to the three months ended December 31, 2016. Management determined this amount was immaterial to the consolidated financial statements in the previous year. As of December 31, 2017, the status of these six loss contracts was as follows:

The first project became a loss contract in the second quarter of 2016. As of December 31, 2017, this project is approximately 98% complete and construction activities are complete as of the date of this report. The unit became operational during the second quarter of 2017, and turnover activities linked to the customer's operation of the facility are expected to be completed during the second quarter of 2018. During the year ended December 31, 2017, we recognized additional contract losses of $20.8 million on the project as a result of differences in actual and estimated costs and schedule delays, $5.8 million of which was recorded in the three months ended December 31, 2017. Our estimate at completion as of December 31, 2017 includes $9.6 million of total expected liquidated damages. As of December 31, 2017, the reserve for estimated contract losses recorded in "other accrued liabilities" in our consolidated balance sheet was $1.6 million. In the year ended December 31, 2016, we recognized charges of $50.3 million (net of accrued insurance proceeds), and as of December 31, 2016, this project had $6.4 million of accrued losses and was 88% complete.

The second project became a loss contract in the fourth quarter of 2016. As of December 31, 2017, this contract was approximately 81% complete, and we expect construction will be completed on this project in mid 2018. During the year ended December 31, 2017, we recognized contract losses of $47.8 million on this project as a result of changes in construction cost estimates and schedule delays, $12.4 million of which was recorded in the three months ended December 31, 2017. Our estimate at completion as of December 31, 2017 includes $20.1 million of total expected liquidated damages due to schedule delays. Our estimate at completion as of December 31, 2017 also includes contractual bonus opportunities for guaranteed higher power output (discussed further below). As of December 31, 2017, the reserve for estimated contract losses recorded in "other accrued liabilities" in our consolidated balance sheet was $12.8 million. In the year ended December 31, 2016, we recognized charges of $28.1 million, and as of December 31, 2016, this project had $5.1 million of accrued losses and was 67% complete.

The third project became a loss contract in the fourth quarter of 2016. As of December 31, 2017, this contract was approximately 98% complete and construction activities are complete as of the date of this report. The unit became operational during the second quarter of 2017, and turnover activities linked to the customer's operation of the facility are expected to be completed during the first quarter of 2018. During the year ended December 31, 2017, we recognized additional contract losses of $10.2 million as a result of changes in the estimated costs at completion, $3.0 million of which was recorded in the three months ended December 31, 2017. Our estimate at completion as of December 31, 2017 includes $7.1 million of total expected liquidated damages due to schedule delays. As of December 31, 2017, the reserve for estimated contract losses recorded in "other accrued liabilities" in our consolidated balance sheet was $0.7 million. In the year ended December 31, 2016, we recognized charges of $30.1 million, and as of December 31, 2016, this project had $3.9 million of accrued losses and was 82% complete.

The fourth project became a loss contract in the fourth quarter of 2016. As of December 31, 2017, this contract was approximately 85% complete, and we expect construction will be completed on this project in mid 2018. During the year ended December 31, 2017, we revised our estimated revenue and costs at completion for this loss contract, which resulted in contract losses of $26.0 million, $8.6 million of which was recorded in the three months ended December 31, 2017. Our estimate at completion as of December 31, 2017 includes $13.7 million of total expected liquidated damages due to schedule delays. Our estimate at completion as of December 31, 2017 also includes contractual bonus opportunities for guaranteed higher power output (discussed further below). The changes in the status of this project in 2017 were primarily attributable to changes in the estimated costs at completion and an increase estimated liquidated damages. As of December 31, 2017, the reserve for estimated contract losses recorded in "other accrued liabilities" in our consolidated balance sheet was $4.7 million. In the year ended December 31, 2016, we recognized charges of $16.4 million, and as of December 31, 2016, this project had $1.6 million of accrued losses and was 61% complete.

The fifth project became a loss contract in the second quarter of 2017. As of December 31, 2017, this contract was approximately 64% complete, and we expect construction will be completed on this project in late 2018. During the year ended December 31, 2017, we revised our estimated revenue and costs at completion for this loss contract, which resulted in additional contract losses of $40.2 million, $4.9 million of which was recorded in the three months ended December 31, 2017. The change in the status of this project in 2017 was primarily attributable to changes in the estimated costs at completion and schedule delays. Our estimate at completion as of December 31, 2017 includes $20.0 million of total expected liquidated damages due to schedule delays. As of December 31, 2017, the reserve for estimated contract losses recorded in "other accrued liabilities" in our consolidated balance sheet was $14.3 million. Further, in late February 2018, we became aware that our partner responsible for civil works on this project would be filing for administration in the United Kingdom (similar to bankruptcy protection in the United States). While we are still evaluating the effect on us, we may assume all of their remaining scope on this project. Our preliminary estimate of costs to complete their remaining scope is up to $10 million. We will pursue multiple paths to recover any additional costs we incur as a result of our partner filing for administration, including a performance bond posted by our partner.

The sixth project became a loss contract in the second quarter of 2017. As of December 31, 2017, this contract was approximately 76% complete, and we expect construction will be completed on this project in the second half of 2018. During the year ended December 31, 2017, we revised our estimated revenue and costs at completion for this loss contract, which resulted in additional contract losses of $18.5 million. There was no significant change in estimated revenue of costs at completion on this project in the three months ended December 31, 2017. Our estimate at completion as of December 31, 2017 includes $6.7 million of total expected liquidated damages due to schedule delays. The change in the status of this project in 2017 was primarily attributable to changes in the estimated costs at completion and schedule delays. As of December 31, 2017, the reserve for estimated contract losses recorded in "other accrued liabilities" in our consolidated balance sheet was $2.5 million.

In September 2017, we identified the failure of a structural steel beam on the fifth project, which stopped work in the boiler building and other areas pending corrective actions to stabilize the structure that are expected to be complete in the first half of 2018. The engineering, design and manufacturing of the steel structure were the responsibility of our subcontractors. A similar design was also used on the second and fourth projects, and although no structural failure occurred on these two other projects, work was also stopped in certain restricted areas while we added reinforcement to the structures, which also resulted in delays that lasted until late January 2018. The total costs related to the structural steel issues on these three projects, including project delays, are estimated to be approximately $42 million, which is included in the December 31, 2017 estimated losses at completion for these three projects.

Also during the third quarter of 2017, we adjusted the design of three renewable facilities to increase the guaranteed power output, which will allow us to achieve contractual bonus opportunities for the higher output. In the fourth quarter of 2017, we obtained agreement from certain customers to increase the value of these bonus opportunities and to provide partial relief on liquidated damages. The bonus opportunities and liquidated damages relief increased the estimated selling price of the three contracts by approximately $19 million in total ($4 million in the three months ended December 31, 2017), and this positive change in estimated cost to complete was fully recognized in 2017 because each were loss projects.

During the years ended December 31, 2017 and 2016, we recognized losses of $2.5 million and $14.2 million, respectively, on our other renewable energy projects that are not loss contracts. Accrued liquidated damages associated with these projects was $9.0 million at December 31, 2016.

During the third quarter of 2016, we determined it was probable that we would receive a $15.0 million insurance recovery for a portion of the losses on the first European renewable energy project discussed above. There was no change in the accrued probable insurance recovery at December 31, 2017. The insurance recovery represents the full amount available under the insurance policy, and is recorded in accounts receivable - other in our consolidated balance sheet at December 31, 2017 and 2016.

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

	December 31,
(in thousands)	2017		2016
Included in contracts in progress:
Costs incurred less costs of revenue recognized	$	80,645	$	96,210
Revenues recognized less billings to customers	80,575		69,800
Contracts in progress	$	161,220	$	166,010
Included in advance billings on contracts:
Billings to customers less revenues recognized	$	177,953	$	199,480
Costs of revenue recognized less cost incurred	3,117		11,162
Advance billings on contracts	$	181,070	$	210,642

The following amounts represent retainage on contracts:

	December 31,
(in thousands)	2017		2016
Retainage expected to be collected within one year	$	14,572	$	18,843
Retainage expected to be collected after one year	6,112		4,583
Total retainage	$	20,684	$	23,426

We have included retainage expected to be collected in 2018 in "accounts receivable – trade, net." Retainage expected to be collected after one year are included in "other assets." Of the long-term retainage at December 31, 2017, we anticipate collecting $4.3 million, $1.6 million and $0.2 million in 2019, 2020 and 2021, respectively.

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Cash and Cash Equivalents

12 Months Ended

Dec. 31, 2017

Cash and Cash Equivalents [Abstract]

Schedule of Cash and Cash Equivalents [Table Text Block]

– CASH AND CASH EQUIVALENTS

The components of cash and cash equivalents are as follows:

(in thousands)	December 31, 2017		December 31, 2016
Held by foreign entities	$	54,274	$	94,415
Held by United States entities	2,393		1,472
Cash and cash equivalents	$	56,667	$	95,887
Reinsurance reserve requirements	$	21,061	$	21,189
Restricted foreign accounts	4,919		6,581
Restricted cash and cash equivalents	$	25,980	$	27,770

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Inventories (Notes)

12 Months Ended

Dec. 31, 2017

Inventory Disclosure [Text Block]

NOTE 13 – INVENTORIES

The components of inventories are as follows:

(in thousands)	December 31, 2017		December 31, 2016
Raw materials and supplies	$	60,708	$	61,630
Work in progress	7,867		6,803
Finished goods	13,587		17,374
Total inventories	$	82,162	$	85,807

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INTANGIBLE ASSETS (Notes)

12 Months Ended

Dec. 31, 2017

Goodwill and Intangible Assets Disclosure [Abstract]

Intangible Assets Disclosure [Text Block]

INTANGIBLE ASSETS

Our intangible assets are as follows:

(in thousands)	December 31, 2017			December 31, 2016
Definite-lived intangible assets
Customer relationships	$	59,794		$	47,892
Unpatented technology	20,160			18,461
Patented technology	6,542			2,499
Tradename	22,951			18,774
Backlog	30,160			28,170
All other	7,611			7,430
Gross value of definite-lived intangible assets	147,218			123,226
Customer relationships amortization	(23,434		)	(17,519		)
Unpatented technology amortization	(5,013		)	(2,864		)
Patented technology amortization	(2,213		)	(1,532		)
Tradename amortization	(5,097		)	(3,826		)
Acquired backlog amortization	(28,695		)	(21,776		)
All other amortization	(7,291		)	(5,974		)
Accumulated amortization	(71,743		)	(53,491		)
Net definite-lived intangible assets	$	75,475		$	69,735
Indefinite-lived intangible assets:
Trademarks and trade names	$	1,305		$	1,305
Total indefinite-lived intangible assets	$	1,305		$	1,305

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

	Twelve months ended December 31,
(in thousands)	2017			2016
Balance at beginning of period	$	71,039		$	37,844
Business acquisitions	19,500			55,438
Amortization expense	(18,252		)	(19,923		)
Currency translation adjustments and other	4,493			(2,320		)
Balance at end of the period	$	76,780		$	71,039

The January 11, 2017 acquisition of Universal resulted in an increase in our intangible asset amortization expense during the year ended December 31, 2017 of $3.1 million.

The July 1, 2016 acquisition of SPIG, S.p.A. resulted in a $9.1 million and $13.3 million increase in our intangible asset amortization expense during the year ended December 31, 2017 and six months ended December 31, 2016, respectively.

Amortization of intangible assets is included in cost of operations in our consolidated statement of operations, but it is not allocated to segment results.

Estimated future intangible asset amortization expense is as follows (in thousands):

Year ending	Amortization expense
December 31, 2018	$	12,423
December 31, 2019	$	10,371
December 31, 2020	$	9,077
December 31, 2021	$	8,817
December 31, 2022	$	7,244
Thereafter	$	27,543

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Property, Plant and Equipment (Notes)

12 Months Ended

Dec. 31, 2017

Property, Plant and Equipment [Abstract]

Property, Plant and Equipment Disclosure [Text Block]

PROPERTY, PLANT & EQUIPMENT

Property, plant and equipment is stated at cost. The composition of our property, plant and equipment less accumulated depreciation is set forth below:

(in thousands)	December 31, 2017		December 31, 2016
Land	$	8,859	$	6,348
Buildings	122,369		114,322
Machinery and equipment	217,791		189,489
Property under construction	6,486		22,378
	355,505		332,537
Less accumulated depreciation	213,574		198,900
Net property, plant and equipment	$	141,931	$	133,637

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Goodwill Goodwill by Segment (Notes)

12 Months Ended

Dec. 31, 2017

Goodwill [Line Items]

Goodwill Disclosure [Text Block]

For the remaining four reporting units where impairment was not indicated at September 30, 2017, the goodwill balances at September 30, 2017 (and October 1, 2017) and the Step 1 goodwill impairment test headroom (the estimated fair value less the carrying value) are as follows:

	Power Segment		Industrial Segment
(in millions)	Power	Construction	MEGTEC	Universal
Reporting unit headroom	60%	98%	12%	18%
Goodwill balance	$38.5	$8.9	$104.3	$14.4

NOTE 15 – GOODWILL

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

(in thousands)	Power			Renewable			Industrial			Total
Balance at December 31, 2015	$	47,137		$	49,624		$	104,308		$	201,069
Increase resulting from SPIG acquisition	—			—			69,862			69,862
Purchase price adjustment - SPIG acquisition	—			—			2,539			2,539
Currency translation adjustments	(917		)	(1,189		)	(3,969		)	(6,075		)
Balance at December 31, 2016	46,220			48,435			172,740			267,395
Increase resulting from Universal acquisition	—			—			14,413			14,413
Impairment charges(1)	—			(49,965		)	(36,938		)	(86,903		)
Currency translation adjustments	1,150			1,530			6,813			9,493
Balance at December 31, 2017	$	47,370		$	—		$	157,028		$	204,398

⁽¹⁾ Prior to September 30, 2017, we had not recorded any goodwill impairment charges.

Our annual goodwill impairment assessment is performed on October 1 of each year (the "annual assessment" date); however, events during 2017 have required two interim assessments of all six of our reporting units. In the second quarter of 2017, significant charges in our Renewable segment were considered to be a triggering event for the interim assessment as of June 30, 2017, which did not indicate impairment. During the third quarter of 2017, our market capitalization significantly decreased to below our equity value, which was considered to be a trigger for a second interim assessment. Additionally, the forecast was reduced for our SPIG reporting unit based on a change in the market strategy implemented by the new segment management to focus on core geographies and products, which we considered to be another triggering event for an interim assessment during the third quarter of 2017. The second interim assessment as of September 30, 2017 indicated impairment for our Renewable and SPIG reporting units as described below. Our 2017 annual goodwill impairment test as of October 1, 2017 did not indicate additional impairment.

Assessing goodwill for impairment involves a two step test. Step 1 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 test is performed to measure the amount of the impairment loss, if any. Step 2 of the test compares the implied fair value of the reporting unit's goodwill with the carrying amount of that goodwill, and impairment is measured as the excess of the carrying value over the implied value of goodwill. Estimating the fair value of a reporting unit requires significant judgment. The fair value of each reporting unit determined under Step 1 of the goodwill impairment test was based on a 50% weighting of an income approach using a discounted cash flow analysis using forward-looking projections of future operating results, a 30% to 40% weighting of a market approach using multiples of revenue and earnings before interest, taxes, depreciation and amortization ("EBITDA") of guideline companies and a 20% to 10% weighting of a market approach using multiples of revenue and EBITDA from recent, similar business combinations.

We primarily attributed the significant decline in our market capitalization in the third quarter of 2017 to the announcement of significant charges in the Renewable reporting unit. Accordingly, we increased the discount rate applied to future projected cash flows from 15.0% at June 30, 2017 to 23.5% at September 30, 2017. As a result of the increase in the discount rate and an increase in the carrying value of the reporting unit, impairment was indicated at September 30, 2017, which measured $50.0 million ($48.9 million net of tax), the full carrying value. Other long-lived assets in the reporting unit were not impaired.

For our SPIG reporting unit, which is included in our Industrial segment, the Step 1 also indicated impairment at September 30, 2017. At June 30, 2017 and October 1, 2016, the fair value exceeded the carrying value by less than 1% and 5%, respectively. At September 30, 2017, the independently obtained fair value estimates decreased under both the income and market valuation approaches due to a short-term decrease in profitability attributable to specific current contracts and changes in SPIG's market strategy introduced by segment management during the third quarter. The discount rate applied to future projected cash flows was 14.0% and 12.5% at each of the September 30, 2017 and June 30, 2017 interim tests, respectively. Step 2 of the impairment test at September 30, 2017 measured $36.9 million of impairment (with no income tax impact). The SPIG reporting unit has $38.3 million of goodwill remaining after the September 30, 2017 impairment charge. Our 2017 annual goodwill impairment test as of October 1, 2017 utilized the same assumptions and inputs as the test we performed at September 30, 2017, and it did not indicate additional impairment. Other long-lived assets in the reporting unit were not impaired.

For the remaining four reporting units where impairment was not indicated at September 30, 2017, the goodwill balances at September 30, 2017 (and October 1, 2017) and the Step 1 goodwill impairment test headroom (the estimated fair value less the carrying value) are as follows:

	Power Segment		Industrial Segment
(in millions)	Power	Construction	MEGTEC	Universal
Reporting unit headroom	60%	98%	12%	18%
Goodwill balance	$38.5	$8.9	$104.3	$14.4

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

(in thousands)	Power			Renewable			Industrial			Total
Balance at December 31, 2015	$	47,137		$	49,624		$	104,308		$	201,069
Increase resulting from SPIG acquisition	—			—			69,862			69,862
Purchase price adjustment - SPIG acquisition	—			—			2,539			2,539
Currency translation adjustments	(917		)	(1,189		)	(3,969		)	(6,075		)
Balance at December 31, 2016	46,220			48,435			172,740			267,395
Increase resulting from Universal acquisition	—			—			14,413			14,413
Impairment charges(1)	—			(49,965		)	(36,938		)	(86,903		)
Currency translation adjustments	1,150			1,530			6,813			9,493
Balance at December 31, 2017	$	47,370		$	—		$	157,028		$	204,398

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Supplemental Cash Flow Information Income Taxes Paid (Notes)

12 Months Ended

Dec. 31, 2017

Supplemental Cash Flow Information [Abstract]

Cash Flow, Supplemental Disclosures [Text Block]

During the twelve months ended December 31, 2017, 2016 and 2015, we recognized the following non-cash activity in our consolidated financial statements:

(in thousands)	2017		2016		2015
Accrued capital expenditures in accounts payable	$	1,383	$	2,751	$	568
Accreted interest expense on our second lien term loan facility	$	3,226	$	—	$	—

During the years ended December 31, 2017, 2016 and 2015 we recognized the following cash activity in our consolidated financial statements:

(in thousands)	2017			2016		2015
Income tax payments (refunds), net	$	(10,889	)	$	10,781	$	15,008
Interest payments on our United States revolving credit facility	$	4,909		$	425	$	—
Interest payments on our second lien term loan facility	$	7,044		$	—	$	—

During the years ended December 31, 2017, 2016 and 2015, interest expense in our consolidated financial statements consisted of the following components:

(in thousands)	2017		2016		2015
Components associated with borrowings from:
United States revolving credit facility	$	5,051	$	1,669	$	1,059
Second lien term loan facility	7,211		—		—
Foreign revolving credit facilities	1,021		847		148
	13,283		2,516		1,207
Components associated with amortization or accretion of:
United States revolving credit facility deferred financing fees	6,270		1,244		1,131
Second lien term loan facility deferred financing fees and discount	3,226		—		—
	9,496		1,244		1,131
Other interest expense	3,526		36		—
Total interest expense	$	26,305	$	3,796	$	2,338

In the year ended December 31, 2017, other interest expense in the table above is primarily attributable to the $3.0 million of interest expense associated with the ARPA litigation settlement (see Note 21). Interest expense included in our consolidated and combined statement of operations for the year ended December 31, 2015 has been corrected to reclassify $1.3 million of interest expense from "other - net" to "interest expense."

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Warranty (Notes)

12 Months Ended

Dec. 31, 2017

Schedule of Product Warranty Liability [Table Text Block]

hanges in the carrying amount of our accrued warranty expense are as follows:

	Year Ended December 31,
(in thousands)	2017			2016			2015
Balance at beginning of period	$	40,467		$	39,847		$	37,735
Additions	23,161			22,472			19,310
Expirations and other changes	(13,887		)	(10,855		)	(982		)
Increases attributable to business combinations	1,060			918			—
Payments	(14,110		)	(11,089		)	(15,215		)
Translation and other	2,329			(826		)	(1,001		)
Balance at end of period	$	39,020		$	40,467		$	39,847

During the years ended December 31, 2017 and 2016, our Power segment reduced its accrued warranty expense by $9.1 million and $4.4 million, respectively, to reflect the expiration of warranties, and updated its estimated warranty accrual rate to reflect its warranty claims experience and current contractual warranty obligations. Additions to the warranty accrual include specific provisions on industrial steam contracts totaling $7.9 million and $2.1 million during the years ended December 31, 2017 and 2016, respectively.

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Pension Plans and Postretirement Benefits

12 Months Ended

Dec. 31, 2017

Compensation and Retirement Disclosure [Abstract]

Defined Benefit Plan, Description of Settlements and Curtailments

PENSION PLANS AND OTHER POSTRETIREMENT BENEFITS

We have historically provided defined benefit retirement benefits to domestic employees under the Retirement Plan for Employees of Babcock & Wilcox Commercial Operations (the "Company Plan"), a noncontributory plan. As of 2006, the Company Plan was closed to new salaried plan entrants. Effective December 31, 2015, benefit accruals for those salaried employees covered by, and continuing to accrue service and salary adjusted benefits under the Company Plan will cease. Furthermore, beginning on January 1, 2016, we began making service-based, cash contributions to a defined contribution 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 6 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. In 2014, benefit accruals under certain hourly Canadian pension plans were ceased with an effective date of January 1, 2015. As part of the spin-off transaction, we split the Canadian defined benefit plans from BWC, which was completed in 2017. We did not present these plans as multi-employer plans because our portion was separately identifiable and we were able to assess the assets, liabilities and periodic expense in the same manner as if it were a separate plan in each period.

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. Funding provisions under the Pension Protection Act accelerate funding requirements to ensure full funding of benefits accrued.

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, and on a limited basis, to future retirees.

Obligations and funded status

	Pension Benefits Year Ended December 31,						Other Postretirement Benefits  Year Ended December 31,
(in thousands)	2017			2016			2017			2016
Change in benefit obligation:
Benefit obligation at beginning of period	$	1,211,720		$	1,205,163		$	11,907		$	31,889
Service cost	789			1,680			15			23
Interest cost	41,113			40,875			319			897
Plan participants’ contributions	—			—			219			574
Curtailments	—			266			—			—
Settlements	509			1,453			—			—
Amendments	—			231			—			(10,801		)
Actuarial loss (gain)	73,403			41,957			(141		)	(7,162		)
Loss (gain) due to transfer	—			3,641			—			—
Foreign currency exchange rate changes	6,222			(5,099		)	126			50
Benefits paid	(78,954		)	(78,447		)	(1,416		)	(3,563		)
Benefit obligation at end of period	$	1,254,802		$	1,211,720		$	11,029		$	11,907
Change in plan assets:
Fair value of plan assets at beginning of period	$	922,868		$	923,030		$	—		$	—
Actual return on plan assets	149,449			76,570			—			—
Employer contribution	17,307			3,986			1,197			2,989
Plan participants' contributions	—			—			219			574
Transfers	—			2,744			—			—
Foreign currency exchange rate changes	(3,668		)	(5,015		)	—			—
Benefits paid	(78,954		)	(78,447		)	(1,416		)	(3,563		)
Fair value of plan assets at the end of period	1,007,002			922,868			—			—
Funded status	$	(247,800	)	$	(288,852	)	$	(11,029	)	$	(11,907	)
Amounts recognized in the balance sheet consist of:
Accrued employee benefits	$	(1,930	)	$	(1,099	)	$	(1,615	)	$	(1,722	)
Accumulated postretirement benefit obligation	—			—			(9,414		)	(10,185		)
Pension liability	(245,870		)	(287,753		)	—			—
Prepaid pension	—			—			—			—
Accrued benefit liability, net	$	(247,800	)	$	(288,852	)	$	(11,029	)	$	(11,907	)
Amount recognized in accumulated comprehensive income (before taxes):
Prior service cost (credit)	$	324		$	432		$	(7,792	)	$	(10,801	)
Supplemental information:
Plans with accumulated benefit obligation in excess of plan assets
Projected benefit obligation	$	1,254,802		$	1,183,345		$	—		$	—
Accumulated benefit obligation	$	1,272,010		$	1,206,056		$	11,029		$	11,907
Fair value of plan assets	$	1,007,002		$	894,105		$	—		$	—
Plans with plan assets in excess of accumulated benefit obligation
Projected benefit obligation	$	—		$	28,375		$	—		$	—
Accumulated benefit obligation	$	—		$	28,375		$	—		$	—
Fair value of plan assets	$	—		$	28,763		$	—		$	—

Components of net periodic benefit cost (benefit) included in net income (loss) are as follows:

	Pension Benefits									Other Benefits
(in thousands)	2017			2016			2015			2017			2016			2015
Service cost	$	789		$	1,680		$	13,677		$	15		$	23		$	24
Interest cost	41,113			40,875			49,501			319			897			1,143
Expected return on plan assets	(59,409		)	(61,939		)	(68,709		)	—			—			—
Amortization of prior service cost	103			250			307			(3,009		)	—			—
Recognized net actuarial loss (gain)	(8,191		)	31,932			41,574			(505		)	(7,822		)	(1,364		)
Net periodic benefit cost (benefit)	$	(25,595	)	$	12,798		$	36,350		$	(3,180	)	$	(6,902	)	$	(197	)

During the first quarter of 2017, lump sum payments from our Canadian pension plan resulted in a plan settlement of $0.4 million, which also resulted in interim mark to market accounting for the pension plan. The mark to market adjustment in the first quarter of 2017 was $0.7 million. The effect of these charges and mark to market adjustments are reflected in the "Recognized net actuarial loss (gain)" in the table above. There were no significant plan settlements or interim mark to market adjustments after the first quarter of 2017.

We terminated the Babcock & Wilcox Retiree Medical Plan (the "Retiree OPEB plan") effective December 31, 2016. The Retiree OPEB plan was originally established to provide secondary medical insurance coverage for retirees that had reached the age of 65, up to a lifetime maximum cost. The Retiree OPEB plan had no plan assets, no accumulated other comprehensive income balance and no active participants as of the termination date. In exchange for terminating the Retiree OPEB plan, the participants had the option to enroll in a third-party health care exchange, which B&W agreed to contribute up to $750 a year for each of the next three years (beginning in 2017), provided the plan participant had not yet reached their lifetime maximum under the terminated Retiree OPEB plan. Based on the number of participants who did not enroll in the new benefit plan, we recognized a settlement gain of $7.2 million on December 31, 2016. Based on the number of participants who did enroll in the new benefit plan, we recognized a curtailment gain of $10.8 million on December 31, 2016 for the actuarially determined difference in the liability for these participants in the Retiree OPEB plan and the new plan. The settlement gain is reported in the "Recognized net actuarial loss" in the table above, and the curtailment gain was deferred in accumulated other comprehensive income and $3.0 million was recognized in 2017, and we expect to recognize the remainder during the periods of 2018 through 2020.

During 2016, we recorded adjustments to our benefit plan liabilities from pension curtailment and settlement events. Lump sum payments from our Canadian pension plan during 2016 resulted in interim pension plan settlement charges totaling $1.2 million in 2016. Also, in May 2016, the closure of our West Point, Mississippi manufacturing facility resulted in a $1.8 million curtailment charge in the Company Plan. These events also resulted in$27.5 millionin interim MTM losses for these pension plans, the effects of which are reflected in the 2016 "Recognized net actuarial loss (gain)" in the table above along with a$1.4 million loss for the annual MTM adjustment of our pension plans at December 31, 2016.

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. Total net mark to market adjustments for our pension and other postretirement benefit plans were (gains) losses of $(8.7) million, $24.1 million and $40.2 million in the years ended, December 31, 2017, 2016 and 2015, respectively. We have excluded the recognized net actuarial loss from our reportable segments and such amount has been reflected in Note 4 as the mark to market adjustment in the reconciliation of reportable segment income (loss) to consolidated operating losses. The recognized net actuarial (gain) loss was recorded in our consolidated statements of operations in the following line items:

(in thousands)	2017			2016		2015
Cost of operations	$	(8,972	)	$	21,208	$	44,307
Selling, general and administrative expenses	274			2,902		(4,097		)
Other	2			—		—
Total	$	(8,696	)	$	24,110	$	40,210

Assumptions

	Pension Benefits		Other Benefits
	2017	2016	2017	2016
Weighted average assumptions used to determine net periodic benefit obligations at December 31:
Discount rate	3.65%	4.13%	3.33%	3.66%
Rate of compensation increase	0.10%	2.40%	—	—
Weighted average assumptions used to determine net periodic benefit cost for the years ended December 31:
Discount rate	4.11%	4.25%	3.33%	3.66%
Expected return on plan assets	6.64%	6.70%	—%	—%
Rate of compensation increase	0.10%	2.40%	—%	—%

The expected rate of return on plan assets 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 asset class. These rates are then adjusted for anticipated future inflation to determine estimated nominal rates of return for each asset 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 asset classes within the total asset portfolio. We use an expected return on plan assets assumption of 6.89% for the majority of our pension plan assets (approximately 93% of our total pension assets at December 31, 2017).

	2016
Assumed health care cost trend rates at December 31
Health care cost trend rate assumed for next year	8.50	%
Rates to which the cost trend rate is assumed to decline (ultimate trend rate)	4.50	%
Year that the rate reaches ultimate trend rate	2024

During the year ended December 31, 2017, we did not utilize health care cost assumptions as a result of our termination of the Babcock & Wilcox Retiree Medical Plan (the "Retiree OPEB plan") effective December 31, 2016.

Investment goals

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 plans' 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 Company Plan, which is a domestic defined benefit plan. The assets of this plan are held by the Trustee in The Babcock & Wilcox Company Master Trust (the "Master Trust"). For the years ended December 31, 2017 and 2016, the investment return on domestic plan assets of the Master Trust (net of deductions for management fees) was approximately 17% and 9%, respectively.

The following is a summary of the asset allocations for the Master Trust at December 31, 2017 and 2016 by asset category:

	2017		2016
Asset Category:
Fixed Income (excluding United States Government Securities)	33	%	32	%
Commingled and Mutual Funds	41	%	38	%
United States Government Securities	21	%	20	%
Equity Securities	3	%	7	%
Derivatives	1	%	1	%
Other	1	%	2	%

The target asset allocation for the domestic defined benefit plan is 55% fixed income and 45% equities.

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 United Kingdom Plan").

The combined weighted average asset allocations of these plans at December 31, 2017 and 2016 by asset category were as follows:

	2017		2016
Asset Category:
Equity Securities and Commingled Mutual Funds	41	%	44	%
Fixed Income	58	%	55	%
Other	1	%	1	%

The target allocation for 2017 for the foreign plans, by asset class, is as follows:

	Canadian Plans		Diamond UK Plan
Asset Class:
United States Equity	27	%	10	%
Global Equity	23	%	12	%
Fixed Income	50	%	78	%

Fair value of plan assets

See Note 23 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, 2017:

(in thousands)	12/31/2017		Level 1		Level 2
Fixed income	$	352,484	$	—	$	352,484
Equities	33,525		33,525		—
Commingled and mutual funds	413,166		—		413,166
United States government securities	193,249		193,249		—
Cash and accrued items	14,578		12,585		1,993
Total pension and other postretirement benefit assets	$	1,007,002	$	239,359	$	767,643

The following is a summary of total investments for our plans measured at fair value at December 31, 2016:

(in thousands)	12/31/2016		Level 1		Level 2
Fixed income	$	321,847	$	—	$	321,847
Equities	83,441		78,268		5,173
Commingled and mutual funds	349,348		4,609		344,739
United States government securities	156,599		156,599		—
Cash and accrued items	11,633		9,394		2,239
Total pension and other postretirement benefit assets	$	922,868	$	248,870	$	673,998

Expected cash flows

	Domestic Plans				Foreign Plans
(in thousands)	Pension Benefits 1		Other Benefits		Pension Benefits 1		Other Benefits
Expected employer contributions to trusts of defined benefit plans:
2018	$	16,798	$	1,400	$	3,126	$	167
Expected benefit payments:
2018	$	71,881	$	1,463	$	3,003	$	167
2019	72,537		1,342		3,095		167
2020	73,104		854		3,175		169
2021	73,331		802		3,252		163
2022	73,434		746		3,318		146
2023-2027	359,308		2,975		18,576		611

¹ Pension benefit payments are made from their respective plan's trust.

Defined contribution plans

We provide benefits under The B&W Thrift Plan (the "Thrift Plan"). The Thrift Plan generally provides for matching employer contributions of 50% of participants' contributions up to 6% of compensation. These matching employer contributions are typically made in cash. 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 totaled approximately $14.4 million, $13.4 million and $8.9 million in the years ended December 31, 2017, 2016 and 2015, respectively.

We also provide benefits under the MEGTEC Union Plan, a defined contribution plan. The total employer contribution expense for the Union plan was approximately $0.2 million, $0.3 million and $0.3 million in the years ended December 31, 2017, 2016 and 2015, respectively. Matching employer contributions are made in cash.

We also provide benefits under the Universal Defined Contribution Plan (the "Universal Plan"). The total employer contribution expense for the Universal Plan was approximately $0.5 million in the year ended December 31, 2017. Matching employer contributions are made in cash.

Effective December 31, 2016, we merged the MEGTEC Non-union Plan and SPIG 401(k) defined contribution plans into the Thrift Plan. For the MEGTEC Non-union Plan, amounts charged to expense for our contributions were approximately $1.1 million and $1.1 million in the years ended December 31, 2016 and 2015, respectively. Matching employer contributions were made in cash. The SPIG 401(k) plan contributions were also made in cash, and were not material to our consolidated financial statements in 2016.

Also, our salaried Canadian employees are provided with a defined contribution plan. As of and in the periods following January 1, 2012, we made cash, service-based contributions under this arrangement. The amount charged to expense for employer contributions was approximately $0.3 million, $0.4 million and $0.1 million in the years ended December 31, 2017, 2016 and 2015, respectively.

Multi-employer plans

One of our subsidiaries in the Power segment contributes to various multi-employer plans. The plans generally provide defined benefits to substantially all unionized workers in this subsidiary. The following table summarizes our contributions to multi-employer plans for the years covered by this report:

Pension Fund	EIN/PIN	Pension Protection Act Zone Status		FIP/RP  Status Pending/ Implemented	Contributions						Surcharge Imposed	Expiration Date Of Collective Bargaining Agreement
					2017		2016		2015
		2017	2016		(in millions)
Boilermaker-Blacksmith National Pension Trust	48-6168020/ 001	Yellow	Yellow	Yes	$	7.9	$	17.8	$	20.3	No	Described Below
All Other					2.0		3.2		4.6
					$	9.9	$	21.0	$	24.9

Our collective bargaining agreements with the Boilermaker-Blacksmith National Pension Trust (the "Boilermaker Plan") is 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 Boilermaker 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.

See Note 29 for the future expected effect of FASB ASU 2017-07 on the presentation of benefit and expense related to our pension and post retirement plans.

Multi-employer plans

One of our subsidiaries in the Power segment contributes to various multi-employer plans. The plans generally provide defined benefits to substantially all unionized workers in this subsidiary. The following table summarizes our contributions to multi-employer plans for the years covered by this report:

Pension Fund	EIN/PIN	Pension Protection Act Zone Status		FIP/RP  Status Pending/ Implemented	Contributions						Surcharge Imposed	Expiration Date Of Collective Bargaining Agreement
					2017		2016		2015
		2017	2016		(in millions)
Boilermaker-Blacksmith National Pension Trust	48-6168020/ 001	Yellow	Yellow	Yes	$	7.9	$	17.8	$	20.3	No	Described Below
All Other					2.0		3.2		4.6
					$	9.9	$	21.0	$	24.9

Our collective bargaining agreements with the Boilermaker-Blacksmith National Pension Trust (the "Boilermaker Plan") is 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 Boilermaker 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.

The recognized net actuarial (gain) loss was recorded in our consolidated statements of operations in the following line items:

(in thousands)	2017			2016		2015
Cost of operations	$	(8,972	)	$	21,208	$	44,307
Selling, general and administrative expenses	274			2,902		(4,097		)
Other	2			—		—
Total	$	(8,696	)	$	24,110	$	40,210

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Contingencies

12 Months Ended

Dec. 31, 2017

Commitments and Contingencies Disclosure [Abstract]

Commitments and Contingencies

CONTINGENCIES

ARPA litigation

On February 28, 2014, the Arkansas River Power Authority ("ARPA") filed suit against Babcock & Wilcox Power Generation Group, Inc. (now known as The Babcock & Wilcox Company and referred to herein as "BW PGG") in the United States District Court for the District of Colorado (Case No. 14-cv-00638-CMA-NYW) alleging breach of contract, negligence, fraud and other claims arising out of BW PGG's delivery of a circulating fluidized bed boiler and related equipment used in the Lamar Repowering Project pursuant to a 2005 contract.

A jury trial took place in mid-November 2016. Some of ARPA's claims were dismissed by the judge during the trial. The jury's verdict on the remaining claims was rendered on November 21, 2016. The jury found in favor of B&W with respect to ARPA's claims of fraudulent concealment and negligent misrepresentation and on one of ARPA's claims of breach of contract. The jury found in favor of ARPA on the three remaining claims for breach of contract and awarded damages totaling $4.2 million, which exceeded the previous $2.3 million accrual we established in 2012 by $1.9 million. Accordingly, we increased our accrual by $1.9 million in the fourth quarter of 2016.

ARPA also requested that pre-judgment interest of $4.1 million plus post-judgment interest at a rate of 0.77% compounded annually be added to the judgment, together with certain litigation costs. The court granted ARPA $3.7 million of pre-judgment interest on July 21, 2017, which we recorded in our June 30, 2017 consolidated financial statements in other accrued liabilities and interest expense. B&W commenced an appeal of the judgment on August 18, 2017, and ARPA filed a notice of cross appeal on August 31, 2017.

In December 2017, we reached an agreement in principle to settle all matters related to the ARPA litigation for $7.0 million. The agreement requires us to make payments of $2.5 million, $2.5 million and $2.0 million on July 1, 2018, 2019 and 2020, respectively. We discounted the liability by approximately $0.6 million at December 31, 2017, and $2.5 million and $3.9 million was included in other current accrued liabilities and other noncurrent accrued liabilities, respectively, in our consolidated balance sheets at December 31, 2017. The settlement resulted in a $1.6 million reduction in our accrual in December 2017.

Stockholder litigation

On March 3, 2017 and March 13, 2017, the Company and certain of its officers were named as defendants in two separate but largely identical complaints alleging violations of the federal securities laws. The complaints were brought on behalf of a putative class of investors who purchased the Company's common stock between July 1, 2015 and February 28, 2017 and were filed in the United States District Court for the Western District of North Carolina (collectively, the "Stockholder Litigation"). During the second quarter of 2017, the Stockholder Litigation was consolidated into a single action and a lead plaintiff was selected by the Court. During the third quarter of 2017, the plaintiff further amended its complaint. As amended, the complaint now purports to cover investors who purchased shares between June 17, 2015 and August 9, 2017. We filed a motion to dismiss in late 2017; the court denied the motion in early 2018.

The plaintiff in the Stockholder Litigation alleges fraud, misrepresentation and a course of conduct relating to the facts surrounding certain projects underway in the Company's Renewable segment, which, according to the plaintiff, had the effect of artificially inflating the price of the Company's common stock. The plaintiff further alleges that stockholders were harmed when the Company later disclosed that it would incur losses on these projects. The plaintiff seeks an unspecified amount of damages.

On February 16, 2018 and February 22, 2018, the Company and certain of its officers and directors were named as defendants in three separate but substantially similar derivative lawsuits filed in the United States District Court for the District of Delaware (the “Derivative Litigation”). The allegations and claims against defendants are largely the same. Plaintiffs assert a variety of claims against defendants including alleged violations of the federal securities laws, gross mismanagement, waste, breach of fiduciary duties and unjust enrichment. Plaintiffs, who all purport to be current shareholders of the Company's common stock, are suing on behalf of the Company to recover costs and unspecified damages, and force implementation of corporate governance changes.

We believe the allegations in the Stockholder Litigation and the Derivative Litigation are without merit, and that the respective outcomes of the Stockholder Litigation and the Derivative Litigation will not have a material adverse impact on our consolidated financial condition, results of operations or cash flows, net of any insurance coverage.

Other

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, premises liability and other claims. Based on 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.

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Fair Value Measurements

12 Months Ended

Dec. 31, 2017

Fair Value Disclosures [Abstract]

Fair Value Measurements

(in thousands)
Available-for-sale securities	December 31, 2016		Level 1		Level 2		Level 3
Commercial paper	$	6,734	$	—	$	6,734	$	—
Certificates of deposit	2,251		—		2,251		—
Mutual funds	1,152		—		1,152		—
Corporate notes and bonds	750		750		—		—
United States Government and agency securities	7,104		7,104		—		—
Total fair value of available-for-sale securities	$	17,991	$	7,854	$	10,137	$	—

FAIR VALUE MEASUREMENTS

The following tables summarize our financial assets and liabilities carried at fair value, all of which were valued from readily available prices or using inputs based upon quoted prices for similar instruments in active markets (known as "Level 1" and "Level 2" inputs, respectively, in the fair value hierarchy established by the FASB Topic Fair Value Measurements and Disclosures).

(in thousands)
Available-for-sale securities	December 31, 2017		Level 1		Level 2		Level 3
Commercial paper	$	1,895	$	—	$	1,895	$	—
Certificates of deposit	2,398		—		2,398		—
Mutual funds	1,331		—		1,331		—
Corporate notes and bonds	4,447		4,447		—		—
United States Government and agency securities	5,738		5,738		—		—
Total fair value of available-for-sale securities	$	15,809	$	10,185	$	5,624	$	—

(in thousands)
Available-for-sale securities	December 31, 2016		Level 1		Level 2		Level 3
Commercial paper	$	6,734	$	—	$	6,734	$	—
Certificates of deposit	2,251		—		2,251		—
Mutual funds	1,152		—		1,152		—
Corporate notes and bonds	750		750		—		—
United States Government and agency securities	7,104		7,104		—		—
Total fair value of available-for-sale securities	$	17,991	$	7,854	$	10,137	$	—

Derivatives	December 31, 2017			December 31, 2016
Forward contracts to purchase/sell foreign currencies	$	(432	)	$	2,940

Available-for-sale securities

We estimate the fair value of available-for-sale securities based on quoted market prices. Our investments in available-for-sale securities are presented in "other assets" on our consolidated balance sheets.

Derivatives

Derivative assets and liabilities currently consist of FX forward contracts. 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.

Other financial instruments

We used the following methods and assumptions in estimating our fair value disclosures for our other financial instruments:

• 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 and restricted cash and cash equivalents approximate their fair values due to their highly liquid nature.

• Revolving 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, 2017 and December 31, 2016.

Non-recurring fair value measurements

The purchase price allocation associated with the January 11, 2017 acquisition of Universal required significant fair value measurements using unobservable inputs ("Level 3" inputs as defined in the fair value hierarchy established by FASB Topic Fair Value Measurements and Disclosures). The fair value of the acquired intangible assets was determined using the income approach (see Note 5).

The other-than-temporary impairment of our equity method investment in TBWES (see Note 7) required significant fair value measurements using unobservable inputs. We determined the impairment charge by first determining an estimate of the price that could be received to sell the assets and transfer the liabilities held by TBWES in an orderly transaction between market participants at June 30, 2017. The fair value of TBWES's net assets was determined through a combination of the cost approach, a market approach and an income approach.

Our interim goodwill impairment tests and third quarter impairment charges required significant fair value measurements using unobservable inputs (see Note 15). The fair value of each reporting unit determined under Step 1 of the goodwill impairment test was based on an income approach using a discounted cash flow analysis, a market approach using multiples of revenue and EBITDA of guideline companies, and a market approach using multiples of revenue and EBITDA from recent, similar business combinations. The fair value of the assets and liabilities for the Renewable and SPIG reporting units determined under Step 2 of the goodwill impairment test were based on either an income or market approach.

The measurement of the net actuarial gain or loss associated with our pension and other postretirement plans was determined using unobservable inputs (see Note 18). These inputs included the estimated discount rate, expected return on plan assets and other actuarial inputs associated with the plan participants.

The determination of the estimated fair value of the related party share repurchase required significant fair value measurements using unobservable inputs (see Note 20). We utilized a discounted cash flow model and estimates of our weighted average cost of capital on the transaction date to derive the estimated fair value of the share repurchase.

Derivatives	December 31, 2017			December 31, 2016
Forward contracts to purchase/sell foreign currencies	$	(432	)	$	2,940

The following tables summarize our financial assets and liabilities carried at fair value, all of which were valued from readily available prices or using inputs based upon quoted prices for similar instruments in active markets (known as "Level 1" and "Level 2" inputs, respectively, in the fair value hierarchy established by the FASB Topic Fair Value Measurements and Disclosures).

(in thousands)
Available-for-sale securities	December 31, 2017		Level 1		Level 2		Level 3
Commercial paper	$	1,895	$	—	$	1,895	$	—
Certificates of deposit	2,398		—		2,398		—
Mutual funds	1,331		—		1,331		—
Corporate notes and bonds	4,447		4,447		—		—
United States Government and agency securities	5,738		5,738		—		—
Total fair value of available-for-sale securities	$	15,809	$	10,185	$	5,624	$	—

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Acquisitions (Notes)

12 Months Ended

Dec. 31, 2017

Acquisitions [Abstract]

Business Combination Disclosure [Text Block]

NOTE 5 – ACQUISITIONS

Universal Acoustic & Emission Technologies, Inc.

On January 11, 2017, we acquired Universal Acoustic & Emission Technologies, Inc. ("Universal") for approximately $52.5 million in cash, funded primarily by borrowings under our United States revolving credit facility, net of $4.4 million cash acquired in the business combination. Transaction costs included in the purchase price were approximately $0.2 million. We accounted for the Universal acquisition using the acquisition method, whereby all of the assets acquired and liabilities assumed were recognized at their fair value on the acquisition date, with any excess of the purchase price over the estimated fair value recorded as goodwill. In order to purchase Universal on January 11, 2017, we borrowed approximately $55.0 million under the United States revolving credit facility in 2017.

Universal provides custom-engineered acoustic, emission and filtration solutions to the natural gas power generation, mid-stream natural gas pipeline, locomotive and general industrial end-markets. Universal's product offering includes gas turbine inlet and exhaust systems, silencers, filters and enclosures. At the acquisition date, Universal employed approximately 460 people, mainly in the United States and Mexico. During 2017, we integrated Universal with our Industrial segment. Universal contributed $69.1 million of revenue and $14.5 million of gross profit to our operating results in the year ended December 31, 2017.

The allocation of the purchase price based on the fair value of assets acquired and liabilities assumed is set forth below. We finalized the purchase price allocation associated with the valuation of certain intangible assets and deferred tax balances at December 31, 2017; as a result, the provisional measurements of intangible assets, goodwill and deferred income tax balances did not change.

(in thousands)	Acquisition date fair values
Cash	$	4,379
Accounts receivable	11,270
Contracts in progress	3,167
Inventories	4,585
Other assets	579
Property, plant and equipment	16,692
Goodwill	14,413
Identifiable intangible assets	19,500
Deferred income tax assets	935
Current liabilities	(10,833		)
Other noncurrent liabilities	(1,423		)
Deferred income tax liabilities	(6,338		)
Net acquisition cost	$	56,926

The intangible assets included above consist of the following:

	Fair value (in thousands)		Weighted average estimated useful life (in years)
Customer relationships	$	10,800	15
Backlog	1,700		1
Trade names / trademarks	3,000		20
Technology	4,000		7
Total amortizable intangible assets	$	19,500

The acquisition of Universal resulted in an increase in our intangible asset amortization expense during the year ended December 31, 2017 of $3.1 million, which is included in cost of operations in our consolidated statement of operations. Amortization of intangible assets is not allocated to segment results.

Approximately $1.7 million of acquisition and integration related costs of Universal was recorded as a component of our SG&A expenses in the consolidated statement of operations in the year ended December 31, 2017.

The following unaudited pro forma financial information below represents our results of operations for year ended December 31, 2016 had the Universal acquisition occurred on January 1, 2016. The unaudited pro forma financial information below is not intended to represent or be indicative of our actual consolidated results had we completed the acquisition at January 1, 2016. This information should not be taken as representative of our future consolidated results of operations.

	Year Ended
(in thousands)	December 31, 2016
Revenues	$	1,660,986
Net income (loss) attributable to B&W	(113,940		)
Basic earnings per common share	(2.27		)
Diluted earnings per common share	(2.27		)

The unaudited pro forma results included in the table above reflect the following pre-tax adjustments to our historical results:

• A net increase in amortization expense related to timing of amortization of the fair value of identifiable intangible assets acquired of $2.8 million in the year ended December 31, 2016.

• Elimination of the historical interest expense recognized by Universal of $0.4 million in the year ended December 31, 2016.

• Elimination of $2.1 million in transaction related costs recognized in the year ended December 31, 2016.

SPIG S.p.A.

On July 1, 2016, we acquired all of the outstanding stock of SPIG S.p.A. ("SPIG") for €155.0 million (approximately $172.1 million) in an all-cash transaction, which wassubject to post-closing adjustments. During September 2016, €2.6 million (approximately $2.9 million) of the transaction price was returned to B&W based on the difference between the actual working capital and pre-close estimates. Transaction costs included in the purchase price associated with closing the acquisition of SPIG on July 1, 2016 were approximately $0.3 million.

Based in Arona, Italy, SPIG is a global provider of custom-engineered comprehensive dry and wet cooling solutions and aftermarket services to the power generation industry including natural gas-fired and renewable energy power plants, as well as downstream oil and gas, petrochemical and other industrial end markets. The acquisition of SPIG was consistent with B&W's goal to grow and diversify its technology-based offerings with new products and services in the industrial markets that are complementary to our core businesses.In the year ended December 31, 2016, SPIG contributed $96.3 million of revenue and $7.8 million of gross profit to the Industrial segment.

We accounted for the SPIG acquisition using the acquisition method. All of the assets acquired and liabilities assumed were recognized at their estimated fair value as of the acquisition date. Any excess of the purchase price over the estimated fair values of the net assets acquired was recorded as goodwill. Several valuation methods were used to determine the fair value of the assets acquired and liabilities assumed. For intangible assets, we used the income method, which required us to forecast the expected future net cash flows for each intangible asset. These cash flows were then adjusted to present value by applying an appropriate discount rate that reflects the risk factors associated with the projected cash flows. Some of the more significant estimates and assumptions inherent in the income method include the amount and timing of projected future cash flows, the discount rate selected to measure the risks inherent in the future cash flows and the assessment of the asset's economic life and the competitive trends impacting the asset, including consideration of any technical, legal, regulatory or economic barriers to entry. Determining the useful life of an intangible asset also required judgment as different types of intangible assets will have different useful lives, or indefinite useful lives.

The allocation of the purchase price, based on the fair value of assets acquired and liabilities assumed, is detailed below.

(in thousands)	Acquisition date fair values
Cash	$	25,994
Accounts receivable	58,843
Contracts in progress	61,155
Inventories	2,554
Other assets	7,341
Property, plant and equipment	6,104
Goodwill	72,401
Identifiable intangible assets	55,164
Deferred income tax assets	5,550
Revolving debt	(27,530		)
Current liabilities	(56,323		)
Advance billings on contracts	(15,226		)
Other noncurrent liabilities	(379		)
Deferred income tax liabilities	(17,120		)
Noncontrolling interest in joint venture	(7,754		)
Net acquisition cost	$	170,774

We finalized the purchase price allocation as of December 31, 2016, which resulted in a $2.5 million increase in goodwill. The goodwill arising from the purchase price allocation of the SPIG acquisition is believed to be a result of the synergies created from combining its operations with B&W's, and the growth it canprovide from its wide scope of engineered cooling and service offerings and customer base.Noneof this goodwill is expected to be deductible for tax purposes. Also, seeNote 15for the results of our subsequent goodwill impairment assessments

The intangible assets included above consist of the following:

(in thousands)	Fair value (in thousands)		Weighted average estimated useful life (in years)
Customer relationships	$	12,217	9
Backlog	17,769		2
Trade names / trademarks	8,885		20
Technology	14,438		10
Non-compete agreements	1,666		3
Internally-developed software	189		3
Total amortizable intangible assets	$	55,164

The acquisition of SPIG added $9.1 million and $13.3 million of intangible asset amortization expense in the years ended December 31, 2017 and 2016, respectively. Amortization of intangible assets is not allocated to segment results.

Approximately $1.6 million and $3.5 million of acquisition and integration related costs of SPIG was recorded as selling, general and administrative expenses in the consolidated statement of operations for the years ended December 31, 2017 and 2016, respectively.

The following unaudited pro forma financial information below represents our results of operations for years endedDecember 31, 2016and2015had the SPIG acquisition occurred on January 1, 2015. The unaudited pro forma financial information below is not intended to represent or be indicative of our actual consolidated results had we completed the acquisition at January 1, 2015. This information should not be taken as representative of our future consolidated results of operations.

	Year Ended December 31,
(in thousands)	2016			2015
Revenues	$	1,663,126		$	1,941,987
Net income (loss) attributable to B&W	(111,500		)	12,047
Basic earnings per common share	(2.22		)	0.23
Diluted earnings per common share	(2.22		)	0.22

The unaudited pro forma results included in the table above reflect the following pre-tax adjustments to our historical results:

• A net increase (decrease) in amortization expense related to timing of amortization of the fair value of identifiable intangible assets acquired of $6.5 million and $18.6 million in the years ended December 31, 2016 and 2015, respectively.

• Elimination of the historical interest expense recognized by SPIG of $0.5 million and $0.7 million in the years ended ended December 31, 2016 and 2015, respectively.

• Elimination of $3.5 million and $0.2 million in transaction related costs recognized in the years ended December 31, 2016 and 2015, respectively.

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Quarterly Financial Data (Notes)

12 Months Ended

Dec. 31, 2017

Quarterly Financial Information Disclosure [Abstract]

Quarterly Financial Information [Text Block]

The following tables set forth selected unaudited quarterly financial information for the years ended December 31, 2017 and 2016:

(in thousands, except per share amounts)	Quarter ended
	March 31, 2017			June 30, 2017			Sept. 30, 2017			Dec. 31, 2017
Revenues	$	391,104		$	349,829		$	408,703		$	408,099
Gross profit	$	62,900		$	(55,822	)	$	47,287		$	45,513
Operating income (loss) (1)	$	(8,798	)	$	(144,646	)	$	(104,748	)	$	(23,373	)
Equity in income (loss) of investees	$	618		$	(15,232	)	$	1,234		$	3,513
Net income (loss) attributable to shareholders	$	(7,045	)	$	(150,999	)	$	(114,302	)	$	(107,478	)
Earnings per common share
Basic	$	(0.14	)	$	(3.09	)	$	(2.48	)	$	(2.44	)
Diluted	$	(0.14	)	$	(3.09	)	$	(2.48	)	$	(2.44	)

⁽¹⁾  Includes equity in income of investees.

(in thousands, except per share amounts)	Quarter ended
	March 31, 2016		June 30, 2016			Sept. 30, 2016		Dec. 31, 2016
Revenues	$	404,116	$	383,208		$	410,955	$	379,984
Gross profit	$	80,156	$	26,052		$	73,757	$	(848	)
Operating income (loss) (1)	$	17,266	$	(72,585	)	$	11,133	$	(58,587	)
Equity in income (loss) of investees	$	2,676	$	(616	)	$	2,827	$	11,553
Net income (loss) attributable to shareholders	$	10,507	$	(63,490	)	$	8,894	$	(71,560	)
Earnings per common share
Basic	$	0.20	$	(1.25	)	$	0.18	$	(1.47	)
Diluted	$	0.20	$	(1.25	)	$	0.18	$	(1.47	)

⁽¹⁾  Includes equity in income of investees.

NOTE 28 – QUARTERLY FINANCIAL DATA

The following tables set forth selected unaudited quarterly financial information for the years ended December 31, 2017 and 2016:

(in thousands, except per share amounts)	Quarter ended
	March 31, 2017			June 30, 2017			Sept. 30, 2017			Dec. 31, 2017
Revenues	$	391,104		$	349,829		$	408,703		$	408,099
Gross profit	$	62,900		$	(55,822	)	$	47,287		$	45,513
Operating income (loss) (1)	$	(8,798	)	$	(144,646	)	$	(104,748	)	$	(23,373	)
Equity in income (loss) of investees	$	618		$	(15,232	)	$	1,234		$	3,513
Net income (loss) attributable to shareholders	$	(7,045	)	$	(150,999	)	$	(114,302	)	$	(107,478	)
Earnings per common share
Basic	$	(0.14	)	$	(3.09	)	$	(2.48	)	$	(2.44	)
Diluted	$	(0.14	)	$	(3.09	)	$	(2.48	)	$	(2.44	)

⁽¹⁾  Includes equity in income of investees.

(in thousands, except per share amounts)	Quarter ended
	March 31, 2016		June 30, 2016			Sept. 30, 2016		Dec. 31, 2016
Revenues	$	404,116	$	383,208		$	410,955	$	379,984
Gross profit	$	80,156	$	26,052		$	73,757	$	(848	)
Operating income (loss) (1)	$	17,266	$	(72,585	)	$	11,133	$	(58,587	)
Equity in income (loss) of investees	$	2,676	$	(616	)	$	2,827	$	11,553
Net income (loss) attributable to shareholders	$	10,507	$	(63,490	)	$	8,894	$	(71,560	)
Earnings per common share
Basic	$	0.20	$	(1.25	)	$	0.18	$	(1.47	)
Diluted	$	0.20	$	(1.25	)	$	0.18	$	(1.47	)

⁽¹⁾  Includes equity in income of investees.

Our quarterly results include the following items that significant affect comparability across periods:

• Actuarial gains and losses from marking to market our pension and postretirement benefit plan assets and liabilities (see Note 18). Such mark to market adjustments resulted in (charges) gains of: $9.8 million in the fourth quarter of 2017, $(1.1) million in the first quarter of 2017, $6.4 million in the fourth quarter of 2016, $(0.5) million in the third quarter of 2016, and $(30.0) million in the second quarter of 2016.

• In the third quarter of 2017, $86.9 million of goodwill impairment charges (see Note 15).

• In the second and fourth quarters of both 2017 and 2016, significant losses related to changes in the estimates of the forecasted revenues and costs to complete six renewable energy contracts (see Note 6

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Related Party Transactions (Notes)

12 Months Ended

Dec. 31, 2017

Related Party Transactions [Abstract]

Related Party Transactions Disclosure [Text Block]

NOTE 25 – RELATED PARTY TRANSACTIONS

Prior to June 30, 2015, we were a party to transactions with our former Parent and its subsidiaries in the normal course of operations. After the spin-off, we no longer consider the former Parent to be a related party. Transactions with our former Parent prior to the spin-off included the following:

(in thousands)	Year Ended December 31, 2015
Sales to our former Parent	$	911
Corporate administrative expenses	35,343

Guarantees

Our former Parent had outstanding performance guarantees for various contracts executed by us in the normal course of business. As of April 21, 2016, these guarantees had all been terminated.

Net transfers from former Parent

Net transfers from former Parent represent the change in our former Parent's historical investment in us. It primarily includes the net effect of cost allocations from transactions with our former Parent, sales to our former Parent, and the net transfers of cash and assets to our former Parent prior to the spin-off. After the spin-off transaction on June 30, 2015, there have been no significant transfers to or from our former Parent. These transactions included the following:

(in thousands)	Year Ended December 31 2015
Sales to former Parent	$	911
Corporate administrative expenses	35,343
Income tax allocation	11,872
Acquisition of business, net of cash acquired	—
Cash pooling and general financing activities	(91,015		)
Cash contribution received at spin-off	125,300
Net transfer from former Parent per statement of cash flows	$	80,589
Non-cash items:
Net transfer of assets and liabilities	$	44,706
Distribution of Nuclear Energy segment	$	(47,839	)
Net transfer from former Parent per statement of shareholders' equity	$	77,456

Transactions with AIP

The second lien term loan and related repurchase of shares of our common stock described in Note 20 was a related party transaction.

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Discontinued Operations (Notes)

12 Months Ended

Dec. 31, 2017

Discontinued Operations and Disposal Groups [Abstract]

Disposal Groups, Including Discontinued Operations [Table Text Block]

NOTE 26 – DISCONTINUED OPERATIONS

We received corporate allocations from our former Parent as described in Note 1, which totaled $2.7 million for the year ended December 31, 2015. Though these allocations relate to our discontinued NE segment, they are included as part of continuing operations because allocations are not eligible for inclusion in discontinued operations.

The following table presents selected financial information regarding the results of operations of our former NE segment through June 30, 2015, the date it was discontinued:

	Six Months Ended June 30,
(in thousands)	2015
Revenues	$	53,064
Income (loss) before income tax expense	3,358
Income tax expense (benefit)	555
Income (loss) from discontinued operations, net of tax	$	2,803

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Taxes (Notes)

12 Months Ended

Dec. 31, 2017

PROVISION FOR INCOME TAXES [Abstract]

Income Tax Disclosure [Text Block]

– PROVISION FOR INCOME TAXES

We are subject to federal income tax in the United States 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 both nominal rates and the basis on which these rates are applied. Our consolidated effective income tax rate can vary significantly from period to period due to these variations, changes in jurisdictional mix of our income and valuation allowances in certain jurisdictions that can offset income tax expense or benefit.

We are currently under audit by various domestic and international authorities. With few exceptions, we do not have any returns under examination for years prior to 2013. The United States Internal Revenue Service has completed examinations of the federal tax returns of BWC through 2014, and all matters arising from such examinations have been resolved.

We recognize the effect of income tax positions only if it is more-likely-than-not that those positions will be sustained. Recognized income tax positions are measured at the largest amount that is greater than 50% likely of being realized. Changes in recognition or measurement are reflected in the period in which the change in judgment occurs. Unrecognized tax benefits are as follows:

(in thousands)	2017			2016			2015
Balance at beginning of period	$	884		$	1,141		$	3,321
Increases based on tax positions taken in the current year	277			178			88
Increases based on tax positions taken in the prior years	56			230			248
Decreases based on tax positions taken in the prior years	(13		)	—			(1,161		)
Decreases due to settlements with tax authorities	—			(665		)	(1,355		)
Decreases due to lapse of applicable statute of limitation	—			—			—
Balance at end of period	$	1,204		$	884		$	1,141

The $1.2 million balance of unrecognized tax benefits at December 31, 2017 would decrease expense if recognized. We do not expect any of our unrecognized income tax benefits to be resolved in the next twelve months. We recognize interest and penalties related to unrecognized tax benefits in our provision for income taxes; however, such amounts are not significant to any period presented.

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, 2017 and 2016 were as follows:

	December 31,
(in thousands)	2017			2016
Deferred tax assets:
Pension liability	$	58,810		$	105,426
Accrued warranty expense	5,262			11,628
Accrued vacation pay	996			4,792
Accrued liabilities for self-insurance (including postretirement health care benefits)	3,910			6,596
Accrued liabilities for executive and employee incentive compensation	4,950			8,334
Investments in joint ventures and affiliated companies	10,422			10,742
Long-term contracts	6,801			10,318
Accrued Legal Fees	1,579			2,110
Inventory Reserve	1,842			2,445
Property, plant and equipment	—			1,587
Net operating loss carryforward	95,715			33,187
State tax net operating loss carryforward	21,658			15,372
Foreign tax credit carryforward	7,150			3,870
Other tax credits	5,678			737
Other	4,980			7,852
Total deferred tax assets	229,753			224,996
Valuation allowance for deferred tax assets	(108,105		)	(40,484		)
Net, total deferred tax assets	121,648			184,512
Deferred tax liabilities:
Long-term contracts	569			3,601
Intangibles	21,215			21,892
Property, plant and equipment	2,835			—
Undistributed foreign earnings	1,314			500
Goodwill	—			1,125
Other	2,445			2,885
Total deferred tax liabilities	28,378			30,003
Net deferred tax assets	$	93,270		$	154,509

At December 31, 2017, we had a valuation allowance of $108.1 million for deferred tax assets, which we expect may not be realized through carrybacks, future reversals of existing taxable temporary differences and estimates 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 estimates of future taxable income. Should we conclude in the future that any or all of our deferred tax assets are not more likely than not to be realized, we would establish additional valuation allowances and 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:

(in thousands)	Beginning balance			Charges to costs and expenses			Charged to other accounts			Ending balance
Year Ended December 31, 2017	$	(40,484	)	$	(61,021	)	$	(6,600	)	$	(108,105	)
Year Ended December 31, 2016	(10,077		)	(29,307		)	(1,100		)	(40,484		)
Year Ended December 31, 2015	(9,216		)	(861		)	—			(10,077		)

We operate in numerous countries that have statutory tax rates below that of the 35% federal statutory rate that has been applicable to the United States through December 31, 2017. The most significant of these foreign operations are located in Canada, Denmark, Germany, Italy, Mexico, Sweden and the United Kingdom with effective tax rates ranging between 20% and approximately 30%. Income before the provision for income taxes was as follows:

	Year Ended December 31,
(in thousands)	2017			2016			2015
United States	$	(44,835	)	$	1,280		$	(20,748	)
Other than the United States	(269,364		)	(109,419		)	40,953
Income before provision for income taxes	$	(314,199	)	$	(108,139	)	$	20,205

The provision for income taxes consisted of:

	Year Ended December 31,
(in thousands)	2017			2016			2015
Current:
United States – federal	$	100		$	284		$	24,084
United States – state and local	397			(415		)	3,458
Other than in the United States	8,612			4,504			8,250
Total current	9,109			4,373			35,792
Deferred:
United States – Federal	58,203			11,512			(35,888		)
United States – state and local	2,546			6,365			(111		)
Other than in the United States	(5,042		)	(15,307		)	3,878
Total deferred (benefit) provision	55,707			2,570			(32,121		)
Provision for income taxes	$	64,816		$	6,943		$	3,671

The following is a reconciliation of the United States statutory federal tax rate (35%) to the consolidated effective tax rate:

	Year Ended December 31,
	2017		2016		2015
United States federal statutory rate	35.0	%	35.0	%	35.0	%
State and local income taxes	0.2		(3.5	)	13.8
Foreign rate differential	(9.5	)	(12.8	)	(13.1	)
Deferred Taxes - Change in Tax Rate	(19.9	)	—		—
Tax credits	0.9		3.0		(14.7	)
Dividends and deemed dividends from affiliates	(1.8	)	(0.2	)	1.7
Valuation allowances	(17.9	)	(28.1	)	4.3
Goodwill impairment	(7.0	)	—		—
Uncertain tax positions	—		0.3		(6.6	)
Non-deductible expenses	0.2		(1.8	)	2.4
Manufacturing deduction	—		—		(2.5	)
Other	(0.8	)	1.7		(2.1	)
Effective tax rate	(20.6	)%	(6.4	)%	18.2	%

We have foreign net operating loss benefits after tax of $75.0 million available to offset future taxable income in certain foreign jurisdictions. Of the foreign net operating loss benefits, $1.7 million is scheduled to expire in 2019 to 2026. The remaining net operating loss benefits have unlimited lives. We are carrying a valuation allowance of $66.0 million against the deferred tax asset related to the foreign loss carryforwards.

At December 31, 2017, we have a tax effected United States federal net operating loss of $20.7 million. The United States federal operating loss will begin to expire in 2037, and we expect to fully utilize this net operating loss in future periods. At December 31, 2017, we have foreign tax credit carryovers of $7.2 million, against which we have a full valuation allowance. At December 31, 2017, we have state net operating loss benefits after tax of $21.7 million available to offset future taxable income in various states, against which we have $21.6 million of valuation allowance. Our state net operating loss carryforwards begin to expire in the year 2018.

It has been our practice to reinvest indefinitely, the earnings of our foreign subsidiaries and that position has not changed as a result of the enactment of the U.S. Tax Cuts and Jobs Act. If we were to distribute earnings from certain foreign subsidiaries, we would be subject to withholding taxes of approximately $4.4 million but U.S. income taxes would generally not be imposed upon such distributions.

We operate in numerous countries that have statutory tax rates below that of the 35% federal statutory rate that has been applicable to the United States through December 31, 2017. The most significant of these foreign operations are located in Canada, Denmark, Germany, Italy, Mexico, Sweden and the United Kingdom with effective tax rates ranging between 20% and approximately 30%. Income before the provision for income taxes was as follows:

	Year Ended December 31,
(in thousands)	2017			2016			2015
United States	$	(44,835	)	$	1,280		$	(20,748	)
Other than the United States	(269,364		)	(109,419		)	40,953
Income before provision for income taxes	$	(314,199	)	$	(108,139	)	$	20,205

The following is a reconciliation of the United States statutory federal tax rate (35%) to the consolidated effective tax rate:

	Year Ended December 31,
	2017		2016		2015
United States federal statutory rate	35.0	%	35.0	%	35.0	%
State and local income taxes	0.2		(3.5	)	13.8
Foreign rate differential	(9.5	)	(12.8	)	(13.1	)
Deferred Taxes - Change in Tax Rate	(19.9	)	—		—
Tax credits	0.9		3.0		(14.7	)
Dividends and deemed dividends from affiliates	(1.8	)	(0.2	)	1.7
Valuation allowances	(17.9	)	(28.1	)	4.3
Goodwill impairment	(7.0	)	—		—
Uncertain tax positions	—		0.3		(6.6	)
Non-deductible expenses	0.2		(1.8	)	2.4
Manufacturing deduction	—		—		(2.5	)
Other	(0.8	)	1.7		(2.1	)
Effective tax rate	(20.6	)%	(6.4	)%	18.2	%

The provision for income taxes consisted of:

	Year Ended December 31,
(in thousands)	2017			2016			2015
Current:
United States – federal	$	100		$	284		$	24,084
United States – state and local	397			(415		)	3,458
Other than in the United States	8,612			4,504			8,250
Total current	9,109			4,373			35,792
Deferred:
United States – Federal	58,203			11,512			(35,888		)
United States – state and local	2,546			6,365			(111		)
Other than in the United States	(5,042		)	(15,307		)	3,878
Total deferred (benefit) provision	55,707			2,570			(32,121		)
Provision for income taxes	$	64,816		$	6,943		$	3,671

New Tax Act

The United States Tax Cuts and Jobs Act (the “Tax Act”) was enacted on December 22, 2017 and introduces significant changes to the United States income tax law. Beginning in 2018, the Tax Act reduces the United States statutory corporate income tax rate from 35% to 21% and creates a modified territorial system that will generally allow United States companies a full dividend received deduction for any future dividends from non-U.S. subsidiaries. In connection with the transition to a modified territorial system, the Tax Act also establishes a mandatory one-time deemed repatriation transition tax on currently deferred foreign earnings.

The SEC staff issued Staff Accounting Bulletin ("SAB 118"), which provides guidance on accounting for the tax effects of the Tax Act. SAB 118 provides a measurement period that should not extend beyond one year from the Tax Act enactment date for companies to complete the accounting under Accounting Standards Codification 740 ("ASC 740"). In accordance with SAB 118, we have made reasonable estimates of the effects of the Tax Act and recorded provisional amounts in our financial statements as of December 31, 2017. We will finalize our estimates in 2018 as we collect and analyze necessary data, and interpret additional guidance that becomes available.

Provisional amounts for the following income tax effects of the Tax Act have been recorded as of December 31, 2017:

Deferred tax effects

We remeasured our deferred taxes and recorded a deferred tax expense of $62.4 million. This amount consists of an expense for the corporate rate reduction of $54.4 million, expense of $0.8 million based on a change in our deferred taxes related to executive compensation and an expense of $7.2 million to record a valuation allowance on foreign tax credit carryforwards that are now expected to expire unused. While we are able to make a reasonable estimate of the deferred tax effects, our continued analysis of other aspects of the Tax Act could impact our estimate.

One-time transition tax

The Deemed Repatriation Transition Tax (Transition Tax) is a tax on previously untaxed accumulated and current earnings and profits (E&P) of certain of our foreign subsidiaries. To determine the amount of the Transition Tax, we must determine, in addition to other factors, the amount of post-1986 E&P of the relevant subsidiaries, as well as the amount of non-United States income taxes paid on such earnings. We are able to make a reasonable estimate of the Transition Tax and because we have estimated an E&P deficit, we have not recorded a Transition Tax. We are continuing to gather additional information to more precisely compute final E&P, including the computation of 2017 current year E&P which we will finalize with the 2017 tax return.

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Significant Accounting Policies Research and Development (Policies)

12 Months Ended

Dec. 31, 2017

Inventories [Abstract]

Research, Development, and Computer Software, Policy [Policy Text Block]

Research and development

Our research and development activities are related to the development and improvement of new and existing products, services and equipment. Research and development activities totaled $9.4 million, $10.4 million and $16.5 million in the years ended December 31, 2017, 2016 and 2015, respectively.

In the twelve months ended December 31, 2015, we recognized a $14.6 million impairment charge primarily related to research and development facilities and equipment dedicated to activities that were determined not to be commercially viable. The impairment is included in losses on asset disposals and impairments in the consolidated statements of operations.

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Significant Accounting Policies Inventories (Policies)

12 Months Ended

Dec. 31, 2017

Inventories [Abstract]

Inventory, Policy [Policy Text Block]

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 segment, for which we use the last-in, first-out ("LIFO") method. We determined the cost of approximately 16% and 18% of our total inventories using the LIFO method at December 31, 2017 and 2016, respectively, and our total LIFO reserve at December 31, 2017 and 2016 was approximately $7.0 million and $7.0 million, respectively. The components of inventories can be found in Note 13.

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Significant Accounting Policies Property, Plant and Equipment (Policies)

12 Months Ended

Dec. 31, 2017

Inventories [Abstract]

Property, Plant and Equipment, Policy [Policy Text Block]

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 33 years for buildings and three to 28 years for machinery and equipment. Our depreciation expense was $21.9 million, $19.7 million and $23.5 million for the years ended December 31, 2017, 2016 and 2015, 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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Significant Accounting Policies Self Insurance (Policies)

12 Months Ended

Dec. 31, 2017

Inventories [Abstract]

Self Insurance Reserve [Policy Text Block]

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 $23.1 million and $24.1 million at the years ended December 31, 2017 and 2016, respectively.

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Significant Accounting Policies Foreign Currency Translation (Policies)

12 Months Ended

Dec. 31, 2017

Inventories [Abstract]

Foreign Currency Transactions and Translations Policy [Policy Text Block]

Foreign currency translation

We translate assets and liabilities of our foreign operations into United States dollars at current exchange rates, and we translate items in our statement of operations 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 (loss). We report foreign currency transaction gains and losses in income. We have included in other - net transaction gains (losses) of $2.9 million, $(5.4) million and $(0.1) million in the years ended December 31, 2017, 2016 and 2015, respectively.

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Significant Accounting Policies Trade Accounts Receivable and Allowance for Doubtful Accounts (Policies)

12 Months Ended

Dec. 31, 2017

Trade accounts receivable and allowance for doubtful accounts [Abstract]

Receivables, Trade and Other Accounts Receivable, Allowance for Doubtful Accounts, Policy [Policy Text Block]

Trade accounts receivable and allowance for doubtful accounts

Our trade accounts receivable balance is stated at the amount owed by our customers, net of allowances for estimated uncollectible balances. We maintain allowances for doubtful accounts for estimated losses expected to result from the inability of our customers to make required payments. These estimates are based on management’s evaluation of the ability of customers to make payments, with emphasis on historical remittance experience, known customer financial difficulties and the age of receivable balances. Accounts receivable are charged to the allowance when it is determined they are no longer collectible. Our allowance for doubtful accounts was $11.0 million and $9.4 million at December 31, 2017 and 2016, respectively. Amounts charged to selling, general and administrative expenses or deducted from the allowance were not significant to our statement of operations in the years ended December 31, 2017, 2016 and 2015.

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Pension Plans and Postretirement Benefits ASU 2017-07 Compensation Retirement Benefits (Topic 715) (Policies)

12 Months Ended

Dec. 31, 2017

Postemployment Benefits [Abstract]

Postemployment Benefit Plans, Policy [Policy Text Block]

The changes in the classification of the historical components of net periodic benefit costs are summarized in the following table:

Pension & other postretirement benefit costs (benefits)
(in thousands)	December 31, 2017			December 31, 2016			December 31, 2015			Current classification	Future classification
Service cost	$	804		$	1,703		$	13,701		Cost of operations	Cost of operations
Interest cost	41,432			41,772			50,644			Cost of operations	Other income (expense)
Expected return on plan assets	(59,409		)	(61,939		)	(68,709		)	Cost of operations	Other income (expense)
Amortization of prior service cost	(2,906		)	250			307			Cost of operations	Other income (expense)
Recognized net actuarial losses and mark to market adjustments	(8,696		)	24,110			40,210			Cost of operations or SG&A expense	Other income (expense)
Net periodic benefit cost (benefit)	$	(28,775	)	$	5,896		$	36,153

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Earnings Per Share (Tables)

12 Months Ended

Dec. 31, 2017

Earnings Per Share [Abstract]

Computation of Basic and Diluted Earnings Per Share

The following table sets forth the computation of basic and diluted earnings per share of our common stock, net of noncontrolling interest:

	Year Ended December 31,
(in thousands, except per share amounts)	2017			2016			2015
Income (loss) from continuing operations	$	(379,824	)	(115,649		)	$	16,338
Income (loss) from discontinued operations, net of tax	—			—			2,803
Net income (loss) attributable to shareholders	$	(379,824	)	$	(115,649	)	$	19,141
Weighted average shares used to calculate basic earnings per share	46,935			50,129			53,487
Dilutive effect of stock options, restricted stock and performance shares	—			—			222
Weighted average shares used to calculate diluted earnings per share	46,935			50,129			53,709
Basic earnings (loss) per share:
Continuing operations	$	(8.09	)	$	(2.31	)	$	0.31
Discontinued operations	—			—			0.05
Basic earnings (loss) per share:	$	(8.09	)	$	(2.31	)	$	0.36
Diluted earnings (loss) per share:
Continuing operations	(8.09		)	(2.31		)	0.30
Discontinued operations	—			—			0.06
Diluted earnings (loss) per share:	$	(8.09	)	$	(2.31	)	$	0.36

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Segment Reporting Schedule of Operating Results by Segment (Tables)

12 Months Ended

Dec. 31, 2017

Segment Reporting Information [Line Items]

Schedule of Segment Reporting Information, by Segment [Table Text Block]

An analysis of our operations by segment is as follows:

	Year Ended December 31,
(in thousands)	2017			2016			2015
REVENUES
Power segment
Retrofits & continuous emissions monitoring systems	$	306,758		$	392,854		$	427,378
New build utility and environmental	155,886			292,302			403,981
Aftermarket parts and field engineering services	277,129			292,535			304,923
Industrial steam generation	123,127			107,267			219,379
Eliminations	(41,838		)	(102,980		)	(120,664		)
	821,062			981,978			1,234,997
Renewable segment
Renewable new build and services	282,228			284,684			277,326
Operations and maintenance	64,970			65,814			63,437
Eliminations	—			(1,326		)	(2,160		)
	347,198			349,172			338,603
Industrial segment
Aftermarket parts and services	117,970			81,690			61,350
Environmental solutions	138,722			74,726			90,343
Cooling systems	126,683			73,797			—
Engineered products	14,416			23,400			32,002
	397,791			253,613			183,695
Eliminations	(8,316		)	(6,500		)	—
	$	1,557,735		$	1,578,263		$	1,757,295

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Segment Reporting Schedule of Gross Profit (Loss) by Segment (Tables)

12 Months Ended

Dec. 31, 2017

Schedule of Operating Results by Segment [Abstract]

Segment Reporting Disclosure [Text Block]

	Year Ended December 31,
(in thousands)	2017			2016			2015
GROSS PROFIT (LOSS)
Power segment	$	191,999		$	233,550		$	247,632
Renewable segment	(128,204		)	(68,109		)	57,682
Industrial segment	41,383			50,726			54,826
Intangible amortization expense included in cost of operations	(14,272		)	(15,842		)	(7,676		)
Mark to market gain (loss) included in cost of operations	8,972			(21,208		)	(44,307		)
	99,878			179,117			308,157
Selling, general and administrative ("SG&A") expenses	(255,545		)	(240,166		)	(240,296		)
Goodwill impairment charges	(86,903		)	—			—
Restructuring activities and spin-off transaction costs	(15,447		)	(40,807		)	(14,946		)
Research and development costs	(9,412		)	(10,406		)	(16,543		)
Intangible amortization expense included in SG&A	(3,980		)	(4,081		)	(3,769		)
Mark to market gain (loss) included in SG&A	(274		)	(2,902		)	4,097
Equity in income of investees	8,326			16,440			(242		)
Impairment of equity method investment	(18,193		)	—			—
Gains (losses) on asset disposals, net	(15		)	32			(14,597		)
Operating income (loss)	$	(281,565	)	$	(102,773	)	$	21,861

SEGMENT REPORTING

Our operations are assessed based on three reportable segments, which are summarized as follows:

• Power segment: focused on the supply of and aftermarket services for steam-generating, environmental and auxiliary equipment for power generation and other industrial applications.

• Renewable segment: focused on the supply of steam-generating systems, environmental and auxiliary equipment for the waste-to-energy and biomass power generation industries.

• Industrial segment: focused on custom-engineered cooling, environmental and other industrial equipment along with related aftermarket services.

An analysis of our operations by segment is as follows:

	Year Ended December 31,
(in thousands)	2017			2016			2015
REVENUES
Power segment
Retrofits & continuous emissions monitoring systems	$	306,758		$	392,854		$	427,378
New build utility and environmental	155,886			292,302			403,981
Aftermarket parts and field engineering services	277,129			292,535			304,923
Industrial steam generation	123,127			107,267			219,379
Eliminations	(41,838		)	(102,980		)	(120,664		)
	821,062			981,978			1,234,997
Renewable segment
Renewable new build and services	282,228			284,684			277,326
Operations and maintenance	64,970			65,814			63,437
Eliminations	—			(1,326		)	(2,160		)
	347,198			349,172			338,603
Industrial segment
Aftermarket parts and services	117,970			81,690			61,350
Environmental solutions	138,722			74,726			90,343
Cooling systems	126,683			73,797			—
Engineered products	14,416			23,400			32,002
	397,791			253,613			183,695
Eliminations	(8,316		)	(6,500		)	—
	$	1,557,735		$	1,578,263		$	1,757,295

The segment information presented in the table above reflects the product line revenues that are reviewed by each segment's manager. These gross product line revenues exclude eliminations of revenues generated from sales to other segments or to other product lines within the segment. The primary component of the Power segment elimination is revenue associated with construction services.

	Year Ended December 31,
(in thousands)	2017			2016			2015
GROSS PROFIT (LOSS)
Power segment	$	191,999		$	233,550		$	247,632
Renewable segment	(128,204		)	(68,109		)	57,682
Industrial segment	41,383			50,726			54,826
Intangible amortization expense included in cost of operations	(14,272		)	(15,842		)	(7,676		)
Mark to market gain (loss) included in cost of operations	8,972			(21,208		)	(44,307		)
	99,878			179,117			308,157
Selling, general and administrative ("SG&A") expenses	(255,545		)	(240,166		)	(240,296		)
Goodwill impairment charges	(86,903		)	—			—
Restructuring activities and spin-off transaction costs	(15,447		)	(40,807		)	(14,946		)
Research and development costs	(9,412		)	(10,406		)	(16,543		)
Intangible amortization expense included in SG&A	(3,980		)	(4,081		)	(3,769		)
Mark to market gain (loss) included in SG&A	(274		)	(2,902		)	4,097
Equity in income of investees	8,326			16,440			(242		)
Impairment of equity method investment	(18,193		)	—			—
Gains (losses) on asset disposals, net	(15		)	32			(14,597		)
Operating income (loss)	$	(281,565	)	$	(102,773	)	$	21,861

	Year Ended December 31,
(in thousands)	2017		2016		2015
DEPRECIATION AND AMORTIZATION
Power segment	$	9,222	$	11,231	$	18,532
Renewable segment	3,208		2,711		2,567
Industrial segment	20,293		19,073		10,345
Segment depreciation and amortization	32,723		33,015		31,444
Corporate	7,415		6,568		3,488
Total depreciation and amortization	$	40,138	$	39,583	$	34,932

We do not separately identify or report our Company's assets by segment as the majority of our assets are shared by the Power and Renewable segments. Additionally, our chief operating decision maker does not consider assets by segment to be a critical measure by which performance is measured.

Information about our consolidated operations in different geographic areas

	Year Ended December 31,
(in thousands)	2017		2016		2015
REVENUES(1)
United States	$	757,159	$	851,955	$	1,034,653
United Kingdom	194,456		201,221		126,285
Canada	108,045		74,629		134,276
Denmark	82,843		54,722		116,064
China	54,883		33,898		41,921
Egypt	43,148		35,878		—
South Korea	41,217		44,660		4,358
Sweden	39,891		24,809		18,302
Germany	28,333		29,559		19,233
Vietnam	15,771		55,265		46,803
Dominican Republic	15,144		21,366		82,916
Saudi Arabia	13,978		2,408		4,220
South Africa	12,453		4,097		4,486
Italy	11,663		7,862		4,671
Netherlands	8,989		3,348		4,651
Finland	8,713		5,756		6,113
Bolivia	8,694		—		—
Oman	7,683		—		—
Indonesia	6,909		6,723		1,730
Nigeria	6,766		—		—
India	6,441		6,856		13,108
Aggregate of all other countries, each with less than $5 million in revenues	84,556		113,251		93,505
	$	1,557,735	$	1,578,263	$	1,757,295

⁽¹⁾ We allocate geographic revenues based on the location of the customer's operations.

	Year Ended December 31,
(in thousands)	2017		2016		2015
NET PROPERTY, PLANT AND EQUIPMENT
United States	$	79,681	$	75,368	$	88,840
Mexico	26,503		22,594		24,643
China	13,373		13,460		13,956
United Kingdom	6,604		6,337		8,070
Denmark	7,953		6,749		6,265
Aggregate of all other countries, each with less than $5 million of net property, plant and equipment	7,817		9,129		3,943
	$	141,931	$	133,637	$	145,717

	Year Ended December 31,
(in thousands)	2017		2016		2015
DEPRECIATION AND AMORTIZATION
Power segment	$	9,222	$	11,231	$	18,532
Renewable segment	3,208		2,711		2,567
Industrial segment	20,293		19,073		10,345
Segment depreciation and amortization	32,723		33,015		31,444
Corporate	7,415		6,568		3,488
Total depreciation and amortization	$	40,138	$	39,583	$	34,932

Information about our consolidated operations in different geographic areas

	Year Ended December 31,
(in thousands)	2017		2016		2015
REVENUES(1)
United States	$	757,159	$	851,955	$	1,034,653
United Kingdom	194,456		201,221		126,285
Canada	108,045		74,629		134,276
Denmark	82,843		54,722		116,064
China	54,883		33,898		41,921
Egypt	43,148		35,878		—
South Korea	41,217		44,660		4,358
Sweden	39,891		24,809		18,302
Germany	28,333		29,559		19,233
Vietnam	15,771		55,265		46,803
Dominican Republic	15,144		21,366		82,916
Saudi Arabia	13,978		2,408		4,220
South Africa	12,453		4,097		4,486
Italy	11,663		7,862		4,671
Netherlands	8,989		3,348		4,651
Finland	8,713		5,756		6,113
Bolivia	8,694		—		—
Oman	7,683		—		—
Indonesia	6,909		6,723		1,730
Nigeria	6,766		—		—
India	6,441		6,856		13,108
Aggregate of all other countries, each with less than $5 million in revenues	84,556		113,251		93,505
	$	1,557,735	$	1,578,263	$	1,757,295

	Year Ended December 31,
(in thousands)	2017			2016			2015
REVENUES
Power segment
Retrofits & continuous emissions monitoring systems	$	306,758		$	392,854		$	427,378
New build utility and environmental	155,886			292,302			403,981
Aftermarket parts and field engineering services	277,129			292,535			304,923
Industrial steam generation	123,127			107,267			219,379
Eliminations	(41,838		)	(102,980		)	(120,664		)
	821,062			981,978			1,234,997
Renewable segment
Renewable new build and services	282,228			284,684			277,326
Operations and maintenance	64,970			65,814			63,437
Eliminations	—			(1,326		)	(2,160		)
	347,198			349,172			338,603
Industrial segment
Aftermarket parts and services	117,970			81,690			61,350
Environmental solutions	138,722			74,726			90,343
Cooling systems	126,683			73,797			—
Engineered products	14,416			23,400			32,002
	397,791			253,613			183,695
Eliminations	(8,316		)	(6,500		)	—
	$	1,557,735		$	1,578,263		$	1,757,295

NOTE 4 – SEGMENT REPORTING

Our operations are assessed based on three reportable segments, which are summarized as follows:

• Power segment: focused on the supply of and aftermarket services for steam-generating, environmental and auxiliary equipment for power generation and other industrial applications.

• Renewable segment: focused on the supply of steam-generating systems, environmental and auxiliary equipment for the waste-to-energy and biomass power generation industries.

• Industrial segment: focused on custom-engineered cooling, environmental and other industrial equipment along with related aftermarket services.

An analysis of our operations by segment is as follows:

	Year Ended December 31,
(in thousands)	2017			2016			2015
REVENUES
Power segment
Retrofits & continuous emissions monitoring systems	$	306,758		$	392,854		$	427,378
New build utility and environmental	155,886			292,302			403,981
Aftermarket parts and field engineering services	277,129			292,535			304,923
Industrial steam generation	123,127			107,267			219,379
Eliminations	(41,838		)	(102,980		)	(120,664		)
	821,062			981,978			1,234,997
Renewable segment
Renewable new build and services	282,228			284,684			277,326
Operations and maintenance	64,970			65,814			63,437
Eliminations	—			(1,326		)	(2,160		)
	347,198			349,172			338,603
Industrial segment
Aftermarket parts and services	117,970			81,690			61,350
Environmental solutions	138,722			74,726			90,343
Cooling systems	126,683			73,797			—
Engineered products	14,416			23,400			32,002
	397,791			253,613			183,695
Eliminations	(8,316		)	(6,500		)	—
	$	1,557,735		$	1,578,263		$	1,757,295

The segment information presented in the table above reflects the product line revenues that are reviewed by each segment's manager. These gross product line revenues exclude eliminations of revenues generated from sales to other segments or to other product lines within the segment. The primary component of the Power segment elimination is revenue associated with construction services.

	Year Ended December 31,
(in thousands)	2017			2016			2015
GROSS PROFIT (LOSS)
Power segment	$	191,999		$	233,550		$	247,632
Renewable segment	(128,204		)	(68,109		)	57,682
Industrial segment	41,383			50,726			54,826
Intangible amortization expense included in cost of operations	(14,272		)	(15,842		)	(7,676		)
Mark to market gain (loss) included in cost of operations	8,972			(21,208		)	(44,307		)
	99,878			179,117			308,157
Selling, general and administrative ("SG&A") expenses	(255,545		)	(240,166		)	(240,296		)
Goodwill impairment charges	(86,903		)	—			—
Restructuring activities and spin-off transaction costs	(15,447		)	(40,807		)	(14,946		)
Research and development costs	(9,412		)	(10,406		)	(16,543		)
Intangible amortization expense included in SG&A	(3,980		)	(4,081		)	(3,769		)
Mark to market gain (loss) included in SG&A	(274		)	(2,902		)	4,097
Equity in income of investees	8,326			16,440			(242		)
Impairment of equity method investment	(18,193		)	—			—
Gains (losses) on asset disposals, net	(15		)	32			(14,597		)
Operating income (loss)	$	(281,565	)	$	(102,773	)	$	21,861

	Year Ended December 31,
(in thousands)	2017		2016		2015
DEPRECIATION AND AMORTIZATION
Power segment	$	9,222	$	11,231	$	18,532
Renewable segment	3,208		2,711		2,567
Industrial segment	20,293		19,073		10,345
Segment depreciation and amortization	32,723		33,015		31,444
Corporate	7,415		6,568		3,488
Total depreciation and amortization	$	40,138	$	39,583	$	34,932

We do not separately identify or report our Company's assets by segment as the majority of our assets are shared by the Power and Renewable segments. Additionally, our chief operating decision maker does not consider assets by segment to be a critical measure by which performance is measured.

Information about our consolidated operations in different geographic areas

	Year Ended December 31,
(in thousands)	2017		2016		2015
REVENUES(1)
United States	$	757,159	$	851,955	$	1,034,653
United Kingdom	194,456		201,221		126,285
Canada	108,045		74,629		134,276
Denmark	82,843		54,722		116,064
China	54,883		33,898		41,921
Egypt	43,148		35,878		—
South Korea	41,217		44,660		4,358
Sweden	39,891		24,809		18,302
Germany	28,333		29,559		19,233
Vietnam	15,771		55,265		46,803
Dominican Republic	15,144		21,366		82,916
Saudi Arabia	13,978		2,408		4,220
South Africa	12,453		4,097		4,486
Italy	11,663		7,862		4,671
Netherlands	8,989		3,348		4,651
Finland	8,713		5,756		6,113
Bolivia	8,694		—		—
Oman	7,683		—		—
Indonesia	6,909		6,723		1,730
Nigeria	6,766		—		—
India	6,441		6,856		13,108
Aggregate of all other countries, each with less than $5 million in revenues	84,556		113,251		93,505
	$	1,557,735	$	1,578,263	$	1,757,295

⁽¹⁾ We allocate geographic revenues based on the location of the customer's operations.

	Year Ended December 31,
(in thousands)	2017		2016		2015
NET PROPERTY, PLANT AND EQUIPMENT
United States	$	79,681	$	75,368	$	88,840
Mexico	26,503		22,594		24,643
China	13,373		13,460		13,956
United Kingdom	6,604		6,337		8,070
Denmark	7,953		6,749		6,265
Aggregate of all other countries, each with less than $5 million of net property, plant and equipment	7,817		9,129		3,943
	$	141,931	$	133,637	$	145,717

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Segment Reporting Depreciation and Amortization (Tables)

12 Months Ended

Dec. 31, 2017

Depreciation, Depletion and Amortization [Abstract]

Segment Reporting Disclosure [Text Block]

	Year Ended December 31,
(in thousands)	2017			2016			2015
GROSS PROFIT (LOSS)
Power segment	$	191,999		$	233,550		$	247,632
Renewable segment	(128,204		)	(68,109		)	57,682
Industrial segment	41,383			50,726			54,826
Intangible amortization expense included in cost of operations	(14,272		)	(15,842		)	(7,676		)
Mark to market gain (loss) included in cost of operations	8,972			(21,208		)	(44,307		)
	99,878			179,117			308,157
Selling, general and administrative ("SG&A") expenses	(255,545		)	(240,166		)	(240,296		)
Goodwill impairment charges	(86,903		)	—			—
Restructuring activities and spin-off transaction costs	(15,447		)	(40,807		)	(14,946		)
Research and development costs	(9,412		)	(10,406		)	(16,543		)
Intangible amortization expense included in SG&A	(3,980		)	(4,081		)	(3,769		)
Mark to market gain (loss) included in SG&A	(274		)	(2,902		)	4,097
Equity in income of investees	8,326			16,440			(242		)
Impairment of equity method investment	(18,193		)	—			—
Gains (losses) on asset disposals, net	(15		)	32			(14,597		)
Operating income (loss)	$	(281,565	)	$	(102,773	)	$	21,861

SEGMENT REPORTING

Our operations are assessed based on three reportable segments, which are summarized as follows:

• Power segment: focused on the supply of and aftermarket services for steam-generating, environmental and auxiliary equipment for power generation and other industrial applications.

• Renewable segment: focused on the supply of steam-generating systems, environmental and auxiliary equipment for the waste-to-energy and biomass power generation industries.

• Industrial segment: focused on custom-engineered cooling, environmental and other industrial equipment along with related aftermarket services.

An analysis of our operations by segment is as follows:

	Year Ended December 31,
(in thousands)	2017			2016			2015
REVENUES
Power segment
Retrofits & continuous emissions monitoring systems	$	306,758		$	392,854		$	427,378
New build utility and environmental	155,886			292,302			403,981
Aftermarket parts and field engineering services	277,129			292,535			304,923
Industrial steam generation	123,127			107,267			219,379
Eliminations	(41,838		)	(102,980		)	(120,664		)
	821,062			981,978			1,234,997
Renewable segment
Renewable new build and services	282,228			284,684			277,326
Operations and maintenance	64,970			65,814			63,437
Eliminations	—			(1,326		)	(2,160		)
	347,198			349,172			338,603
Industrial segment
Aftermarket parts and services	117,970			81,690			61,350
Environmental solutions	138,722			74,726			90,343
Cooling systems	126,683			73,797			—
Engineered products	14,416			23,400			32,002
	397,791			253,613			183,695
Eliminations	(8,316		)	(6,500		)	—
	$	1,557,735		$	1,578,263		$	1,757,295

The segment information presented in the table above reflects the product line revenues that are reviewed by each segment's manager. These gross product line revenues exclude eliminations of revenues generated from sales to other segments or to other product lines within the segment. The primary component of the Power segment elimination is revenue associated with construction services.

	Year Ended December 31,
(in thousands)	2017			2016			2015
GROSS PROFIT (LOSS)
Power segment	$	191,999		$	233,550		$	247,632
Renewable segment	(128,204		)	(68,109		)	57,682
Industrial segment	41,383			50,726			54,826
Intangible amortization expense included in cost of operations	(14,272		)	(15,842		)	(7,676		)
Mark to market gain (loss) included in cost of operations	8,972			(21,208		)	(44,307		)
	99,878			179,117			308,157
Selling, general and administrative ("SG&A") expenses	(255,545		)	(240,166		)	(240,296		)
Goodwill impairment charges	(86,903		)	—			—
Restructuring activities and spin-off transaction costs	(15,447		)	(40,807		)	(14,946		)
Research and development costs	(9,412		)	(10,406		)	(16,543		)
Intangible amortization expense included in SG&A	(3,980		)	(4,081		)	(3,769		)
Mark to market gain (loss) included in SG&A	(274		)	(2,902		)	4,097
Equity in income of investees	8,326			16,440			(242		)
Impairment of equity method investment	(18,193		)	—			—
Gains (losses) on asset disposals, net	(15		)	32			(14,597		)
Operating income (loss)	$	(281,565	)	$	(102,773	)	$	21,861

	Year Ended December 31,
(in thousands)	2017		2016		2015
DEPRECIATION AND AMORTIZATION
Power segment	$	9,222	$	11,231	$	18,532
Renewable segment	3,208		2,711		2,567
Industrial segment	20,293		19,073		10,345
Segment depreciation and amortization	32,723		33,015		31,444
Corporate	7,415		6,568		3,488
Total depreciation and amortization	$	40,138	$	39,583	$	34,932

We do not separately identify or report our Company's assets by segment as the majority of our assets are shared by the Power and Renewable segments. Additionally, our chief operating decision maker does not consider assets by segment to be a critical measure by which performance is measured.

Information about our consolidated operations in different geographic areas

	Year Ended December 31,
(in thousands)	2017		2016		2015
REVENUES(1)
United States	$	757,159	$	851,955	$	1,034,653
United Kingdom	194,456		201,221		126,285
Canada	108,045		74,629		134,276
Denmark	82,843		54,722		116,064
China	54,883		33,898		41,921
Egypt	43,148		35,878		—
South Korea	41,217		44,660		4,358
Sweden	39,891		24,809		18,302
Germany	28,333		29,559		19,233
Vietnam	15,771		55,265		46,803
Dominican Republic	15,144		21,366		82,916
Saudi Arabia	13,978		2,408		4,220
South Africa	12,453		4,097		4,486
Italy	11,663		7,862		4,671
Netherlands	8,989		3,348		4,651
Finland	8,713		5,756		6,113
Bolivia	8,694		—		—
Oman	7,683		—		—
Indonesia	6,909		6,723		1,730
Nigeria	6,766		—		—
India	6,441		6,856		13,108
Aggregate of all other countries, each with less than $5 million in revenues	84,556		113,251		93,505
	$	1,557,735	$	1,578,263	$	1,757,295

⁽¹⁾ We allocate geographic revenues based on the location of the customer's operations.

	Year Ended December 31,
(in thousands)	2017		2016		2015
NET PROPERTY, PLANT AND EQUIPMENT
United States	$	79,681	$	75,368	$	88,840
Mexico	26,503		22,594		24,643
China	13,373		13,460		13,956
United Kingdom	6,604		6,337		8,070
Denmark	7,953		6,749		6,265
Aggregate of all other countries, each with less than $5 million of net property, plant and equipment	7,817		9,129		3,943
	$	141,931	$	133,637	$	145,717

	Year Ended December 31,
(in thousands)	2017		2016		2015
DEPRECIATION AND AMORTIZATION
Power segment	$	9,222	$	11,231	$	18,532
Renewable segment	3,208		2,711		2,567
Industrial segment	20,293		19,073		10,345
Segment depreciation and amortization	32,723		33,015		31,444
Corporate	7,415		6,568		3,488
Total depreciation and amortization	$	40,138	$	39,583	$	34,932

Information about our consolidated operations in different geographic areas

	Year Ended December 31,
(in thousands)	2017		2016		2015
REVENUES(1)
United States	$	757,159	$	851,955	$	1,034,653
United Kingdom	194,456		201,221		126,285
Canada	108,045		74,629		134,276
Denmark	82,843		54,722		116,064
China	54,883		33,898		41,921
Egypt	43,148		35,878		—
South Korea	41,217		44,660		4,358
Sweden	39,891		24,809		18,302
Germany	28,333		29,559		19,233
Vietnam	15,771		55,265		46,803
Dominican Republic	15,144		21,366		82,916
Saudi Arabia	13,978		2,408		4,220
South Africa	12,453		4,097		4,486
Italy	11,663		7,862		4,671
Netherlands	8,989		3,348		4,651
Finland	8,713		5,756		6,113
Bolivia	8,694		—		—
Oman	7,683		—		—
Indonesia	6,909		6,723		1,730
Nigeria	6,766		—		—
India	6,441		6,856		13,108
Aggregate of all other countries, each with less than $5 million in revenues	84,556		113,251		93,505
	$	1,557,735	$	1,578,263	$	1,757,295

	Year Ended December 31,
(in thousands)	2017			2016			2015
REVENUES
Power segment
Retrofits & continuous emissions monitoring systems	$	306,758		$	392,854		$	427,378
New build utility and environmental	155,886			292,302			403,981
Aftermarket parts and field engineering services	277,129			292,535			304,923
Industrial steam generation	123,127			107,267			219,379
Eliminations	(41,838		)	(102,980		)	(120,664		)
	821,062			981,978			1,234,997
Renewable segment
Renewable new build and services	282,228			284,684			277,326
Operations and maintenance	64,970			65,814			63,437
Eliminations	—			(1,326		)	(2,160		)
	347,198			349,172			338,603
Industrial segment
Aftermarket parts and services	117,970			81,690			61,350
Environmental solutions	138,722			74,726			90,343
Cooling systems	126,683			73,797			—
Engineered products	14,416			23,400			32,002
	397,791			253,613			183,695
Eliminations	(8,316		)	(6,500		)	—
	$	1,557,735		$	1,578,263		$	1,757,295

NOTE 4 – SEGMENT REPORTING

Our operations are assessed based on three reportable segments, which are summarized as follows:

• Power segment: focused on the supply of and aftermarket services for steam-generating, environmental and auxiliary equipment for power generation and other industrial applications.

• Renewable segment: focused on the supply of steam-generating systems, environmental and auxiliary equipment for the waste-to-energy and biomass power generation industries.

• Industrial segment: focused on custom-engineered cooling, environmental and other industrial equipment along with related aftermarket services.

An analysis of our operations by segment is as follows:

	Year Ended December 31,
(in thousands)	2017			2016			2015
REVENUES
Power segment
Retrofits & continuous emissions monitoring systems	$	306,758		$	392,854		$	427,378
New build utility and environmental	155,886			292,302			403,981
Aftermarket parts and field engineering services	277,129			292,535			304,923
Industrial steam generation	123,127			107,267			219,379
Eliminations	(41,838		)	(102,980		)	(120,664		)
	821,062			981,978			1,234,997
Renewable segment
Renewable new build and services	282,228			284,684			277,326
Operations and maintenance	64,970			65,814			63,437
Eliminations	—			(1,326		)	(2,160		)
	347,198			349,172			338,603
Industrial segment
Aftermarket parts and services	117,970			81,690			61,350
Environmental solutions	138,722			74,726			90,343
Cooling systems	126,683			73,797			—
Engineered products	14,416			23,400			32,002
	397,791			253,613			183,695
Eliminations	(8,316		)	(6,500		)	—
	$	1,557,735		$	1,578,263		$	1,757,295

The segment information presented in the table above reflects the product line revenues that are reviewed by each segment's manager. These gross product line revenues exclude eliminations of revenues generated from sales to other segments or to other product lines within the segment. The primary component of the Power segment elimination is revenue associated with construction services.

	Year Ended December 31,
(in thousands)	2017			2016			2015
GROSS PROFIT (LOSS)
Power segment	$	191,999		$	233,550		$	247,632
Renewable segment	(128,204		)	(68,109		)	57,682
Industrial segment	41,383			50,726			54,826
Intangible amortization expense included in cost of operations	(14,272		)	(15,842		)	(7,676		)
Mark to market gain (loss) included in cost of operations	8,972			(21,208		)	(44,307		)
	99,878			179,117			308,157
Selling, general and administrative ("SG&A") expenses	(255,545		)	(240,166		)	(240,296		)
Goodwill impairment charges	(86,903		)	—			—
Restructuring activities and spin-off transaction costs	(15,447		)	(40,807		)	(14,946		)
Research and development costs	(9,412		)	(10,406		)	(16,543		)
Intangible amortization expense included in SG&A	(3,980		)	(4,081		)	(3,769		)
Mark to market gain (loss) included in SG&A	(274		)	(2,902		)	4,097
Equity in income of investees	8,326			16,440			(242		)
Impairment of equity method investment	(18,193		)	—			—
Gains (losses) on asset disposals, net	(15		)	32			(14,597		)
Operating income (loss)	$	(281,565	)	$	(102,773	)	$	21,861

	Year Ended December 31,
(in thousands)	2017		2016		2015
DEPRECIATION AND AMORTIZATION
Power segment	$	9,222	$	11,231	$	18,532
Renewable segment	3,208		2,711		2,567
Industrial segment	20,293		19,073		10,345
Segment depreciation and amortization	32,723		33,015		31,444
Corporate	7,415		6,568		3,488
Total depreciation and amortization	$	40,138	$	39,583	$	34,932

We do not separately identify or report our Company's assets by segment as the majority of our assets are shared by the Power and Renewable segments. Additionally, our chief operating decision maker does not consider assets by segment to be a critical measure by which performance is measured.

Information about our consolidated operations in different geographic areas

	Year Ended December 31,
(in thousands)	2017		2016		2015
REVENUES(1)
United States	$	757,159	$	851,955	$	1,034,653
United Kingdom	194,456		201,221		126,285
Canada	108,045		74,629		134,276
Denmark	82,843		54,722		116,064
China	54,883		33,898		41,921
Egypt	43,148		35,878		—
South Korea	41,217		44,660		4,358
Sweden	39,891		24,809		18,302
Germany	28,333		29,559		19,233
Vietnam	15,771		55,265		46,803
Dominican Republic	15,144		21,366		82,916
Saudi Arabia	13,978		2,408		4,220
South Africa	12,453		4,097		4,486
Italy	11,663		7,862		4,671
Netherlands	8,989		3,348		4,651
Finland	8,713		5,756		6,113
Bolivia	8,694		—		—
Oman	7,683		—		—
Indonesia	6,909		6,723		1,730
Nigeria	6,766		—		—
India	6,441		6,856		13,108
Aggregate of all other countries, each with less than $5 million in revenues	84,556		113,251		93,505
	$	1,557,735	$	1,578,263	$	1,757,295

⁽¹⁾ We allocate geographic revenues based on the location of the customer's operations.

	Year Ended December 31,
(in thousands)	2017		2016		2015
NET PROPERTY, PLANT AND EQUIPMENT
United States	$	79,681	$	75,368	$	88,840
Mexico	26,503		22,594		24,643
China	13,373		13,460		13,956
United Kingdom	6,604		6,337		8,070
Denmark	7,953		6,749		6,265
Aggregate of all other countries, each with less than $5 million of net property, plant and equipment	7,817		9,129		3,943
	$	141,931	$	133,637	$	145,717

XML

Segment Reporting Revenue by Country (Tables)

12 Months Ended

Dec. 31, 2017

Revenue by Country [Abstract]

Segment Reporting Disclosure [Text Block]

	Year Ended December 31,
(in thousands)	2017			2016			2015
GROSS PROFIT (LOSS)
Power segment	$	191,999		$	233,550		$	247,632
Renewable segment	(128,204		)	(68,109		)	57,682
Industrial segment	41,383			50,726			54,826
Intangible amortization expense included in cost of operations	(14,272		)	(15,842		)	(7,676		)
Mark to market gain (loss) included in cost of operations	8,972			(21,208		)	(44,307		)
	99,878			179,117			308,157
Selling, general and administrative ("SG&A") expenses	(255,545		)	(240,166		)	(240,296		)
Goodwill impairment charges	(86,903		)	—			—
Restructuring activities and spin-off transaction costs	(15,447		)	(40,807		)	(14,946		)
Research and development costs	(9,412		)	(10,406		)	(16,543		)
Intangible amortization expense included in SG&A	(3,980		)	(4,081		)	(3,769		)
Mark to market gain (loss) included in SG&A	(274		)	(2,902		)	4,097
Equity in income of investees	8,326			16,440			(242		)
Impairment of equity method investment	(18,193		)	—			—
Gains (losses) on asset disposals, net	(15		)	32			(14,597		)
Operating income (loss)	$	(281,565	)	$	(102,773	)	$	21,861

SEGMENT REPORTING

Our operations are assessed based on three reportable segments, which are summarized as follows:

• Power segment: focused on the supply of and aftermarket services for steam-generating, environmental and auxiliary equipment for power generation and other industrial applications.

• Renewable segment: focused on the supply of steam-generating systems, environmental and auxiliary equipment for the waste-to-energy and biomass power generation industries.

• Industrial segment: focused on custom-engineered cooling, environmental and other industrial equipment along with related aftermarket services.

An analysis of our operations by segment is as follows:

	Year Ended December 31,
(in thousands)	2017			2016			2015
REVENUES
Power segment
Retrofits & continuous emissions monitoring systems	$	306,758		$	392,854		$	427,378
New build utility and environmental	155,886			292,302			403,981
Aftermarket parts and field engineering services	277,129			292,535			304,923
Industrial steam generation	123,127			107,267			219,379
Eliminations	(41,838		)	(102,980		)	(120,664		)
	821,062			981,978			1,234,997
Renewable segment
Renewable new build and services	282,228			284,684			277,326
Operations and maintenance	64,970			65,814			63,437
Eliminations	—			(1,326		)	(2,160		)
	347,198			349,172			338,603
Industrial segment
Aftermarket parts and services	117,970			81,690			61,350
Environmental solutions	138,722			74,726			90,343
Cooling systems	126,683			73,797			—
Engineered products	14,416			23,400			32,002
	397,791			253,613			183,695
Eliminations	(8,316		)	(6,500		)	—
	$	1,557,735		$	1,578,263		$	1,757,295

The segment information presented in the table above reflects the product line revenues that are reviewed by each segment's manager. These gross product line revenues exclude eliminations of revenues generated from sales to other segments or to other product lines within the segment. The primary component of the Power segment elimination is revenue associated with construction services.

	Year Ended December 31,
(in thousands)	2017			2016			2015
GROSS PROFIT (LOSS)
Power segment	$	191,999		$	233,550		$	247,632
Renewable segment	(128,204		)	(68,109		)	57,682
Industrial segment	41,383			50,726			54,826
Intangible amortization expense included in cost of operations	(14,272		)	(15,842		)	(7,676		)
Mark to market gain (loss) included in cost of operations	8,972			(21,208		)	(44,307		)
	99,878			179,117			308,157
Selling, general and administrative ("SG&A") expenses	(255,545		)	(240,166		)	(240,296		)
Goodwill impairment charges	(86,903		)	—			—
Restructuring activities and spin-off transaction costs	(15,447		)	(40,807		)	(14,946		)
Research and development costs	(9,412		)	(10,406		)	(16,543		)
Intangible amortization expense included in SG&A	(3,980		)	(4,081		)	(3,769		)
Mark to market gain (loss) included in SG&A	(274		)	(2,902		)	4,097
Equity in income of investees	8,326			16,440			(242		)
Impairment of equity method investment	(18,193		)	—			—
Gains (losses) on asset disposals, net	(15		)	32			(14,597		)
Operating income (loss)	$	(281,565	)	$	(102,773	)	$	21,861

	Year Ended December 31,
(in thousands)	2017		2016		2015
DEPRECIATION AND AMORTIZATION
Power segment	$	9,222	$	11,231	$	18,532
Renewable segment	3,208		2,711		2,567
Industrial segment	20,293		19,073		10,345
Segment depreciation and amortization	32,723		33,015		31,444
Corporate	7,415		6,568		3,488
Total depreciation and amortization	$	40,138	$	39,583	$	34,932

We do not separately identify or report our Company's assets by segment as the majority of our assets are shared by the Power and Renewable segments. Additionally, our chief operating decision maker does not consider assets by segment to be a critical measure by which performance is measured.

Information about our consolidated operations in different geographic areas

	Year Ended December 31,
(in thousands)	2017		2016		2015
REVENUES(1)
United States	$	757,159	$	851,955	$	1,034,653
United Kingdom	194,456		201,221		126,285
Canada	108,045		74,629		134,276
Denmark	82,843		54,722		116,064
China	54,883		33,898		41,921
Egypt	43,148		35,878		—
South Korea	41,217		44,660		4,358
Sweden	39,891		24,809		18,302
Germany	28,333		29,559		19,233
Vietnam	15,771		55,265		46,803
Dominican Republic	15,144		21,366		82,916
Saudi Arabia	13,978		2,408		4,220
South Africa	12,453		4,097		4,486
Italy	11,663		7,862		4,671
Netherlands	8,989		3,348		4,651
Finland	8,713		5,756		6,113
Bolivia	8,694		—		—
Oman	7,683		—		—
Indonesia	6,909		6,723		1,730
Nigeria	6,766		—		—
India	6,441		6,856		13,108
Aggregate of all other countries, each with less than $5 million in revenues	84,556		113,251		93,505
	$	1,557,735	$	1,578,263	$	1,757,295

⁽¹⁾ We allocate geographic revenues based on the location of the customer's operations.

	Year Ended December 31,
(in thousands)	2017		2016		2015
NET PROPERTY, PLANT AND EQUIPMENT
United States	$	79,681	$	75,368	$	88,840
Mexico	26,503		22,594		24,643
China	13,373		13,460		13,956
United Kingdom	6,604		6,337		8,070
Denmark	7,953		6,749		6,265
Aggregate of all other countries, each with less than $5 million of net property, plant and equipment	7,817		9,129		3,943
	$	141,931	$	133,637	$	145,717

	Year Ended December 31,
(in thousands)	2017		2016		2015
DEPRECIATION AND AMORTIZATION
Power segment	$	9,222	$	11,231	$	18,532
Renewable segment	3,208		2,711		2,567
Industrial segment	20,293		19,073		10,345
Segment depreciation and amortization	32,723		33,015		31,444
Corporate	7,415		6,568		3,488
Total depreciation and amortization	$	40,138	$	39,583	$	34,932

Information about our consolidated operations in different geographic areas

	Year Ended December 31,
(in thousands)	2017		2016		2015
REVENUES(1)
United States	$	757,159	$	851,955	$	1,034,653
United Kingdom	194,456		201,221		126,285
Canada	108,045		74,629		134,276
Denmark	82,843		54,722		116,064
China	54,883		33,898		41,921
Egypt	43,148		35,878		—
South Korea	41,217		44,660		4,358
Sweden	39,891		24,809		18,302
Germany	28,333		29,559		19,233
Vietnam	15,771		55,265		46,803
Dominican Republic	15,144		21,366		82,916
Saudi Arabia	13,978		2,408		4,220
South Africa	12,453		4,097		4,486
Italy	11,663		7,862		4,671
Netherlands	8,989		3,348		4,651
Finland	8,713		5,756		6,113
Bolivia	8,694		—		—
Oman	7,683		—		—
Indonesia	6,909		6,723		1,730
Nigeria	6,766		—		—
India	6,441		6,856		13,108
Aggregate of all other countries, each with less than $5 million in revenues	84,556		113,251		93,505
	$	1,557,735	$	1,578,263	$	1,757,295

	Year Ended December 31,
(in thousands)	2017			2016			2015
REVENUES
Power segment
Retrofits & continuous emissions monitoring systems	$	306,758		$	392,854		$	427,378
New build utility and environmental	155,886			292,302			403,981
Aftermarket parts and field engineering services	277,129			292,535			304,923
Industrial steam generation	123,127			107,267			219,379
Eliminations	(41,838		)	(102,980		)	(120,664		)
	821,062			981,978			1,234,997
Renewable segment
Renewable new build and services	282,228			284,684			277,326
Operations and maintenance	64,970			65,814			63,437
Eliminations	—			(1,326		)	(2,160		)
	347,198			349,172			338,603
Industrial segment
Aftermarket parts and services	117,970			81,690			61,350
Environmental solutions	138,722			74,726			90,343
Cooling systems	126,683			73,797			—
Engineered products	14,416			23,400			32,002
	397,791			253,613			183,695
Eliminations	(8,316		)	(6,500		)	—
	$	1,557,735		$	1,578,263		$	1,757,295

NOTE 4 – SEGMENT REPORTING

Our operations are assessed based on three reportable segments, which are summarized as follows:

• Power segment: focused on the supply of and aftermarket services for steam-generating, environmental and auxiliary equipment for power generation and other industrial applications.

• Renewable segment: focused on the supply of steam-generating systems, environmental and auxiliary equipment for the waste-to-energy and biomass power generation industries.

• Industrial segment: focused on custom-engineered cooling, environmental and other industrial equipment along with related aftermarket services.

An analysis of our operations by segment is as follows:

	Year Ended December 31,
(in thousands)	2017			2016			2015
REVENUES
Power segment
Retrofits & continuous emissions monitoring systems	$	306,758		$	392,854		$	427,378
New build utility and environmental	155,886			292,302			403,981
Aftermarket parts and field engineering services	277,129			292,535			304,923
Industrial steam generation	123,127			107,267			219,379
Eliminations	(41,838		)	(102,980		)	(120,664		)
	821,062			981,978			1,234,997
Renewable segment
Renewable new build and services	282,228			284,684			277,326
Operations and maintenance	64,970			65,814			63,437
Eliminations	—			(1,326		)	(2,160		)
	347,198			349,172			338,603
Industrial segment
Aftermarket parts and services	117,970			81,690			61,350
Environmental solutions	138,722			74,726			90,343
Cooling systems	126,683			73,797			—
Engineered products	14,416			23,400			32,002
	397,791			253,613			183,695
Eliminations	(8,316		)	(6,500		)	—
	$	1,557,735		$	1,578,263		$	1,757,295

The segment information presented in the table above reflects the product line revenues that are reviewed by each segment's manager. These gross product line revenues exclude eliminations of revenues generated from sales to other segments or to other product lines within the segment. The primary component of the Power segment elimination is revenue associated with construction services.

	Year Ended December 31,
(in thousands)	2017			2016			2015
GROSS PROFIT (LOSS)
Power segment	$	191,999		$	233,550		$	247,632
Renewable segment	(128,204		)	(68,109		)	57,682
Industrial segment	41,383			50,726			54,826
Intangible amortization expense included in cost of operations	(14,272		)	(15,842		)	(7,676		)
Mark to market gain (loss) included in cost of operations	8,972			(21,208		)	(44,307		)
	99,878			179,117			308,157
Selling, general and administrative ("SG&A") expenses	(255,545		)	(240,166		)	(240,296		)
Goodwill impairment charges	(86,903		)	—			—
Restructuring activities and spin-off transaction costs	(15,447		)	(40,807		)	(14,946		)
Research and development costs	(9,412		)	(10,406		)	(16,543		)
Intangible amortization expense included in SG&A	(3,980		)	(4,081		)	(3,769		)
Mark to market gain (loss) included in SG&A	(274		)	(2,902		)	4,097
Equity in income of investees	8,326			16,440			(242		)
Impairment of equity method investment	(18,193		)	—			—
Gains (losses) on asset disposals, net	(15		)	32			(14,597		)
Operating income (loss)	$	(281,565	)	$	(102,773	)	$	21,861

	Year Ended December 31,
(in thousands)	2017		2016		2015
DEPRECIATION AND AMORTIZATION
Power segment	$	9,222	$	11,231	$	18,532
Renewable segment	3,208		2,711		2,567
Industrial segment	20,293		19,073		10,345
Segment depreciation and amortization	32,723		33,015		31,444
Corporate	7,415		6,568		3,488
Total depreciation and amortization	$	40,138	$	39,583	$	34,932

We do not separately identify or report our Company's assets by segment as the majority of our assets are shared by the Power and Renewable segments. Additionally, our chief operating decision maker does not consider assets by segment to be a critical measure by which performance is measured.

Information about our consolidated operations in different geographic areas

	Year Ended December 31,
(in thousands)	2017		2016		2015
REVENUES(1)
United States	$	757,159	$	851,955	$	1,034,653
United Kingdom	194,456		201,221		126,285
Canada	108,045		74,629		134,276
Denmark	82,843		54,722		116,064
China	54,883		33,898		41,921
Egypt	43,148		35,878		—
South Korea	41,217		44,660		4,358
Sweden	39,891		24,809		18,302
Germany	28,333		29,559		19,233
Vietnam	15,771		55,265		46,803
Dominican Republic	15,144		21,366		82,916
Saudi Arabia	13,978		2,408		4,220
South Africa	12,453		4,097		4,486
Italy	11,663		7,862		4,671
Netherlands	8,989		3,348		4,651
Finland	8,713		5,756		6,113
Bolivia	8,694		—		—
Oman	7,683		—		—
Indonesia	6,909		6,723		1,730
Nigeria	6,766		—		—
India	6,441		6,856		13,108
Aggregate of all other countries, each with less than $5 million in revenues	84,556		113,251		93,505
	$	1,557,735	$	1,578,263	$	1,757,295

⁽¹⁾ We allocate geographic revenues based on the location of the customer's operations.

	Year Ended December 31,
(in thousands)	2017		2016		2015
NET PROPERTY, PLANT AND EQUIPMENT
United States	$	79,681	$	75,368	$	88,840
Mexico	26,503		22,594		24,643
China	13,373		13,460		13,956
United Kingdom	6,604		6,337		8,070
Denmark	7,953		6,749		6,265
Aggregate of all other countries, each with less than $5 million of net property, plant and equipment	7,817		9,129		3,943
	$	141,931	$	133,637	$	145,717

XML

Segment Reporting PP&E by Country (Tables)

12 Months Ended

Dec. 31, 2017

PP&E by Country [Abstract]

Segment Reporting Disclosure [Text Block]

	Year Ended December 31,
(in thousands)	2017			2016			2015
GROSS PROFIT (LOSS)
Power segment	$	191,999		$	233,550		$	247,632
Renewable segment	(128,204		)	(68,109		)	57,682
Industrial segment	41,383			50,726			54,826
Intangible amortization expense included in cost of operations	(14,272		)	(15,842		)	(7,676		)
Mark to market gain (loss) included in cost of operations	8,972			(21,208		)	(44,307		)
	99,878			179,117			308,157
Selling, general and administrative ("SG&A") expenses	(255,545		)	(240,166		)	(240,296		)
Goodwill impairment charges	(86,903		)	—			—
Restructuring activities and spin-off transaction costs	(15,447		)	(40,807		)	(14,946		)
Research and development costs	(9,412		)	(10,406		)	(16,543		)
Intangible amortization expense included in SG&A	(3,980		)	(4,081		)	(3,769		)
Mark to market gain (loss) included in SG&A	(274		)	(2,902		)	4,097
Equity in income of investees	8,326			16,440			(242		)
Impairment of equity method investment	(18,193		)	—			—
Gains (losses) on asset disposals, net	(15		)	32			(14,597		)
Operating income (loss)	$	(281,565	)	$	(102,773	)	$	21,861

SEGMENT REPORTING

Our operations are assessed based on three reportable segments, which are summarized as follows:

• Power segment: focused on the supply of and aftermarket services for steam-generating, environmental and auxiliary equipment for power generation and other industrial applications.

• Renewable segment: focused on the supply of steam-generating systems, environmental and auxiliary equipment for the waste-to-energy and biomass power generation industries.

• Industrial segment: focused on custom-engineered cooling, environmental and other industrial equipment along with related aftermarket services.

An analysis of our operations by segment is as follows:

	Year Ended December 31,
(in thousands)	2017			2016			2015
REVENUES
Power segment
Retrofits & continuous emissions monitoring systems	$	306,758		$	392,854		$	427,378
New build utility and environmental	155,886			292,302			403,981
Aftermarket parts and field engineering services	277,129			292,535			304,923
Industrial steam generation	123,127			107,267			219,379
Eliminations	(41,838		)	(102,980		)	(120,664		)
	821,062			981,978			1,234,997
Renewable segment
Renewable new build and services	282,228			284,684			277,326
Operations and maintenance	64,970			65,814			63,437
Eliminations	—			(1,326		)	(2,160		)
	347,198			349,172			338,603
Industrial segment
Aftermarket parts and services	117,970			81,690			61,350
Environmental solutions	138,722			74,726			90,343
Cooling systems	126,683			73,797			—
Engineered products	14,416			23,400			32,002
	397,791			253,613			183,695
Eliminations	(8,316		)	(6,500		)	—
	$	1,557,735		$	1,578,263		$	1,757,295

The segment information presented in the table above reflects the product line revenues that are reviewed by each segment's manager. These gross product line revenues exclude eliminations of revenues generated from sales to other segments or to other product lines within the segment. The primary component of the Power segment elimination is revenue associated with construction services.

	Year Ended December 31,
(in thousands)	2017			2016			2015
GROSS PROFIT (LOSS)
Power segment	$	191,999		$	233,550		$	247,632
Renewable segment	(128,204		)	(68,109		)	57,682
Industrial segment	41,383			50,726			54,826
Intangible amortization expense included in cost of operations	(14,272		)	(15,842		)	(7,676		)
Mark to market gain (loss) included in cost of operations	8,972			(21,208		)	(44,307		)
	99,878			179,117			308,157
Selling, general and administrative ("SG&A") expenses	(255,545		)	(240,166		)	(240,296		)
Goodwill impairment charges	(86,903		)	—			—
Restructuring activities and spin-off transaction costs	(15,447		)	(40,807		)	(14,946		)
Research and development costs	(9,412		)	(10,406		)	(16,543		)
Intangible amortization expense included in SG&A	(3,980		)	(4,081		)	(3,769		)
Mark to market gain (loss) included in SG&A	(274		)	(2,902		)	4,097
Equity in income of investees	8,326			16,440			(242		)
Impairment of equity method investment	(18,193		)	—			—
Gains (losses) on asset disposals, net	(15		)	32			(14,597		)
Operating income (loss)	$	(281,565	)	$	(102,773	)	$	21,861

	Year Ended December 31,
(in thousands)	2017		2016		2015
DEPRECIATION AND AMORTIZATION
Power segment	$	9,222	$	11,231	$	18,532
Renewable segment	3,208		2,711		2,567
Industrial segment	20,293		19,073		10,345
Segment depreciation and amortization	32,723		33,015		31,444
Corporate	7,415		6,568		3,488
Total depreciation and amortization	$	40,138	$	39,583	$	34,932

We do not separately identify or report our Company's assets by segment as the majority of our assets are shared by the Power and Renewable segments. Additionally, our chief operating decision maker does not consider assets by segment to be a critical measure by which performance is measured.

Information about our consolidated operations in different geographic areas

	Year Ended December 31,
(in thousands)	2017		2016		2015
REVENUES(1)
United States	$	757,159	$	851,955	$	1,034,653
United Kingdom	194,456		201,221		126,285
Canada	108,045		74,629		134,276
Denmark	82,843		54,722		116,064
China	54,883		33,898		41,921
Egypt	43,148		35,878		—
South Korea	41,217		44,660		4,358
Sweden	39,891		24,809		18,302
Germany	28,333		29,559		19,233
Vietnam	15,771		55,265		46,803
Dominican Republic	15,144		21,366		82,916
Saudi Arabia	13,978		2,408		4,220
South Africa	12,453		4,097		4,486
Italy	11,663		7,862		4,671
Netherlands	8,989		3,348		4,651
Finland	8,713		5,756		6,113
Bolivia	8,694		—		—
Oman	7,683		—		—
Indonesia	6,909		6,723		1,730
Nigeria	6,766		—		—
India	6,441		6,856		13,108
Aggregate of all other countries, each with less than $5 million in revenues	84,556		113,251		93,505
	$	1,557,735	$	1,578,263	$	1,757,295

⁽¹⁾ We allocate geographic revenues based on the location of the customer's operations.

	Year Ended December 31,
(in thousands)	2017		2016		2015
NET PROPERTY, PLANT AND EQUIPMENT
United States	$	79,681	$	75,368	$	88,840
Mexico	26,503		22,594		24,643
China	13,373		13,460		13,956
United Kingdom	6,604		6,337		8,070
Denmark	7,953		6,749		6,265
Aggregate of all other countries, each with less than $5 million of net property, plant and equipment	7,817		9,129		3,943
	$	141,931	$	133,637	$	145,717

	Year Ended December 31,
(in thousands)	2017		2016		2015
DEPRECIATION AND AMORTIZATION
Power segment	$	9,222	$	11,231	$	18,532
Renewable segment	3,208		2,711		2,567
Industrial segment	20,293		19,073		10,345
Segment depreciation and amortization	32,723		33,015		31,444
Corporate	7,415		6,568		3,488
Total depreciation and amortization	$	40,138	$	39,583	$	34,932

Information about our consolidated operations in different geographic areas

	Year Ended December 31,
(in thousands)	2017		2016		2015
REVENUES(1)
United States	$	757,159	$	851,955	$	1,034,653
United Kingdom	194,456		201,221		126,285
Canada	108,045		74,629		134,276
Denmark	82,843		54,722		116,064
China	54,883		33,898		41,921
Egypt	43,148		35,878		—
South Korea	41,217		44,660		4,358
Sweden	39,891		24,809		18,302
Germany	28,333		29,559		19,233
Vietnam	15,771		55,265		46,803
Dominican Republic	15,144		21,366		82,916
Saudi Arabia	13,978		2,408		4,220
South Africa	12,453		4,097		4,486
Italy	11,663		7,862		4,671
Netherlands	8,989		3,348		4,651
Finland	8,713		5,756		6,113
Bolivia	8,694		—		—
Oman	7,683		—		—
Indonesia	6,909		6,723		1,730
Nigeria	6,766		—		—
India	6,441		6,856		13,108
Aggregate of all other countries, each with less than $5 million in revenues	84,556		113,251		93,505
	$	1,557,735	$	1,578,263	$	1,757,295

	Year Ended December 31,
(in thousands)	2017			2016			2015
REVENUES
Power segment
Retrofits & continuous emissions monitoring systems	$	306,758		$	392,854		$	427,378
New build utility and environmental	155,886			292,302			403,981
Aftermarket parts and field engineering services	277,129			292,535			304,923
Industrial steam generation	123,127			107,267			219,379
Eliminations	(41,838		)	(102,980		)	(120,664		)
	821,062			981,978			1,234,997
Renewable segment
Renewable new build and services	282,228			284,684			277,326
Operations and maintenance	64,970			65,814			63,437
Eliminations	—			(1,326		)	(2,160		)
	347,198			349,172			338,603
Industrial segment
Aftermarket parts and services	117,970			81,690			61,350
Environmental solutions	138,722			74,726			90,343
Cooling systems	126,683			73,797			—
Engineered products	14,416			23,400			32,002
	397,791			253,613			183,695
Eliminations	(8,316		)	(6,500		)	—
	$	1,557,735		$	1,578,263		$	1,757,295

NOTE 4 – SEGMENT REPORTING

Our operations are assessed based on three reportable segments, which are summarized as follows:

• Power segment: focused on the supply of and aftermarket services for steam-generating, environmental and auxiliary equipment for power generation and other industrial applications.

• Renewable segment: focused on the supply of steam-generating systems, environmental and auxiliary equipment for the waste-to-energy and biomass power generation industries.

• Industrial segment: focused on custom-engineered cooling, environmental and other industrial equipment along with related aftermarket services.

An analysis of our operations by segment is as follows:

	Year Ended December 31,
(in thousands)	2017			2016			2015
REVENUES
Power segment
Retrofits & continuous emissions monitoring systems	$	306,758		$	392,854		$	427,378
New build utility and environmental	155,886			292,302			403,981
Aftermarket parts and field engineering services	277,129			292,535			304,923
Industrial steam generation	123,127			107,267			219,379
Eliminations	(41,838		)	(102,980		)	(120,664		)
	821,062			981,978			1,234,997
Renewable segment
Renewable new build and services	282,228			284,684			277,326
Operations and maintenance	64,970			65,814			63,437
Eliminations	—			(1,326		)	(2,160		)
	347,198			349,172			338,603
Industrial segment
Aftermarket parts and services	117,970			81,690			61,350
Environmental solutions	138,722			74,726			90,343
Cooling systems	126,683			73,797			—
Engineered products	14,416			23,400			32,002
	397,791			253,613			183,695
Eliminations	(8,316		)	(6,500		)	—
	$	1,557,735		$	1,578,263		$	1,757,295

The segment information presented in the table above reflects the product line revenues that are reviewed by each segment's manager. These gross product line revenues exclude eliminations of revenues generated from sales to other segments or to other product lines within the segment. The primary component of the Power segment elimination is revenue associated with construction services.

	Year Ended December 31,
(in thousands)	2017			2016			2015
GROSS PROFIT (LOSS)
Power segment	$	191,999		$	233,550		$	247,632
Renewable segment	(128,204		)	(68,109		)	57,682
Industrial segment	41,383			50,726			54,826
Intangible amortization expense included in cost of operations	(14,272		)	(15,842		)	(7,676		)
Mark to market gain (loss) included in cost of operations	8,972			(21,208		)	(44,307		)
	99,878			179,117			308,157
Selling, general and administrative ("SG&A") expenses	(255,545		)	(240,166		)	(240,296		)
Goodwill impairment charges	(86,903		)	—			—
Restructuring activities and spin-off transaction costs	(15,447		)	(40,807		)	(14,946		)
Research and development costs	(9,412		)	(10,406		)	(16,543		)
Intangible amortization expense included in SG&A	(3,980		)	(4,081		)	(3,769		)
Mark to market gain (loss) included in SG&A	(274		)	(2,902		)	4,097
Equity in income of investees	8,326			16,440			(242		)
Impairment of equity method investment	(18,193		)	—			—
Gains (losses) on asset disposals, net	(15		)	32			(14,597		)
Operating income (loss)	$	(281,565	)	$	(102,773	)	$	21,861

	Year Ended December 31,
(in thousands)	2017		2016		2015
DEPRECIATION AND AMORTIZATION
Power segment	$	9,222	$	11,231	$	18,532
Renewable segment	3,208		2,711		2,567
Industrial segment	20,293		19,073		10,345
Segment depreciation and amortization	32,723		33,015		31,444
Corporate	7,415		6,568		3,488
Total depreciation and amortization	$	40,138	$	39,583	$	34,932

We do not separately identify or report our Company's assets by segment as the majority of our assets are shared by the Power and Renewable segments. Additionally, our chief operating decision maker does not consider assets by segment to be a critical measure by which performance is measured.

Information about our consolidated operations in different geographic areas

	Year Ended December 31,
(in thousands)	2017		2016		2015
REVENUES(1)
United States	$	757,159	$	851,955	$	1,034,653
United Kingdom	194,456		201,221		126,285
Canada	108,045		74,629		134,276
Denmark	82,843		54,722		116,064
China	54,883		33,898		41,921
Egypt	43,148		35,878		—
South Korea	41,217		44,660		4,358
Sweden	39,891		24,809		18,302
Germany	28,333		29,559		19,233
Vietnam	15,771		55,265		46,803
Dominican Republic	15,144		21,366		82,916
Saudi Arabia	13,978		2,408		4,220
South Africa	12,453		4,097		4,486
Italy	11,663		7,862		4,671
Netherlands	8,989		3,348		4,651
Finland	8,713		5,756		6,113
Bolivia	8,694		—		—
Oman	7,683		—		—
Indonesia	6,909		6,723		1,730
Nigeria	6,766		—		—
India	6,441		6,856		13,108
Aggregate of all other countries, each with less than $5 million in revenues	84,556		113,251		93,505
	$	1,557,735	$	1,578,263	$	1,757,295

⁽¹⁾ We allocate geographic revenues based on the location of the customer's operations.

	Year Ended December 31,
(in thousands)	2017		2016		2015
NET PROPERTY, PLANT AND EQUIPMENT
United States	$	79,681	$	75,368	$	88,840
Mexico	26,503		22,594		24,643
China	13,373		13,460		13,956
United Kingdom	6,604		6,337		8,070
Denmark	7,953		6,749		6,265
Aggregate of all other countries, each with less than $5 million of net property, plant and equipment	7,817		9,129		3,943
	$	141,931	$	133,637	$	145,717

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Restructuring Activities and Spin Transaction Costs Restructuring liabilities (Tables)

12 Months Ended

Dec. 31, 2017

Restructuring Cost and Reserve [Line Items]

Restructuring and Related Activities Disclosure [Text Block]

Restructuring liabilities

Restructuring liabilities are included in other accrued liabilities on our consolidated balance sheets. Activity related to the restructuring liabilities is as follows:

	Year ended December 31,
(in thousands)	2017			2016
Balance at beginning of period	$	2,253		$	740
Restructuring expense	13,923			21,939
Payments	(13,857		)	(20,426		)
Balance at December 31	$	2,319		$	2,253

Restructuring liabilities are included in other accrued liabilities on our consolidated balance sheets. Activity related to the restructuring liabilities is as follows:

	Year ended December 31,
(in thousands)	2017			2016
Balance at beginning of period	$	2,253		$	740
Restructuring expense	13,923			21,939
Payments	(13,857		)	(20,426		)
Balance at December 31	$	2,319		$	2,253

Accrued restructuring liabilities at December 31, 2017 and 2016 relate primarily to employee termination benefits.

Excluded from restructuring expense in the table above are non-cash restructuring charges that did not impact the accrued restructuring liability. In the years ended December 31, 2017 and 2016, we recognized $0.3 million and $15.0 million, respectively, in non-cash restructuring expense related to losses (gains) on the disposals of long-lived assets.

Spin-off transaction costs

Spin-off costs were primarily attributable to employee retention awards directly related to the spin-off from our former parent, The Babcock & Wilcox Company (now known as BWX Technologies, Inc.). In the years ended December 31, 2017 and 2016, we recognized spin-off costs of $1.2 million and $3.8 million, respectively. During 2017, we disbursed $1.9 million of the accrued retention awards.

Spin-off transaction costs

Spin-off costs were primarily attributable to employee retention awards directly related to the spin-off from our former parent, The Babcock & Wilcox Company (now known as BWX Technologies, Inc.). In the years ended December 31, 2017 and 2016, we recognized spin-off costs of $1.2 million and $3.8 million, respectively. During 2017, we disbursed $1.9 million of the accrued retention awards.

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Restructuring Activities and Spin Transaction Costs Spin-off transaction costs (Tables)

12 Months Ended

Dec. 31, 2017

Restructuring Cost and Reserve [Line Items]

Restructuring and Related Activities Disclosure [Text Block]

Restructuring liabilities

Restructuring liabilities are included in other accrued liabilities on our consolidated balance sheets. Activity related to the restructuring liabilities is as follows:

	Year ended December 31,
(in thousands)	2017			2016
Balance at beginning of period	$	2,253		$	740
Restructuring expense	13,923			21,939
Payments	(13,857		)	(20,426		)
Balance at December 31	$	2,319		$	2,253

Restructuring liabilities are included in other accrued liabilities on our consolidated balance sheets. Activity related to the restructuring liabilities is as follows:

	Year ended December 31,
(in thousands)	2017			2016
Balance at beginning of period	$	2,253		$	740
Restructuring expense	13,923			21,939
Payments	(13,857		)	(20,426		)
Balance at December 31	$	2,319		$	2,253

Accrued restructuring liabilities at December 31, 2017 and 2016 relate primarily to employee termination benefits.

Excluded from restructuring expense in the table above are non-cash restructuring charges that did not impact the accrued restructuring liability. In the years ended December 31, 2017 and 2016, we recognized $0.3 million and $15.0 million, respectively, in non-cash restructuring expense related to losses (gains) on the disposals of long-lived assets.

Spin-off transaction costs

Spin-off costs were primarily attributable to employee retention awards directly related to the spin-off from our former parent, The Babcock & Wilcox Company (now known as BWX Technologies, Inc.). In the years ended December 31, 2017 and 2016, we recognized spin-off costs of $1.2 million and $3.8 million, respectively. During 2017, we disbursed $1.9 million of the accrued retention awards.

Spin-off transaction costs

Spin-off costs were primarily attributable to employee retention awards directly related to the spin-off from our former parent, The Babcock & Wilcox Company (now known as BWX Technologies, Inc.). In the years ended December 31, 2017 and 2016, we recognized spin-off costs of $1.2 million and $3.8 million, respectively. During 2017, we disbursed $1.9 million of the accrued retention awards.

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Contracts and Revenue Recognition Changes in Estimates in Long Term Contracts (Tables) - USD ($)
$ in Millions

12 Months Ended

Dec. 31, 2017

Dec. 31, 2016

Deferred Revenue Arrangement [Line Items]

schedule of contracts in progress and adv billings [Table Text Block]

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

	December 31,
(in thousands)	2017		2016
Included in contracts in progress:
Costs incurred less costs of revenue recognized	$	80,645	$	96,210
Revenues recognized less billings to customers	80,575		69,800
Contracts in progress	$	161,220	$	166,010
Included in advance billings on contracts:
Billings to customers less revenues recognized	$	177,953	$	199,480
Costs of revenue recognized less cost incurred	3,117		11,162
Advance billings on contracts	$	181,070	$	210,642

Schedule of Retainages on Contract [Table Text Block]

The following amounts represent retainage on contracts:

	December 31,
(in thousands)	2017		2016
Retainage expected to be collected within one year	$	14,572	$	18,843
Retainage expected to be collected after one year	6,112		4,583
Total retainage	$	20,684	$	23,426

Proceeds from Insurance Settlement, Operating Activities

$ 15

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Equity Method Investments Transactions with unconsolidated affiliates (Tables)

12 Months Ended

Dec. 31, 2017

Postemployment Benefits [Abstract]

Equity Method Investments [Table Text Block]

Our transactions with unconsolidated affiliates were as follows:

	Year Ended December 31,
(in thousands)	2017		2016		2015
Sales to	$	7,143	$	17,220	$	18,014
Purchases from	12,470		32,490		45,397
Dividends received (1)	50,134		12,160		20,830
Capital contributions (2)	—		26,256		7,424

⁽¹⁾ includes $48.1 million, $6.0 million and $18.2 million in dividends received from BWBC in 2017, 2016 and 2015, respectively, before taxes.

⁽²⁾ includes a $26.3 million contribution we made in April 2016 to increase our ownership interest in TBWES for the purpose of extinguishing the joint venture's high-interest third-party debt and avoiding the associated future interest cost (our joint venture partner contributed the same amount to TBWES).

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Equity Method Investments Condensed Balance Sheet (Tables)

12 Months Ended

Dec. 31, 2017

Postemployment Benefits [Abstract]

Condensed Balance Sheet [Table Text Block]

The undistributed earnings of our equity method investees were $7.9 million and $59.6 million at December 31, 2017 and 2016, respectively. Summarized below is consolidated balance sheet and statement of operations information for investments accounted for under the equity method:

	December 31,
(in thousands)	2017		2016
Current assets	$	322,956	$	335,577
Noncurrent assets	137,081		126,958
Total assets	460,037		462,535
Current liabilities	342,178		231,150
Noncurrent liabilities	24,474		40,537
Owners' equity	93,385		190,848
Total liabilities and equity	$	460,037	$	462,535

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Equity Method Investments Condensed Income Statement (Tables)

12 Months Ended

Dec. 31, 2017

Condensed Income Statement [Abstract]

Condensed Income Statement [Table Text Block]

	Year Ended December 31,
(in thousands)	2017			2016		2015
Revenues	$	346,459		$	488,101	$	475,459
Gross profit	32,682			76,986		69,021
Income before provision for income taxes	(10,626		)	19,529		3,072
Provision for income taxes	1,907			3,715		4,500
Net income	$	(12,533	)	$	15,814	$	(1,428	)

The following table presents selected financial information regarding the results of operations of our former NE segment through June 30, 2015, the date it was discontinued:

	Six Months Ended June 30,
(in thousands)	2015
Revenues	$	53,064
Income (loss) before income tax expense	3,358
Income tax expense (benefit)	555
Income (loss) from discontinued operations, net of tax	$	2,803

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Equity Method Investments Reconciliation of Net Income (Tables)

12 Months Ended

Dec. 31, 2017

Equity Method Investments and Joint Ventures [Abstract]

Equity Method Investment Reconciliation of Net Income to Equity in Income [Table Text Block]

Reconciliation of net income in the statement of operations of our investees to equity in income of investees in our consolidated statements of operations is as follows:

	Year Ended December 31,
(in thousands)	2017			2016		2015
Equity income based on stated ownership percentages	$	7,530		$	7,898	$	(542	)
TBWES other than temporary impairment	(18,193		)	—		—
Gain on sale of our interest in HMA	—			8,324		—
All other adjustments due to amortization of basis differences, timing of GAAP adjustments and other adjustments	796			218		300
Equity in income of investees	$	(9,867	)	$	16,440	$	(242	)

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Equity Method Investments Investments in and Advances to Affiliates (Tables)

12 Months Ended

Dec. 31, 2017

Equity Method Investments and Joint Ventures [Abstract]

Investments in and Advances to Affiliates, Schedule of Investments [Text Block]

Our transactions with unconsolidated affiliates were as follows:

	Year Ended December 31,
(in thousands)	2017		2016		2015
Sales to	$	7,143	$	17,220	$	18,014
Purchases from	12,470		32,490		45,397
Dividends received (1)	50,134		12,160		20,830
Capital contributions (2)	—		26,256		7,424

⁽¹⁾ includes $48.1 million, $6.0 million and $18.2 million in dividends received from BWBC in 2017, 2016 and 2015, respectively, before taxes.

⁽²⁾ includes a $26.3 million contribution we made in April 2016 to increase our ownership interest in TBWES for the purpose of extinguishing the joint venture's high-interest third-party debt and avoiding the associated future interest cost (our joint venture partner contributed the same amount to TBWES).

Our accounts receivable-other includes receivables from these unconsolidated affiliates of $5.8 million and $8.7 million at December 31, 2017 and 2016, respectively.

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Equity Method Investments Investments accounted for under the equity method. (Tables)

12 Months Ended

Dec. 31, 2017

Postemployment Benefits [Abstract]

Condensed Balance Sheet [Table Text Block]

The undistributed earnings of our equity method investees were $7.9 million and $59.6 million at December 31, 2017 and 2016, respectively. Summarized below is consolidated balance sheet and statement of operations information for investments accounted for under the equity method:

	December 31,
(in thousands)	2017		2016
Current assets	$	322,956	$	335,577
Noncurrent assets	137,081		126,958
Total assets	460,037		462,535
Current liabilities	342,178		231,150
Noncurrent liabilities	24,474		40,537
Owners' equity	93,385		190,848
Total liabilities and equity	$	460,037	$	462,535

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Comprehensive Income Accumulated Other Comprehensive Income (Tables)

12 Months Ended

Dec. 31, 2017

Accumulated Other Comprehensive Income (Loss) [Line Items]

Schedule of Accumulated Other Comprehensive Income (Loss) [Table Text Block]

(in thousands)	Currency translation gain (loss) (net of tax)			Net unrealized gain (loss) on investments (net of tax)			Net unrealized gain (loss) on derivative instruments (net of tax)			Net unrecognized gain (loss) related to benefit plans (net of tax)			Total
Balance at December 31, 2014	$	11,551		$	(22	)	$	(123	)	$	(1,032	)	$	10,374
Other comprehensive income (loss) before reclassifications	(19,459		)	(49		)	339			519			(18,650		)
Amounts reclassified from AOCI to net income (loss)	—			27			1,133			(195		)	965
Net transfers from Parent	(11,585		)	—			437			(394		)	(11,542		)
Net current-period other comprehensive income (loss)	(31,044		)	(22		)	1,909			(70		)	(29,227		)
Balance at December 31, 2015	$	(19,493	)	$	(44	)	$	1,786		$	(1,102	)	$	(18,853	)
Other comprehensive income (loss) before reclassifications	(24,494		)	7			2,046			7,692			(14,749		)
Amounts reclassified from AOCI to net income (loss)	—			—			(3,030		)	150			(2,880		)
Net current-period other comprehensive income (loss)	(24,494		)	7			(984		)	7,842			(17,629		)
Balance at December 31, 2016	(43,987		)	(37		)	802			6,740			(36,482		)
Other comprehensive income (loss) before reclassifications	16,150			99			3,204			(152		)	19,301
Amounts reclassified from AOCI to net income (loss)	—			(24		)	(2,269		)	(2,955		)	(5,248		)
Net current-period other comprehensive income (loss)	16,150			75			935			(3,107		)	14,053
Balance at December 31, 2017	$	(27,837	)	$	38		$	1,737		$	3,633		$	(22,429	)

The amounts reclassified out of AOCI by component and the affected consolidated statements of operations line items are as follows (in thousands):

AOCI component	Line items in the Consolidated Statements of Operations affected by reclassifications from AOCI	Year Ended December 31,
		2017			2016			2015
Derivative financial instruments	Revenues	$	10,059		$	4,624		$	546
	Cost of operations	(118		)	195			155
	Other-net	(7,438		)	(1,221		)	(24		)
	Total before tax	2,503			3,598			677
	Provision for income taxes	234			568			149
	Net income	$	2,269		$	3,030		$	528
Amortization of prior service cost on benefit obligations	Cost of operations	$	2,912		$	254		$	(1,475	)
	Provision for income taxes	(43		)	404			(1,168		)
	Net income (loss)	$	2,955		$	(150	)	$	(307	)
Realized gain on investments	Other-net	$	38		$	—		$	(42	)
	Provision for income taxes	14			—			(15		)
	Net income (loss)	$	24		$	—		$	(27	)

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INTANGIBLE ASSETS Intangible Assets (Tables)

12 Months Ended

Dec. 31, 2017

Finite-Lived Intangible Assets [Line Items]

Schedule of Intangible Assets and Goodwill [Table Text Block]

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

	Twelve months ended December 31,
(in thousands)	2017			2016
Balance at beginning of period	$	71,039		$	37,844
Business acquisitions	19,500			55,438
Amortization expense	(18,252		)	(19,923		)
Currency translation adjustments and other	4,493			(2,320		)
Balance at end of the period	$	76,780		$	71,039

Our intangible assets are as follows:

(in thousands)	December 31, 2017			December 31, 2016
Definite-lived intangible assets
Customer relationships	$	59,794		$	47,892
Unpatented technology	20,160			18,461
Patented technology	6,542			2,499
Tradename	22,951			18,774
Backlog	30,160			28,170
All other	7,611			7,430
Gross value of definite-lived intangible assets	147,218			123,226
Customer relationships amortization	(23,434		)	(17,519		)
Unpatented technology amortization	(5,013		)	(2,864		)
Patented technology amortization	(2,213		)	(1,532		)
Tradename amortization	(5,097		)	(3,826		)
Acquired backlog amortization	(28,695		)	(21,776		)
All other amortization	(7,291		)	(5,974		)
Accumulated amortization	(71,743		)	(53,491		)
Net definite-lived intangible assets	$	75,475		$	69,735
Indefinite-lived intangible assets:
Trademarks and trade names	$	1,305		$	1,305
Total indefinite-lived intangible assets	$	1,305		$	1,305

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Supplemental Cash Flow Information (Tables)

12 Months Ended

Dec. 31, 2017

Supplemental Cash Flow Information [Abstract]

Cash Flow, Supplemental Disclosures [Text Block]

During the twelve months ended December 31, 2017, 2016 and 2015, we recognized the following non-cash activity in our consolidated financial statements:

(in thousands)	2017		2016		2015
Accrued capital expenditures in accounts payable	$	1,383	$	2,751	$	568
Accreted interest expense on our second lien term loan facility	$	3,226	$	—	$	—

During the years ended December 31, 2017, 2016 and 2015 we recognized the following cash activity in our consolidated financial statements:

(in thousands)	2017			2016		2015
Income tax payments (refunds), net	$	(10,889	)	$	10,781	$	15,008
Interest payments on our United States revolving credit facility	$	4,909		$	425	$	—
Interest payments on our second lien term loan facility	$	7,044		$	—	$	—

During the years ended December 31, 2017, 2016 and 2015, interest expense in our consolidated financial statements consisted of the following components:

(in thousands)	2017		2016		2015
Components associated with borrowings from:
United States revolving credit facility	$	5,051	$	1,669	$	1,059
Second lien term loan facility	7,211		—		—
Foreign revolving credit facilities	1,021		847		148
	13,283		2,516		1,207
Components associated with amortization or accretion of:
United States revolving credit facility deferred financing fees	6,270		1,244		1,131
Second lien term loan facility deferred financing fees and discount	3,226		—		—
	9,496		1,244		1,131
Other interest expense	3,526		36		—
Total interest expense	$	26,305	$	3,796	$	2,338

In the year ended December 31, 2017, other interest expense in the table above is primarily attributable to the $3.0 million of interest expense associated with the ARPA litigation settlement (see Note 21). Interest expense included in our consolidated and combined statement of operations for the year ended December 31, 2015 has been corrected to reclassify $1.3 million of interest expense from "other - net" to "interest expense."

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Goodwill Carrying Value of Goodwill (Tables)

12 Months Ended

Dec. 31, 2017

Goodwill [Line Items]

Goodwill Disclosure [Text Block]

For the remaining four reporting units where impairment was not indicated at September 30, 2017, the goodwill balances at September 30, 2017 (and October 1, 2017) and the Step 1 goodwill impairment test headroom (the estimated fair value less the carrying value) are as follows:

	Power Segment		Industrial Segment
(in millions)	Power	Construction	MEGTEC	Universal
Reporting unit headroom	60%	98%	12%	18%
Goodwill balance	$38.5	$8.9	$104.3	$14.4

NOTE 15 – GOODWILL

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

(in thousands)	Power			Renewable			Industrial			Total
Balance at December 31, 2015	$	47,137		$	49,624		$	104,308		$	201,069
Increase resulting from SPIG acquisition	—			—			69,862			69,862
Purchase price adjustment - SPIG acquisition	—			—			2,539			2,539
Currency translation adjustments	(917		)	(1,189		)	(3,969		)	(6,075		)
Balance at December 31, 2016	46,220			48,435			172,740			267,395
Increase resulting from Universal acquisition	—			—			14,413			14,413
Impairment charges(1)	—			(49,965		)	(36,938		)	(86,903		)
Currency translation adjustments	1,150			1,530			6,813			9,493
Balance at December 31, 2017	$	47,370		$	—		$	157,028		$	204,398

⁽¹⁾ Prior to September 30, 2017, we had not recorded any goodwill impairment charges.

Our annual goodwill impairment assessment is performed on October 1 of each year (the "annual assessment" date); however, events during 2017 have required two interim assessments of all six of our reporting units. In the second quarter of 2017, significant charges in our Renewable segment were considered to be a triggering event for the interim assessment as of June 30, 2017, which did not indicate impairment. During the third quarter of 2017, our market capitalization significantly decreased to below our equity value, which was considered to be a trigger for a second interim assessment. Additionally, the forecast was reduced for our SPIG reporting unit based on a change in the market strategy implemented by the new segment management to focus on core geographies and products, which we considered to be another triggering event for an interim assessment during the third quarter of 2017. The second interim assessment as of September 30, 2017 indicated impairment for our Renewable and SPIG reporting units as described below. Our 2017 annual goodwill impairment test as of October 1, 2017 did not indicate additional impairment.

Assessing goodwill for impairment involves a two step test. Step 1 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 test is performed to measure the amount of the impairment loss, if any. Step 2 of the test compares the implied fair value of the reporting unit's goodwill with the carrying amount of that goodwill, and impairment is measured as the excess of the carrying value over the implied value of goodwill. Estimating the fair value of a reporting unit requires significant judgment. The fair value of each reporting unit determined under Step 1 of the goodwill impairment test was based on a 50% weighting of an income approach using a discounted cash flow analysis using forward-looking projections of future operating results, a 30% to 40% weighting of a market approach using multiples of revenue and earnings before interest, taxes, depreciation and amortization ("EBITDA") of guideline companies and a 20% to 10% weighting of a market approach using multiples of revenue and EBITDA from recent, similar business combinations.

We primarily attributed the significant decline in our market capitalization in the third quarter of 2017 to the announcement of significant charges in the Renewable reporting unit. Accordingly, we increased the discount rate applied to future projected cash flows from 15.0% at June 30, 2017 to 23.5% at September 30, 2017. As a result of the increase in the discount rate and an increase in the carrying value of the reporting unit, impairment was indicated at September 30, 2017, which measured $50.0 million ($48.9 million net of tax), the full carrying value. Other long-lived assets in the reporting unit were not impaired.

For our SPIG reporting unit, which is included in our Industrial segment, the Step 1 also indicated impairment at September 30, 2017. At June 30, 2017 and October 1, 2016, the fair value exceeded the carrying value by less than 1% and 5%, respectively. At September 30, 2017, the independently obtained fair value estimates decreased under both the income and market valuation approaches due to a short-term decrease in profitability attributable to specific current contracts and changes in SPIG's market strategy introduced by segment management during the third quarter. The discount rate applied to future projected cash flows was 14.0% and 12.5% at each of the September 30, 2017 and June 30, 2017 interim tests, respectively. Step 2 of the impairment test at September 30, 2017 measured $36.9 million of impairment (with no income tax impact). The SPIG reporting unit has $38.3 million of goodwill remaining after the September 30, 2017 impairment charge. Our 2017 annual goodwill impairment test as of October 1, 2017 utilized the same assumptions and inputs as the test we performed at September 30, 2017, and it did not indicate additional impairment. Other long-lived assets in the reporting unit were not impaired.

For the remaining four reporting units where impairment was not indicated at September 30, 2017, the goodwill balances at September 30, 2017 (and October 1, 2017) and the Step 1 goodwill impairment test headroom (the estimated fair value less the carrying value) are as follows:

	Power Segment		Industrial Segment
(in millions)	Power	Construction	MEGTEC	Universal
Reporting unit headroom	60%	98%	12%	18%
Goodwill balance	$38.5	$8.9	$104.3	$14.4

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

(in thousands)	Power			Renewable			Industrial			Total
Balance at December 31, 2015	$	47,137		$	49,624		$	104,308		$	201,069
Increase resulting from SPIG acquisition	—			—			69,862			69,862
Purchase price adjustment - SPIG acquisition	—			—			2,539			2,539
Currency translation adjustments	(917		)	(1,189		)	(3,969		)	(6,075		)
Balance at December 31, 2016	46,220			48,435			172,740			267,395
Increase resulting from Universal acquisition	—			—			14,413			14,413
Impairment charges(1)	—			(49,965		)	(36,938		)	(86,903		)
Currency translation adjustments	1,150			1,530			6,813			9,493
Balance at December 31, 2017	$	47,370		$	—		$	157,028		$	204,398

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Goodwill Step 1 Goodwill Results (Tables)

12 Months Ended

Dec. 31, 2017

Goodwill [Line Items]

Goodwill Disclosure [Text Block]

For the remaining four reporting units where impairment was not indicated at September 30, 2017, the goodwill balances at September 30, 2017 (and October 1, 2017) and the Step 1 goodwill impairment test headroom (the estimated fair value less the carrying value) are as follows:

	Power Segment		Industrial Segment
(in millions)	Power	Construction	MEGTEC	Universal
Reporting unit headroom	60%	98%	12%	18%
Goodwill balance	$38.5	$8.9	$104.3	$14.4

NOTE 15 – GOODWILL

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

(in thousands)	Power			Renewable			Industrial			Total
Balance at December 31, 2015	$	47,137		$	49,624		$	104,308		$	201,069
Increase resulting from SPIG acquisition	—			—			69,862			69,862
Purchase price adjustment - SPIG acquisition	—			—			2,539			2,539
Currency translation adjustments	(917		)	(1,189		)	(3,969		)	(6,075		)
Balance at December 31, 2016	46,220			48,435			172,740			267,395
Increase resulting from Universal acquisition	—			—			14,413			14,413
Impairment charges(1)	—			(49,965		)	(36,938		)	(86,903		)
Currency translation adjustments	1,150			1,530			6,813			9,493
Balance at December 31, 2017	$	47,370		$	—		$	157,028		$	204,398

⁽¹⁾ Prior to September 30, 2017, we had not recorded any goodwill impairment charges.

Our annual goodwill impairment assessment is performed on October 1 of each year (the "annual assessment" date); however, events during 2017 have required two interim assessments of all six of our reporting units. In the second quarter of 2017, significant charges in our Renewable segment were considered to be a triggering event for the interim assessment as of June 30, 2017, which did not indicate impairment. During the third quarter of 2017, our market capitalization significantly decreased to below our equity value, which was considered to be a trigger for a second interim assessment. Additionally, the forecast was reduced for our SPIG reporting unit based on a change in the market strategy implemented by the new segment management to focus on core geographies and products, which we considered to be another triggering event for an interim assessment during the third quarter of 2017. The second interim assessment as of September 30, 2017 indicated impairment for our Renewable and SPIG reporting units as described below. Our 2017 annual goodwill impairment test as of October 1, 2017 did not indicate additional impairment.

Assessing goodwill for impairment involves a two step test. Step 1 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 test is performed to measure the amount of the impairment loss, if any. Step 2 of the test compares the implied fair value of the reporting unit's goodwill with the carrying amount of that goodwill, and impairment is measured as the excess of the carrying value over the implied value of goodwill. Estimating the fair value of a reporting unit requires significant judgment. The fair value of each reporting unit determined under Step 1 of the goodwill impairment test was based on a 50% weighting of an income approach using a discounted cash flow analysis using forward-looking projections of future operating results, a 30% to 40% weighting of a market approach using multiples of revenue and earnings before interest, taxes, depreciation and amortization ("EBITDA") of guideline companies and a 20% to 10% weighting of a market approach using multiples of revenue and EBITDA from recent, similar business combinations.

We primarily attributed the significant decline in our market capitalization in the third quarter of 2017 to the announcement of significant charges in the Renewable reporting unit. Accordingly, we increased the discount rate applied to future projected cash flows from 15.0% at June 30, 2017 to 23.5% at September 30, 2017. As a result of the increase in the discount rate and an increase in the carrying value of the reporting unit, impairment was indicated at September 30, 2017, which measured $50.0 million ($48.9 million net of tax), the full carrying value. Other long-lived assets in the reporting unit were not impaired.

For our SPIG reporting unit, which is included in our Industrial segment, the Step 1 also indicated impairment at September 30, 2017. At June 30, 2017 and October 1, 2016, the fair value exceeded the carrying value by less than 1% and 5%, respectively. At September 30, 2017, the independently obtained fair value estimates decreased under both the income and market valuation approaches due to a short-term decrease in profitability attributable to specific current contracts and changes in SPIG's market strategy introduced by segment management during the third quarter. The discount rate applied to future projected cash flows was 14.0% and 12.5% at each of the September 30, 2017 and June 30, 2017 interim tests, respectively. Step 2 of the impairment test at September 30, 2017 measured $36.9 million of impairment (with no income tax impact). The SPIG reporting unit has $38.3 million of goodwill remaining after the September 30, 2017 impairment charge. Our 2017 annual goodwill impairment test as of October 1, 2017 utilized the same assumptions and inputs as the test we performed at September 30, 2017, and it did not indicate additional impairment. Other long-lived assets in the reporting unit were not impaired.

For the remaining four reporting units where impairment was not indicated at September 30, 2017, the goodwill balances at September 30, 2017 (and October 1, 2017) and the Step 1 goodwill impairment test headroom (the estimated fair value less the carrying value) are as follows:

	Power Segment		Industrial Segment
(in millions)	Power	Construction	MEGTEC	Universal
Reporting unit headroom	60%	98%	12%	18%
Goodwill balance	$38.5	$8.9	$104.3	$14.4

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

(in thousands)	Power			Renewable			Industrial			Total
Balance at December 31, 2015	$	47,137		$	49,624		$	104,308		$	201,069
Increase resulting from SPIG acquisition	—			—			69,862			69,862
Purchase price adjustment - SPIG acquisition	—			—			2,539			2,539
Currency translation adjustments	(917		)	(1,189		)	(3,969		)	(6,075		)
Balance at December 31, 2016	46,220			48,435			172,740			267,395
Increase resulting from Universal acquisition	—			—			14,413			14,413
Impairment charges(1)	—			(49,965		)	(36,938		)	(86,903		)
Currency translation adjustments	1,150			1,530			6,813			9,493
Balance at December 31, 2017	$	47,370		$	—		$	157,028		$	204,398

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Pension Plans and Postretirement Benefits Fair value of plan assets (Tables)

12 Months Ended

Dec. 31, 2017

Postemployment Benefits [Abstract]

Schedule of Changes in Fair Value of Plan Assets [Table Text Block]

Fair value of plan assets

See Note 23 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, 2017:

(in thousands)	12/31/2017		Level 1		Level 2
Fixed income	$	352,484	$	—	$	352,484
Equities	33,525		33,525		—
Commingled and mutual funds	413,166		—		413,166
United States government securities	193,249		193,249		—
Cash and accrued items	14,578		12,585		1,993
Total pension and other postretirement benefit assets	$	1,007,002	$	239,359	$	767,643

The following is a summary of total investments for our plans measured at fair value at December 31, 2016:

(in thousands)	12/31/2016		Level 1		Level 2
Fixed income	$	321,847	$	—	$	321,847
Equities	83,441		78,268		5,173
Commingled and mutual funds	349,348		4,609		344,739
United States government securities	156,599		156,599		—
Cash and accrued items	11,633		9,394		2,239
Total pension and other postretirement benefit assets	$	922,868	$	248,870	$	673,998

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Pension Plans and Postretirement Benefits Obligations and Funded Status (Tables)

12 Months Ended

Dec. 31, 2017

Postemployment Benefits [Abstract]

Changes in Projected Benefit Obligations, Fair Value of Plan Assets, and Funded Status of Plan [Table Text Block]

	Pension Benefits Year Ended December 31,						Other Postretirement Benefits  Year Ended December 31,
(in thousands)	2017			2016			2017			2016
Change in benefit obligation:
Benefit obligation at beginning of period	$	1,211,720		$	1,205,163		$	11,907		$	31,889
Service cost	789			1,680			15			23
Interest cost	41,113			40,875			319			897
Plan participants’ contributions	—			—			219			574
Curtailments	—			266			—			—
Settlements	509			1,453			—			—
Amendments	—			231			—			(10,801		)
Actuarial loss (gain)	73,403			41,957			(141		)	(7,162		)
Loss (gain) due to transfer	—			3,641			—			—
Foreign currency exchange rate changes	6,222			(5,099		)	126			50
Benefits paid	(78,954		)	(78,447		)	(1,416		)	(3,563		)
Benefit obligation at end of period	$	1,254,802		$	1,211,720		$	11,029		$	11,907
Change in plan assets:
Fair value of plan assets at beginning of period	$	922,868		$	923,030		$	—		$	—
Actual return on plan assets	149,449			76,570			—			—
Employer contribution	17,307			3,986			1,197			2,989
Plan participants' contributions	—			—			219			574
Transfers	—			2,744			—			—
Foreign currency exchange rate changes	(3,668		)	(5,015		)	—			—
Benefits paid	(78,954		)	(78,447		)	(1,416		)	(3,563		)
Fair value of plan assets at the end of period	1,007,002			922,868			—			—
Funded status	$	(247,800	)	$	(288,852	)	$	(11,029	)	$	(11,907	)
Amounts recognized in the balance sheet consist of:
Accrued employee benefits	$	(1,930	)	$	(1,099	)	$	(1,615	)	$	(1,722	)
Accumulated postretirement benefit obligation	—			—			(9,414		)	(10,185		)
Pension liability	(245,870		)	(287,753		)	—			—
Prepaid pension	—			—			—			—
Accrued benefit liability, net	$	(247,800	)	$	(288,852	)	$	(11,029	)	$	(11,907	)
Amount recognized in accumulated comprehensive income (before taxes):
Prior service cost (credit)	$	324		$	432		$	(7,792	)	$	(10,801	)
Supplemental information:
Plans with accumulated benefit obligation in excess of plan assets
Projected benefit obligation	$	1,254,802		$	1,183,345		$	—		$	—
Accumulated benefit obligation	$	1,272,010		$	1,206,056		$	11,029		$	11,907
Fair value of plan assets	$	1,007,002		$	894,105		$	—		$	—
Plans with plan assets in excess of accumulated benefit obligation
Projected benefit obligation	$	—		$	28,375		$	—		$	—
Accumulated benefit obligation	$	—		$	28,375		$	—		$	—
Fair value of plan assets	$	—		$	28,763		$	—		$	—

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Pension Plans and Postretirement Benefits Components of Net Periodic Benefit (Tables)

12 Months Ended

Dec. 31, 2017

Postemployment Benefits [Abstract]

Components of Net Periodic Benefit Cost

Components of net periodic benefit cost (benefit) included in net income (loss) are as follows:

	Pension Benefits									Other Benefits
(in thousands)	2017			2016			2015			2017			2016			2015
Service cost	$	789		$	1,680		$	13,677		$	15		$	23		$	24
Interest cost	41,113			40,875			49,501			319			897			1,143
Expected return on plan assets	(59,409		)	(61,939		)	(68,709		)	—			—			—
Amortization of prior service cost	103			250			307			(3,009		)	—			—
Recognized net actuarial loss (gain)	(8,191		)	31,932			41,574			(505		)	(7,822		)	(1,364		)
Net periodic benefit cost (benefit)	$	(25,595	)	$	12,798		$	36,350		$	(3,180	)	$	(6,902	)	$	(197	)

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Pension Plans and Postretirement Benefits Recognized Net Actuarial Loss (Tables)

12 Months Ended

Dec. 31, 2017

Postemployment Benefits [Abstract]

Pension and Other Postretirement Benefits Disclosure [Text Block]

PENSION PLANS AND OTHER POSTRETIREMENT BENEFITS

We have historically provided defined benefit retirement benefits to domestic employees under the Retirement Plan for Employees of Babcock & Wilcox Commercial Operations (the "Company Plan"), a noncontributory plan. As of 2006, the Company Plan was closed to new salaried plan entrants. Effective December 31, 2015, benefit accruals for those salaried employees covered by, and continuing to accrue service and salary adjusted benefits under the Company Plan will cease. Furthermore, beginning on January 1, 2016, we began making service-based, cash contributions to a defined contribution 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 6 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. In 2014, benefit accruals under certain hourly Canadian pension plans were ceased with an effective date of January 1, 2015. As part of the spin-off transaction, we split the Canadian defined benefit plans from BWC, which was completed in 2017. We did not present these plans as multi-employer plans because our portion was separately identifiable and we were able to assess the assets, liabilities and periodic expense in the same manner as if it were a separate plan in each period.

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. Funding provisions under the Pension Protection Act accelerate funding requirements to ensure full funding of benefits accrued.

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, and on a limited basis, to future retirees.

Obligations and funded status

	Pension Benefits Year Ended December 31,						Other Postretirement Benefits  Year Ended December 31,
(in thousands)	2017			2016			2017			2016
Change in benefit obligation:
Benefit obligation at beginning of period	$	1,211,720		$	1,205,163		$	11,907		$	31,889
Service cost	789			1,680			15			23
Interest cost	41,113			40,875			319			897
Plan participants’ contributions	—			—			219			574
Curtailments	—			266			—			—
Settlements	509			1,453			—			—
Amendments	—			231			—			(10,801		)
Actuarial loss (gain)	73,403			41,957			(141		)	(7,162		)
Loss (gain) due to transfer	—			3,641			—			—
Foreign currency exchange rate changes	6,222			(5,099		)	126			50
Benefits paid	(78,954		)	(78,447		)	(1,416		)	(3,563		)
Benefit obligation at end of period	$	1,254,802		$	1,211,720		$	11,029		$	11,907
Change in plan assets:
Fair value of plan assets at beginning of period	$	922,868		$	923,030		$	—		$	—
Actual return on plan assets	149,449			76,570			—			—
Employer contribution	17,307			3,986			1,197			2,989
Plan participants' contributions	—			—			219			574
Transfers	—			2,744			—			—
Foreign currency exchange rate changes	(3,668		)	(5,015		)	—			—
Benefits paid	(78,954		)	(78,447		)	(1,416		)	(3,563		)
Fair value of plan assets at the end of period	1,007,002			922,868			—			—
Funded status	$	(247,800	)	$	(288,852	)	$	(11,029	)	$	(11,907	)
Amounts recognized in the balance sheet consist of:
Accrued employee benefits	$	(1,930	)	$	(1,099	)	$	(1,615	)	$	(1,722	)
Accumulated postretirement benefit obligation	—			—			(9,414		)	(10,185		)
Pension liability	(245,870		)	(287,753		)	—			—
Prepaid pension	—			—			—			—
Accrued benefit liability, net	$	(247,800	)	$	(288,852	)	$	(11,029	)	$	(11,907	)
Amount recognized in accumulated comprehensive income (before taxes):
Prior service cost (credit)	$	324		$	432		$	(7,792	)	$	(10,801	)
Supplemental information:
Plans with accumulated benefit obligation in excess of plan assets
Projected benefit obligation	$	1,254,802		$	1,183,345		$	—		$	—
Accumulated benefit obligation	$	1,272,010		$	1,206,056		$	11,029		$	11,907
Fair value of plan assets	$	1,007,002		$	894,105		$	—		$	—
Plans with plan assets in excess of accumulated benefit obligation
Projected benefit obligation	$	—		$	28,375		$	—		$	—
Accumulated benefit obligation	$	—		$	28,375		$	—		$	—
Fair value of plan assets	$	—		$	28,763		$	—		$	—

Components of net periodic benefit cost (benefit) included in net income (loss) are as follows:

	Pension Benefits									Other Benefits
(in thousands)	2017			2016			2015			2017			2016			2015
Service cost	$	789		$	1,680		$	13,677		$	15		$	23		$	24
Interest cost	41,113			40,875			49,501			319			897			1,143
Expected return on plan assets	(59,409		)	(61,939		)	(68,709		)	—			—			—
Amortization of prior service cost	103			250			307			(3,009		)	—			—
Recognized net actuarial loss (gain)	(8,191		)	31,932			41,574			(505		)	(7,822		)	(1,364		)
Net periodic benefit cost (benefit)	$	(25,595	)	$	12,798		$	36,350		$	(3,180	)	$	(6,902	)	$	(197	)

During the first quarter of 2017, lump sum payments from our Canadian pension plan resulted in a plan settlement of $0.4 million, which also resulted in interim mark to market accounting for the pension plan. The mark to market adjustment in the first quarter of 2017 was $0.7 million. The effect of these charges and mark to market adjustments are reflected in the "Recognized net actuarial loss (gain)" in the table above. There were no significant plan settlements or interim mark to market adjustments after the first quarter of 2017.

We terminated the Babcock & Wilcox Retiree Medical Plan (the "Retiree OPEB plan") effective December 31, 2016. The Retiree OPEB plan was originally established to provide secondary medical insurance coverage for retirees that had reached the age of 65, up to a lifetime maximum cost. The Retiree OPEB plan had no plan assets, no accumulated other comprehensive income balance and no active participants as of the termination date. In exchange for terminating the Retiree OPEB plan, the participants had the option to enroll in a third-party health care exchange, which B&W agreed to contribute up to $750 a year for each of the next three years (beginning in 2017), provided the plan participant had not yet reached their lifetime maximum under the terminated Retiree OPEB plan. Based on the number of participants who did not enroll in the new benefit plan, we recognized a settlement gain of $7.2 million on December 31, 2016. Based on the number of participants who did enroll in the new benefit plan, we recognized a curtailment gain of $10.8 million on December 31, 2016 for the actuarially determined difference in the liability for these participants in the Retiree OPEB plan and the new plan. The settlement gain is reported in the "Recognized net actuarial loss" in the table above, and the curtailment gain was deferred in accumulated other comprehensive income and $3.0 million was recognized in 2017, and we expect to recognize the remainder during the periods of 2018 through 2020.

During 2016, we recorded adjustments to our benefit plan liabilities from pension curtailment and settlement events. Lump sum payments from our Canadian pension plan during 2016 resulted in interim pension plan settlement charges totaling $1.2 million in 2016. Also, in May 2016, the closure of our West Point, Mississippi manufacturing facility resulted in a $1.8 million curtailment charge in the Company Plan. These events also resulted in$27.5 millionin interim MTM losses for these pension plans, the effects of which are reflected in the 2016 "Recognized net actuarial loss (gain)" in the table above along with a$1.4 million loss for the annual MTM adjustment of our pension plans at December 31, 2016.

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. Total net mark to market adjustments for our pension and other postretirement benefit plans were (gains) losses of $(8.7) million, $24.1 million and $40.2 million in the years ended, December 31, 2017, 2016 and 2015, respectively. We have excluded the recognized net actuarial loss from our reportable segments and such amount has been reflected in Note 4 as the mark to market adjustment in the reconciliation of reportable segment income (loss) to consolidated operating losses. The recognized net actuarial (gain) loss was recorded in our consolidated statements of operations in the following line items:

(in thousands)	2017			2016		2015
Cost of operations	$	(8,972	)	$	21,208	$	44,307
Selling, general and administrative expenses	274			2,902		(4,097		)
Other	2			—		—
Total	$	(8,696	)	$	24,110	$	40,210

Assumptions

	Pension Benefits		Other Benefits
	2017	2016	2017	2016
Weighted average assumptions used to determine net periodic benefit obligations at December 31:
Discount rate	3.65%	4.13%	3.33%	3.66%
Rate of compensation increase	0.10%	2.40%	—	—
Weighted average assumptions used to determine net periodic benefit cost for the years ended December 31:
Discount rate	4.11%	4.25%	3.33%	3.66%
Expected return on plan assets	6.64%	6.70%	—%	—%
Rate of compensation increase	0.10%	2.40%	—%	—%

The expected rate of return on plan assets 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 asset class. These rates are then adjusted for anticipated future inflation to determine estimated nominal rates of return for each asset 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 asset classes within the total asset portfolio. We use an expected return on plan assets assumption of 6.89% for the majority of our pension plan assets (approximately 93% of our total pension assets at December 31, 2017).

	2016
Assumed health care cost trend rates at December 31
Health care cost trend rate assumed for next year	8.50	%
Rates to which the cost trend rate is assumed to decline (ultimate trend rate)	4.50	%
Year that the rate reaches ultimate trend rate	2024

During the year ended December 31, 2017, we did not utilize health care cost assumptions as a result of our termination of the Babcock & Wilcox Retiree Medical Plan (the "Retiree OPEB plan") effective December 31, 2016.

Investment goals

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 plans' 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 Company Plan, which is a domestic defined benefit plan. The assets of this plan are held by the Trustee in The Babcock & Wilcox Company Master Trust (the "Master Trust"). For the years ended December 31, 2017 and 2016, the investment return on domestic plan assets of the Master Trust (net of deductions for management fees) was approximately 17% and 9%, respectively.

The following is a summary of the asset allocations for the Master Trust at December 31, 2017 and 2016 by asset category:

	2017		2016
Asset Category:
Fixed Income (excluding United States Government Securities)	33	%	32	%
Commingled and Mutual Funds	41	%	38	%
United States Government Securities	21	%	20	%
Equity Securities	3	%	7	%
Derivatives	1	%	1	%
Other	1	%	2	%

The target asset allocation for the domestic defined benefit plan is 55% fixed income and 45% equities.

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 United Kingdom Plan").

The combined weighted average asset allocations of these plans at December 31, 2017 and 2016 by asset category were as follows:

	2017		2016
Asset Category:
Equity Securities and Commingled Mutual Funds	41	%	44	%
Fixed Income	58	%	55	%
Other	1	%	1	%

The target allocation for 2017 for the foreign plans, by asset class, is as follows:

	Canadian Plans		Diamond UK Plan
Asset Class:
United States Equity	27	%	10	%
Global Equity	23	%	12	%
Fixed Income	50	%	78	%

Fair value of plan assets

See Note 23 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, 2017:

(in thousands)	12/31/2017		Level 1		Level 2
Fixed income	$	352,484	$	—	$	352,484
Equities	33,525		33,525		—
Commingled and mutual funds	413,166		—		413,166
United States government securities	193,249		193,249		—
Cash and accrued items	14,578		12,585		1,993
Total pension and other postretirement benefit assets	$	1,007,002	$	239,359	$	767,643

The following is a summary of total investments for our plans measured at fair value at December 31, 2016:

(in thousands)	12/31/2016		Level 1		Level 2
Fixed income	$	321,847	$	—	$	321,847
Equities	83,441		78,268		5,173
Commingled and mutual funds	349,348		4,609		344,739
United States government securities	156,599		156,599		—
Cash and accrued items	11,633		9,394		2,239
Total pension and other postretirement benefit assets	$	922,868	$	248,870	$	673,998

Expected cash flows

	Domestic Plans				Foreign Plans
(in thousands)	Pension Benefits 1		Other Benefits		Pension Benefits 1		Other Benefits
Expected employer contributions to trusts of defined benefit plans:
2018	$	16,798	$	1,400	$	3,126	$	167
Expected benefit payments:
2018	$	71,881	$	1,463	$	3,003	$	167
2019	72,537		1,342		3,095		167
2020	73,104		854		3,175		169
2021	73,331		802		3,252		163
2022	73,434		746		3,318		146
2023-2027	359,308		2,975		18,576		611

¹ Pension benefit payments are made from their respective plan's trust.

Defined contribution plans

We provide benefits under The B&W Thrift Plan (the "Thrift Plan"). The Thrift Plan generally provides for matching employer contributions of 50% of participants' contributions up to 6% of compensation. These matching employer contributions are typically made in cash. 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 totaled approximately $14.4 million, $13.4 million and $8.9 million in the years ended December 31, 2017, 2016 and 2015, respectively.

We also provide benefits under the MEGTEC Union Plan, a defined contribution plan. The total employer contribution expense for the Union plan was approximately $0.2 million, $0.3 million and $0.3 million in the years ended December 31, 2017, 2016 and 2015, respectively. Matching employer contributions are made in cash.

We also provide benefits under the Universal Defined Contribution Plan (the "Universal Plan"). The total employer contribution expense for the Universal Plan was approximately $0.5 million in the year ended December 31, 2017. Matching employer contributions are made in cash.

Effective December 31, 2016, we merged the MEGTEC Non-union Plan and SPIG 401(k) defined contribution plans into the Thrift Plan. For the MEGTEC Non-union Plan, amounts charged to expense for our contributions were approximately $1.1 million and $1.1 million in the years ended December 31, 2016 and 2015, respectively. Matching employer contributions were made in cash. The SPIG 401(k) plan contributions were also made in cash, and were not material to our consolidated financial statements in 2016.

Also, our salaried Canadian employees are provided with a defined contribution plan. As of and in the periods following January 1, 2012, we made cash, service-based contributions under this arrangement. The amount charged to expense for employer contributions was approximately $0.3 million, $0.4 million and $0.1 million in the years ended December 31, 2017, 2016 and 2015, respectively.

Multi-employer plans

One of our subsidiaries in the Power segment contributes to various multi-employer plans. The plans generally provide defined benefits to substantially all unionized workers in this subsidiary. The following table summarizes our contributions to multi-employer plans for the years covered by this report:

Pension Fund	EIN/PIN	Pension Protection Act Zone Status		FIP/RP  Status Pending/ Implemented	Contributions						Surcharge Imposed	Expiration Date Of Collective Bargaining Agreement
					2017		2016		2015
		2017	2016		(in millions)
Boilermaker-Blacksmith National Pension Trust	48-6168020/ 001	Yellow	Yellow	Yes	$	7.9	$	17.8	$	20.3	No	Described Below
All Other					2.0		3.2		4.6
					$	9.9	$	21.0	$	24.9

Our collective bargaining agreements with the Boilermaker-Blacksmith National Pension Trust (the "Boilermaker Plan") is 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 Boilermaker 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.

See Note 29 for the future expected effect of FASB ASU 2017-07 on the presentation of benefit and expense related to our pension and post retirement plans.

Multi-employer plans

One of our subsidiaries in the Power segment contributes to various multi-employer plans. The plans generally provide defined benefits to substantially all unionized workers in this subsidiary. The following table summarizes our contributions to multi-employer plans for the years covered by this report:

Pension Fund	EIN/PIN	Pension Protection Act Zone Status		FIP/RP  Status Pending/ Implemented	Contributions						Surcharge Imposed	Expiration Date Of Collective Bargaining Agreement
					2017		2016		2015
		2017	2016		(in millions)
Boilermaker-Blacksmith National Pension Trust	48-6168020/ 001	Yellow	Yellow	Yes	$	7.9	$	17.8	$	20.3	No	Described Below
All Other					2.0		3.2		4.6
					$	9.9	$	21.0	$	24.9

Our collective bargaining agreements with the Boilermaker-Blacksmith National Pension Trust (the "Boilermaker Plan") is 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 Boilermaker 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.

The recognized net actuarial (gain) loss was recorded in our consolidated statements of operations in the following line items:

(in thousands)	2017			2016		2015
Cost of operations	$	(8,972	)	$	21,208	$	44,307
Selling, general and administrative expenses	274			2,902		(4,097		)
Other	2			—		—
Total	$	(8,696	)	$	24,110	$	40,210

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Pension Plans and Postretirement Benefits Health care cost trend (Tables)

12 Months Ended

Dec. 31, 2017

Postemployment Benefits [Abstract]

Schedule of Health Care Cost Trend Rates [Table Text Block]

	2016
Assumed health care cost trend rates at December 31
Health care cost trend rate assumed for next year	8.50	%
Rates to which the cost trend rate is assumed to decline (ultimate trend rate)	4.50	%
Year that the rate reaches ultimate trend rate	2024

XML

Pension Plans and Postretirement Benefits Allocation of Plan Assets (Tables)

12 Months Ended

Dec. 31, 2017

Postemployment Benefits [Abstract]

Schedule of Allocation of Plan Assets [Table Text Block]

The following is a summary of the asset allocations for the Master Trust at December 31, 2017 and 2016 by asset category:

	2017		2016
Asset Category:
Fixed Income (excluding United States Government Securities)	33	%	32	%
Commingled and Mutual Funds	41	%	38	%
United States Government Securities	21	%	20	%
Equity Securities	3	%	7	%
Derivatives	1	%	1	%
Other	1	%	2	%

The target asset allocation for the domestic defined benefit plan is 55% fixed income and 45% equities.

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 United Kingdom Plan").

The combined weighted average asset allocations of these plans at December 31, 2017 and 2016 by asset category were as follows:

	2017		2016
Asset Category:
Equity Securities and Commingled Mutual Funds	41	%	44	%
Fixed Income	58	%	55	%
Other	1	%	1	%

The target allocation for 2017 for the foreign plans, by asset class, is as follows:

	Canadian Plans		Diamond UK Plan
Asset Class:
United States Equity	27	%	10	%
Global Equity	23	%	12	%
Fixed Income	50	%	78	%

XML

Pension Plans and Postretirement Benefits Foreign Plan - Allocation of Plan Assets (Tables)

12 Months Ended

Dec. 31, 2017

Postemployment Benefits [Abstract]

Schedule of Allocation of Plan Assets [Table Text Block]

The following is a summary of the asset allocations for the Master Trust at December 31, 2017 and 2016 by asset category:

	2017		2016
Asset Category:
Fixed Income (excluding United States Government Securities)	33	%	32	%
Commingled and Mutual Funds	41	%	38	%
United States Government Securities	21	%	20	%
Equity Securities	3	%	7	%
Derivatives	1	%	1	%
Other	1	%	2	%

The target asset allocation for the domestic defined benefit plan is 55% fixed income and 45% equities.

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 United Kingdom Plan").

The combined weighted average asset allocations of these plans at December 31, 2017 and 2016 by asset category were as follows:

	2017		2016
Asset Category:
Equity Securities and Commingled Mutual Funds	41	%	44	%
Fixed Income	58	%	55	%
Other	1	%	1	%

The target allocation for 2017 for the foreign plans, by asset class, is as follows:

	Canadian Plans		Diamond UK Plan
Asset Class:
United States Equity	27	%	10	%
Global Equity	23	%	12	%
Fixed Income	50	%	78	%

XML

Pension Plans and Postretirement Benefits Cash Flows (Tables)

12 Months Ended

Dec. 31, 2017

Postemployment Benefits [Abstract]

Schedule of Defined Benefit Plans Disclosures [Table Text Block]

Expected cash flows

	Domestic Plans				Foreign Plans
(in thousands)	Pension Benefits 1		Other Benefits		Pension Benefits 1		Other Benefits
Expected employer contributions to trusts of defined benefit plans:
2018	$	16,798	$	1,400	$	3,126	$	167
Expected benefit payments:
2018	$	71,881	$	1,463	$	3,003	$	167
2019	72,537		1,342		3,095		167
2020	73,104		854		3,175		169
2021	73,331		802		3,252		163
2022	73,434		746		3,318		146
2023-2027	359,308		2,975		18,576		611

¹ Pension benefit payments are made from their respective plan's trust.

XML

Pension Plans and Postretirement Benefits Multi-Employer Plans (Tables)

12 Months Ended

Dec. 31, 2017

Multiemployer Plans [Line Items]

Pension and Other Postretirement Benefits Disclosure [Text Block]

PENSION PLANS AND OTHER POSTRETIREMENT BENEFITS

We have historically provided defined benefit retirement benefits to domestic employees under the Retirement Plan for Employees of Babcock & Wilcox Commercial Operations (the "Company Plan"), a noncontributory plan. As of 2006, the Company Plan was closed to new salaried plan entrants. Effective December 31, 2015, benefit accruals for those salaried employees covered by, and continuing to accrue service and salary adjusted benefits under the Company Plan will cease. Furthermore, beginning on January 1, 2016, we began making service-based, cash contributions to a defined contribution 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 6 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. In 2014, benefit accruals under certain hourly Canadian pension plans were ceased with an effective date of January 1, 2015. As part of the spin-off transaction, we split the Canadian defined benefit plans from BWC, which was completed in 2017. We did not present these plans as multi-employer plans because our portion was separately identifiable and we were able to assess the assets, liabilities and periodic expense in the same manner as if it were a separate plan in each period.

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. Funding provisions under the Pension Protection Act accelerate funding requirements to ensure full funding of benefits accrued.

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, and on a limited basis, to future retirees.

Obligations and funded status

	Pension Benefits Year Ended December 31,						Other Postretirement Benefits  Year Ended December 31,
(in thousands)	2017			2016			2017			2016
Change in benefit obligation:
Benefit obligation at beginning of period	$	1,211,720		$	1,205,163		$	11,907		$	31,889
Service cost	789			1,680			15			23
Interest cost	41,113			40,875			319			897
Plan participants’ contributions	—			—			219			574
Curtailments	—			266			—			—
Settlements	509			1,453			—			—
Amendments	—			231			—			(10,801		)
Actuarial loss (gain)	73,403			41,957			(141		)	(7,162		)
Loss (gain) due to transfer	—			3,641			—			—
Foreign currency exchange rate changes	6,222			(5,099		)	126			50
Benefits paid	(78,954		)	(78,447		)	(1,416		)	(3,563		)
Benefit obligation at end of period	$	1,254,802		$	1,211,720		$	11,029		$	11,907
Change in plan assets:
Fair value of plan assets at beginning of period	$	922,868		$	923,030		$	—		$	—
Actual return on plan assets	149,449			76,570			—			—
Employer contribution	17,307			3,986			1,197			2,989
Plan participants' contributions	—			—			219			574
Transfers	—			2,744			—			—
Foreign currency exchange rate changes	(3,668		)	(5,015		)	—			—
Benefits paid	(78,954		)	(78,447		)	(1,416		)	(3,563		)
Fair value of plan assets at the end of period	1,007,002			922,868			—			—
Funded status	$	(247,800	)	$	(288,852	)	$	(11,029	)	$	(11,907	)
Amounts recognized in the balance sheet consist of:
Accrued employee benefits	$	(1,930	)	$	(1,099	)	$	(1,615	)	$	(1,722	)
Accumulated postretirement benefit obligation	—			—			(9,414		)	(10,185		)
Pension liability	(245,870		)	(287,753		)	—			—
Prepaid pension	—			—			—			—
Accrued benefit liability, net	$	(247,800	)	$	(288,852	)	$	(11,029	)	$	(11,907	)
Amount recognized in accumulated comprehensive income (before taxes):
Prior service cost (credit)	$	324		$	432		$	(7,792	)	$	(10,801	)
Supplemental information:
Plans with accumulated benefit obligation in excess of plan assets
Projected benefit obligation	$	1,254,802		$	1,183,345		$	—		$	—
Accumulated benefit obligation	$	1,272,010		$	1,206,056		$	11,029		$	11,907
Fair value of plan assets	$	1,007,002		$	894,105		$	—		$	—
Plans with plan assets in excess of accumulated benefit obligation
Projected benefit obligation	$	—		$	28,375		$	—		$	—
Accumulated benefit obligation	$	—		$	28,375		$	—		$	—
Fair value of plan assets	$	—		$	28,763		$	—		$	—

Components of net periodic benefit cost (benefit) included in net income (loss) are as follows:

	Pension Benefits									Other Benefits
(in thousands)	2017			2016			2015			2017			2016			2015
Service cost	$	789		$	1,680		$	13,677		$	15		$	23		$	24
Interest cost	41,113			40,875			49,501			319			897			1,143
Expected return on plan assets	(59,409		)	(61,939		)	(68,709		)	—			—			—
Amortization of prior service cost	103			250			307			(3,009		)	—			—
Recognized net actuarial loss (gain)	(8,191		)	31,932			41,574			(505		)	(7,822		)	(1,364		)
Net periodic benefit cost (benefit)	$	(25,595	)	$	12,798		$	36,350		$	(3,180	)	$	(6,902	)	$	(197	)

During the first quarter of 2017, lump sum payments from our Canadian pension plan resulted in a plan settlement of $0.4 million, which also resulted in interim mark to market accounting for the pension plan. The mark to market adjustment in the first quarter of 2017 was $0.7 million. The effect of these charges and mark to market adjustments are reflected in the "Recognized net actuarial loss (gain)" in the table above. There were no significant plan settlements or interim mark to market adjustments after the first quarter of 2017.

We terminated the Babcock & Wilcox Retiree Medical Plan (the "Retiree OPEB plan") effective December 31, 2016. The Retiree OPEB plan was originally established to provide secondary medical insurance coverage for retirees that had reached the age of 65, up to a lifetime maximum cost. The Retiree OPEB plan had no plan assets, no accumulated other comprehensive income balance and no active participants as of the termination date. In exchange for terminating the Retiree OPEB plan, the participants had the option to enroll in a third-party health care exchange, which B&W agreed to contribute up to $750 a year for each of the next three years (beginning in 2017), provided the plan participant had not yet reached their lifetime maximum under the terminated Retiree OPEB plan. Based on the number of participants who did not enroll in the new benefit plan, we recognized a settlement gain of $7.2 million on December 31, 2016. Based on the number of participants who did enroll in the new benefit plan, we recognized a curtailment gain of $10.8 million on December 31, 2016 for the actuarially determined difference in the liability for these participants in the Retiree OPEB plan and the new plan. The settlement gain is reported in the "Recognized net actuarial loss" in the table above, and the curtailment gain was deferred in accumulated other comprehensive income and $3.0 million was recognized in 2017, and we expect to recognize the remainder during the periods of 2018 through 2020.

During 2016, we recorded adjustments to our benefit plan liabilities from pension curtailment and settlement events. Lump sum payments from our Canadian pension plan during 2016 resulted in interim pension plan settlement charges totaling $1.2 million in 2016. Also, in May 2016, the closure of our West Point, Mississippi manufacturing facility resulted in a $1.8 million curtailment charge in the Company Plan. These events also resulted in$27.5 millionin interim MTM losses for these pension plans, the effects of which are reflected in the 2016 "Recognized net actuarial loss (gain)" in the table above along with a$1.4 million loss for the annual MTM adjustment of our pension plans at December 31, 2016.

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. Total net mark to market adjustments for our pension and other postretirement benefit plans were (gains) losses of $(8.7) million, $24.1 million and $40.2 million in the years ended, December 31, 2017, 2016 and 2015, respectively. We have excluded the recognized net actuarial loss from our reportable segments and such amount has been reflected in Note 4 as the mark to market adjustment in the reconciliation of reportable segment income (loss) to consolidated operating losses. The recognized net actuarial (gain) loss was recorded in our consolidated statements of operations in the following line items:

(in thousands)	2017			2016		2015
Cost of operations	$	(8,972	)	$	21,208	$	44,307
Selling, general and administrative expenses	274			2,902		(4,097		)
Other	2			—		—
Total	$	(8,696	)	$	24,110	$	40,210

Assumptions

	Pension Benefits		Other Benefits
	2017	2016	2017	2016
Weighted average assumptions used to determine net periodic benefit obligations at December 31:
Discount rate	3.65%	4.13%	3.33%	3.66%
Rate of compensation increase	0.10%	2.40%	—	—
Weighted average assumptions used to determine net periodic benefit cost for the years ended December 31:
Discount rate	4.11%	4.25%	3.33%	3.66%
Expected return on plan assets	6.64%	6.70%	—%	—%
Rate of compensation increase	0.10%	2.40%	—%	—%

The expected rate of return on plan assets 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 asset class. These rates are then adjusted for anticipated future inflation to determine estimated nominal rates of return for each asset 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 asset classes within the total asset portfolio. We use an expected return on plan assets assumption of 6.89% for the majority of our pension plan assets (approximately 93% of our total pension assets at December 31, 2017).

	2016
Assumed health care cost trend rates at December 31
Health care cost trend rate assumed for next year	8.50	%
Rates to which the cost trend rate is assumed to decline (ultimate trend rate)	4.50	%
Year that the rate reaches ultimate trend rate	2024

During the year ended December 31, 2017, we did not utilize health care cost assumptions as a result of our termination of the Babcock & Wilcox Retiree Medical Plan (the "Retiree OPEB plan") effective December 31, 2016.

Investment goals

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 plans' 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 Company Plan, which is a domestic defined benefit plan. The assets of this plan are held by the Trustee in The Babcock & Wilcox Company Master Trust (the "Master Trust"). For the years ended December 31, 2017 and 2016, the investment return on domestic plan assets of the Master Trust (net of deductions for management fees) was approximately 17% and 9%, respectively.

The following is a summary of the asset allocations for the Master Trust at December 31, 2017 and 2016 by asset category:

	2017		2016
Asset Category:
Fixed Income (excluding United States Government Securities)	33	%	32	%
Commingled and Mutual Funds	41	%	38	%
United States Government Securities	21	%	20	%
Equity Securities	3	%	7	%
Derivatives	1	%	1	%
Other	1	%	2	%

The target asset allocation for the domestic defined benefit plan is 55% fixed income and 45% equities.

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 United Kingdom Plan").

The combined weighted average asset allocations of these plans at December 31, 2017 and 2016 by asset category were as follows:

	2017		2016
Asset Category:
Equity Securities and Commingled Mutual Funds	41	%	44	%
Fixed Income	58	%	55	%
Other	1	%	1	%

The target allocation for 2017 for the foreign plans, by asset class, is as follows:

	Canadian Plans		Diamond UK Plan
Asset Class:
United States Equity	27	%	10	%
Global Equity	23	%	12	%
Fixed Income	50	%	78	%

Fair value of plan assets

See Note 23 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, 2017:

(in thousands)	12/31/2017		Level 1		Level 2
Fixed income	$	352,484	$	—	$	352,484
Equities	33,525		33,525		—
Commingled and mutual funds	413,166		—		413,166
United States government securities	193,249		193,249		—
Cash and accrued items	14,578		12,585		1,993
Total pension and other postretirement benefit assets	$	1,007,002	$	239,359	$	767,643

The following is a summary of total investments for our plans measured at fair value at December 31, 2016:

(in thousands)	12/31/2016		Level 1		Level 2
Fixed income	$	321,847	$	—	$	321,847
Equities	83,441		78,268		5,173
Commingled and mutual funds	349,348		4,609		344,739
United States government securities	156,599		156,599		—
Cash and accrued items	11,633		9,394		2,239
Total pension and other postretirement benefit assets	$	922,868	$	248,870	$	673,998

Expected cash flows

	Domestic Plans				Foreign Plans
(in thousands)	Pension Benefits 1		Other Benefits		Pension Benefits 1		Other Benefits
Expected employer contributions to trusts of defined benefit plans:
2018	$	16,798	$	1,400	$	3,126	$	167
Expected benefit payments:
2018	$	71,881	$	1,463	$	3,003	$	167
2019	72,537		1,342		3,095		167
2020	73,104		854		3,175		169
2021	73,331		802		3,252		163
2022	73,434		746		3,318		146
2023-2027	359,308		2,975		18,576		611

¹ Pension benefit payments are made from their respective plan's trust.

Defined contribution plans

We provide benefits under The B&W Thrift Plan (the "Thrift Plan"). The Thrift Plan generally provides for matching employer contributions of 50% of participants' contributions up to 6% of compensation. These matching employer contributions are typically made in cash. 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 totaled approximately $14.4 million, $13.4 million and $8.9 million in the years ended December 31, 2017, 2016 and 2015, respectively.

We also provide benefits under the MEGTEC Union Plan, a defined contribution plan. The total employer contribution expense for the Union plan was approximately $0.2 million, $0.3 million and $0.3 million in the years ended December 31, 2017, 2016 and 2015, respectively. Matching employer contributions are made in cash.

We also provide benefits under the Universal Defined Contribution Plan (the "Universal Plan"). The total employer contribution expense for the Universal Plan was approximately $0.5 million in the year ended December 31, 2017. Matching employer contributions are made in cash.

Effective December 31, 2016, we merged the MEGTEC Non-union Plan and SPIG 401(k) defined contribution plans into the Thrift Plan. For the MEGTEC Non-union Plan, amounts charged to expense for our contributions were approximately $1.1 million and $1.1 million in the years ended December 31, 2016 and 2015, respectively. Matching employer contributions were made in cash. The SPIG 401(k) plan contributions were also made in cash, and were not material to our consolidated financial statements in 2016.

Also, our salaried Canadian employees are provided with a defined contribution plan. As of and in the periods following January 1, 2012, we made cash, service-based contributions under this arrangement. The amount charged to expense for employer contributions was approximately $0.3 million, $0.4 million and $0.1 million in the years ended December 31, 2017, 2016 and 2015, respectively.

Multi-employer plans

One of our subsidiaries in the Power segment contributes to various multi-employer plans. The plans generally provide defined benefits to substantially all unionized workers in this subsidiary. The following table summarizes our contributions to multi-employer plans for the years covered by this report:

Pension Fund	EIN/PIN	Pension Protection Act Zone Status		FIP/RP  Status Pending/ Implemented	Contributions						Surcharge Imposed	Expiration Date Of Collective Bargaining Agreement
					2017		2016		2015
		2017	2016		(in millions)
Boilermaker-Blacksmith National Pension Trust	48-6168020/ 001	Yellow	Yellow	Yes	$	7.9	$	17.8	$	20.3	No	Described Below
All Other					2.0		3.2		4.6
					$	9.9	$	21.0	$	24.9

Our collective bargaining agreements with the Boilermaker-Blacksmith National Pension Trust (the "Boilermaker Plan") is 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 Boilermaker 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.

See Note 29 for the future expected effect of FASB ASU 2017-07 on the presentation of benefit and expense related to our pension and post retirement plans.

Multi-employer plans

One of our subsidiaries in the Power segment contributes to various multi-employer plans. The plans generally provide defined benefits to substantially all unionized workers in this subsidiary. The following table summarizes our contributions to multi-employer plans for the years covered by this report:

Pension Fund	EIN/PIN	Pension Protection Act Zone Status		FIP/RP  Status Pending/ Implemented	Contributions						Surcharge Imposed	Expiration Date Of Collective Bargaining Agreement
					2017		2016		2015
		2017	2016		(in millions)
Boilermaker-Blacksmith National Pension Trust	48-6168020/ 001	Yellow	Yellow	Yes	$	7.9	$	17.8	$	20.3	No	Described Below
All Other					2.0		3.2		4.6
					$	9.9	$	21.0	$	24.9

Our collective bargaining agreements with the Boilermaker-Blacksmith National Pension Trust (the "Boilermaker Plan") is 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 Boilermaker 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.

The recognized net actuarial (gain) loss was recorded in our consolidated statements of operations in the following line items:

(in thousands)	2017			2016		2015
Cost of operations	$	(8,972	)	$	21,208	$	44,307
Selling, general and administrative expenses	274			2,902		(4,097		)
Other	2			—		—
Total	$	(8,696	)	$	24,110	$	40,210

XML

Pension Plans and Postretirement Benefits (Tables)

12 Months Ended

Dec. 31, 2017

Defined Benefit Plan Disclosure [Line Items]

Pension and Other Postretirement Benefits Disclosure [Text Block]

PENSION PLANS AND OTHER POSTRETIREMENT BENEFITS

We have historically provided defined benefit retirement benefits to domestic employees under the Retirement Plan for Employees of Babcock & Wilcox Commercial Operations (the "Company Plan"), a noncontributory plan. As of 2006, the Company Plan was closed to new salaried plan entrants. Effective December 31, 2015, benefit accruals for those salaried employees covered by, and continuing to accrue service and salary adjusted benefits under the Company Plan will cease. Furthermore, beginning on January 1, 2016, we began making service-based, cash contributions to a defined contribution 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 6 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. In 2014, benefit accruals under certain hourly Canadian pension plans were ceased with an effective date of January 1, 2015. As part of the spin-off transaction, we split the Canadian defined benefit plans from BWC, which was completed in 2017. We did not present these plans as multi-employer plans because our portion was separately identifiable and we were able to assess the assets, liabilities and periodic expense in the same manner as if it were a separate plan in each period.

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. Funding provisions under the Pension Protection Act accelerate funding requirements to ensure full funding of benefits accrued.

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, and on a limited basis, to future retirees.

Obligations and funded status

	Pension Benefits Year Ended December 31,						Other Postretirement Benefits  Year Ended December 31,
(in thousands)	2017			2016			2017			2016
Change in benefit obligation:
Benefit obligation at beginning of period	$	1,211,720		$	1,205,163		$	11,907		$	31,889
Service cost	789			1,680			15			23
Interest cost	41,113			40,875			319			897
Plan participants’ contributions	—			—			219			574
Curtailments	—			266			—			—
Settlements	509			1,453			—			—
Amendments	—			231			—			(10,801		)
Actuarial loss (gain)	73,403			41,957			(141		)	(7,162		)
Loss (gain) due to transfer	—			3,641			—			—
Foreign currency exchange rate changes	6,222			(5,099		)	126			50
Benefits paid	(78,954		)	(78,447		)	(1,416		)	(3,563		)
Benefit obligation at end of period	$	1,254,802		$	1,211,720		$	11,029		$	11,907
Change in plan assets:
Fair value of plan assets at beginning of period	$	922,868		$	923,030		$	—		$	—
Actual return on plan assets	149,449			76,570			—			—
Employer contribution	17,307			3,986			1,197			2,989
Plan participants' contributions	—			—			219			574
Transfers	—			2,744			—			—
Foreign currency exchange rate changes	(3,668		)	(5,015		)	—			—
Benefits paid	(78,954		)	(78,447		)	(1,416		)	(3,563		)
Fair value of plan assets at the end of period	1,007,002			922,868			—			—
Funded status	$	(247,800	)	$	(288,852	)	$	(11,029	)	$	(11,907	)
Amounts recognized in the balance sheet consist of:
Accrued employee benefits	$	(1,930	)	$	(1,099	)	$	(1,615	)	$	(1,722	)
Accumulated postretirement benefit obligation	—			—			(9,414		)	(10,185		)
Pension liability	(245,870		)	(287,753		)	—			—
Prepaid pension	—			—			—			—
Accrued benefit liability, net	$	(247,800	)	$	(288,852	)	$	(11,029	)	$	(11,907	)
Amount recognized in accumulated comprehensive income (before taxes):
Prior service cost (credit)	$	324		$	432		$	(7,792	)	$	(10,801	)
Supplemental information:
Plans with accumulated benefit obligation in excess of plan assets
Projected benefit obligation	$	1,254,802		$	1,183,345		$	—		$	—
Accumulated benefit obligation	$	1,272,010		$	1,206,056		$	11,029		$	11,907
Fair value of plan assets	$	1,007,002		$	894,105		$	—		$	—
Plans with plan assets in excess of accumulated benefit obligation
Projected benefit obligation	$	—		$	28,375		$	—		$	—
Accumulated benefit obligation	$	—		$	28,375		$	—		$	—
Fair value of plan assets	$	—		$	28,763		$	—		$	—

Components of net periodic benefit cost (benefit) included in net income (loss) are as follows:

	Pension Benefits									Other Benefits
(in thousands)	2017			2016			2015			2017			2016			2015
Service cost	$	789		$	1,680		$	13,677		$	15		$	23		$	24
Interest cost	41,113			40,875			49,501			319			897			1,143
Expected return on plan assets	(59,409		)	(61,939		)	(68,709		)	—			—			—
Amortization of prior service cost	103			250			307			(3,009		)	—			—
Recognized net actuarial loss (gain)	(8,191		)	31,932			41,574			(505		)	(7,822		)	(1,364		)
Net periodic benefit cost (benefit)	$	(25,595	)	$	12,798		$	36,350		$	(3,180	)	$	(6,902	)	$	(197	)

During the first quarter of 2017, lump sum payments from our Canadian pension plan resulted in a plan settlement of $0.4 million, which also resulted in interim mark to market accounting for the pension plan. The mark to market adjustment in the first quarter of 2017 was $0.7 million. The effect of these charges and mark to market adjustments are reflected in the "Recognized net actuarial loss (gain)" in the table above. There were no significant plan settlements or interim mark to market adjustments after the first quarter of 2017.

We terminated the Babcock & Wilcox Retiree Medical Plan (the "Retiree OPEB plan") effective December 31, 2016. The Retiree OPEB plan was originally established to provide secondary medical insurance coverage for retirees that had reached the age of 65, up to a lifetime maximum cost. The Retiree OPEB plan had no plan assets, no accumulated other comprehensive income balance and no active participants as of the termination date. In exchange for terminating the Retiree OPEB plan, the participants had the option to enroll in a third-party health care exchange, which B&W agreed to contribute up to $750 a year for each of the next three years (beginning in 2017), provided the plan participant had not yet reached their lifetime maximum under the terminated Retiree OPEB plan. Based on the number of participants who did not enroll in the new benefit plan, we recognized a settlement gain of $7.2 million on December 31, 2016. Based on the number of participants who did enroll in the new benefit plan, we recognized a curtailment gain of $10.8 million on December 31, 2016 for the actuarially determined difference in the liability for these participants in the Retiree OPEB plan and the new plan. The settlement gain is reported in the "Recognized net actuarial loss" in the table above, and the curtailment gain was deferred in accumulated other comprehensive income and $3.0 million was recognized in 2017, and we expect to recognize the remainder during the periods of 2018 through 2020.

During 2016, we recorded adjustments to our benefit plan liabilities from pension curtailment and settlement events. Lump sum payments from our Canadian pension plan during 2016 resulted in interim pension plan settlement charges totaling $1.2 million in 2016. Also, in May 2016, the closure of our West Point, Mississippi manufacturing facility resulted in a $1.8 million curtailment charge in the Company Plan. These events also resulted in$27.5 millionin interim MTM losses for these pension plans, the effects of which are reflected in the 2016 "Recognized net actuarial loss (gain)" in the table above along with a$1.4 million loss for the annual MTM adjustment of our pension plans at December 31, 2016.

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. Total net mark to market adjustments for our pension and other postretirement benefit plans were (gains) losses of $(8.7) million, $24.1 million and $40.2 million in the years ended, December 31, 2017, 2016 and 2015, respectively. We have excluded the recognized net actuarial loss from our reportable segments and such amount has been reflected in Note 4 as the mark to market adjustment in the reconciliation of reportable segment income (loss) to consolidated operating losses. The recognized net actuarial (gain) loss was recorded in our consolidated statements of operations in the following line items:

(in thousands)	2017			2016		2015
Cost of operations	$	(8,972	)	$	21,208	$	44,307
Selling, general and administrative expenses	274			2,902		(4,097		)
Other	2			—		—
Total	$	(8,696	)	$	24,110	$	40,210

Assumptions

	Pension Benefits		Other Benefits
	2017	2016	2017	2016
Weighted average assumptions used to determine net periodic benefit obligations at December 31:
Discount rate	3.65%	4.13%	3.33%	3.66%
Rate of compensation increase	0.10%	2.40%	—	—
Weighted average assumptions used to determine net periodic benefit cost for the years ended December 31:
Discount rate	4.11%	4.25%	3.33%	3.66%
Expected return on plan assets	6.64%	6.70%	—%	—%
Rate of compensation increase	0.10%	2.40%	—%	—%

The expected rate of return on plan assets 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 asset class. These rates are then adjusted for anticipated future inflation to determine estimated nominal rates of return for each asset 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 asset classes within the total asset portfolio. We use an expected return on plan assets assumption of 6.89% for the majority of our pension plan assets (approximately 93% of our total pension assets at December 31, 2017).

	2016
Assumed health care cost trend rates at December 31
Health care cost trend rate assumed for next year	8.50	%
Rates to which the cost trend rate is assumed to decline (ultimate trend rate)	4.50	%
Year that the rate reaches ultimate trend rate	2024

During the year ended December 31, 2017, we did not utilize health care cost assumptions as a result of our termination of the Babcock & Wilcox Retiree Medical Plan (the "Retiree OPEB plan") effective December 31, 2016.

Investment goals

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 plans' 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 Company Plan, which is a domestic defined benefit plan. The assets of this plan are held by the Trustee in The Babcock & Wilcox Company Master Trust (the "Master Trust"). For the years ended December 31, 2017 and 2016, the investment return on domestic plan assets of the Master Trust (net of deductions for management fees) was approximately 17% and 9%, respectively.

The following is a summary of the asset allocations for the Master Trust at December 31, 2017 and 2016 by asset category:

	2017		2016
Asset Category:
Fixed Income (excluding United States Government Securities)	33	%	32	%
Commingled and Mutual Funds	41	%	38	%
United States Government Securities	21	%	20	%
Equity Securities	3	%	7	%
Derivatives	1	%	1	%
Other	1	%	2	%

The target asset allocation for the domestic defined benefit plan is 55% fixed income and 45% equities.

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 United Kingdom Plan").

The combined weighted average asset allocations of these plans at December 31, 2017 and 2016 by asset category were as follows:

	2017		2016
Asset Category:
Equity Securities and Commingled Mutual Funds	41	%	44	%
Fixed Income	58	%	55	%
Other	1	%	1	%

The target allocation for 2017 for the foreign plans, by asset class, is as follows:

	Canadian Plans		Diamond UK Plan
Asset Class:
United States Equity	27	%	10	%
Global Equity	23	%	12	%
Fixed Income	50	%	78	%

Fair value of plan assets

See Note 23 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, 2017:

(in thousands)	12/31/2017		Level 1		Level 2
Fixed income	$	352,484	$	—	$	352,484
Equities	33,525		33,525		—
Commingled and mutual funds	413,166		—		413,166
United States government securities	193,249		193,249		—
Cash and accrued items	14,578		12,585		1,993
Total pension and other postretirement benefit assets	$	1,007,002	$	239,359	$	767,643

The following is a summary of total investments for our plans measured at fair value at December 31, 2016:

(in thousands)	12/31/2016		Level 1		Level 2
Fixed income	$	321,847	$	—	$	321,847
Equities	83,441		78,268		5,173
Commingled and mutual funds	349,348		4,609		344,739
United States government securities	156,599		156,599		—
Cash and accrued items	11,633		9,394		2,239
Total pension and other postretirement benefit assets	$	922,868	$	248,870	$	673,998

Expected cash flows

	Domestic Plans				Foreign Plans
(in thousands)	Pension Benefits 1		Other Benefits		Pension Benefits 1		Other Benefits
Expected employer contributions to trusts of defined benefit plans:
2018	$	16,798	$	1,400	$	3,126	$	167
Expected benefit payments:
2018	$	71,881	$	1,463	$	3,003	$	167
2019	72,537		1,342		3,095		167
2020	73,104		854		3,175		169
2021	73,331		802		3,252		163
2022	73,434		746		3,318		146
2023-2027	359,308		2,975		18,576		611

¹ Pension benefit payments are made from their respective plan's trust.

Defined contribution plans

We provide benefits under The B&W Thrift Plan (the "Thrift Plan"). The Thrift Plan generally provides for matching employer contributions of 50% of participants' contributions up to 6% of compensation. These matching employer contributions are typically made in cash. 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 totaled approximately $14.4 million, $13.4 million and $8.9 million in the years ended December 31, 2017, 2016 and 2015, respectively.

We also provide benefits under the MEGTEC Union Plan, a defined contribution plan. The total employer contribution expense for the Union plan was approximately $0.2 million, $0.3 million and $0.3 million in the years ended December 31, 2017, 2016 and 2015, respectively. Matching employer contributions are made in cash.

We also provide benefits under the Universal Defined Contribution Plan (the "Universal Plan"). The total employer contribution expense for the Universal Plan was approximately $0.5 million in the year ended December 31, 2017. Matching employer contributions are made in cash.

Effective December 31, 2016, we merged the MEGTEC Non-union Plan and SPIG 401(k) defined contribution plans into the Thrift Plan. For the MEGTEC Non-union Plan, amounts charged to expense for our contributions were approximately $1.1 million and $1.1 million in the years ended December 31, 2016 and 2015, respectively. Matching employer contributions were made in cash. The SPIG 401(k) plan contributions were also made in cash, and were not material to our consolidated financial statements in 2016.

Also, our salaried Canadian employees are provided with a defined contribution plan. As of and in the periods following January 1, 2012, we made cash, service-based contributions under this arrangement. The amount charged to expense for employer contributions was approximately $0.3 million, $0.4 million and $0.1 million in the years ended December 31, 2017, 2016 and 2015, respectively.

Multi-employer plans

One of our subsidiaries in the Power segment contributes to various multi-employer plans. The plans generally provide defined benefits to substantially all unionized workers in this subsidiary. The following table summarizes our contributions to multi-employer plans for the years covered by this report:

Pension Fund	EIN/PIN	Pension Protection Act Zone Status		FIP/RP  Status Pending/ Implemented	Contributions						Surcharge Imposed	Expiration Date Of Collective Bargaining Agreement
					2017		2016		2015
		2017	2016		(in millions)
Boilermaker-Blacksmith National Pension Trust	48-6168020/ 001	Yellow	Yellow	Yes	$	7.9	$	17.8	$	20.3	No	Described Below
All Other					2.0		3.2		4.6
					$	9.9	$	21.0	$	24.9

Our collective bargaining agreements with the Boilermaker-Blacksmith National Pension Trust (the "Boilermaker Plan") is 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 Boilermaker 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.

See Note 29 for the future expected effect of FASB ASU 2017-07 on the presentation of benefit and expense related to our pension and post retirement plans.

Multi-employer plans

One of our subsidiaries in the Power segment contributes to various multi-employer plans. The plans generally provide defined benefits to substantially all unionized workers in this subsidiary. The following table summarizes our contributions to multi-employer plans for the years covered by this report:

Pension Fund	EIN/PIN	Pension Protection Act Zone Status		FIP/RP  Status Pending/ Implemented	Contributions						Surcharge Imposed	Expiration Date Of Collective Bargaining Agreement
					2017		2016		2015
		2017	2016		(in millions)
Boilermaker-Blacksmith National Pension Trust	48-6168020/ 001	Yellow	Yellow	Yes	$	7.9	$	17.8	$	20.3	No	Described Below
All Other					2.0		3.2		4.6
					$	9.9	$	21.0	$	24.9

Our collective bargaining agreements with the Boilermaker-Blacksmith National Pension Trust (the "Boilermaker Plan") is 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 Boilermaker 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.

The recognized net actuarial (gain) loss was recorded in our consolidated statements of operations in the following line items:

(in thousands)	2017			2016		2015
Cost of operations	$	(8,972	)	$	21,208	$	44,307
Selling, general and administrative expenses	274			2,902		(4,097		)
Other	2			—		—
Total	$	(8,696	)	$	24,110	$	40,210

Components of Net Periodic Benefit Cost

Components of net periodic benefit cost (benefit) included in net income (loss) are as follows:

	Pension Benefits									Other Benefits
(in thousands)	2017			2016			2015			2017			2016			2015
Service cost	$	789		$	1,680		$	13,677		$	15		$	23		$	24
Interest cost	41,113			40,875			49,501			319			897			1,143
Expected return on plan assets	(59,409		)	(61,939		)	(68,709		)	—			—			—
Amortization of prior service cost	103			250			307			(3,009		)	—			—
Recognized net actuarial loss (gain)	(8,191		)	31,932			41,574			(505		)	(7,822		)	(1,364		)
Net periodic benefit cost (benefit)	$	(25,595	)	$	12,798		$	36,350		$	(3,180	)	$	(6,902	)	$	(197	)

XML

Pension Plans and Postretirement Benefits Assumptions (Tables)

12 Months Ended

Dec. 31, 2017

Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]

Schedule of Assumptions Used [Table Text Block]

Assumptions

	Pension Benefits		Other Benefits
	2017	2016	2017	2016
Weighted average assumptions used to determine net periodic benefit obligations at December 31:
Discount rate	3.65%	4.13%	3.33%	3.66%
Rate of compensation increase	0.10%	2.40%	—	—
Weighted average assumptions used to determine net periodic benefit cost for the years ended December 31:
Discount rate	4.11%	4.25%	3.33%	3.66%
Expected return on plan assets	6.64%	6.70%	—%	—%
Rate of compensation increase	0.10%	2.40%	—%	—%

The expected rate of return on plan assets 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 asset class. These rates are then adjusted for anticipated future inflation to determine estimated nominal rates of return for each asset 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 asset classes within the total asset portfolio. We use an expected return on plan assets assumption of 6.89% for the majority of our pension plan assets (approximately 93% of our total pension assets at December 31, 2017).

XML

Pension Plans and Postretirement Benefits Investment goals (Tables)

12 Months Ended

Dec. 31, 2017

Defined Benefit Plan Disclosure [Line Items]

Pension and Other Postretirement Benefits Disclosure [Text Block]

PENSION PLANS AND OTHER POSTRETIREMENT BENEFITS

We have historically provided defined benefit retirement benefits to domestic employees under the Retirement Plan for Employees of Babcock & Wilcox Commercial Operations (the "Company Plan"), a noncontributory plan. As of 2006, the Company Plan was closed to new salaried plan entrants. Effective December 31, 2015, benefit accruals for those salaried employees covered by, and continuing to accrue service and salary adjusted benefits under the Company Plan will cease. Furthermore, beginning on January 1, 2016, we began making service-based, cash contributions to a defined contribution 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 6 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. In 2014, benefit accruals under certain hourly Canadian pension plans were ceased with an effective date of January 1, 2015. As part of the spin-off transaction, we split the Canadian defined benefit plans from BWC, which was completed in 2017. We did not present these plans as multi-employer plans because our portion was separately identifiable and we were able to assess the assets, liabilities and periodic expense in the same manner as if it were a separate plan in each period.

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. Funding provisions under the Pension Protection Act accelerate funding requirements to ensure full funding of benefits accrued.

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, and on a limited basis, to future retirees.

Obligations and funded status

	Pension Benefits Year Ended December 31,						Other Postretirement Benefits  Year Ended December 31,
(in thousands)	2017			2016			2017			2016
Change in benefit obligation:
Benefit obligation at beginning of period	$	1,211,720		$	1,205,163		$	11,907		$	31,889
Service cost	789			1,680			15			23
Interest cost	41,113			40,875			319			897
Plan participants’ contributions	—			—			219			574
Curtailments	—			266			—			—
Settlements	509			1,453			—			—
Amendments	—			231			—			(10,801		)
Actuarial loss (gain)	73,403			41,957			(141		)	(7,162		)
Loss (gain) due to transfer	—			3,641			—			—
Foreign currency exchange rate changes	6,222			(5,099		)	126			50
Benefits paid	(78,954		)	(78,447		)	(1,416		)	(3,563		)
Benefit obligation at end of period	$	1,254,802		$	1,211,720		$	11,029		$	11,907
Change in plan assets:
Fair value of plan assets at beginning of period	$	922,868		$	923,030		$	—		$	—
Actual return on plan assets	149,449			76,570			—			—
Employer contribution	17,307			3,986			1,197			2,989
Plan participants' contributions	—			—			219			574
Transfers	—			2,744			—			—
Foreign currency exchange rate changes	(3,668		)	(5,015		)	—			—
Benefits paid	(78,954		)	(78,447		)	(1,416		)	(3,563		)
Fair value of plan assets at the end of period	1,007,002			922,868			—			—
Funded status	$	(247,800	)	$	(288,852	)	$	(11,029	)	$	(11,907	)
Amounts recognized in the balance sheet consist of:
Accrued employee benefits	$	(1,930	)	$	(1,099	)	$	(1,615	)	$	(1,722	)
Accumulated postretirement benefit obligation	—			—			(9,414		)	(10,185		)
Pension liability	(245,870		)	(287,753		)	—			—
Prepaid pension	—			—			—			—
Accrued benefit liability, net	$	(247,800	)	$	(288,852	)	$	(11,029	)	$	(11,907	)
Amount recognized in accumulated comprehensive income (before taxes):
Prior service cost (credit)	$	324		$	432		$	(7,792	)	$	(10,801	)
Supplemental information:
Plans with accumulated benefit obligation in excess of plan assets
Projected benefit obligation	$	1,254,802		$	1,183,345		$	—		$	—
Accumulated benefit obligation	$	1,272,010		$	1,206,056		$	11,029		$	11,907
Fair value of plan assets	$	1,007,002		$	894,105		$	—		$	—
Plans with plan assets in excess of accumulated benefit obligation
Projected benefit obligation	$	—		$	28,375		$	—		$	—
Accumulated benefit obligation	$	—		$	28,375		$	—		$	—
Fair value of plan assets	$	—		$	28,763		$	—		$	—

Components of net periodic benefit cost (benefit) included in net income (loss) are as follows:

	Pension Benefits									Other Benefits
(in thousands)	2017			2016			2015			2017			2016			2015
Service cost	$	789		$	1,680		$	13,677		$	15		$	23		$	24
Interest cost	41,113			40,875			49,501			319			897			1,143
Expected return on plan assets	(59,409		)	(61,939		)	(68,709		)	—			—			—
Amortization of prior service cost	103			250			307			(3,009		)	—			—
Recognized net actuarial loss (gain)	(8,191		)	31,932			41,574			(505		)	(7,822		)	(1,364		)
Net periodic benefit cost (benefit)	$	(25,595	)	$	12,798		$	36,350		$	(3,180	)	$	(6,902	)	$	(197	)

During the first quarter of 2017, lump sum payments from our Canadian pension plan resulted in a plan settlement of $0.4 million, which also resulted in interim mark to market accounting for the pension plan. The mark to market adjustment in the first quarter of 2017 was $0.7 million. The effect of these charges and mark to market adjustments are reflected in the "Recognized net actuarial loss (gain)" in the table above. There were no significant plan settlements or interim mark to market adjustments after the first quarter of 2017.

We terminated the Babcock & Wilcox Retiree Medical Plan (the "Retiree OPEB plan") effective December 31, 2016. The Retiree OPEB plan was originally established to provide secondary medical insurance coverage for retirees that had reached the age of 65, up to a lifetime maximum cost. The Retiree OPEB plan had no plan assets, no accumulated other comprehensive income balance and no active participants as of the termination date. In exchange for terminating the Retiree OPEB plan, the participants had the option to enroll in a third-party health care exchange, which B&W agreed to contribute up to $750 a year for each of the next three years (beginning in 2017), provided the plan participant had not yet reached their lifetime maximum under the terminated Retiree OPEB plan. Based on the number of participants who did not enroll in the new benefit plan, we recognized a settlement gain of $7.2 million on December 31, 2016. Based on the number of participants who did enroll in the new benefit plan, we recognized a curtailment gain of $10.8 million on December 31, 2016 for the actuarially determined difference in the liability for these participants in the Retiree OPEB plan and the new plan. The settlement gain is reported in the "Recognized net actuarial loss" in the table above, and the curtailment gain was deferred in accumulated other comprehensive income and $3.0 million was recognized in 2017, and we expect to recognize the remainder during the periods of 2018 through 2020.

During 2016, we recorded adjustments to our benefit plan liabilities from pension curtailment and settlement events. Lump sum payments from our Canadian pension plan during 2016 resulted in interim pension plan settlement charges totaling $1.2 million in 2016. Also, in May 2016, the closure of our West Point, Mississippi manufacturing facility resulted in a $1.8 million curtailment charge in the Company Plan. These events also resulted in$27.5 millionin interim MTM losses for these pension plans, the effects of which are reflected in the 2016 "Recognized net actuarial loss (gain)" in the table above along with a$1.4 million loss for the annual MTM adjustment of our pension plans at December 31, 2016.

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. Total net mark to market adjustments for our pension and other postretirement benefit plans were (gains) losses of $(8.7) million, $24.1 million and $40.2 million in the years ended, December 31, 2017, 2016 and 2015, respectively. We have excluded the recognized net actuarial loss from our reportable segments and such amount has been reflected in Note 4 as the mark to market adjustment in the reconciliation of reportable segment income (loss) to consolidated operating losses. The recognized net actuarial (gain) loss was recorded in our consolidated statements of operations in the following line items:

(in thousands)	2017			2016		2015
Cost of operations	$	(8,972	)	$	21,208	$	44,307
Selling, general and administrative expenses	274			2,902		(4,097		)
Other	2			—		—
Total	$	(8,696	)	$	24,110	$	40,210

Assumptions

	Pension Benefits		Other Benefits
	2017	2016	2017	2016
Weighted average assumptions used to determine net periodic benefit obligations at December 31:
Discount rate	3.65%	4.13%	3.33%	3.66%
Rate of compensation increase	0.10%	2.40%	—	—
Weighted average assumptions used to determine net periodic benefit cost for the years ended December 31:
Discount rate	4.11%	4.25%	3.33%	3.66%
Expected return on plan assets	6.64%	6.70%	—%	—%
Rate of compensation increase	0.10%	2.40%	—%	—%

The expected rate of return on plan assets 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 asset class. These rates are then adjusted for anticipated future inflation to determine estimated nominal rates of return for each asset 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 asset classes within the total asset portfolio. We use an expected return on plan assets assumption of 6.89% for the majority of our pension plan assets (approximately 93% of our total pension assets at December 31, 2017).

	2016
Assumed health care cost trend rates at December 31
Health care cost trend rate assumed for next year	8.50	%
Rates to which the cost trend rate is assumed to decline (ultimate trend rate)	4.50	%
Year that the rate reaches ultimate trend rate	2024

During the year ended December 31, 2017, we did not utilize health care cost assumptions as a result of our termination of the Babcock & Wilcox Retiree Medical Plan (the "Retiree OPEB plan") effective December 31, 2016.

Investment goals

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 plans' 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 Company Plan, which is a domestic defined benefit plan. The assets of this plan are held by the Trustee in The Babcock & Wilcox Company Master Trust (the "Master Trust"). For the years ended December 31, 2017 and 2016, the investment return on domestic plan assets of the Master Trust (net of deductions for management fees) was approximately 17% and 9%, respectively.

The following is a summary of the asset allocations for the Master Trust at December 31, 2017 and 2016 by asset category:

	2017		2016
Asset Category:
Fixed Income (excluding United States Government Securities)	33	%	32	%
Commingled and Mutual Funds	41	%	38	%
United States Government Securities	21	%	20	%
Equity Securities	3	%	7	%
Derivatives	1	%	1	%
Other	1	%	2	%

The target asset allocation for the domestic defined benefit plan is 55% fixed income and 45% equities.

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 United Kingdom Plan").

The combined weighted average asset allocations of these plans at December 31, 2017 and 2016 by asset category were as follows:

	2017		2016
Asset Category:
Equity Securities and Commingled Mutual Funds	41	%	44	%
Fixed Income	58	%	55	%
Other	1	%	1	%

The target allocation for 2017 for the foreign plans, by asset class, is as follows:

	Canadian Plans		Diamond UK Plan
Asset Class:
United States Equity	27	%	10	%
Global Equity	23	%	12	%
Fixed Income	50	%	78	%

Fair value of plan assets

See Note 23 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, 2017:

(in thousands)	12/31/2017		Level 1		Level 2
Fixed income	$	352,484	$	—	$	352,484
Equities	33,525		33,525		—
Commingled and mutual funds	413,166		—		413,166
United States government securities	193,249		193,249		—
Cash and accrued items	14,578		12,585		1,993
Total pension and other postretirement benefit assets	$	1,007,002	$	239,359	$	767,643

The following is a summary of total investments for our plans measured at fair value at December 31, 2016:

(in thousands)	12/31/2016		Level 1		Level 2
Fixed income	$	321,847	$	—	$	321,847
Equities	83,441		78,268		5,173
Commingled and mutual funds	349,348		4,609		344,739
United States government securities	156,599		156,599		—
Cash and accrued items	11,633		9,394		2,239
Total pension and other postretirement benefit assets	$	922,868	$	248,870	$	673,998

Expected cash flows

	Domestic Plans				Foreign Plans
(in thousands)	Pension Benefits 1		Other Benefits		Pension Benefits 1		Other Benefits
Expected employer contributions to trusts of defined benefit plans:
2018	$	16,798	$	1,400	$	3,126	$	167
Expected benefit payments:
2018	$	71,881	$	1,463	$	3,003	$	167
2019	72,537		1,342		3,095		167
2020	73,104		854		3,175		169
2021	73,331		802		3,252		163
2022	73,434		746		3,318		146
2023-2027	359,308		2,975		18,576		611

¹ Pension benefit payments are made from their respective plan's trust.

Defined contribution plans

We provide benefits under The B&W Thrift Plan (the "Thrift Plan"). The Thrift Plan generally provides for matching employer contributions of 50% of participants' contributions up to 6% of compensation. These matching employer contributions are typically made in cash. 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 totaled approximately $14.4 million, $13.4 million and $8.9 million in the years ended December 31, 2017, 2016 and 2015, respectively.

We also provide benefits under the MEGTEC Union Plan, a defined contribution plan. The total employer contribution expense for the Union plan was approximately $0.2 million, $0.3 million and $0.3 million in the years ended December 31, 2017, 2016 and 2015, respectively. Matching employer contributions are made in cash.

We also provide benefits under the Universal Defined Contribution Plan (the "Universal Plan"). The total employer contribution expense for the Universal Plan was approximately $0.5 million in the year ended December 31, 2017. Matching employer contributions are made in cash.

Effective December 31, 2016, we merged the MEGTEC Non-union Plan and SPIG 401(k) defined contribution plans into the Thrift Plan. For the MEGTEC Non-union Plan, amounts charged to expense for our contributions were approximately $1.1 million and $1.1 million in the years ended December 31, 2016 and 2015, respectively. Matching employer contributions were made in cash. The SPIG 401(k) plan contributions were also made in cash, and were not material to our consolidated financial statements in 2016.

Also, our salaried Canadian employees are provided with a defined contribution plan. As of and in the periods following January 1, 2012, we made cash, service-based contributions under this arrangement. The amount charged to expense for employer contributions was approximately $0.3 million, $0.4 million and $0.1 million in the years ended December 31, 2017, 2016 and 2015, respectively.

Multi-employer plans

One of our subsidiaries in the Power segment contributes to various multi-employer plans. The plans generally provide defined benefits to substantially all unionized workers in this subsidiary. The following table summarizes our contributions to multi-employer plans for the years covered by this report:

Pension Fund	EIN/PIN	Pension Protection Act Zone Status		FIP/RP  Status Pending/ Implemented	Contributions						Surcharge Imposed	Expiration Date Of Collective Bargaining Agreement
					2017		2016		2015
		2017	2016		(in millions)
Boilermaker-Blacksmith National Pension Trust	48-6168020/ 001	Yellow	Yellow	Yes	$	7.9	$	17.8	$	20.3	No	Described Below
All Other					2.0		3.2		4.6
					$	9.9	$	21.0	$	24.9

Our collective bargaining agreements with the Boilermaker-Blacksmith National Pension Trust (the "Boilermaker Plan") is 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 Boilermaker 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.

See Note 29 for the future expected effect of FASB ASU 2017-07 on the presentation of benefit and expense related to our pension and post retirement plans.

Multi-employer plans

One of our subsidiaries in the Power segment contributes to various multi-employer plans. The plans generally provide defined benefits to substantially all unionized workers in this subsidiary. The following table summarizes our contributions to multi-employer plans for the years covered by this report:

Pension Fund	EIN/PIN	Pension Protection Act Zone Status		FIP/RP  Status Pending/ Implemented	Contributions						Surcharge Imposed	Expiration Date Of Collective Bargaining Agreement
					2017		2016		2015
		2017	2016		(in millions)
Boilermaker-Blacksmith National Pension Trust	48-6168020/ 001	Yellow	Yellow	Yes	$	7.9	$	17.8	$	20.3	No	Described Below
All Other					2.0		3.2		4.6
					$	9.9	$	21.0	$	24.9

Our collective bargaining agreements with the Boilermaker-Blacksmith National Pension Trust (the "Boilermaker Plan") is 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 Boilermaker 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.

The recognized net actuarial (gain) loss was recorded in our consolidated statements of operations in the following line items:

(in thousands)	2017			2016		2015
Cost of operations	$	(8,972	)	$	21,208	$	44,307
Selling, general and administrative expenses	274			2,902		(4,097		)
Other	2			—		—
Total	$	(8,696	)	$	24,110	$	40,210

XML

Derivative Financial Instruments (Tables)

12 Months Ended

Dec. 31, 2017

Derivative Instruments and Hedging Activities Disclosure [Text Block]

DERIVATIVE FINANCIAL INSTRUMENTS

Our foreign currency exchange ("FX") forward contracts that qualify for hedge accounting are designated as cash flow hedges. The hedged risk is the risk of changes in functional-currency-equivalent cash flows attributable to changes in FX spot rates of forecasted transactions related to long-term contracts. We exclude from our assessment of effectiveness the portion of the fair value of the FX forward contracts attributable to the difference between FX spot rates and FX forward rates. At December 31, 2017 and 2016, we had deferred approximately $1.8 million and $0.8 million, respectively, of net gains on these derivative financial instruments in accumulated other comprehensive income ("AOCI").

At December 31, 2017, our derivative financial instruments consisted solely of FX forward contracts. The notional value of our FX forward contracts totaled $63.0 million at December 31, 2017 with maturities extending to November 2019. These instruments consist primarily of contracts to purchase or sell euros and British pounds sterling. 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 party to our United States revolving credit facility. Our hedge counterparties have the benefit of the same collateral arrangements and covenants as described under our United States revolving credit facility. During the third quarter of 2017, our hedge counterparties removed the lines of credit supporting new FX forward contracts. Subsequently, we have not entered into any new FX forward contracts.

The following tables summarize our derivative financial instruments:

	Asset and Liability Derivative
(in thousands)	December 31, 2017		December 31, 2016
Derivatives designated as hedges:
Foreign exchange contracts:
Location of FX forward contracts designated as hedges:
Accounts receivable-other	$	1,088	$	3,805
Other assets	312		665
Accounts payable	105		1,012
Other liabilities	—		213
Derivatives not designated as hedges:
Foreign exchange contracts:
Location of FX forward contracts not designated as hedges:
Accounts receivable-other	$	7	$	105
Accounts payable	1,722		403
Other liabilities	12		7

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

	Year Ended December 31,
(in thousands)	2017			2016
Derivatives designated as hedges:
Cash flow hedges
Foreign exchange contracts
Amount of gain (loss) recognized in other comprehensive income	$	3,346		2,208
Effective portion of gain (loss) reclassified from AOCI into earnings by location:
Revenues	10,059			4,624
Cost of operations	(118		)	195
Other-net	(7,438		)	(1,221		)
Portion of gain (loss) recognized in income that is excluded from effectiveness testing by location:
Other-net	(5,277		)	4,518
Derivatives not designated as hedges:
Forward contracts
Loss recognized in income by location:
Other-net	$	(3,436	)	$	(872	)

Summary of Derivative Financial Instruments

The following tables summarize our derivative financial instruments:

	Asset and Liability Derivative
(in thousands)	December 31, 2017		December 31, 2016
Derivatives designated as hedges:
Foreign exchange contracts:
Location of FX forward contracts designated as hedges:
Accounts receivable-other	$	1,088	$	3,805
Other assets	312		665
Accounts payable	105		1,012
Other liabilities	—		213
Derivatives not designated as hedges:
Foreign exchange contracts:
Location of FX forward contracts not designated as hedges:
Accounts receivable-other	$	7	$	105
Accounts payable	1,722		403
Other liabilities	12		7

Schedule of Effect of Derivative Instruments on Statements of Financial Performance

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

	Year Ended December 31,
(in thousands)	2017			2016
Derivatives designated as hedges:
Cash flow hedges
Foreign exchange contracts
Amount of gain (loss) recognized in other comprehensive income	$	3,346		2,208
Effective portion of gain (loss) reclassified from AOCI into earnings by location:
Revenues	10,059			4,624
Cost of operations	(118		)	195
Other-net	(7,438		)	(1,221		)
Portion of gain (loss) recognized in income that is excluded from effectiveness testing by location:
Other-net	(5,277		)	4,518
Derivatives not designated as hedges:
Forward contracts
Loss recognized in income by location:
Other-net	$	(3,436	)	$	(872	)

XML

Fair Value Measurements (Tables)

12 Months Ended

Dec. 31, 2017

Fair Value Disclosures [Text Block]

(in thousands)
Available-for-sale securities	December 31, 2016		Level 1		Level 2		Level 3
Commercial paper	$	6,734	$	—	$	6,734	$	—
Certificates of deposit	2,251		—		2,251		—
Mutual funds	1,152		—		1,152		—
Corporate notes and bonds	750		750		—		—
United States Government and agency securities	7,104		7,104		—		—
Total fair value of available-for-sale securities	$	17,991	$	7,854	$	10,137	$	—

FAIR VALUE MEASUREMENTS

The following tables summarize our financial assets and liabilities carried at fair value, all of which were valued from readily available prices or using inputs based upon quoted prices for similar instruments in active markets (known as "Level 1" and "Level 2" inputs, respectively, in the fair value hierarchy established by the FASB Topic Fair Value Measurements and Disclosures).

(in thousands)
Available-for-sale securities	December 31, 2017		Level 1		Level 2		Level 3
Commercial paper	$	1,895	$	—	$	1,895	$	—
Certificates of deposit	2,398		—		2,398		—
Mutual funds	1,331		—		1,331		—
Corporate notes and bonds	4,447		4,447		—		—
United States Government and agency securities	5,738		5,738		—		—
Total fair value of available-for-sale securities	$	15,809	$	10,185	$	5,624	$	—

(in thousands)
Available-for-sale securities	December 31, 2016		Level 1		Level 2		Level 3
Commercial paper	$	6,734	$	—	$	6,734	$	—
Certificates of deposit	2,251		—		2,251		—
Mutual funds	1,152		—		1,152		—
Corporate notes and bonds	750		750		—		—
United States Government and agency securities	7,104		7,104		—		—
Total fair value of available-for-sale securities	$	17,991	$	7,854	$	10,137	$	—

Derivatives	December 31, 2017			December 31, 2016
Forward contracts to purchase/sell foreign currencies	$	(432	)	$	2,940

Available-for-sale securities

We estimate the fair value of available-for-sale securities based on quoted market prices. Our investments in available-for-sale securities are presented in "other assets" on our consolidated balance sheets.

Derivatives

Derivative assets and liabilities currently consist of FX forward contracts. 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.

Other financial instruments

We used the following methods and assumptions in estimating our fair value disclosures for our other financial instruments:

• 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 and restricted cash and cash equivalents approximate their fair values due to their highly liquid nature.

• Revolving 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, 2017 and December 31, 2016.

Non-recurring fair value measurements

The purchase price allocation associated with the January 11, 2017 acquisition of Universal required significant fair value measurements using unobservable inputs ("Level 3" inputs as defined in the fair value hierarchy established by FASB Topic Fair Value Measurements and Disclosures). The fair value of the acquired intangible assets was determined using the income approach (see Note 5).

The other-than-temporary impairment of our equity method investment in TBWES (see Note 7) required significant fair value measurements using unobservable inputs. We determined the impairment charge by first determining an estimate of the price that could be received to sell the assets and transfer the liabilities held by TBWES in an orderly transaction between market participants at June 30, 2017. The fair value of TBWES's net assets was determined through a combination of the cost approach, a market approach and an income approach.

Our interim goodwill impairment tests and third quarter impairment charges required significant fair value measurements using unobservable inputs (see Note 15). The fair value of each reporting unit determined under Step 1 of the goodwill impairment test was based on an income approach using a discounted cash flow analysis, a market approach using multiples of revenue and EBITDA of guideline companies, and a market approach using multiples of revenue and EBITDA from recent, similar business combinations. The fair value of the assets and liabilities for the Renewable and SPIG reporting units determined under Step 2 of the goodwill impairment test were based on either an income or market approach.

The measurement of the net actuarial gain or loss associated with our pension and other postretirement plans was determined using unobservable inputs (see Note 18). These inputs included the estimated discount rate, expected return on plan assets and other actuarial inputs associated with the plan participants.

The determination of the estimated fair value of the related party share repurchase required significant fair value measurements using unobservable inputs (see Note 20). We utilized a discounted cash flow model and estimates of our weighted average cost of capital on the transaction date to derive the estimated fair value of the share repurchase.

Derivatives	December 31, 2017			December 31, 2016
Forward contracts to purchase/sell foreign currencies	$	(432	)	$	2,940

The following tables summarize our financial assets and liabilities carried at fair value, all of which were valued from readily available prices or using inputs based upon quoted prices for similar instruments in active markets (known as "Level 1" and "Level 2" inputs, respectively, in the fair value hierarchy established by the FASB Topic Fair Value Measurements and Disclosures).

(in thousands)
Available-for-sale securities	December 31, 2017		Level 1		Level 2		Level 3
Commercial paper	$	1,895	$	—	$	1,895	$	—
Certificates of deposit	2,398		—		2,398		—
Mutual funds	1,331		—		1,331		—
Corporate notes and bonds	4,447		4,447		—		—
United States Government and agency securities	5,738		5,738		—		—
Total fair value of available-for-sale securities	$	15,809	$	10,185	$	5,624	$	—

Summary of Available-for-Sale Securities Measured at Fair Value

The following tables summarize our financial assets and liabilities carried at fair value, all of which were valued from readily available prices or using inputs based upon quoted prices for similar instruments in active markets (known as "Level 1" and "Level 2" inputs, respectively, in the fair value hierarchy established by the FASB Topic Fair Value Measurements and Disclosures).

(in thousands)
Available-for-sale securities	December 31, 2017		Level 1		Level 2		Level 3
Commercial paper	$	1,895	$	—	$	1,895	$	—
Certificates of deposit	2,398		—		2,398		—
Mutual funds	1,331		—		1,331		—
Corporate notes and bonds	4,447		4,447		—		—
United States Government and agency securities	5,738		5,738		—		—
Total fair value of available-for-sale securities	$	15,809	$	10,185	$	5,624	$	—

(in thousands)
Available-for-sale securities	December 31, 2016		Level 1		Level 2		Level 3
Commercial paper	$	6,734	$	—	$	6,734	$	—
Certificates of deposit	2,251		—		2,251		—
Mutual funds	1,152		—		1,152		—
Corporate notes and bonds	750		750		—		—
United States Government and agency securities	7,104		7,104		—		—
Total fair value of available-for-sale securities	$	17,991	$	7,854	$	10,137	$	—

Derivatives	December 31, 2017			December 31, 2016
Forward contracts to purchase/sell foreign currencies	$	(432	)	$	2,940

Available-for-sale securities

We estimate the fair value of available-for-sale securities based on quoted market prices. Our investments in available-for-sale securities are presented in "other assets" on our consolidated balance sheets.

Derivatives

Derivative assets and liabilities currently consist of FX forward contracts. 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.

Other financial instruments

We used the following methods and assumptions in estimating our fair value disclosures for our other financial instruments:

• 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 and restricted cash and cash equivalents approximate their fair values due to their highly liquid nature.

• Revolving 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, 2017 and December 31, 2016.

Non-recurring fair value measurements

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Revolving Debt (Tables)

12 Months Ended

Dec. 31, 2017

Debt Instrument [Line Items]

Long-term Debt [Text Block]

The components of our revolving debt are comprised of separate revolving credit facilities in the following locations:

(in thousands)	December 31, 2017		December 31, 2016
United States	$	94,300	$	9,800
Foreign	9,173		14,241
Total revolving debt	$	103,473	$	24,041

United States revolving credit facility

On May 11, 2015, we entered into a credit agreement with a syndicate of lenders ("Credit Agreement") in connection with our spin-off from The Babcock & Wilcox Company. The Credit Agreement, which is scheduled to mature on June 30, 2020, provides for a senior secured revolving credit facility, initially in an aggregate amount of up to $600.0 million. The proceeds from loans under the Credit Agreement are available for working capital needs and other general corporate purposes, and the full amount is available to support the issuance of letters of credit.

On February 24, 2017, August 9, 2017 and March 1, 2018, we entered into amendments to the Credit Agreement (the "Amendments" and the Credit Agreement, as amended to date, the "Amended Credit Agreement") to, among other things: (1) permit us to incur the debt under the second lien term loan facility (discussed further in Note 20), (2) modify the definition of EBITDA in the Amended Credit Agreement to exclude: up to $98.1 million of charges for certain Renewable segment contracts for periods including the quarter ended December 31, 2016, up to $115.2 million of charges for certain Renewable segment contracts for periods including the quarter ended June 30, 2017, up to $30.1 million of charges for certain Renewable segment contracts for periods including the quarter ended September 30, 2017, up to $38.7 million of charges for certain Renewable segment contracts for periods including the quarter ended December 31, 2017, up to $4.0 million of aggregate restructuring expenses incurred during the period from July 1, 2017 through September 30, 2018 measured on a consecutive four-quarter basis, realized and unrealized foreign exchange losses resulting from the impact of foreign currency changes on the valuation of assets and liabilities, and fees and expenses incurred in connection with the August 9, 2017 and March 1, 2018 amendments, (3) replace the maximum leverage ratio with a maximum senior debt leverage ratio, (4) decrease the minimum consolidated interest coverage ratio, (5) limit our ability to borrow under the Amended Credit Agreement during the covenant relief period to $250.0 million in the aggregate, (6) reduce commitments under the revolving credit facility from $600.0 million to $450.0 million, (7) require us to maintain liquidity (as defined in the Amended Credit Agreement) of at least $75.0 million as of the last business day of any calendar month, (8) require us to repay outstanding borrowings under the revolving credit facility (without any reduction in commitments) with certain excess cash, (9) increase the pricing for borrowings and commitment fees under the Amended Credit Agreement, (10) limit our ability to incur debt and liens during the covenant relief period, (11) limit our ability to make acquisitions and investments in third parties during the covenant relief period, (12) prohibit us from paying dividends and undertaking stock repurchases during the covenant relief period (other than our share repurchase from an affiliate of AIP (discussed further in Note 20)), (13) prohibit us from exercising the accordion described below during the covenant relief period, (14) limit our financial and commercial letters of credit outstanding under the Amended Credit Agreement to $30.0 million, (15) require us to reduce commitments under the Amended Credit Agreement with the proceeds of certain debt issuances and asset sales, (16) beginning with the quarter ended March 31, 2018, limit to no more than $15.0 million any cumulative net income losses attributable to eight specified Vølund projects, (17) increase reporting obligations and require us to hire a third-party consultant and a chief implementation officer, (18) require us to pledge the equity of certain of our foreign subsidiaries to guarantee and provide collateral for our obligations under the United States credit facility, (19) require us to pay a deferred facility fee as more fully set forth in the March 1, 2018 Amendment, and (20) require us to sell at least $100 million of assets before March 31, 2019. The covenant relief period will end, at our election, when the conditions set forth in the Amended Credit Agreement are satisfied, but in no event earlier than the date on which we provide the compliance certificate for our fiscal quarter ended December 31, 2019.

Other than during the covenant relief period, the Amended Credit Agreement contains an accordion feature that allows us, subject to the satisfaction of certain conditions, including the receipt of increased commitments from existing lenders or new commitments from new lenders, to increase the amount of the commitments under the revolving credit facility in an aggregate amount not to exceed the sum of (1) $200.0 million plus (2) an unlimited amount, so long as for any commitment increase under this subclause (2) our senior leverage ratio (assuming the full amount of any commitment increase under this subclause (2) is drawn) is equal to or less than 2.00:1.0 after giving pro forma effect thereto. During the covenant relief period, our ability to exercise the accordion feature will be prohibited.

The Amended Credit Agreement and our obligations under certain hedging agreements and cash management agreements with our lenders and their affiliates are (1) guaranteed by substantially all of our wholly owned domestic subsidiaries, but excluding our captive insurance subsidiary, and (2) secured by first-priority liens on certain assets owned by us and the guarantors. The Amended Credit Agreement requires interest payments on revolving loans on a periodic basis until maturity. We may prepay all loans at any time without premium or penalty (other than customary LIBOR breakage costs), subject to notice requirements. The Amended Credit Agreement requires us to make certain prepayments on any outstanding revolving loans after receipt of cash proceeds from certain asset sales or other events, subject to certain exceptions and a right to reinvest such proceeds in certain circumstances. During the covenant relief period, such prepayments may require us to reduce the commitments under the Amended Credit Agreement by a corresponding amount of such prepayments. Following the covenant relief period, such prepayments will not require us to reduce the commitments under the Amended Credit Agreement.

The March 1, 2018 Amendment temporarily waived certain defaults and events of default under our United States credit facility that were breached on December 31, 2017 or that may occur in the future, with certain amendments effective immediately and other amendments effective upon the completion of the Rights Offering and the repayment of the outstanding balance of our Second Lien Notes Offering. If the Rights Offering and the repayment of the outstanding balance of our Second Lien Notes Offering do not occur by April 15, 2018 (subject to extension in certain cases), the temporary waiver will end. The temporary waiver will also end if certain other conditions specified in the March 1, 2018 Amendment occur. Upon any such termination of the waiver, our ability to borrow funds under the United States credit facility will terminate.

After giving effect to the Amendments, loans outstanding under the Amended Credit Agreement bear interest at our option at either LIBOR rate plus 7.0% per annum or the Base Rate plus 6.0% per annum until we complete the Rights Offering and prepay the Second Lien Term Loan facility and thereafter at our option at either (1) the LIBOR rate plus 5.0% per annum during 2018, 6.0% per annum during 2019 and 7.0% per annum during 2020, or (2) the Base Rate plus 4.0% per annum during 2018, 5.0% per annum during 2019, and 6.0% per annum during 2020. The Base Rate is the highest of the Federal Funds rate plus 0.5%, the one month LIBOR rate plus 1.0%, or the administrative agent's prime rate. Interest expense associated with our United States revolving credit facility loans for the year ended December 31, 2017 was $11.3 million, respectively. Included in interest expense was $6.3 million of non-cash amortization of direct financing costs for the year ended December 31, 2017. A commitment fee of 1.0% per annum is charged on the unused portions of the revolving credit facility. A letter of credit fee of 2.50% per annum is charged with respect to the amount of each financial letter of credit outstanding, and a letter of credit fee of 1.50% per annum is charged with respect to the amount of each performance and commercial letter of credit outstanding. Additionally, an annual facility fee of $1.5 million is payable on the first business day of 2018 and 2019, and a pro rated amount is payable on the first business day of 2020.

The Amended Credit Agreement includes financial covenants that are tested on a quarterly basis, based on the rolling four-quarter period that ends on the last day of each fiscal quarter. After we complete the Rights Offering and the repayment of the outstanding balance of our Second Lien Notes Offering within the time period required by the March 1, 2018 Amendment, the maximum permitted senior debt leverage ratio as defined in the Amended Credit Agreement is:

• 8.50:1.0 for the quarter ended December 31, 2017,

• 7.00:1.0 for the quarter ending March 31, 2018,

• 6.50:1.0 for the quarters ending June 30, 2018 and September 30, 2018,

• 4.75:1.0 for the quarter ending December 31, 2018,

• 3.00:1.0 for the quarter ending March 31, 2019,

• 2.75:1.0 for the quarters ending June 30, 2019 and September 30, 2019 and

• 2.50:1.0 for the quarter ending December 31, 2019 and each quarter thereafter.

After we complete the Rights Offering and the repayment of the outstanding balance of our Second Lien Notes Offering within the time period required by the March 1, 2018 Amendment, the minimum consolidated interest coverage ratio as defined in the Credit Agreement is:

• 1.25:1.0 for the quarter ended December 31, 2017,

• 1.15:1.0 for the quarter ending March 31, 2018,

• 1.00:1.0 for the quarter ending June 30, 2018,

• 0.85:1.0 for the quarter ending September 30, 2018,

• 1.25:1.0 for the quarter ending December 31, 2018,

• 1.50:1.0 for the quarter ending March 31, 2019 and

• 2.00:1.0 for the quarters ending June 30, 2019 and each quarter thereafter.

Beginning with September 30, 2017, consolidated capital expenditures in each fiscal year are limited to $27.5 million.

At December 31, 2017, borrowings under the Amended Credit Agreement and foreign facilities consisted of $103.5 million at an effective interest rate of 6.89%. Usage under the Amended Credit Agreement consisted of $94.3 million of borrowings, $7.4 million of financial letters of credit and $123.7 million of performance letters of credit. After giving effect to the March 1, 2018 amendment, at December 31, 2017, we had approximately $221.4 million available for borrowings or to meet letter of credit requirements primarily based on trailing 12 month EBITDA (as defined in the Amended Credit Agreement), and our leverage and interest coverage ratios (as defined in the Amended Credit Agreement) were 2.59 and 2.50, respectively. We expect to be closest to the minimum financial covenant thresholds at September 30, 2018.

Foreign revolving credit facilities

Outside of the United States, we have revolving credit facilities in Turkey and India that are used to provide working capital to our operations in each country. These foreign revolving credit facilities allow us to borrow up to $9.2 million in aggregate and each have a one year term. At December 31, 2017, we had $9.2 million in borrowings outstanding under these foreign revolving credit facilities at an effective weighted-average interest rate of 6.07%. Subsequent to December 31, 2017, the foreign facilities were repaid and extinguished.

Letters of credit, bank guarantees and surety bonds

Certain subsidiaries primarily outside of the United States have credit arrangements with various commercial banks and other financial institutions for the issuance of letters of credit and bank guarantees in association with contracting activity. The aggregate value of all such letters of credit and bank guarantees not secured by the United States revolving credit facility as of December 31, 2017 and 2016 was $269.1 million and $255.2 million, respectively. The aggregate value of all such letters of credit and bank guarantees that are partially secured by the United States revolving credit facility as of December 31, 2017 was $114.2 million. The aggregate value of the letters of credit provided by the Company's United States revolving credit facility in support of letters of credit outside of the United States was $40.4 million as of December 31, 2017.

We have posted surety bonds to support contractual obligations to customers relating to certain contracts. 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 adequate to support our existing contract requirements for the next 12 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, 2017, bonds issued and outstanding under these arrangements in support of contracts totaled approximately $378.8 million.

Interest expense associated with our second lien credit agreement is comprised of the following:

(in thousands)	Coupon Interest	Accretion of debt discount and amortization of financing costs	Total Interest Expense
For the three months ended September 30, 2017	$2,554	$1,095	$3,649
For the three months ended December 31, 2017	$4,657	$2,131	$6,788
Forecasted for the year ending December 31, 2018	$20,266	$9,838	$30,104

The carrying value of the second lien term loan facility at December 31, 2017 was as follows (in thousands):

Face value	Unamortized debt discount and direct financing costs	Net carrying value
$195,884	$35,743	$160,141

Schedule of Debt [Table Text Block]

The components of our revolving debt are comprised of separate revolving credit facilities in the following locations:

(in thousands)	December 31, 2017		December 31, 2016
United States	$	94,300	$	9,800
Foreign	9,173		14,241
Total revolving debt	$	103,473	$	24,041

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Stock-Based Compensation Company Stock Options Fair Value (Tables)

12 Months Ended

Dec. 31, 2017

Share-based Compensation Arrangement by Share-based Payment Award [Line Items]

Schedule of Share-based Payment Award, Stock Options, Valuation Assumptions [Table Text Block]

The fair value of each option grant awarded in 2016 and 2015 was estimated at the date of grant using Black-Scholes, with the following weighted-average assumptions:

	Year Ended December 31,
	2016		2015
Risk-free interest rate	1.14	%	1.38	%
Expected volatility	25	%	28	%
Expected life of the option in years	3.95		3.96
Expected dividend yield	—	%	—	%

XML

Stock-Based Compensation Stock Options Rollforward (Tables)

12 Months Ended

Dec. 31, 2017

Share-based Compensation Arrangement by Share-based Payment Award [Line Items]

Schedule of Share-based Compensation, Stock Options, Activity [Table Text Block]

The following table summarizes activity for our stock options the year ending December 31, 2017:

(share data in thousands)	Number of Shares		Weighted-Average Exercise Price		Weighted-Average Remaining Contractual Term (in years)	Aggregate Intrinsic Value (in thousands)
Outstanding at beginning of period	2,652		$	18.27
Granted	—		—
Exercised	(24	)	15.04
Cancelled/expired/forfeited	(150	)	18.50
Outstanding at end of period	2,478		$	18.28	5.46	$	—
Exercisable at end of period	1,844		$	18.14	4.69	$	—

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Stock-Based Compensation Restricted Stock Unit Rollforward (Tables)

12 Months Ended

Dec. 31, 2017

Share-based Compensation Arrangement by Share-based Payment Award [Line Items]

Schedule of Nonvested Restricted Stock Units Activity [Table Text Block]

Nonvested restricted stock units activity for the year ending December 31, 2017 was as follows:

(share data in thousands)	Number of Shares		Weighted-Average Grant Date Fair Value
Nonvested at beginning of period	712		$	19.14
Granted	1,902		5.35
Vested	(282	)	18.48
Cancelled/forfeited	(105	)	15.00
Nonvested at end of period	2,227		$	7.63

XML

Stock-Based Compensation PRSU Fair Value (Tables)

12 Months Ended

Dec. 31, 2017

Share-based Compensation Arrangement by Share-based Payment Award [Line Items]

Schedule of Share-based Payment Award, Employee Stock Purchase Plan, Valuation Assumptions [Table Text Block]

The fair value of the TSR portion of each PSU granted was estimated at the date of grant using a Monte Carlo methodology based on market prices and the following weighted-average assumptions:

	Year Ended December 31,		Year Ended December 31,
	2017		2016
Risk-free interest rate	1.54	%	0.96	%
Expected volatility	42	%	25	%
Expected life of the option in years	2.83		2.83
Expected dividend yield	—	%	—	%

XML

Stock-Based Compensation PRSU Rollforward (Tables)

12 Months Ended

Dec. 31, 2017

Share-based Compensation Arrangement by Share-based Payment Award [Line Items]

Schedule of Share-based Compensation, Restricted Stock and Restricted Stock Units Activity [Table Text Block]

Company performance-based, cash settled units

In 2017, we granted certain B&W employees cash-settled performance units under the Plan, the value of which is tied to the fair market value of our common stock on the vesting dates, subject to a ceiling of 150% of the grant date share value. The activity for the cash-settled performance units for the year ending December 31, 2017 was as follows:

(share data in thousands)	Number of Shares		Weighted-Average Grant Date Fair Value
Nonvested at beginning of period	32		$	18.53
Granted	1,908		2.90
Vested	(7	)	—
Cancelled/forfeited	(134	)	3.93
Nonvested at end of period	1,799		$	4.53

PSU activity for the year ending December 31, 2017 was as follows:

(share data in thousands)	Number of Shares		Weighted-Average Grant Date Fair Value
Nonvested at beginning of period	451		$	19.29
Granted	828		9.74
Vested	(3	)	9.67
Cancelled/forfeited	(141	)	14.07
Nonvested at end of period	1,135		$	12.75

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Stock-Based Compensation PRSU Cash Settled Units Rollforward (Tables)

12 Months Ended

Dec. 31, 2017

Share-based Compensation Arrangement by Share-based Payment Award [Line Items]

Schedule of Share-based Compensation, Restricted Stock and Restricted Stock Units Activity [Table Text Block]

Company performance-based, cash settled units

In 2017, we granted certain B&W employees cash-settled performance units under the Plan, the value of which is tied to the fair market value of our common stock on the vesting dates, subject to a ceiling of 150% of the grant date share value. The activity for the cash-settled performance units for the year ending December 31, 2017 was as follows:

(share data in thousands)	Number of Shares		Weighted-Average Grant Date Fair Value
Nonvested at beginning of period	32		$	18.53
Granted	1,908		2.90
Vested	(7	)	—
Cancelled/forfeited	(134	)	3.93
Nonvested at end of period	1,799		$	4.53

PSU activity for the year ending December 31, 2017 was as follows:

(share data in thousands)	Number of Shares		Weighted-Average Grant Date Fair Value
Nonvested at beginning of period	451		$	19.29
Granted	828		9.74
Vested	(3	)	9.67
Cancelled/forfeited	(141	)	14.07
Nonvested at end of period	1,135		$	12.75

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Acquisitions Universal Intangible Assets (Tables)

12 Months Ended

Dec. 31, 2017

Acquired Indefinite-lived Intangible Assets [Line Items]

Schedule of Finite-Lived Intangible Assets Acquired as Part of Business Combination [Table Text Block]

The intangible assets included above consist of the following:

	Fair value (in thousands)		Weighted average estimated useful life (in years)
Customer relationships	$	10,800	15
Backlog	1,700		1
Trade names / trademarks	3,000		20
Technology	4,000		7
Total amortizable intangible assets	$	19,500

The intangible assets included above consist of the following:

(in thousands)	Fair value (in thousands)		Weighted average estimated useful life (in years)
Customer relationships	$	12,217	9
Backlog	17,769		2
Trade names / trademarks	8,885		20
Technology	14,438		10
Non-compete agreements	1,666		3
Internally-developed software	189		3
Total amortizable intangible assets	$	55,164

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Acquisitions Universal Acquisition Purchase Price Allocation (Tables)

12 Months Ended

Dec. 31, 2017

Acquisitions [Abstract]

Schedule of Recognized Identified Assets Acquired and Liabilities Assumed [Table Text Block]

(in thousands)	Acquisition date fair values
Cash	$	4,379
Accounts receivable	11,270
Contracts in progress	3,167
Inventories	4,585
Other assets	579
Property, plant and equipment	16,692
Goodwill	14,413
Identifiable intangible assets	19,500
Deferred income tax assets	935
Current liabilities	(10,833		)
Other noncurrent liabilities	(1,423		)
Deferred income tax liabilities	(6,338		)
Net acquisition cost	$	56,926

The allocation of the purchase price, based on the fair value of assets acquired and liabilities assumed, is detailed below.

(in thousands)	Acquisition date fair values
Cash	$	25,994
Accounts receivable	58,843
Contracts in progress	61,155
Inventories	2,554
Other assets	7,341
Property, plant and equipment	6,104
Goodwill	72,401
Identifiable intangible assets	55,164
Deferred income tax assets	5,550
Revolving debt	(27,530		)
Current liabilities	(56,323		)
Advance billings on contracts	(15,226		)
Other noncurrent liabilities	(379		)
Deferred income tax liabilities	(17,120		)
Noncontrolling interest in joint venture	(7,754		)
Net acquisition cost	$	170,774

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Acquisitions Universal Pro Forma (Tables)

12 Months Ended

Dec. 31, 2017

Acquisitions [Abstract]

Business Acquisition, Pro Forma Information [Table Text Block]

	Year Ended December 31,
(in thousands)	2016			2015
Revenues	$	1,663,126		$	1,941,987
Net income (loss) attributable to B&W	(111,500		)	12,047
Basic earnings per common share	(2.22		)	0.23
Diluted earnings per common share	(2.22		)	0.22

ACQUISITIONS

Universal Acoustic & Emission Technologies, Inc.

On January 11, 2017, we acquired Universal Acoustic & Emission Technologies, Inc. ("Universal") for approximately $52.5 million in cash, funded primarily by borrowings under our United States revolving credit facility, net of $4.4 million cash acquired in the business combination. Transaction costs included in the purchase price were approximately $0.2 million. We accounted for the Universal acquisition using the acquisition method, whereby all of the assets acquired and liabilities assumed were recognized at their fair value on the acquisition date, with any excess of the purchase price over the estimated fair value recorded as goodwill. In order to purchase Universal on January 11, 2017, we borrowed approximately $55.0 million under the United States revolving credit facility in 2017.

Universal provides custom-engineered acoustic, emission and filtration solutions to the natural gas power generation, mid-stream natural gas pipeline, locomotive and general industrial end-markets. Universal's product offering includes gas turbine inlet and exhaust systems, silencers, filters and enclosures. At the acquisition date, Universal employed approximately 460 people, mainly in the United States and Mexico. During 2017, we integrated Universal with our Industrial segment. Universal contributed $69.1 million of revenue and $14.5 million of gross profit to our operating results in the year ended December 31, 2017.

The allocation of the purchase price based on the fair value of assets acquired and liabilities assumed is set forth below. We finalized the purchase price allocation associated with the valuation of certain intangible assets and deferred tax balances at December 31, 2017; as a result, the provisional measurements of intangible assets, goodwill and deferred income tax balances did not change.

(in thousands)	Acquisition date fair values
Cash	$	4,379
Accounts receivable	11,270
Contracts in progress	3,167
Inventories	4,585
Other assets	579
Property, plant and equipment	16,692
Goodwill	14,413
Identifiable intangible assets	19,500
Deferred income tax assets	935
Current liabilities	(10,833		)
Other noncurrent liabilities	(1,423		)
Deferred income tax liabilities	(6,338		)
Net acquisition cost	$	56,926

The intangible assets included above consist of the following:

	Fair value (in thousands)		Weighted average estimated useful life (in years)
Customer relationships	$	10,800	15
Backlog	1,700		1
Trade names / trademarks	3,000		20
Technology	4,000		7
Total amortizable intangible assets	$	19,500

The acquisition of Universal resulted in an increase in our intangible asset amortization expense during the year ended December 31, 2017 of $3.1 million, which is included in cost of operations in our consolidated statement of operations. Amortization of intangible assets is not allocated to segment results.

Approximately $1.7 million of acquisition and integration related costs of Universal was recorded as a component of our SG&A expenses in the consolidated statement of operations in the year ended December 31, 2017.

The following unaudited pro forma financial information below represents our results of operations for year ended December 31, 2016 had the Universal acquisition occurred on January 1, 2016. The unaudited pro forma financial information below is not intended to represent or be indicative of our actual consolidated results had we completed the acquisition at January 1, 2016. This information should not be taken as representative of our future consolidated results of operations.

	Year Ended
(in thousands)	December 31, 2016
Revenues	$	1,660,986
Net income (loss) attributable to B&W	(113,940		)
Basic earnings per common share	(2.27		)
Diluted earnings per common share	(2.27		)

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Acquisitions SPIG Purchase Price Allocation (Tables)

12 Months Ended

Dec. 31, 2017

Acquisitions [Abstract]

Schedule of Recognized Identified Assets Acquired and Liabilities Assumed [Table Text Block]

(in thousands)	Acquisition date fair values
Cash	$	4,379
Accounts receivable	11,270
Contracts in progress	3,167
Inventories	4,585
Other assets	579
Property, plant and equipment	16,692
Goodwill	14,413
Identifiable intangible assets	19,500
Deferred income tax assets	935
Current liabilities	(10,833		)
Other noncurrent liabilities	(1,423		)
Deferred income tax liabilities	(6,338		)
Net acquisition cost	$	56,926

The allocation of the purchase price, based on the fair value of assets acquired and liabilities assumed, is detailed below.

(in thousands)	Acquisition date fair values
Cash	$	25,994
Accounts receivable	58,843
Contracts in progress	61,155
Inventories	2,554
Other assets	7,341
Property, plant and equipment	6,104
Goodwill	72,401
Identifiable intangible assets	55,164
Deferred income tax assets	5,550
Revolving debt	(27,530		)
Current liabilities	(56,323		)
Advance billings on contracts	(15,226		)
Other noncurrent liabilities	(379		)
Deferred income tax liabilities	(17,120		)
Noncontrolling interest in joint venture	(7,754		)
Net acquisition cost	$	170,774

XML

Acquisitions SPIG Intangible Assets (Tables)

12 Months Ended

Dec. 31, 2017

Business Acquisition [Line Items]

Schedule of Finite-Lived Intangible Assets Acquired as Part of Business Combination [Table Text Block]

The intangible assets included above consist of the following:

	Fair value (in thousands)		Weighted average estimated useful life (in years)
Customer relationships	$	10,800	15
Backlog	1,700		1
Trade names / trademarks	3,000		20
Technology	4,000		7
Total amortizable intangible assets	$	19,500

The intangible assets included above consist of the following:

(in thousands)	Fair value (in thousands)		Weighted average estimated useful life (in years)
Customer relationships	$	12,217	9
Backlog	17,769		2
Trade names / trademarks	8,885		20
Technology	14,438		10
Non-compete agreements	1,666		3
Internally-developed software	189		3
Total amortizable intangible assets	$	55,164

XML

Acquisitions SPIG Pro Forma (Tables)

12 Months Ended

Dec. 31, 2017

Acquisitions [Abstract]

Business Acquisition, Pro Forma Information [Table Text Block]

	Year Ended December 31,
(in thousands)	2016			2015
Revenues	$	1,663,126		$	1,941,987
Net income (loss) attributable to B&W	(111,500		)	12,047
Basic earnings per common share	(2.22		)	0.23
Diluted earnings per common share	(2.22		)	0.22

ACQUISITIONS

Universal Acoustic & Emission Technologies, Inc.

On January 11, 2017, we acquired Universal Acoustic & Emission Technologies, Inc. ("Universal") for approximately $52.5 million in cash, funded primarily by borrowings under our United States revolving credit facility, net of $4.4 million cash acquired in the business combination. Transaction costs included in the purchase price were approximately $0.2 million. We accounted for the Universal acquisition using the acquisition method, whereby all of the assets acquired and liabilities assumed were recognized at their fair value on the acquisition date, with any excess of the purchase price over the estimated fair value recorded as goodwill. In order to purchase Universal on January 11, 2017, we borrowed approximately $55.0 million under the United States revolving credit facility in 2017.

Universal provides custom-engineered acoustic, emission and filtration solutions to the natural gas power generation, mid-stream natural gas pipeline, locomotive and general industrial end-markets. Universal's product offering includes gas turbine inlet and exhaust systems, silencers, filters and enclosures. At the acquisition date, Universal employed approximately 460 people, mainly in the United States and Mexico. During 2017, we integrated Universal with our Industrial segment. Universal contributed $69.1 million of revenue and $14.5 million of gross profit to our operating results in the year ended December 31, 2017.

The allocation of the purchase price based on the fair value of assets acquired and liabilities assumed is set forth below. We finalized the purchase price allocation associated with the valuation of certain intangible assets and deferred tax balances at December 31, 2017; as a result, the provisional measurements of intangible assets, goodwill and deferred income tax balances did not change.

(in thousands)	Acquisition date fair values
Cash	$	4,379
Accounts receivable	11,270
Contracts in progress	3,167
Inventories	4,585
Other assets	579
Property, plant and equipment	16,692
Goodwill	14,413
Identifiable intangible assets	19,500
Deferred income tax assets	935
Current liabilities	(10,833		)
Other noncurrent liabilities	(1,423		)
Deferred income tax liabilities	(6,338		)
Net acquisition cost	$	56,926

The intangible assets included above consist of the following:

	Fair value (in thousands)		Weighted average estimated useful life (in years)
Customer relationships	$	10,800	15
Backlog	1,700		1
Trade names / trademarks	3,000		20
Technology	4,000		7
Total amortizable intangible assets	$	19,500

The acquisition of Universal resulted in an increase in our intangible asset amortization expense during the year ended December 31, 2017 of $3.1 million, which is included in cost of operations in our consolidated statement of operations. Amortization of intangible assets is not allocated to segment results.

Approximately $1.7 million of acquisition and integration related costs of Universal was recorded as a component of our SG&A expenses in the consolidated statement of operations in the year ended December 31, 2017.

The following unaudited pro forma financial information below represents our results of operations for year ended December 31, 2016 had the Universal acquisition occurred on January 1, 2016. The unaudited pro forma financial information below is not intended to represent or be indicative of our actual consolidated results had we completed the acquisition at January 1, 2016. This information should not be taken as representative of our future consolidated results of operations.

	Year Ended
(in thousands)	December 31, 2016
Revenues	$	1,660,986
Net income (loss) attributable to B&W	(113,940		)
Basic earnings per common share	(2.27		)
Diluted earnings per common share	(2.27		)

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Quarterly Financial Data (Tables)

12 Months Ended

Dec. 31, 2017

Quarterly Financial Information Disclosure [Abstract]

Quarterly Financial Information [Text Block]

The following tables set forth selected unaudited quarterly financial information for the years ended December 31, 2017 and 2016:

(in thousands, except per share amounts)	Quarter ended
	March 31, 2017			June 30, 2017			Sept. 30, 2017			Dec. 31, 2017
Revenues	$	391,104		$	349,829		$	408,703		$	408,099
Gross profit	$	62,900		$	(55,822	)	$	47,287		$	45,513
Operating income (loss) (1)	$	(8,798	)	$	(144,646	)	$	(104,748	)	$	(23,373	)
Equity in income (loss) of investees	$	618		$	(15,232	)	$	1,234		$	3,513
Net income (loss) attributable to shareholders	$	(7,045	)	$	(150,999	)	$	(114,302	)	$	(107,478	)
Earnings per common share
Basic	$	(0.14	)	$	(3.09	)	$	(2.48	)	$	(2.44	)
Diluted	$	(0.14	)	$	(3.09	)	$	(2.48	)	$	(2.44	)

⁽¹⁾  Includes equity in income of investees.

(in thousands, except per share amounts)	Quarter ended
	March 31, 2016		June 30, 2016			Sept. 30, 2016		Dec. 31, 2016
Revenues	$	404,116	$	383,208		$	410,955	$	379,984
Gross profit	$	80,156	$	26,052		$	73,757	$	(848	)
Operating income (loss) (1)	$	17,266	$	(72,585	)	$	11,133	$	(58,587	)
Equity in income (loss) of investees	$	2,676	$	(616	)	$	2,827	$	11,553
Net income (loss) attributable to shareholders	$	10,507	$	(63,490	)	$	8,894	$	(71,560	)
Earnings per common share
Basic	$	0.20	$	(1.25	)	$	0.18	$	(1.47	)
Diluted	$	0.20	$	(1.25	)	$	0.18	$	(1.47	)

⁽¹⁾  Includes equity in income of investees.

NOTE 28 – QUARTERLY FINANCIAL DATA

The following tables set forth selected unaudited quarterly financial information for the years ended December 31, 2017 and 2016:

(in thousands, except per share amounts)	Quarter ended
	March 31, 2017			June 30, 2017			Sept. 30, 2017			Dec. 31, 2017
Revenues	$	391,104		$	349,829		$	408,703		$	408,099
Gross profit	$	62,900		$	(55,822	)	$	47,287		$	45,513
Operating income (loss) (1)	$	(8,798	)	$	(144,646	)	$	(104,748	)	$	(23,373	)
Equity in income (loss) of investees	$	618		$	(15,232	)	$	1,234		$	3,513
Net income (loss) attributable to shareholders	$	(7,045	)	$	(150,999	)	$	(114,302	)	$	(107,478	)
Earnings per common share
Basic	$	(0.14	)	$	(3.09	)	$	(2.48	)	$	(2.44	)
Diluted	$	(0.14	)	$	(3.09	)	$	(2.48	)	$	(2.44	)

⁽¹⁾  Includes equity in income of investees.

(in thousands, except per share amounts)	Quarter ended
	March 31, 2016		June 30, 2016			Sept. 30, 2016		Dec. 31, 2016
Revenues	$	404,116	$	383,208		$	410,955	$	379,984
Gross profit	$	80,156	$	26,052		$	73,757	$	(848	)
Operating income (loss) (1)	$	17,266	$	(72,585	)	$	11,133	$	(58,587	)
Equity in income (loss) of investees	$	2,676	$	(616	)	$	2,827	$	11,553
Net income (loss) attributable to shareholders	$	10,507	$	(63,490	)	$	8,894	$	(71,560	)
Earnings per common share
Basic	$	0.20	$	(1.25	)	$	0.18	$	(1.47	)
Diluted	$	0.20	$	(1.25	)	$	0.18	$	(1.47	)

⁽¹⁾  Includes equity in income of investees.

Our quarterly results include the following items that significant affect comparability across periods:

• Actuarial gains and losses from marking to market our pension and postretirement benefit plan assets and liabilities (see Note 18). Such mark to market adjustments resulted in (charges) gains of: $9.8 million in the fourth quarter of 2017, $(1.1) million in the first quarter of 2017, $6.4 million in the fourth quarter of 2016, $(0.5) million in the third quarter of 2016, and $(30.0) million in the second quarter of 2016.

• In the third quarter of 2017, $86.9 million of goodwill impairment charges (see Note 15).

• In the second and fourth quarters of both 2017 and 2016, significant losses related to changes in the estimates of the forecasted revenues and costs to complete six renewable energy contracts (see Note 6

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Related Party Transactions Transactions with former parent (Tables)

12 Months Ended

Dec. 31, 2017

Related Party Transactions [Abstract]

Schedule of Related Party Transactions [Table Text Block]

Prior to June 30, 2015, we were a party to transactions with our former Parent and its subsidiaries in the normal course of operations. After the spin-off, we no longer consider the former Parent to be a related party. Transactions with our former Parent prior to the spin-off included the following:

(in thousands)	Year Ended December 31, 2015
Sales to our former Parent	$	911
Corporate administrative expenses	35,343

Schedule Of Change In Companys Historical Investment Due To Net Transfers To From Parent [Table Text Block]

Net transfers from former Parent

Net transfers from former Parent represent the change in our former Parent's historical investment in us. It primarily includes the net effect of cost allocations from transactions with our former Parent, sales to our former Parent, and the net transfers of cash and assets to our former Parent prior to the spin-off. After the spin-off transaction on June 30, 2015, there have been no significant transfers to or from our former Parent. These transactions included the following:

(in thousands)	Year Ended December 31 2015
Sales to former Parent	$	911
Corporate administrative expenses	35,343
Income tax allocation	11,872
Acquisition of business, net of cash acquired	—
Cash pooling and general financing activities	(91,015		)
Cash contribution received at spin-off	125,300
Net transfer from former Parent per statement of cash flows	$	80,589
Non-cash items:
Net transfer of assets and liabilities	$	44,706
Distribution of Nuclear Energy segment	$	(47,839	)
Net transfer from former Parent per statement of shareholders' equity	$	77,456

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Discontinued Operations (Tables)

12 Months Ended

Dec. 31, 2017

Discontinued Operations and Disposal Groups [Abstract]

Condensed Income Statement [Table Text Block]

	Year Ended December 31,
(in thousands)	2017			2016		2015
Revenues	$	346,459		$	488,101	$	475,459
Gross profit	32,682			76,986		69,021
Income before provision for income taxes	(10,626		)	19,529		3,072
Provision for income taxes	1,907			3,715		4,500
Net income	$	(12,533	)	$	15,814	$	(1,428	)

The following table presents selected financial information regarding the results of operations of our former NE segment through June 30, 2015, the date it was discontinued:

	Six Months Ended June 30,
(in thousands)	2015
Revenues	$	53,064
Income (loss) before income tax expense	3,358
Income tax expense (benefit)	555
Income (loss) from discontinued operations, net of tax	$	2,803

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Taxes Reconciliation of Unrecognized Tax Benefits (Tables)

12 Months Ended

Dec. 31, 2017

Income Tax Contingency [Line Items]

Summary of Positions for which Significant Change in Unrecognized Tax Benefits is Reasonably Possible [Table Text Block]

. Unrecognized tax benefits are as follows:

(in thousands)	2017			2016			2015
Balance at beginning of period	$	884		$	1,141		$	3,321
Increases based on tax positions taken in the current year	277			178			88
Increases based on tax positions taken in the prior years	56			230			248
Decreases based on tax positions taken in the prior years	(13		)	—			(1,161		)
Decreases due to settlements with tax authorities	—			(665		)	(1,355		)
Decreases due to lapse of applicable statute of limitation	—			—			—
Balance at end of period	$	1,204		$	884		$	1,141

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Taxes Components of Deferred Tax Assets and Liabilities (Tables)

12 Months Ended

Dec. 31, 2017

Tax Credit Carryforward [Line Items]

Schedule of Deferred Tax Assets and Liabilities [Table Text Block]

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, 2017 and 2016 were as follows:

	December 31,
(in thousands)	2017			2016
Deferred tax assets:
Pension liability	$	58,810		$	105,426
Accrued warranty expense	5,262			11,628
Accrued vacation pay	996			4,792
Accrued liabilities for self-insurance (including postretirement health care benefits)	3,910			6,596
Accrued liabilities for executive and employee incentive compensation	4,950			8,334
Investments in joint ventures and affiliated companies	10,422			10,742
Long-term contracts	6,801			10,318
Accrued Legal Fees	1,579			2,110
Inventory Reserve	1,842			2,445
Property, plant and equipment	—			1,587
Net operating loss carryforward	95,715			33,187
State tax net operating loss carryforward	21,658			15,372
Foreign tax credit carryforward	7,150			3,870
Other tax credits	5,678			737
Other	4,980			7,852
Total deferred tax assets	229,753			224,996
Valuation allowance for deferred tax assets	(108,105		)	(40,484		)
Net, total deferred tax assets	121,648			184,512
Deferred tax liabilities:
Long-term contracts	569			3,601
Intangibles	21,215			21,892
Property, plant and equipment	2,835			—
Undistributed foreign earnings	1,314			500
Goodwill	—			1,125
Other	2,445			2,885
Total deferred tax liabilities	28,378			30,003
Net deferred tax assets	$	93,270		$	154,509

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Taxes Valuation allowance for deferred tax assets (Tables)

12 Months Ended

Dec. 31, 2017

Valuation Allowance [Line Items]

Summary of Valuation Allowance [Table Text Block]

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

(in thousands)	Beginning balance			Charges to costs and expenses			Charged to other accounts			Ending balance
Year Ended December 31, 2017	$	(40,484	)	$	(61,021	)	$	(6,600	)	$	(108,105	)
Year Ended December 31, 2016	(10,077		)	(29,307		)	(1,100		)	(40,484		)
Year Ended December 31, 2015	(9,216		)	(861		)	—			(10,077		)

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Taxes Income before Provision for Income Taxes (Tables)

12 Months Ended

Dec. 31, 2017

Income before Provision for Income Taxes [Abstract]

Income Tax Disclosure [Text Block]

– PROVISION FOR INCOME TAXES

We are subject to federal income tax in the United States 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 both nominal rates and the basis on which these rates are applied. Our consolidated effective income tax rate can vary significantly from period to period due to these variations, changes in jurisdictional mix of our income and valuation allowances in certain jurisdictions that can offset income tax expense or benefit.

We are currently under audit by various domestic and international authorities. With few exceptions, we do not have any returns under examination for years prior to 2013. The United States Internal Revenue Service has completed examinations of the federal tax returns of BWC through 2014, and all matters arising from such examinations have been resolved.

We recognize the effect of income tax positions only if it is more-likely-than-not that those positions will be sustained. Recognized income tax positions are measured at the largest amount that is greater than 50% likely of being realized. Changes in recognition or measurement are reflected in the period in which the change in judgment occurs. Unrecognized tax benefits are as follows:

(in thousands)	2017			2016			2015
Balance at beginning of period	$	884		$	1,141		$	3,321
Increases based on tax positions taken in the current year	277			178			88
Increases based on tax positions taken in the prior years	56			230			248
Decreases based on tax positions taken in the prior years	(13		)	—			(1,161		)
Decreases due to settlements with tax authorities	—			(665		)	(1,355		)
Decreases due to lapse of applicable statute of limitation	—			—			—
Balance at end of period	$	1,204		$	884		$	1,141

The $1.2 million balance of unrecognized tax benefits at December 31, 2017 would decrease expense if recognized. We do not expect any of our unrecognized income tax benefits to be resolved in the next twelve months. We recognize interest and penalties related to unrecognized tax benefits in our provision for income taxes; however, such amounts are not significant to any period presented.

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, 2017 and 2016 were as follows:

	December 31,
(in thousands)	2017			2016
Deferred tax assets:
Pension liability	$	58,810		$	105,426
Accrued warranty expense	5,262			11,628
Accrued vacation pay	996			4,792
Accrued liabilities for self-insurance (including postretirement health care benefits)	3,910			6,596
Accrued liabilities for executive and employee incentive compensation	4,950			8,334
Investments in joint ventures and affiliated companies	10,422			10,742
Long-term contracts	6,801			10,318
Accrued Legal Fees	1,579			2,110
Inventory Reserve	1,842			2,445
Property, plant and equipment	—			1,587
Net operating loss carryforward	95,715			33,187
State tax net operating loss carryforward	21,658			15,372
Foreign tax credit carryforward	7,150			3,870
Other tax credits	5,678			737
Other	4,980			7,852
Total deferred tax assets	229,753			224,996
Valuation allowance for deferred tax assets	(108,105		)	(40,484		)
Net, total deferred tax assets	121,648			184,512
Deferred tax liabilities:
Long-term contracts	569			3,601
Intangibles	21,215			21,892
Property, plant and equipment	2,835			—
Undistributed foreign earnings	1,314			500
Goodwill	—			1,125
Other	2,445			2,885
Total deferred tax liabilities	28,378			30,003
Net deferred tax assets	$	93,270		$	154,509

At December 31, 2017, we had a valuation allowance of $108.1 million for deferred tax assets, which we expect may not be realized through carrybacks, future reversals of existing taxable temporary differences and estimates 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 estimates of future taxable income. Should we conclude in the future that any or all of our deferred tax assets are not more likely than not to be realized, we would establish additional valuation allowances and 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:

(in thousands)	Beginning balance			Charges to costs and expenses			Charged to other accounts			Ending balance
Year Ended December 31, 2017	$	(40,484	)	$	(61,021	)	$	(6,600	)	$	(108,105	)
Year Ended December 31, 2016	(10,077		)	(29,307		)	(1,100		)	(40,484		)
Year Ended December 31, 2015	(9,216		)	(861		)	—			(10,077		)

We operate in numerous countries that have statutory tax rates below that of the 35% federal statutory rate that has been applicable to the United States through December 31, 2017. The most significant of these foreign operations are located in Canada, Denmark, Germany, Italy, Mexico, Sweden and the United Kingdom with effective tax rates ranging between 20% and approximately 30%. Income before the provision for income taxes was as follows:

	Year Ended December 31,
(in thousands)	2017			2016			2015
United States	$	(44,835	)	$	1,280		$	(20,748	)
Other than the United States	(269,364		)	(109,419		)	40,953
Income before provision for income taxes	$	(314,199	)	$	(108,139	)	$	20,205

The provision for income taxes consisted of:

	Year Ended December 31,
(in thousands)	2017			2016			2015
Current:
United States – federal	$	100		$	284		$	24,084
United States – state and local	397			(415		)	3,458
Other than in the United States	8,612			4,504			8,250
Total current	9,109			4,373			35,792
Deferred:
United States – Federal	58,203			11,512			(35,888		)
United States – state and local	2,546			6,365			(111		)
Other than in the United States	(5,042		)	(15,307		)	3,878
Total deferred (benefit) provision	55,707			2,570			(32,121		)
Provision for income taxes	$	64,816		$	6,943		$	3,671

The following is a reconciliation of the United States statutory federal tax rate (35%) to the consolidated effective tax rate:

	Year Ended December 31,
	2017		2016		2015
United States federal statutory rate	35.0	%	35.0	%	35.0	%
State and local income taxes	0.2		(3.5	)	13.8
Foreign rate differential	(9.5	)	(12.8	)	(13.1	)
Deferred Taxes - Change in Tax Rate	(19.9	)	—		—
Tax credits	0.9		3.0		(14.7	)
Dividends and deemed dividends from affiliates	(1.8	)	(0.2	)	1.7
Valuation allowances	(17.9	)	(28.1	)	4.3
Goodwill impairment	(7.0	)	—		—
Uncertain tax positions	—		0.3		(6.6	)
Non-deductible expenses	0.2		(1.8	)	2.4
Manufacturing deduction	—		—		(2.5	)
Other	(0.8	)	1.7		(2.1	)
Effective tax rate	(20.6	)%	(6.4	)%	18.2	%

We have foreign net operating loss benefits after tax of $75.0 million available to offset future taxable income in certain foreign jurisdictions. Of the foreign net operating loss benefits, $1.7 million is scheduled to expire in 2019 to 2026. The remaining net operating loss benefits have unlimited lives. We are carrying a valuation allowance of $66.0 million against the deferred tax asset related to the foreign loss carryforwards.

At December 31, 2017, we have a tax effected United States federal net operating loss of $20.7 million. The United States federal operating loss will begin to expire in 2037, and we expect to fully utilize this net operating loss in future periods. At December 31, 2017, we have foreign tax credit carryovers of $7.2 million, against which we have a full valuation allowance. At December 31, 2017, we have state net operating loss benefits after tax of $21.7 million available to offset future taxable income in various states, against which we have $21.6 million of valuation allowance. Our state net operating loss carryforwards begin to expire in the year 2018.

It has been our practice to reinvest indefinitely, the earnings of our foreign subsidiaries and that position has not changed as a result of the enactment of the U.S. Tax Cuts and Jobs Act. If we were to distribute earnings from certain foreign subsidiaries, we would be subject to withholding taxes of approximately $4.4 million but U.S. income taxes would generally not be imposed upon such distributions.

We operate in numerous countries that have statutory tax rates below that of the 35% federal statutory rate that has been applicable to the United States through December 31, 2017. The most significant of these foreign operations are located in Canada, Denmark, Germany, Italy, Mexico, Sweden and the United Kingdom with effective tax rates ranging between 20% and approximately 30%. Income before the provision for income taxes was as follows:

	Year Ended December 31,
(in thousands)	2017			2016			2015
United States	$	(44,835	)	$	1,280		$	(20,748	)
Other than the United States	(269,364		)	(109,419		)	40,953
Income before provision for income taxes	$	(314,199	)	$	(108,139	)	$	20,205

The following is a reconciliation of the United States statutory federal tax rate (35%) to the consolidated effective tax rate:

	Year Ended December 31,
	2017		2016		2015
United States federal statutory rate	35.0	%	35.0	%	35.0	%
State and local income taxes	0.2		(3.5	)	13.8
Foreign rate differential	(9.5	)	(12.8	)	(13.1	)
Deferred Taxes - Change in Tax Rate	(19.9	)	—		—
Tax credits	0.9		3.0		(14.7	)
Dividends and deemed dividends from affiliates	(1.8	)	(0.2	)	1.7
Valuation allowances	(17.9	)	(28.1	)	4.3
Goodwill impairment	(7.0	)	—		—
Uncertain tax positions	—		0.3		(6.6	)
Non-deductible expenses	0.2		(1.8	)	2.4
Manufacturing deduction	—		—		(2.5	)
Other	(0.8	)	1.7		(2.1	)
Effective tax rate	(20.6	)%	(6.4	)%	18.2	%

The provision for income taxes consisted of:

	Year Ended December 31,
(in thousands)	2017			2016			2015
Current:
United States – federal	$	100		$	284		$	24,084
United States – state and local	397			(415		)	3,458
Other than in the United States	8,612			4,504			8,250
Total current	9,109			4,373			35,792
Deferred:
United States – Federal	58,203			11,512			(35,888		)
United States – state and local	2,546			6,365			(111		)
Other than in the United States	(5,042		)	(15,307		)	3,878
Total deferred (benefit) provision	55,707			2,570			(32,121		)
Provision for income taxes	$	64,816		$	6,943		$	3,671

New Tax Act

The United States Tax Cuts and Jobs Act (the “Tax Act”) was enacted on December 22, 2017 and introduces significant changes to the United States income tax law. Beginning in 2018, the Tax Act reduces the United States statutory corporate income tax rate from 35% to 21% and creates a modified territorial system that will generally allow United States companies a full dividend received deduction for any future dividends from non-U.S. subsidiaries. In connection with the transition to a modified territorial system, the Tax Act also establishes a mandatory one-time deemed repatriation transition tax on currently deferred foreign earnings.

The SEC staff issued Staff Accounting Bulletin ("SAB 118"), which provides guidance on accounting for the tax effects of the Tax Act. SAB 118 provides a measurement period that should not extend beyond one year from the Tax Act enactment date for companies to complete the accounting under Accounting Standards Codification 740 ("ASC 740"). In accordance with SAB 118, we have made reasonable estimates of the effects of the Tax Act and recorded provisional amounts in our financial statements as of December 31, 2017. We will finalize our estimates in 2018 as we collect and analyze necessary data, and interpret additional guidance that becomes available.

Provisional amounts for the following income tax effects of the Tax Act have been recorded as of December 31, 2017:

Deferred tax effects

We remeasured our deferred taxes and recorded a deferred tax expense of $62.4 million. This amount consists of an expense for the corporate rate reduction of $54.4 million, expense of $0.8 million based on a change in our deferred taxes related to executive compensation and an expense of $7.2 million to record a valuation allowance on foreign tax credit carryforwards that are now expected to expire unused. While we are able to make a reasonable estimate of the deferred tax effects, our continued analysis of other aspects of the Tax Act could impact our estimate.

One-time transition tax

The Deemed Repatriation Transition Tax (Transition Tax) is a tax on previously untaxed accumulated and current earnings and profits (E&P) of certain of our foreign subsidiaries. To determine the amount of the Transition Tax, we must determine, in addition to other factors, the amount of post-1986 E&P of the relevant subsidiaries, as well as the amount of non-United States income taxes paid on such earnings. We are able to make a reasonable estimate of the Transition Tax and because we have estimated an E&P deficit, we have not recorded a Transition Tax. We are continuing to gather additional information to more precisely compute final E&P, including the computation of 2017 current year E&P which we will finalize with the 2017 tax return.

XML

Taxes Components of Provision for Income Tax (Tables)

12 Months Ended

Dec. 31, 2017

Components of Provision for Income Tax [Abstract]

Income Tax Disclosure [Text Block]

– PROVISION FOR INCOME TAXES

We are subject to federal income tax in the United States 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 both nominal rates and the basis on which these rates are applied. Our consolidated effective income tax rate can vary significantly from period to period due to these variations, changes in jurisdictional mix of our income and valuation allowances in certain jurisdictions that can offset income tax expense or benefit.

We are currently under audit by various domestic and international authorities. With few exceptions, we do not have any returns under examination for years prior to 2013. The United States Internal Revenue Service has completed examinations of the federal tax returns of BWC through 2014, and all matters arising from such examinations have been resolved.

We recognize the effect of income tax positions only if it is more-likely-than-not that those positions will be sustained. Recognized income tax positions are measured at the largest amount that is greater than 50% likely of being realized. Changes in recognition or measurement are reflected in the period in which the change in judgment occurs. Unrecognized tax benefits are as follows:

(in thousands)	2017			2016			2015
Balance at beginning of period	$	884		$	1,141		$	3,321
Increases based on tax positions taken in the current year	277			178			88
Increases based on tax positions taken in the prior years	56			230			248
Decreases based on tax positions taken in the prior years	(13		)	—			(1,161		)
Decreases due to settlements with tax authorities	—			(665		)	(1,355		)
Decreases due to lapse of applicable statute of limitation	—			—			—
Balance at end of period	$	1,204		$	884		$	1,141

The $1.2 million balance of unrecognized tax benefits at December 31, 2017 would decrease expense if recognized. We do not expect any of our unrecognized income tax benefits to be resolved in the next twelve months. We recognize interest and penalties related to unrecognized tax benefits in our provision for income taxes; however, such amounts are not significant to any period presented.

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, 2017 and 2016 were as follows:

	December 31,
(in thousands)	2017			2016
Deferred tax assets:
Pension liability	$	58,810		$	105,426
Accrued warranty expense	5,262			11,628
Accrued vacation pay	996			4,792
Accrued liabilities for self-insurance (including postretirement health care benefits)	3,910			6,596
Accrued liabilities for executive and employee incentive compensation	4,950			8,334
Investments in joint ventures and affiliated companies	10,422			10,742
Long-term contracts	6,801			10,318
Accrued Legal Fees	1,579			2,110
Inventory Reserve	1,842			2,445
Property, plant and equipment	—			1,587
Net operating loss carryforward	95,715			33,187
State tax net operating loss carryforward	21,658			15,372
Foreign tax credit carryforward	7,150			3,870
Other tax credits	5,678			737
Other	4,980			7,852
Total deferred tax assets	229,753			224,996
Valuation allowance for deferred tax assets	(108,105		)	(40,484		)
Net, total deferred tax assets	121,648			184,512
Deferred tax liabilities:
Long-term contracts	569			3,601
Intangibles	21,215			21,892
Property, plant and equipment	2,835			—
Undistributed foreign earnings	1,314			500
Goodwill	—			1,125
Other	2,445			2,885
Total deferred tax liabilities	28,378			30,003
Net deferred tax assets	$	93,270		$	154,509

At December 31, 2017, we had a valuation allowance of $108.1 million for deferred tax assets, which we expect may not be realized through carrybacks, future reversals of existing taxable temporary differences and estimates 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 estimates of future taxable income. Should we conclude in the future that any or all of our deferred tax assets are not more likely than not to be realized, we would establish additional valuation allowances and 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:

(in thousands)	Beginning balance			Charges to costs and expenses			Charged to other accounts			Ending balance
Year Ended December 31, 2017	$	(40,484	)	$	(61,021	)	$	(6,600	)	$	(108,105	)
Year Ended December 31, 2016	(10,077		)	(29,307		)	(1,100		)	(40,484		)
Year Ended December 31, 2015	(9,216		)	(861		)	—			(10,077		)

We operate in numerous countries that have statutory tax rates below that of the 35% federal statutory rate that has been applicable to the United States through December 31, 2017. The most significant of these foreign operations are located in Canada, Denmark, Germany, Italy, Mexico, Sweden and the United Kingdom with effective tax rates ranging between 20% and approximately 30%. Income before the provision for income taxes was as follows:

	Year Ended December 31,
(in thousands)	2017			2016			2015
United States	$	(44,835	)	$	1,280		$	(20,748	)
Other than the United States	(269,364		)	(109,419		)	40,953
Income before provision for income taxes	$	(314,199	)	$	(108,139	)	$	20,205

The provision for income taxes consisted of:

	Year Ended December 31,
(in thousands)	2017			2016			2015
Current:
United States – federal	$	100		$	284		$	24,084
United States – state and local	397			(415		)	3,458
Other than in the United States	8,612			4,504			8,250
Total current	9,109			4,373			35,792
Deferred:
United States – Federal	58,203			11,512			(35,888		)
United States – state and local	2,546			6,365			(111		)
Other than in the United States	(5,042		)	(15,307		)	3,878
Total deferred (benefit) provision	55,707			2,570			(32,121		)
Provision for income taxes	$	64,816		$	6,943		$	3,671

The following is a reconciliation of the United States statutory federal tax rate (35%) to the consolidated effective tax rate:

	Year Ended December 31,
	2017		2016		2015
United States federal statutory rate	35.0	%	35.0	%	35.0	%
State and local income taxes	0.2		(3.5	)	13.8
Foreign rate differential	(9.5	)	(12.8	)	(13.1	)
Deferred Taxes - Change in Tax Rate	(19.9	)	—		—
Tax credits	0.9		3.0		(14.7	)
Dividends and deemed dividends from affiliates	(1.8	)	(0.2	)	1.7
Valuation allowances	(17.9	)	(28.1	)	4.3
Goodwill impairment	(7.0	)	—		—
Uncertain tax positions	—		0.3		(6.6	)
Non-deductible expenses	0.2		(1.8	)	2.4
Manufacturing deduction	—		—		(2.5	)
Other	(0.8	)	1.7		(2.1	)
Effective tax rate	(20.6	)%	(6.4	)%	18.2	%

We have foreign net operating loss benefits after tax of $75.0 million available to offset future taxable income in certain foreign jurisdictions. Of the foreign net operating loss benefits, $1.7 million is scheduled to expire in 2019 to 2026. The remaining net operating loss benefits have unlimited lives. We are carrying a valuation allowance of $66.0 million against the deferred tax asset related to the foreign loss carryforwards.

At December 31, 2017, we have a tax effected United States federal net operating loss of $20.7 million. The United States federal operating loss will begin to expire in 2037, and we expect to fully utilize this net operating loss in future periods. At December 31, 2017, we have foreign tax credit carryovers of $7.2 million, against which we have a full valuation allowance. At December 31, 2017, we have state net operating loss benefits after tax of $21.7 million available to offset future taxable income in various states, against which we have $21.6 million of valuation allowance. Our state net operating loss carryforwards begin to expire in the year 2018.

It has been our practice to reinvest indefinitely, the earnings of our foreign subsidiaries and that position has not changed as a result of the enactment of the U.S. Tax Cuts and Jobs Act. If we were to distribute earnings from certain foreign subsidiaries, we would be subject to withholding taxes of approximately $4.4 million but U.S. income taxes would generally not be imposed upon such distributions.

We operate in numerous countries that have statutory tax rates below that of the 35% federal statutory rate that has been applicable to the United States through December 31, 2017. The most significant of these foreign operations are located in Canada, Denmark, Germany, Italy, Mexico, Sweden and the United Kingdom with effective tax rates ranging between 20% and approximately 30%. Income before the provision for income taxes was as follows:

	Year Ended December 31,
(in thousands)	2017			2016			2015
United States	$	(44,835	)	$	1,280		$	(20,748	)
Other than the United States	(269,364		)	(109,419		)	40,953
Income before provision for income taxes	$	(314,199	)	$	(108,139	)	$	20,205

The following is a reconciliation of the United States statutory federal tax rate (35%) to the consolidated effective tax rate:

	Year Ended December 31,
	2017		2016		2015
United States federal statutory rate	35.0	%	35.0	%	35.0	%
State and local income taxes	0.2		(3.5	)	13.8
Foreign rate differential	(9.5	)	(12.8	)	(13.1	)
Deferred Taxes - Change in Tax Rate	(19.9	)	—		—
Tax credits	0.9		3.0		(14.7	)
Dividends and deemed dividends from affiliates	(1.8	)	(0.2	)	1.7
Valuation allowances	(17.9	)	(28.1	)	4.3
Goodwill impairment	(7.0	)	—		—
Uncertain tax positions	—		0.3		(6.6	)
Non-deductible expenses	0.2		(1.8	)	2.4
Manufacturing deduction	—		—		(2.5	)
Other	(0.8	)	1.7		(2.1	)
Effective tax rate	(20.6	)%	(6.4	)%	18.2	%

The provision for income taxes consisted of:

	Year Ended December 31,
(in thousands)	2017			2016			2015
Current:
United States – federal	$	100		$	284		$	24,084
United States – state and local	397			(415		)	3,458
Other than in the United States	8,612			4,504			8,250
Total current	9,109			4,373			35,792
Deferred:
United States – Federal	58,203			11,512			(35,888		)
United States – state and local	2,546			6,365			(111		)
Other than in the United States	(5,042		)	(15,307		)	3,878
Total deferred (benefit) provision	55,707			2,570			(32,121		)
Provision for income taxes	$	64,816		$	6,943		$	3,671

New Tax Act

The United States Tax Cuts and Jobs Act (the “Tax Act”) was enacted on December 22, 2017 and introduces significant changes to the United States income tax law. Beginning in 2018, the Tax Act reduces the United States statutory corporate income tax rate from 35% to 21% and creates a modified territorial system that will generally allow United States companies a full dividend received deduction for any future dividends from non-U.S. subsidiaries. In connection with the transition to a modified territorial system, the Tax Act also establishes a mandatory one-time deemed repatriation transition tax on currently deferred foreign earnings.

The SEC staff issued Staff Accounting Bulletin ("SAB 118"), which provides guidance on accounting for the tax effects of the Tax Act. SAB 118 provides a measurement period that should not extend beyond one year from the Tax Act enactment date for companies to complete the accounting under Accounting Standards Codification 740 ("ASC 740"). In accordance with SAB 118, we have made reasonable estimates of the effects of the Tax Act and recorded provisional amounts in our financial statements as of December 31, 2017. We will finalize our estimates in 2018 as we collect and analyze necessary data, and interpret additional guidance that becomes available.

Provisional amounts for the following income tax effects of the Tax Act have been recorded as of December 31, 2017:

Deferred tax effects

We remeasured our deferred taxes and recorded a deferred tax expense of $62.4 million. This amount consists of an expense for the corporate rate reduction of $54.4 million, expense of $0.8 million based on a change in our deferred taxes related to executive compensation and an expense of $7.2 million to record a valuation allowance on foreign tax credit carryforwards that are now expected to expire unused. While we are able to make a reasonable estimate of the deferred tax effects, our continued analysis of other aspects of the Tax Act could impact our estimate.

One-time transition tax

The Deemed Repatriation Transition Tax (Transition Tax) is a tax on previously untaxed accumulated and current earnings and profits (E&P) of certain of our foreign subsidiaries. To determine the amount of the Transition Tax, we must determine, in addition to other factors, the amount of post-1986 E&P of the relevant subsidiaries, as well as the amount of non-United States income taxes paid on such earnings. We are able to make a reasonable estimate of the Transition Tax and because we have estimated an E&P deficit, we have not recorded a Transition Tax. We are continuing to gather additional information to more precisely compute final E&P, including the computation of 2017 current year E&P which we will finalize with the 2017 tax return.

XML

Taxes Reconciliation of U.S. Statutory Federal Tax Rate (Tables)

12 Months Ended

Dec. 31, 2017

Reconciliation of U.S. Statutory Federal Tax Rate [Abstract]

Income Tax Disclosure [Text Block]

– PROVISION FOR INCOME TAXES

We are subject to federal income tax in the United States 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 both nominal rates and the basis on which these rates are applied. Our consolidated effective income tax rate can vary significantly from period to period due to these variations, changes in jurisdictional mix of our income and valuation allowances in certain jurisdictions that can offset income tax expense or benefit.

We are currently under audit by various domestic and international authorities. With few exceptions, we do not have any returns under examination for years prior to 2013. The United States Internal Revenue Service has completed examinations of the federal tax returns of BWC through 2014, and all matters arising from such examinations have been resolved.

We recognize the effect of income tax positions only if it is more-likely-than-not that those positions will be sustained. Recognized income tax positions are measured at the largest amount that is greater than 50% likely of being realized. Changes in recognition or measurement are reflected in the period in which the change in judgment occurs. Unrecognized tax benefits are as follows:

(in thousands)	2017			2016			2015
Balance at beginning of period	$	884		$	1,141		$	3,321
Increases based on tax positions taken in the current year	277			178			88
Increases based on tax positions taken in the prior years	56			230			248
Decreases based on tax positions taken in the prior years	(13		)	—			(1,161		)
Decreases due to settlements with tax authorities	—			(665		)	(1,355		)
Decreases due to lapse of applicable statute of limitation	—			—			—
Balance at end of period	$	1,204		$	884		$	1,141

The $1.2 million balance of unrecognized tax benefits at December 31, 2017 would decrease expense if recognized. We do not expect any of our unrecognized income tax benefits to be resolved in the next twelve months. We recognize interest and penalties related to unrecognized tax benefits in our provision for income taxes; however, such amounts are not significant to any period presented.

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, 2017 and 2016 were as follows:

	December 31,
(in thousands)	2017			2016
Deferred tax assets:
Pension liability	$	58,810		$	105,426
Accrued warranty expense	5,262			11,628
Accrued vacation pay	996			4,792
Accrued liabilities for self-insurance (including postretirement health care benefits)	3,910			6,596
Accrued liabilities for executive and employee incentive compensation	4,950			8,334
Investments in joint ventures and affiliated companies	10,422			10,742
Long-term contracts	6,801			10,318
Accrued Legal Fees	1,579			2,110
Inventory Reserve	1,842			2,445
Property, plant and equipment	—			1,587
Net operating loss carryforward	95,715			33,187
State tax net operating loss carryforward	21,658			15,372
Foreign tax credit carryforward	7,150			3,870
Other tax credits	5,678			737
Other	4,980			7,852
Total deferred tax assets	229,753			224,996
Valuation allowance for deferred tax assets	(108,105		)	(40,484		)
Net, total deferred tax assets	121,648			184,512
Deferred tax liabilities:
Long-term contracts	569			3,601
Intangibles	21,215			21,892
Property, plant and equipment	2,835			—
Undistributed foreign earnings	1,314			500
Goodwill	—			1,125
Other	2,445			2,885
Total deferred tax liabilities	28,378			30,003
Net deferred tax assets	$	93,270		$	154,509

At December 31, 2017, we had a valuation allowance of $108.1 million for deferred tax assets, which we expect may not be realized through carrybacks, future reversals of existing taxable temporary differences and estimates 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 estimates of future taxable income. Should we conclude in the future that any or all of our deferred tax assets are not more likely than not to be realized, we would establish additional valuation allowances and 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:

(in thousands)	Beginning balance			Charges to costs and expenses			Charged to other accounts			Ending balance
Year Ended December 31, 2017	$	(40,484	)	$	(61,021	)	$	(6,600	)	$	(108,105	)
Year Ended December 31, 2016	(10,077		)	(29,307		)	(1,100		)	(40,484		)
Year Ended December 31, 2015	(9,216		)	(861		)	—			(10,077		)

We operate in numerous countries that have statutory tax rates below that of the 35% federal statutory rate that has been applicable to the United States through December 31, 2017. The most significant of these foreign operations are located in Canada, Denmark, Germany, Italy, Mexico, Sweden and the United Kingdom with effective tax rates ranging between 20% and approximately 30%. Income before the provision for income taxes was as follows:

	Year Ended December 31,
(in thousands)	2017			2016			2015
United States	$	(44,835	)	$	1,280		$	(20,748	)
Other than the United States	(269,364		)	(109,419		)	40,953
Income before provision for income taxes	$	(314,199	)	$	(108,139	)	$	20,205

The provision for income taxes consisted of:

	Year Ended December 31,
(in thousands)	2017			2016			2015
Current:
United States – federal	$	100		$	284		$	24,084
United States – state and local	397			(415		)	3,458
Other than in the United States	8,612			4,504			8,250
Total current	9,109			4,373			35,792
Deferred:
United States – Federal	58,203			11,512			(35,888		)
United States – state and local	2,546			6,365			(111		)
Other than in the United States	(5,042		)	(15,307		)	3,878
Total deferred (benefit) provision	55,707			2,570			(32,121		)
Provision for income taxes	$	64,816		$	6,943		$	3,671

The following is a reconciliation of the United States statutory federal tax rate (35%) to the consolidated effective tax rate:

	Year Ended December 31,
	2017		2016		2015
United States federal statutory rate	35.0	%	35.0	%	35.0	%
State and local income taxes	0.2		(3.5	)	13.8
Foreign rate differential	(9.5	)	(12.8	)	(13.1	)
Deferred Taxes - Change in Tax Rate	(19.9	)	—		—
Tax credits	0.9		3.0		(14.7	)
Dividends and deemed dividends from affiliates	(1.8	)	(0.2	)	1.7
Valuation allowances	(17.9	)	(28.1	)	4.3
Goodwill impairment	(7.0	)	—		—
Uncertain tax positions	—		0.3		(6.6	)
Non-deductible expenses	0.2		(1.8	)	2.4
Manufacturing deduction	—		—		(2.5	)
Other	(0.8	)	1.7		(2.1	)
Effective tax rate	(20.6	)%	(6.4	)%	18.2	%

We have foreign net operating loss benefits after tax of $75.0 million available to offset future taxable income in certain foreign jurisdictions. Of the foreign net operating loss benefits, $1.7 million is scheduled to expire in 2019 to 2026. The remaining net operating loss benefits have unlimited lives. We are carrying a valuation allowance of $66.0 million against the deferred tax asset related to the foreign loss carryforwards.

At December 31, 2017, we have a tax effected United States federal net operating loss of $20.7 million. The United States federal operating loss will begin to expire in 2037, and we expect to fully utilize this net operating loss in future periods. At December 31, 2017, we have foreign tax credit carryovers of $7.2 million, against which we have a full valuation allowance. At December 31, 2017, we have state net operating loss benefits after tax of $21.7 million available to offset future taxable income in various states, against which we have $21.6 million of valuation allowance. Our state net operating loss carryforwards begin to expire in the year 2018.

It has been our practice to reinvest indefinitely, the earnings of our foreign subsidiaries and that position has not changed as a result of the enactment of the U.S. Tax Cuts and Jobs Act. If we were to distribute earnings from certain foreign subsidiaries, we would be subject to withholding taxes of approximately $4.4 million but U.S. income taxes would generally not be imposed upon such distributions.

We operate in numerous countries that have statutory tax rates below that of the 35% federal statutory rate that has been applicable to the United States through December 31, 2017. The most significant of these foreign operations are located in Canada, Denmark, Germany, Italy, Mexico, Sweden and the United Kingdom with effective tax rates ranging between 20% and approximately 30%. Income before the provision for income taxes was as follows:

	Year Ended December 31,
(in thousands)	2017			2016			2015
United States	$	(44,835	)	$	1,280		$	(20,748	)
Other than the United States	(269,364		)	(109,419		)	40,953
Income before provision for income taxes	$	(314,199	)	$	(108,139	)	$	20,205

The following is a reconciliation of the United States statutory federal tax rate (35%) to the consolidated effective tax rate:

	Year Ended December 31,
	2017		2016		2015
United States federal statutory rate	35.0	%	35.0	%	35.0	%
State and local income taxes	0.2		(3.5	)	13.8
Foreign rate differential	(9.5	)	(12.8	)	(13.1	)
Deferred Taxes - Change in Tax Rate	(19.9	)	—		—
Tax credits	0.9		3.0		(14.7	)
Dividends and deemed dividends from affiliates	(1.8	)	(0.2	)	1.7
Valuation allowances	(17.9	)	(28.1	)	4.3
Goodwill impairment	(7.0	)	—		—
Uncertain tax positions	—		0.3		(6.6	)
Non-deductible expenses	0.2		(1.8	)	2.4
Manufacturing deduction	—		—		(2.5	)
Other	(0.8	)	1.7		(2.1	)
Effective tax rate	(20.6	)%	(6.4	)%	18.2	%

The provision for income taxes consisted of:

	Year Ended December 31,
(in thousands)	2017			2016			2015
Current:
United States – federal	$	100		$	284		$	24,084
United States – state and local	397			(415		)	3,458
Other than in the United States	8,612			4,504			8,250
Total current	9,109			4,373			35,792
Deferred:
United States – Federal	58,203			11,512			(35,888		)
United States – state and local	2,546			6,365			(111		)
Other than in the United States	(5,042		)	(15,307		)	3,878
Total deferred (benefit) provision	55,707			2,570			(32,121		)
Provision for income taxes	$	64,816		$	6,943		$	3,671

New Tax Act

The United States Tax Cuts and Jobs Act (the “Tax Act”) was enacted on December 22, 2017 and introduces significant changes to the United States income tax law. Beginning in 2018, the Tax Act reduces the United States statutory corporate income tax rate from 35% to 21% and creates a modified territorial system that will generally allow United States companies a full dividend received deduction for any future dividends from non-U.S. subsidiaries. In connection with the transition to a modified territorial system, the Tax Act also establishes a mandatory one-time deemed repatriation transition tax on currently deferred foreign earnings.

The SEC staff issued Staff Accounting Bulletin ("SAB 118"), which provides guidance on accounting for the tax effects of the Tax Act. SAB 118 provides a measurement period that should not extend beyond one year from the Tax Act enactment date for companies to complete the accounting under Accounting Standards Codification 740 ("ASC 740"). In accordance with SAB 118, we have made reasonable estimates of the effects of the Tax Act and recorded provisional amounts in our financial statements as of December 31, 2017. We will finalize our estimates in 2018 as we collect and analyze necessary data, and interpret additional guidance that becomes available.

Provisional amounts for the following income tax effects of the Tax Act have been recorded as of December 31, 2017:

Deferred tax effects

We remeasured our deferred taxes and recorded a deferred tax expense of $62.4 million. This amount consists of an expense for the corporate rate reduction of $54.4 million, expense of $0.8 million based on a change in our deferred taxes related to executive compensation and an expense of $7.2 million to record a valuation allowance on foreign tax credit carryforwards that are now expected to expire unused. While we are able to make a reasonable estimate of the deferred tax effects, our continued analysis of other aspects of the Tax Act could impact our estimate.

One-time transition tax

The Deemed Repatriation Transition Tax (Transition Tax) is a tax on previously untaxed accumulated and current earnings and profits (E&P) of certain of our foreign subsidiaries. To determine the amount of the Transition Tax, we must determine, in addition to other factors, the amount of post-1986 E&P of the relevant subsidiaries, as well as the amount of non-United States income taxes paid on such earnings. We are able to make a reasonable estimate of the Transition Tax and because we have estimated an E&P deficit, we have not recorded a Transition Tax. We are continuing to gather additional information to more precisely compute final E&P, including the computation of 2017 current year E&P which we will finalize with the 2017 tax return.

XML

Leases & Debt Obligations (Tables)

12 Months Ended

Dec. 31, 2017

Lease Obligations [Abstract]

Operating Leases of Lessee Disclosure [Table Text Block]

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, 2017 are as follows (in thousands):

Fiscal Year Ending December 31,	Amount
2018	$	6,814
2019	$	5,100
2020	$	3,553
2021	$	2,741
2022	$	2,258
Thereafter	$	3,337

Total rental expense for the years ended December 31, 2017, 2016 and 2015, was $10.5 million, $8.3 million and $13.5 million, respectively.

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Leases & Debt Obligations Long-Term Borrowings Obligations (Tables)

12 Months Ended

Dec. 31, 2017

Lease Obligations [Abstract]

Schedule of Short-term Debt [Table Text Block]

Long-term borrowings

Maturities of our long-term borrowings in the five years succeeding December 31, 2017 are as follows (in thousands):

Fiscal year ending December 31,	Amount
2018	$	9,173
2019	$	—
2020	$	290,184
2021	$	—
2022	$	—
Thereafter	$	—

XML

Second Lien Term Loan Facility (Tables)

12 Months Ended

Dec. 31, 2017

Debt Instrument [Line Items]

Long-term Debt [Text Block]

The components of our revolving debt are comprised of separate revolving credit facilities in the following locations:

(in thousands)	December 31, 2017		December 31, 2016
United States	$	94,300	$	9,800
Foreign	9,173		14,241
Total revolving debt	$	103,473	$	24,041

United States revolving credit facility

On May 11, 2015, we entered into a credit agreement with a syndicate of lenders ("Credit Agreement") in connection with our spin-off from The Babcock & Wilcox Company. The Credit Agreement, which is scheduled to mature on June 30, 2020, provides for a senior secured revolving credit facility, initially in an aggregate amount of up to $600.0 million. The proceeds from loans under the Credit Agreement are available for working capital needs and other general corporate purposes, and the full amount is available to support the issuance of letters of credit.

On February 24, 2017, August 9, 2017 and March 1, 2018, we entered into amendments to the Credit Agreement (the "Amendments" and the Credit Agreement, as amended to date, the "Amended Credit Agreement") to, among other things: (1) permit us to incur the debt under the second lien term loan facility (discussed further in Note 20), (2) modify the definition of EBITDA in the Amended Credit Agreement to exclude: up to $98.1 million of charges for certain Renewable segment contracts for periods including the quarter ended December 31, 2016, up to $115.2 million of charges for certain Renewable segment contracts for periods including the quarter ended June 30, 2017, up to $30.1 million of charges for certain Renewable segment contracts for periods including the quarter ended September 30, 2017, up to $38.7 million of charges for certain Renewable segment contracts for periods including the quarter ended December 31, 2017, up to $4.0 million of aggregate restructuring expenses incurred during the period from July 1, 2017 through September 30, 2018 measured on a consecutive four-quarter basis, realized and unrealized foreign exchange losses resulting from the impact of foreign currency changes on the valuation of assets and liabilities, and fees and expenses incurred in connection with the August 9, 2017 and March 1, 2018 amendments, (3) replace the maximum leverage ratio with a maximum senior debt leverage ratio, (4) decrease the minimum consolidated interest coverage ratio, (5) limit our ability to borrow under the Amended Credit Agreement during the covenant relief period to $250.0 million in the aggregate, (6) reduce commitments under the revolving credit facility from $600.0 million to $450.0 million, (7) require us to maintain liquidity (as defined in the Amended Credit Agreement) of at least $75.0 million as of the last business day of any calendar month, (8) require us to repay outstanding borrowings under the revolving credit facility (without any reduction in commitments) with certain excess cash, (9) increase the pricing for borrowings and commitment fees under the Amended Credit Agreement, (10) limit our ability to incur debt and liens during the covenant relief period, (11) limit our ability to make acquisitions and investments in third parties during the covenant relief period, (12) prohibit us from paying dividends and undertaking stock repurchases during the covenant relief period (other than our share repurchase from an affiliate of AIP (discussed further in Note 20)), (13) prohibit us from exercising the accordion described below during the covenant relief period, (14) limit our financial and commercial letters of credit outstanding under the Amended Credit Agreement to $30.0 million, (15) require us to reduce commitments under the Amended Credit Agreement with the proceeds of certain debt issuances and asset sales, (16) beginning with the quarter ended March 31, 2018, limit to no more than $15.0 million any cumulative net income losses attributable to eight specified Vølund projects, (17) increase reporting obligations and require us to hire a third-party consultant and a chief implementation officer, (18) require us to pledge the equity of certain of our foreign subsidiaries to guarantee and provide collateral for our obligations under the United States credit facility, (19) require us to pay a deferred facility fee as more fully set forth in the March 1, 2018 Amendment, and (20) require us to sell at least $100 million of assets before March 31, 2019. The covenant relief period will end, at our election, when the conditions set forth in the Amended Credit Agreement are satisfied, but in no event earlier than the date on which we provide the compliance certificate for our fiscal quarter ended December 31, 2019.

Other than during the covenant relief period, the Amended Credit Agreement contains an accordion feature that allows us, subject to the satisfaction of certain conditions, including the receipt of increased commitments from existing lenders or new commitments from new lenders, to increase the amount of the commitments under the revolving credit facility in an aggregate amount not to exceed the sum of (1) $200.0 million plus (2) an unlimited amount, so long as for any commitment increase under this subclause (2) our senior leverage ratio (assuming the full amount of any commitment increase under this subclause (2) is drawn) is equal to or less than 2.00:1.0 after giving pro forma effect thereto. During the covenant relief period, our ability to exercise the accordion feature will be prohibited.

The Amended Credit Agreement and our obligations under certain hedging agreements and cash management agreements with our lenders and their affiliates are (1) guaranteed by substantially all of our wholly owned domestic subsidiaries, but excluding our captive insurance subsidiary, and (2) secured by first-priority liens on certain assets owned by us and the guarantors. The Amended Credit Agreement requires interest payments on revolving loans on a periodic basis until maturity. We may prepay all loans at any time without premium or penalty (other than customary LIBOR breakage costs), subject to notice requirements. The Amended Credit Agreement requires us to make certain prepayments on any outstanding revolving loans after receipt of cash proceeds from certain asset sales or other events, subject to certain exceptions and a right to reinvest such proceeds in certain circumstances. During the covenant relief period, such prepayments may require us to reduce the commitments under the Amended Credit Agreement by a corresponding amount of such prepayments. Following the covenant relief period, such prepayments will not require us to reduce the commitments under the Amended Credit Agreement.

The March 1, 2018 Amendment temporarily waived certain defaults and events of default under our United States credit facility that were breached on December 31, 2017 or that may occur in the future, with certain amendments effective immediately and other amendments effective upon the completion of the Rights Offering and the repayment of the outstanding balance of our Second Lien Notes Offering. If the Rights Offering and the repayment of the outstanding balance of our Second Lien Notes Offering do not occur by April 15, 2018 (subject to extension in certain cases), the temporary waiver will end. The temporary waiver will also end if certain other conditions specified in the March 1, 2018 Amendment occur. Upon any such termination of the waiver, our ability to borrow funds under the United States credit facility will terminate.

After giving effect to the Amendments, loans outstanding under the Amended Credit Agreement bear interest at our option at either LIBOR rate plus 7.0% per annum or the Base Rate plus 6.0% per annum until we complete the Rights Offering and prepay the Second Lien Term Loan facility and thereafter at our option at either (1) the LIBOR rate plus 5.0% per annum during 2018, 6.0% per annum during 2019 and 7.0% per annum during 2020, or (2) the Base Rate plus 4.0% per annum during 2018, 5.0% per annum during 2019, and 6.0% per annum during 2020. The Base Rate is the highest of the Federal Funds rate plus 0.5%, the one month LIBOR rate plus 1.0%, or the administrative agent's prime rate. Interest expense associated with our United States revolving credit facility loans for the year ended December 31, 2017 was $11.3 million, respectively. Included in interest expense was $6.3 million of non-cash amortization of direct financing costs for the year ended December 31, 2017. A commitment fee of 1.0% per annum is charged on the unused portions of the revolving credit facility. A letter of credit fee of 2.50% per annum is charged with respect to the amount of each financial letter of credit outstanding, and a letter of credit fee of 1.50% per annum is charged with respect to the amount of each performance and commercial letter of credit outstanding. Additionally, an annual facility fee of $1.5 million is payable on the first business day of 2018 and 2019, and a pro rated amount is payable on the first business day of 2020.

The Amended Credit Agreement includes financial covenants that are tested on a quarterly basis, based on the rolling four-quarter period that ends on the last day of each fiscal quarter. After we complete the Rights Offering and the repayment of the outstanding balance of our Second Lien Notes Offering within the time period required by the March 1, 2018 Amendment, the maximum permitted senior debt leverage ratio as defined in the Amended Credit Agreement is:

• 8.50:1.0 for the quarter ended December 31, 2017,

• 7.00:1.0 for the quarter ending March 31, 2018,

• 6.50:1.0 for the quarters ending June 30, 2018 and September 30, 2018,

• 4.75:1.0 for the quarter ending December 31, 2018,

• 3.00:1.0 for the quarter ending March 31, 2019,

• 2.75:1.0 for the quarters ending June 30, 2019 and September 30, 2019 and

• 2.50:1.0 for the quarter ending December 31, 2019 and each quarter thereafter.

After we complete the Rights Offering and the repayment of the outstanding balance of our Second Lien Notes Offering within the time period required by the March 1, 2018 Amendment, the minimum consolidated interest coverage ratio as defined in the Credit Agreement is:

• 1.25:1.0 for the quarter ended December 31, 2017,

• 1.15:1.0 for the quarter ending March 31, 2018,

• 1.00:1.0 for the quarter ending June 30, 2018,

• 0.85:1.0 for the quarter ending September 30, 2018,

• 1.25:1.0 for the quarter ending December 31, 2018,

• 1.50:1.0 for the quarter ending March 31, 2019 and

• 2.00:1.0 for the quarters ending June 30, 2019 and each quarter thereafter.

Beginning with September 30, 2017, consolidated capital expenditures in each fiscal year are limited to $27.5 million.

At December 31, 2017, borrowings under the Amended Credit Agreement and foreign facilities consisted of $103.5 million at an effective interest rate of 6.89%. Usage under the Amended Credit Agreement consisted of $94.3 million of borrowings, $7.4 million of financial letters of credit and $123.7 million of performance letters of credit. After giving effect to the March 1, 2018 amendment, at December 31, 2017, we had approximately $221.4 million available for borrowings or to meet letter of credit requirements primarily based on trailing 12 month EBITDA (as defined in the Amended Credit Agreement), and our leverage and interest coverage ratios (as defined in the Amended Credit Agreement) were 2.59 and 2.50, respectively. We expect to be closest to the minimum financial covenant thresholds at September 30, 2018.

Foreign revolving credit facilities

Outside of the United States, we have revolving credit facilities in Turkey and India that are used to provide working capital to our operations in each country. These foreign revolving credit facilities allow us to borrow up to $9.2 million in aggregate and each have a one year term. At December 31, 2017, we had $9.2 million in borrowings outstanding under these foreign revolving credit facilities at an effective weighted-average interest rate of 6.07%. Subsequent to December 31, 2017, the foreign facilities were repaid and extinguished.

Letters of credit, bank guarantees and surety bonds

Certain subsidiaries primarily outside of the United States have credit arrangements with various commercial banks and other financial institutions for the issuance of letters of credit and bank guarantees in association with contracting activity. The aggregate value of all such letters of credit and bank guarantees not secured by the United States revolving credit facility as of December 31, 2017 and 2016 was $269.1 million and $255.2 million, respectively. The aggregate value of all such letters of credit and bank guarantees that are partially secured by the United States revolving credit facility as of December 31, 2017 was $114.2 million. The aggregate value of the letters of credit provided by the Company's United States revolving credit facility in support of letters of credit outside of the United States was $40.4 million as of December 31, 2017.

We have posted surety bonds to support contractual obligations to customers relating to certain contracts. 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 adequate to support our existing contract requirements for the next 12 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, 2017, bonds issued and outstanding under these arrangements in support of contracts totaled approximately $378.8 million.

Interest expense associated with our second lien credit agreement is comprised of the following:

(in thousands)	Coupon Interest	Accretion of debt discount and amortization of financing costs	Total Interest Expense
For the three months ended September 30, 2017	$2,554	$1,095	$3,649
For the three months ended December 31, 2017	$4,657	$2,131	$6,788
Forecasted for the year ending December 31, 2018	$20,266	$9,838	$30,104

The carrying value of the second lien term loan facility at December 31, 2017 was as follows (in thousands):

Face value	Unamortized debt discount and direct financing costs	Net carrying value
$195,884	$35,743	$160,141

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Second Lien Term Loan Facility Interest Expense (Tables)

12 Months Ended

Dec. 31, 2017

Interest Expense [Abstract]

Long-term Debt [Text Block]

The components of our revolving debt are comprised of separate revolving credit facilities in the following locations:

(in thousands)	December 31, 2017		December 31, 2016
United States	$	94,300	$	9,800
Foreign	9,173		14,241
Total revolving debt	$	103,473	$	24,041

United States revolving credit facility

On May 11, 2015, we entered into a credit agreement with a syndicate of lenders ("Credit Agreement") in connection with our spin-off from The Babcock & Wilcox Company. The Credit Agreement, which is scheduled to mature on June 30, 2020, provides for a senior secured revolving credit facility, initially in an aggregate amount of up to $600.0 million. The proceeds from loans under the Credit Agreement are available for working capital needs and other general corporate purposes, and the full amount is available to support the issuance of letters of credit.

On February 24, 2017, August 9, 2017 and March 1, 2018, we entered into amendments to the Credit Agreement (the "Amendments" and the Credit Agreement, as amended to date, the "Amended Credit Agreement") to, among other things: (1) permit us to incur the debt under the second lien term loan facility (discussed further in Note 20), (2) modify the definition of EBITDA in the Amended Credit Agreement to exclude: up to $98.1 million of charges for certain Renewable segment contracts for periods including the quarter ended December 31, 2016, up to $115.2 million of charges for certain Renewable segment contracts for periods including the quarter ended June 30, 2017, up to $30.1 million of charges for certain Renewable segment contracts for periods including the quarter ended September 30, 2017, up to $38.7 million of charges for certain Renewable segment contracts for periods including the quarter ended December 31, 2017, up to $4.0 million of aggregate restructuring expenses incurred during the period from July 1, 2017 through September 30, 2018 measured on a consecutive four-quarter basis, realized and unrealized foreign exchange losses resulting from the impact of foreign currency changes on the valuation of assets and liabilities, and fees and expenses incurred in connection with the August 9, 2017 and March 1, 2018 amendments, (3) replace the maximum leverage ratio with a maximum senior debt leverage ratio, (4) decrease the minimum consolidated interest coverage ratio, (5) limit our ability to borrow under the Amended Credit Agreement during the covenant relief period to $250.0 million in the aggregate, (6) reduce commitments under the revolving credit facility from $600.0 million to $450.0 million, (7) require us to maintain liquidity (as defined in the Amended Credit Agreement) of at least $75.0 million as of the last business day of any calendar month, (8) require us to repay outstanding borrowings under the revolving credit facility (without any reduction in commitments) with certain excess cash, (9) increase the pricing for borrowings and commitment fees under the Amended Credit Agreement, (10) limit our ability to incur debt and liens during the covenant relief period, (11) limit our ability to make acquisitions and investments in third parties during the covenant relief period, (12) prohibit us from paying dividends and undertaking stock repurchases during the covenant relief period (other than our share repurchase from an affiliate of AIP (discussed further in Note 20)), (13) prohibit us from exercising the accordion described below during the covenant relief period, (14) limit our financial and commercial letters of credit outstanding under the Amended Credit Agreement to $30.0 million, (15) require us to reduce commitments under the Amended Credit Agreement with the proceeds of certain debt issuances and asset sales, (16) beginning with the quarter ended March 31, 2018, limit to no more than $15.0 million any cumulative net income losses attributable to eight specified Vølund projects, (17) increase reporting obligations and require us to hire a third-party consultant and a chief implementation officer, (18) require us to pledge the equity of certain of our foreign subsidiaries to guarantee and provide collateral for our obligations under the United States credit facility, (19) require us to pay a deferred facility fee as more fully set forth in the March 1, 2018 Amendment, and (20) require us to sell at least $100 million of assets before March 31, 2019. The covenant relief period will end, at our election, when the conditions set forth in the Amended Credit Agreement are satisfied, but in no event earlier than the date on which we provide the compliance certificate for our fiscal quarter ended December 31, 2019.

Other than during the covenant relief period, the Amended Credit Agreement contains an accordion feature that allows us, subject to the satisfaction of certain conditions, including the receipt of increased commitments from existing lenders or new commitments from new lenders, to increase the amount of the commitments under the revolving credit facility in an aggregate amount not to exceed the sum of (1) $200.0 million plus (2) an unlimited amount, so long as for any commitment increase under this subclause (2) our senior leverage ratio (assuming the full amount of any commitment increase under this subclause (2) is drawn) is equal to or less than 2.00:1.0 after giving pro forma effect thereto. During the covenant relief period, our ability to exercise the accordion feature will be prohibited.

The Amended Credit Agreement and our obligations under certain hedging agreements and cash management agreements with our lenders and their affiliates are (1) guaranteed by substantially all of our wholly owned domestic subsidiaries, but excluding our captive insurance subsidiary, and (2) secured by first-priority liens on certain assets owned by us and the guarantors. The Amended Credit Agreement requires interest payments on revolving loans on a periodic basis until maturity. We may prepay all loans at any time without premium or penalty (other than customary LIBOR breakage costs), subject to notice requirements. The Amended Credit Agreement requires us to make certain prepayments on any outstanding revolving loans after receipt of cash proceeds from certain asset sales or other events, subject to certain exceptions and a right to reinvest such proceeds in certain circumstances. During the covenant relief period, such prepayments may require us to reduce the commitments under the Amended Credit Agreement by a corresponding amount of such prepayments. Following the covenant relief period, such prepayments will not require us to reduce the commitments under the Amended Credit Agreement.

The March 1, 2018 Amendment temporarily waived certain defaults and events of default under our United States credit facility that were breached on December 31, 2017 or that may occur in the future, with certain amendments effective immediately and other amendments effective upon the completion of the Rights Offering and the repayment of the outstanding balance of our Second Lien Notes Offering. If the Rights Offering and the repayment of the outstanding balance of our Second Lien Notes Offering do not occur by April 15, 2018 (subject to extension in certain cases), the temporary waiver will end. The temporary waiver will also end if certain other conditions specified in the March 1, 2018 Amendment occur. Upon any such termination of the waiver, our ability to borrow funds under the United States credit facility will terminate.

After giving effect to the Amendments, loans outstanding under the Amended Credit Agreement bear interest at our option at either LIBOR rate plus 7.0% per annum or the Base Rate plus 6.0% per annum until we complete the Rights Offering and prepay the Second Lien Term Loan facility and thereafter at our option at either (1) the LIBOR rate plus 5.0% per annum during 2018, 6.0% per annum during 2019 and 7.0% per annum during 2020, or (2) the Base Rate plus 4.0% per annum during 2018, 5.0% per annum during 2019, and 6.0% per annum during 2020. The Base Rate is the highest of the Federal Funds rate plus 0.5%, the one month LIBOR rate plus 1.0%, or the administrative agent's prime rate. Interest expense associated with our United States revolving credit facility loans for the year ended December 31, 2017 was $11.3 million, respectively. Included in interest expense was $6.3 million of non-cash amortization of direct financing costs for the year ended December 31, 2017. A commitment fee of 1.0% per annum is charged on the unused portions of the revolving credit facility. A letter of credit fee of 2.50% per annum is charged with respect to the amount of each financial letter of credit outstanding, and a letter of credit fee of 1.50% per annum is charged with respect to the amount of each performance and commercial letter of credit outstanding. Additionally, an annual facility fee of $1.5 million is payable on the first business day of 2018 and 2019, and a pro rated amount is payable on the first business day of 2020.

The Amended Credit Agreement includes financial covenants that are tested on a quarterly basis, based on the rolling four-quarter period that ends on the last day of each fiscal quarter. After we complete the Rights Offering and the repayment of the outstanding balance of our Second Lien Notes Offering within the time period required by the March 1, 2018 Amendment, the maximum permitted senior debt leverage ratio as defined in the Amended Credit Agreement is:

• 8.50:1.0 for the quarter ended December 31, 2017,

• 7.00:1.0 for the quarter ending March 31, 2018,

• 6.50:1.0 for the quarters ending June 30, 2018 and September 30, 2018,

• 4.75:1.0 for the quarter ending December 31, 2018,

• 3.00:1.0 for the quarter ending March 31, 2019,

• 2.75:1.0 for the quarters ending June 30, 2019 and September 30, 2019 and

• 2.50:1.0 for the quarter ending December 31, 2019 and each quarter thereafter.

After we complete the Rights Offering and the repayment of the outstanding balance of our Second Lien Notes Offering within the time period required by the March 1, 2018 Amendment, the minimum consolidated interest coverage ratio as defined in the Credit Agreement is:

• 1.25:1.0 for the quarter ended December 31, 2017,

• 1.15:1.0 for the quarter ending March 31, 2018,

• 1.00:1.0 for the quarter ending June 30, 2018,

• 0.85:1.0 for the quarter ending September 30, 2018,

• 1.25:1.0 for the quarter ending December 31, 2018,

• 1.50:1.0 for the quarter ending March 31, 2019 and

• 2.00:1.0 for the quarters ending June 30, 2019 and each quarter thereafter.

Beginning with September 30, 2017, consolidated capital expenditures in each fiscal year are limited to $27.5 million.

At December 31, 2017, borrowings under the Amended Credit Agreement and foreign facilities consisted of $103.5 million at an effective interest rate of 6.89%. Usage under the Amended Credit Agreement consisted of $94.3 million of borrowings, $7.4 million of financial letters of credit and $123.7 million of performance letters of credit. After giving effect to the March 1, 2018 amendment, at December 31, 2017, we had approximately $221.4 million available for borrowings or to meet letter of credit requirements primarily based on trailing 12 month EBITDA (as defined in the Amended Credit Agreement), and our leverage and interest coverage ratios (as defined in the Amended Credit Agreement) were 2.59 and 2.50, respectively. We expect to be closest to the minimum financial covenant thresholds at September 30, 2018.

Foreign revolving credit facilities

Outside of the United States, we have revolving credit facilities in Turkey and India that are used to provide working capital to our operations in each country. These foreign revolving credit facilities allow us to borrow up to $9.2 million in aggregate and each have a one year term. At December 31, 2017, we had $9.2 million in borrowings outstanding under these foreign revolving credit facilities at an effective weighted-average interest rate of 6.07%. Subsequent to December 31, 2017, the foreign facilities were repaid and extinguished.

Letters of credit, bank guarantees and surety bonds

Certain subsidiaries primarily outside of the United States have credit arrangements with various commercial banks and other financial institutions for the issuance of letters of credit and bank guarantees in association with contracting activity. The aggregate value of all such letters of credit and bank guarantees not secured by the United States revolving credit facility as of December 31, 2017 and 2016 was $269.1 million and $255.2 million, respectively. The aggregate value of all such letters of credit and bank guarantees that are partially secured by the United States revolving credit facility as of December 31, 2017 was $114.2 million. The aggregate value of the letters of credit provided by the Company's United States revolving credit facility in support of letters of credit outside of the United States was $40.4 million as of December 31, 2017.

We have posted surety bonds to support contractual obligations to customers relating to certain contracts. 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 adequate to support our existing contract requirements for the next 12 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, 2017, bonds issued and outstanding under these arrangements in support of contracts totaled approximately $378.8 million.

Interest expense associated with our second lien credit agreement is comprised of the following:

(in thousands)	Coupon Interest	Accretion of debt discount and amortization of financing costs	Total Interest Expense
For the three months ended September 30, 2017	$2,554	$1,095	$3,649
For the three months ended December 31, 2017	$4,657	$2,131	$6,788
Forecasted for the year ending December 31, 2018	$20,266	$9,838	$30,104

The carrying value of the second lien term loan facility at December 31, 2017 was as follows (in thousands):

Face value	Unamortized debt discount and direct financing costs	Net carrying value
$195,884	$35,743	$160,141

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Significant Accounting Policies Research and Development (Details) - USD ($) $ in Thousands	3 Months Ended								12 Months Ended
	Dec. 31, 2017	Sep. 30, 2017	Jun. 30, 2017	Mar. 31, 2017	Dec. 31, 2016	Sep. 30, 2016	Jun. 30, 2016	Mar. 31, 2016	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Research and Development [Abstract]
Research and development costs									$ 9,400	$ 10,400	$ 16,500
Revenues	$ 408,099	$ 408,703	$ 349,829	$ 391,104	$ 379,984	$ 410,955	$ 383,208	$ 404,116	$ 1,557,735	$ 1,578,263	1,757,295
(Gain) Loss on Disposition of Property Plant Equipment, Excluding Oil and Gas Property and Timber Property											$ 14,600

XML

Significant Accounting Policies Inventories (Details) - USD ($) $ in Millions	Dec. 31, 2017	Dec. 31, 2016
Inventories [Abstract]
Percentage of LIFO Inventory	16.00%	18.00%
Inventory, LIFO Reserve	$ 7.0	$ 7.0

XML

Significant Accounting Policies Property, Plant and Equipment (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Inventories [Abstract]
Depreciation	$ 21.9	$ 19.7	$ 23.5

XML

Significant Accounting Policies Self Insurance (Details) - USD ($) $ in Millions	Dec. 31, 2017	Dec. 31, 2016
Inventories [Abstract]
Self Insurance Reserve	$ 23.1	$ 24.1

XML

Significant Accounting Policies Foreign Currency Translation (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Foreign Currency Translation [Abstract]
Foreign Currency Transaction Gain (Loss), before Tax	$ 2.9	$ (5.4)	$ (0.1)

XML

Significant Accounting Policies Trade accounts receivable and allowance for doubtful accounts (Details) - USD ($) $ in Millions	Dec. 31, 2017	Dec. 31, 2016
Accounts, Notes, Loans and Financing Receivable [Line Items]
Allowance for Doubtful Accounts Receivable	$ 11.0	$ 9.4

XML

Earnings Per Share - Additional Information (Detail) - USD ($) shares in Millions, $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]
Excluded shares from the WAS to calculated diluted EPS as company was in a net loss position	$ 0.4	$ 0.5
Antidilutive Securities Excluded from Computation of Earnings Per Share, Amount	2.0	3.4	1.3

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Earnings Per Share - Computation of Basic and Diluted Earnings Per Share (Detail) - USD ($) $ / shares in Units, shares in Thousands, $ in Thousands	3 Months Ended								12 Months Ended
	Dec. 31, 2017	Sep. 30, 2017	Jun. 30, 2017	Mar. 31, 2017	Dec. 31, 2016	Sep. 30, 2016	Jun. 30, 2016	Mar. 31, 2016	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Income (loss) from continuing operations									$ (379,824)	$ (115,649)	$ 16,338
Income (loss) from discontinued operations, net of tax									0	0	2,803
Net income (loss) attributable to stockholders	$ (107,478)	$ (114,302)	$ (150,999)	$ (7,045)	$ (71,560)	$ 8,894	$ (63,490)	$ 10,507	(379,824)	(115,649)	$ 19,141
Excluded shares from the WAS to calculated diluted EPS as company was in a net loss position									$ 400	$ 500
Antidilutive Securities Excluded from Computation of Earnings Per Share, Amount									2,000	3,400	1,300
Effect of dilutive securities:
Weighted average shares used to calculate basic earnings per share									46,935	50,129	53,487
Dilutive effect of stock options, restricted stock and performance shares									0	0	222
Weighted average shares used to calculate diluted earnings per share									46,935	50,129	53,709
Basic earnings per common share:
Basic earnings (loss) per share from continuing operations	$ (2.44)	$ (2.48)	$ (3.09)	$ (0.14)	$ (1.47)	$ 0.18	$ (1.25)	$ 0.20	$ (8.09)	$ (2.31)	$ 0.31
Basic earnings (loss) per share from Discontinued operations									0.00	0.00	0.05
Basic earnings (loss) per share									(8.09)	(2.31)	0.36
Basic earnings (loss) per share - discontinued operations
Diluted earnings (loss) per share from Continuing operations	$ (2.44)	$ (2.48)	$ (3.09)	$ (0.14)	$ (1.47)	$ 0.18	$ (1.25)	$ 0.20	(8.09)	(2.31)	0.30
Diluted earnings (loss) per share from discontinued operations									0.00	0.00	0.06
Diluted earnings (loss) per share									$ (8.09)	$ (2.31)	$ 0.36

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Segment Reporting Additional Information (Detail) (Details)	12 Months Ended
	Dec. 31, 2017 segment
Segment Reporting, Disclosure of Entity's Reportable Segments [Abstract]
Number of Reportable Segments	3

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Segment Reporting Schedule of Operating Results by Segment (Details) - USD ($) $ in Thousands	3 Months Ended								12 Months Ended
	Dec. 31, 2017	Sep. 30, 2017	Jun. 30, 2017	Mar. 31, 2017	Dec. 31, 2016	Sep. 30, 2016	Jun. 30, 2016	Mar. 31, 2016	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Industrial [Abstract]
Eliminations									$ (8,316)	$ (6,500)	$ 0
Revenues	$ 408,099	$ 408,703	$ 349,829	$ 391,104	$ 379,984	$ 410,955	$ 383,208	$ 404,116	1,557,735	1,578,263	1,757,295
Power [Member]
Power [Abstract]
Retrofits & continuous emissions monitoring systems									306,758	392,854	427,378
New build utility and environmental									155,886	292,302	403,981
Aftermarket parts and field engineering services									277,129	292,535	304,923
Industrial steam generation									123,127	107,267	219,379
Eliminations (Power)									(41,838)	(102,980)	(120,664)
Industrial [Abstract]
Revenues									821,062	981,978	1,234,997
Renewable [Domain] [Domain]
Renewable [Abstract]
Renewable new build and services									282,228	284,684	277,326
Operations and maintenance									64,970	65,814	63,437
Eliminations (Renewable)									0	(1,326)	(2,160)
Industrial [Abstract]
Revenues									347,198	349,172	338,603
Industrial [Domain]
Industrial [Abstract]
Industrial aftermarket parts and services									117,970	81,690	61,350
Environmental solutions									138,722	74,726	90,343
Cooling systems									126,683	73,797	0
Engineered products									14,416	23,400	32,002
Revenues									$ 397,791	$ 253,613	$ 183,695

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Segment Reporting Schedule of Gross Profit (Loss) by Segment (Details) - USD ($) $ in Thousands	3 Months Ended								12 Months Ended
	Dec. 31, 2017	Sep. 30, 2017	Jun. 30, 2017	Mar. 31, 2017	Dec. 31, 2016	Sep. 30, 2016	Jun. 30, 2016	Mar. 31, 2016	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
GROSS PROFIT (LOSS)
Gross profit (loss)	$ 45,513	$ 47,287	$ (55,822)	$ 62,900	$ (848)	$ 73,757	$ 26,052	$ 80,156	$ 99,878	$ 179,117	$ 308,157
SG&A less pension MTM adjustment									(255,545)	(240,166)	(240,296)
Goodwill impairment charges									(86,903)	0	0
Restructuring activities and spin-off transaction costs									(15,447)	(40,807)	(14,946)
Research and development costs									(9,412)	(10,406)	(16,543)
Mark to market gain (loss) included in SG&A									(8,696)	24,110	40,210
Equity in Income of Investees									8,326	16,440	(242)
TBWES other than temporary impairment									(18,193)	0	0
Gains (losses) on asset disposals									(15)	32	(14,597)
Operating income (loss)	$ (23,373)	$ (104,748)	$ (144,646)	$ (8,798)	$ (58,587)	$ 11,133	$ (72,585)	$ 17,266	(281,565)	(102,773)	21,861
Power [Member]
GROSS PROFIT (LOSS)
Gross profit (loss)									191,999	233,550	247,632
Goodwill impairment charges									0
Renewable [Domain] [Domain]
GROSS PROFIT (LOSS)
Gross profit (loss)									(128,204)	(68,109)	57,682
Goodwill impairment charges									49,965
Industrial [Domain]
GROSS PROFIT (LOSS)
Gross profit (loss)									41,383	50,726	54,826
Goodwill impairment charges									36,938
Cost of operations
GROSS PROFIT (LOSS)
Mark to market gain (loss) included in SG&A									8,972	(21,208)	(44,307)
Cost of operations | Intangible Asset Amortization [Member]
GROSS PROFIT (LOSS)
Intangible amortization expense included in cost of operations									(14,272)	(15,842)	(7,676)
Cost of operations | Mark to Market Adjustments [Member]
GROSS PROFIT (LOSS)
Mark to market gain (loss) included in SG&A									(8,972)
Cost of operations | Operating Segments [Member] | Mark to Market Adjustments [Member]
GROSS PROFIT (LOSS)
Mark to market gain (loss) included in SG&A										21,208	44,307
Selling, General and Administrative Expenses
GROSS PROFIT (LOSS)
Intangible amortization expense included in cost of operations									(3,980)	(4,081)	(3,769)
Mark to market gain (loss) included in SG&A									(274)	$ (2,902)	4,097
Thermax (TBWES) [Domain]
GROSS PROFIT (LOSS)
TBWES other than temporary impairment									$ (18,200)		$ 0

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Segment Reporting Depreciation and Amortization (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Segment Reporting Information [Line Items]
Depreciation and amortization	$ 40,138	$ 39,583	$ 34,932
Operating Segments [Member]
Segment Reporting Information [Line Items]
Depreciation and amortization	32,723	33,015	31,444
Operating Segments [Member] | Power [Member]
Segment Reporting Information [Line Items]
Depreciation and amortization	9,222	11,231	18,532
Operating Segments [Member] | Renewable [Domain] [Domain]
Segment Reporting Information [Line Items]
Depreciation and amortization	3,208	2,711	2,567
Operating Segments [Member] | Industrial [Domain]
Segment Reporting Information [Line Items]
Depreciation and amortization	20,293	19,073	10,345
Corporate, Non-Segment [Member]
Segment Reporting Information [Line Items]
Depreciation and amortization	$ 7,415	$ 6,568	$ 3,488

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Segment Reporting Revenue by Country (Details) - USD ($) $ in Thousands	3 Months Ended								12 Months Ended
	Dec. 31, 2017	Sep. 30, 2017	Jun. 30, 2017	Mar. 31, 2017	Dec. 31, 2016	Sep. 30, 2016	Jun. 30, 2016	Mar. 31, 2016	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Revenues [Abstract]
United States									$ 757,159	$ 851,955	$ 1,034,653
United Kingdom									194,456	201,221	126,285
Canada									108,045	74,629	134,276
Denmark									82,843	54,722	116,064
China									54,883	33,898	41,921
Egypt									43,148	35,878	0
South Korea									41,217	44,660	4,358
Sweden									39,891	24,809	18,302
Germany									28,333	29,559	19,233
Vietnam									15,771	55,265	46,803
Dominican Republic									15,144	21,366	82,916
Saudi Arabia									13,978	2,408	4,220
South Africa									12,453	4,097	4,486
Italy									11,663	7,862	4,671
Netherlands									8,989	3,348	4,651
Finland									8,713	5,756	6,113
Bolivia									8,694	0	0
Oman									7,683	0	0
Indonesia									6,909	6,723	1,730
Nigeria									6,766	0	0
India									6,441	6,856	13,108
Aggregate of all other countries, each with less than $5 million in revenues									84,556	113,251	93,505
Revenues	$ 408,099	$ 408,703	$ 349,829	$ 391,104	$ 379,984	$ 410,955	$ 383,208	$ 404,116	$ 1,557,735	$ 1,578,263	$ 1,757,295

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Segment Reporting PP&E by Country (Details) - USD ($) $ in Thousands	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Segment Reporting Information [Line Items]
Property, Plant and Equipment, Net	$ 141,931	$ 133,637	$ 145,717
UNITED STATES
Segment Reporting Information [Line Items]
Property, Plant and Equipment, Net	79,681	75,368	88,840
MEXICO
Segment Reporting Information [Line Items]
Property, Plant and Equipment, Net	26,503	22,594	24,643
CHINA
Segment Reporting Information [Line Items]
Property, Plant and Equipment, Net	13,373	13,460	13,956
UNITED KINGDOM
Segment Reporting Information [Line Items]
Property, Plant and Equipment, Net	6,604	6,337	8,070
DENMARK
Segment Reporting Information [Line Items]
Property, Plant and Equipment, Net	7,953	6,749	6,265
All Other Geographic Areas [Member]
Segment Reporting Information [Line Items]
Property, Plant and Equipment, Net	$ 7,817	$ 9,129	$ 3,943

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Restructuring Activities and Spin Transaction Costs Restructuring liabilities (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016
Restructuring Cost and Reserve [Line Items]
Balance at beginning of period	$ 2,253	$ 740
Restructuring expense	13,923	21,939
Payments	(13,857)	(20,426)
Balance at December 31	2,319	2,253
Impaired Long-Lived Assets Held and Used, Asset Name [Domain]
Restructuring Cost and Reserve [Line Items]
Restructuring Costs and Asset Impairment Charges	$ (300)	$ 15,000

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Restructuring Activities and Spin Transaction Costs Spin-off transaction costs (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016
Restructuring Cost and Reserve [Line Items]
Disbursed accrued retention awards	$ 1.9
Spinoff [Member] | Selling, General and Administrative Expenses
Restructuring Cost and Reserve [Line Items]
Employee Benefits and Share-based Compensation	$ 1.2	$ 3.8

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Contracts and Revenue Recognition First European Renewable Project (Details) - USD ($)	3 Months Ended				12 Months Ended
	Dec. 31, 2017	Sep. 30, 2017	Jun. 30, 2017	Dec. 31, 2016	Dec. 31, 2017	Dec. 31, 2016
Change in construction cost estimates	$ (34,700,000)	$ 30,100,000	$ (115,200,000)	$ (98,100,000)	$ (158,500,000)	$ (141,100,000)
Liquidated Damages Balance on European Renewable Loss Contracts					77,100,000	35,800,000
Periodic Changes in Liquidated Damages on European Renewable Loss Contracts	14,300,000			$ 35,800,000	41,300,000	35,800,000
First European renewable project [Member]
Percentage of completion on European renewable energy project					0.98	0.88
Change in construction cost estimates	$ (5,800,000)				$ (20,800,000)	(50,300,000)
Liquidated damages due to schedule delays					9568
Accrued Liabilities [Member] | First European renewable project [Member]
Change in construction cost estimates					$ (1,600,000)	$ (6,400,000)

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Contracts and Revenue Recognition Second European Renewable Energy Project (Details) - USD ($)	3 Months Ended				12 Months Ended
	Dec. 31, 2017	Sep. 30, 2017	Jun. 30, 2017	Dec. 31, 2016	Dec. 31, 2017	Dec. 31, 2016
Change in construction cost estimates	$ (34,700,000)	$ 30,100,000	$ (115,200,000)	$ (98,100,000)	$ (158,500,000)	$ (141,100,000)
Second European renewable project [Member] [Member]
Percentage of completion on European renewable energy project					0.81	0.67
Change in construction cost estimates	$ (12,400,000)				$ (47,800,000)	(28,100,000)
Liquidated damages due to schedule delays					20057
Accrued Liabilities [Member] | Second European renewable project [Member] [Member]
Change in construction cost estimates					$ (12,800,000)	$ (5,100,000)

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Contracts and Revenue Recognition Third European Renewable Energy Project (Details) - USD ($)	3 Months Ended				12 Months Ended
	Dec. 31, 2017	Sep. 30, 2017	Jun. 30, 2017	Dec. 31, 2016	Dec. 31, 2017	Dec. 31, 2016
Change in construction cost estimates	$ (34,700,000)	$ 30,100,000	$ (115,200,000)	$ (98,100,000)	$ (158,500,000)	$ (141,100,000)
Third European renewable project [Member] [Member] [Member]
Percentage of completion on European renewable energy project					0.98	0.82
Change in construction cost estimates	$ (3,000,000)				$ (10,200,000)	(30,100,000)
Liquidated damages due to schedule delays					7072
Accrued Liabilities [Member] | Third European renewable project [Member] [Member] [Member]
Change in construction cost estimates					$ (700,000)	$ (3,900,000)

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Contracts and Revenue Recognition Fourth European Renewable Energy Project (Details) - USD ($)	3 Months Ended				12 Months Ended
	Dec. 31, 2017	Sep. 30, 2017	Jun. 30, 2017	Dec. 31, 2016	Dec. 31, 2017	Dec. 31, 2016
Change in construction cost estimates	$ (34,700,000)	$ 30,100,000	$ (115,200,000)	$ (98,100,000)	$ (158,500,000)	$ (141,100,000)
Fourth European renewable project [Member]
Percentage of completion on European renewable energy project					0.85	0.61
Change in construction cost estimates	$ (8,600,000)				$ (26,000,000)	(16,400,000)
Liquidated damages due to schedule delays					13732
Accrued Liabilities [Member] | Fourth European renewable project [Member]
Change in construction cost estimates					$ (4,700,000)	$ (1,600,000)

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Contracts and Revenue Recognition Fifth European Renewable Energy Project (Details) - USD ($)	3 Months Ended				12 Months Ended
	Dec. 31, 2017	Sep. 30, 2017	Jun. 30, 2017	Dec. 31, 2016	Dec. 31, 2017	Dec. 31, 2016
Change in construction cost estimates	$ (34,700,000)	$ 30,100,000	$ (115,200,000)	$ (98,100,000)	$ (158,500,000)	$ (141,100,000)
Fifth European renewable project [Domain]
Percentage of completion on European renewable energy project					0.64
Change in construction cost estimates	$ (4,900,000)				(40,200,000)
Structural Steel Beam Costs					$ 42,300,000
Liquidated damages due to schedule delays					19995
Accrued Liabilities [Member] | Fifth European Renewable project [Member]
Change in construction cost estimates					$ (14,300,000)

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Contracts and Revenue Recognition Sixth Renewable European Energy Project (Details) - USD ($)	3 Months Ended				12 Months Ended
	Dec. 31, 2017	Sep. 30, 2017	Jun. 30, 2017	Dec. 31, 2016	Dec. 31, 2017	Dec. 31, 2016
Change in construction cost estimates	$ (34,700,000)	$ 30,100,000	$ (115,200,000)	$ (98,100,000)	$ (158,500,000)	$ (141,100,000)
Sixth European renewable project [Domain]
Percentage of completion on European renewable energy project					0.76
Change in construction cost estimates					$ (18,500,000)
Liquidated damages due to schedule delays					6651
Accrued Liabilities [Member] | Sixth European renewable project [Domain]
Change in construction cost estimates					$ (2,500,000)

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Contracts and Revenue Recognition Change in Estimates on Long Term Contracts (Details) - USD ($) $ in Thousands	3 Months Ended				12 Months Ended
	Dec. 31, 2017	Sep. 30, 2017	Jun. 30, 2017	Dec. 31, 2016	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Change in construction cost estimates for specified loss contracts	$ (34,700)	$ 30,100	$ (115,200)	$ (98,100)	$ (158,500)	$ (141,100)
Periodic Changes in Liquidated Damages on European Renewable Loss Contracts	14,300			35,800	41,300	35,800
Liquidated Damages Balance on European Renewable Loss Contracts					77,100	35,800
Increases in estimates for percentage-of-completion contracts					21,638	42,368	$ 36,653
Decreases in estimates for percentage-of-completion contracts					(174,906)	(149,169)	(36,235)
Net changes in estimates for percentage of completion contracts					(153,268)	$ (106,801)	$ 418
Correction to estimate of project loss					1,000
Other renewable energy projects [Member]
Change in construction cost estimates for specified loss contracts				$ (14,200)	(2,500)
Power Output Bonus Opportunities	$ 4,000				$ 19,000
Liquidated damages due to schedule delays				8989

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Contracts and Revenue Recognition Contracts in progress and Advance Billings on contracts (Details) - USD ($) $ in Thousands	Dec. 31, 2017	Dec. 31, 2016
Deferred Revenue Arrangement [Line Items]
Cost incurred less cost of revenue recognized	$ 80,645	$ 96,210
Revenue recognized less billings to customer	80,575	69,800
Contracts in progress	161,220	166,010
Billings to customers less revenue recognized	177,953	199,480
Costs of revenue recognized less cost incurred	3,117	11,162
Advance billings on contracts	$ 181,070	$ 210,642

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Contracts and Revenue Recognition Retainage on contracts (Details) - USD ($) $ in Thousands	Dec. 31, 2017	Dec. 31, 2016
Deferred Revenue Arrangement [Line Items]
Contract Receivable Retainage, Next Twelve Months	$ 14,572	$ 18,843
Contract Receivable, Due after Year One	6,112	4,583
Contract Receivable Retainage, Year Two	4,300
Contract Receivable Retainage, Year Three	1,600
Contract Receivable Retainage, Year Four	200
Contract Receivable Retainage	$ 20,684	$ 23,426

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Equity Method Investments Equity Method Investees - Income Statement (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Schedule of Equity Method Investments [Line Items]
Equity Method Investment, Summarized Financial Information, Revenue	$ 346,459	$ 488,101	$ 475,459
Equity Method Investment, Summarized Financial Information, Gross Profit (Loss)	32,682	76,986	69,021
Equity Method Investment, Summarized Financial Information, Income (Loss) before provision for income taxes	(10,626)	19,529	3,072
Equity Method Investment, Summarized Financial Information, Provision for Income Taxes	1,907	3,715	4,500
Equity Method Investment, Summarized Financial Information, Net Income (Loss)	$ (12,533)	$ 15,814	$ (1,428)

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Equity Method Investments Equity Method Investees - Balance Sheet (Details) - USD ($)	Dec. 31, 2017	Dec. 31, 2016
Schedule of Equity Method Investments [Line Items]
Current assets	$ 322,956,000	$ 335,577,000
Noncurrent assets	137,081,000	126,958,000
Total assets	460,037,000	462,535,000
Current liabilities	342,178,000	231,150,000
Noncurrent liabilities	24,474,000	40,537,000
Owners' equity	93,385,000	190,848,000
Total liabilities and equity	460,037,000	462,535,000
Retained Earnings, Undistributed Earnings from Equity Method Investees	$ 7,900,000	$ 59,600,000

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Equity Method Investments Accounts Receivable - Other (Details) - USD ($)	Dec. 31, 2017	Dec. 31, 2016
Restructuring liabilities [Abstract]
Accounts Receivable, Related Parties, Current	$ 5,800,000	$ 8,700,000

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Equity Method Investments Transactions with Unconsolidated Affiliates (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Schedule of Equity Method Investments [Line Items]
Sales to	$ 7,143	$ 17,220	$ 18,014
Purchases from	12,470	32,490	45,397
Dividends received	50,134	12,160	20,830
Capital contributions	0	26,256	7,424
BWBC Investment [Domain]
Schedule of Equity Method Investments [Line Items]
Dividends received	$ 48,093	$ 6,000	$ 18,200

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Equity Method Investments Other Than Temporary Impairment (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Equity Method Investments and Joint Ventures [Abstract]
Investments in unconsolidated affiliates	$ 43,278	$ 98,682
TBWES other than temporary impairment	$ (18,193)	$ 0	$ 0

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Equity Method Investments Reconciliation of Net Income (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Equity Method Investments and Joint Ventures [Abstract]
Equity income based on stated ownership percentages	$ 7,530	$ 7,898	$ (542)
Other than temporary impairment on Equity Method Investment	(18,193)	0	0
Gain on sale of our interest in HMA	0	8,300
All other adjustments due to amortization of basis differences, timing of GAAP adjustments and other adjustments	796	218	300
Equity in income of investees	$ (9,867)	$ 16,440	$ (242)

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Equity Method Investments Babcock & Wilcox Beijing Company (BWBC) (Details) - USD ($) $ in Thousands	3 Months Ended								12 Months Ended
	Dec. 31, 2017	Sep. 30, 2017	Jun. 30, 2017	Mar. 31, 2017	Dec. 31, 2016	Sep. 30, 2016	Jun. 30, 2016	Mar. 31, 2016	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Schedule of Equity Method Investments [Line Items]
Equity in income (loss) and impairment of investees	$ 3,513	$ 1,234	$ (15,232)	$ 618	$ 11,553	$ 2,827	$ (616)	$ 2,676	$ (9,867)	$ 16,440	$ (242)
Investments in unconsolidated affiliates	43,278				98,682				43,278	98,682
Proceeds from Divestiture of Interest in Joint Venture									0
Equity Method Investment, Realized Gain (Loss) on Disposal									0	8,300
BWBC Investment [Domain]
Schedule of Equity Method Investments [Line Items]
Equity in income (loss) and impairment of investees									6,100	4,500	$ 4,900
Investments in unconsolidated affiliates	$ 16,600				$ 55,500				16,600	$ 55,500
Proceeds from Divestiture of Interest in Joint Venture									21,000
Equity Method Investment, Realized Gain (Loss) on Disposal									$ 4,400

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Equity Method Investments Thermax (TBWES) (Details) - USD ($) $ in Thousands	3 Months Ended								12 Months Ended
	Dec. 31, 2017	Sep. 30, 2017	Jun. 30, 2017	Mar. 31, 2017	Dec. 31, 2016	Sep. 30, 2016	Jun. 30, 2016	Mar. 31, 2016	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Schedule of Equity Method Investments [Line Items]
Equity in income (loss) of investees	$ 3,513	$ 1,234	$ (15,232)	$ 618	$ 11,553	$ 2,827	$ (616)	$ 2,676	$ (9,867)	$ 16,440	$ (242)
TBWES other than temporary impairment									(18,193)	0	0
Investments in unconsolidated affiliates	43,278				98,682				43,278	98,682
Thermax (TBWES) [Domain]
Schedule of Equity Method Investments [Line Items]
Equity in income (loss) of investees									2,200	1,500	(8,200)
TBWES other than temporary impairment									(18,200)		$ 0
Investments in unconsolidated affiliates	$ 26,000				$ 40,600				$ 26,000	$ 40,600

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Equity Method Investments Halley & Mellowes (HMA) (Details) - USD ($) $ in Thousands	3 Months Ended								12 Months Ended
	Dec. 31, 2017	Sep. 30, 2017	Jun. 30, 2017	Mar. 31, 2017	Dec. 31, 2016	Sep. 30, 2016	Jun. 30, 2016	Mar. 31, 2016	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Schedule of Equity Method Investments [Line Items]
Proceeds from Divestiture of Interest in Joint Venture									$ 0
Equity Method Investment, Realized Gain (Loss) on Disposal									0	$ 8,300
Equity in income (loss) and impairment of investees	$ 3,513	$ 1,234	$ (15,232)	$ 618	$ 11,553	$ 2,827	$ (616)	$ 2,676	$ (9,867)	16,440	$ (242)
HMA [Domain]
Schedule of Equity Method Investments [Line Items]
Proceeds from Divestiture of Interest in Joint Venture										18,000	0
Equity Method Investment, Realized Gain (Loss) on Disposal										8,300
Equity in income (loss) and impairment of investees										$ 2,200	$ 3,100

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Comprehensive Income Accumulated Other Comprehensive Income (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2017
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance at beginning of period	$ (36,482)	$ (18,853)	$ 10,374
Other comprehensive income (loss) before reclassifications	19,301	(14,749)	(18,650)
Amounts reclassified from AOCI to net income (loss)	(5,248)	(2,880)	965
Net current-period other comprehensive income	14,053	(17,629)	(17,685)
Balance at end of period	(36,482)	(18,853)	10,374	$ (22,429)
Currency translation gain (loss)
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance at beginning of period	(43,987)	(19,493)	11,551
Other comprehensive income (loss) before reclassifications	16,150	(24,494)	(19,459)
Amounts reclassified from AOCI to net income (loss)	0	0	0
Net current-period other comprehensive income	16,150	(24,494)	(31,044)
Balance at end of period	(43,987)	(19,493)	11,551	(27,837)
Net unrealized gain (loss) on investments (net of tax)
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance at beginning of period	(37)	(44)	(22)
Other comprehensive income (loss) before reclassifications	99	7	(49)
Amounts reclassified from AOCI to net income (loss)	(24)	0	27
Net current-period other comprehensive income	75	7	(22)
Balance at end of period	(37)	(44)	(22)	38
Net unrealized gain (loss) on derivative instruments
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance at beginning of period	802	1,786	(123)
Other comprehensive income (loss) before reclassifications	3,204	2,046	339
Amounts reclassified from AOCI to net income (loss)	(2,269)	(3,030)	1,133
Net current-period other comprehensive income	935	(984)	1,909
Balance at end of period	802	1,786	(123)	1,737
Net unrecognized gain (loss) related to benefit plans (net of tax)
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance at beginning of period	6,740	(1,102)	(1,032)
Other comprehensive income (loss) before reclassifications	(152)	7,692	519
Amounts reclassified from AOCI to net income (loss)	(2,955)	150	(195)
Net current-period other comprehensive income	(3,107)	7,842	(70)
Balance at end of period	$ 6,740	$ (1,102)	$ (1,032)	$ 3,633

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Comprehensive Income Reclassification out of Accumulated other Comprehensive Income (Details) - USD ($) $ in Thousands	3 Months Ended								12 Months Ended
	Dec. 31, 2017	Sep. 30, 2017	Jun. 30, 2017	Mar. 31, 2017	Dec. 31, 2016	Sep. 30, 2016	Jun. 30, 2016	Mar. 31, 2016	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Other comprehensive income (loss) before reclassifications									$ 19,301	$ (14,749)	$ (18,650)
Revenues	$ 408,099	$ 408,703	$ 349,829	$ 391,104	$ 379,984	$ 410,955	$ 383,208	$ 404,116	1,557,735	1,578,263	1,757,295
Other - net									(6,839)	(2,380)	64
Total before tax									(314,199)	(108,139)	20,205
Income tax expense									64,816	6,943	3,671
Income (loss) from continuing operations									(379,015)	(115,082)	16,534
Amounts reclassified from AOCI to net income (loss)									(5,248)	(2,880)	965
Other Comprehensive Income (Loss), Net Transfer From To Former Parent											(11,542)
Other Comprehensive Income (Loss), Net of Tax									14,053	(17,629)	(17,685)
Accumulated other comprehensive loss	(22,429)				(36,482)				(22,429)	(36,482)	(18,853)	$ 10,374
Currency translation gain (loss)
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Other comprehensive income (loss) before reclassifications									16,150	(24,494)	(19,459)
Amounts reclassified from AOCI to net income (loss)									0	0	0
Other Comprehensive Income (Loss), Net Transfer From To Former Parent											(11,585)
Other Comprehensive Income (Loss), Net of Tax									16,150	(24,494)	(31,044)
Accumulated other comprehensive loss	(27,837)				(43,987)				(27,837)	(43,987)	(19,493)	11,551
Net unrealized gain (loss) on investments (net of tax)
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Other comprehensive income (loss) before reclassifications									99	7	(49)
Amounts reclassified from AOCI to net income (loss)									(24)	0	27
Other Comprehensive Income (Loss), Net Transfer From To Former Parent											0
Other Comprehensive Income (Loss), Net of Tax									75	7	(22)
Accumulated other comprehensive loss	38				(37)				38	(37)	(44)	(22)
Net unrealized gain (loss) on derivative instruments
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Other comprehensive income (loss) before reclassifications									3,204	2,046	339
Amounts reclassified from AOCI to net income (loss)									(2,269)	(3,030)	1,133
Other Comprehensive Income (Loss), Net Transfer From To Former Parent											437
Other Comprehensive Income (Loss), Net of Tax									935	(984)	1,909
Accumulated other comprehensive loss	1,737				802				1,737	802	1,786	(123)
Net unrealized gain (loss) on derivative instruments | Reclassification out of Accumulated Other Comprehensive Income [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Revenues									10,059	4,624	546
Cost of Goods Sold									(118)	195	155
Other - net									(7,438)	(1,221)	(24)
Total before tax									2,503	3,598	677
Income tax expense									234	568	149
Income (loss) from continuing operations									2,269	3,030	528
Accumulated Defined Benefit Plans Adjustment, Net Prior Service Attributable to Parent [Member] | Reclassification out of Accumulated Other Comprehensive Income [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Cost of Goods Sold									2,912	254	(1,475)
Income tax expense									(43)	404	(1,168)
Income (loss) from continuing operations									2,955	(150)	(307)
Realized Gain Loss On Sale Of Investment [Member] | Reclassification out of Accumulated Other Comprehensive Income [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Other - net									38	0	(42)
Income tax expense									14	0	(15)
Income (loss) from continuing operations									24	0	(27)
Net unrecognized gain (loss) related to benefit plans (net of tax)
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Other comprehensive income (loss) before reclassifications									(152)	7,692	519
Amounts reclassified from AOCI to net income (loss)									(2,955)	150	(195)
Other Comprehensive Income (Loss), Net Transfer From To Former Parent											(394)
Other Comprehensive Income (Loss), Net of Tax									(3,107)	7,842	(70)
Accumulated other comprehensive loss	$ 3,633				$ 6,740				$ 3,633	$ 6,740	(1,102)	$ (1,032)
Including net transfers from parent [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Other Comprehensive Income (Loss), Net of Tax											$ (29,227)

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Cash and Cash Equivalents Restricted Cash and Cash Equivalents (Details) - USD ($) $ in Thousands	Dec. 31, 2017	Dec. 31, 2016
Restricted Cash and Cash Equivalents Items [Line Items]
Restricted Cash and Cash Equivalents	$ 25,980	$ 27,770
Reinsurance reserve requirements
Restricted Cash and Cash Equivalents Items [Line Items]
Restricted Cash and Cash Equivalents	21,061	21,189
Restricted foreign accounts
Restricted Cash and Cash Equivalents Items [Line Items]
Restricted Cash and Cash Equivalents	$ 4,919	$ 6,581

XML

Cash and Cash Equivalents Unrestricted Cash and Cash Equivalents (Details) - USD ($) $ in Thousands	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Cash and Cash Equivalents [Line Items]
Cash and Cash Equivalents, at Carrying Value	$ 56,667	$ 95,887	$ 365,192	$ 218,659
Held by foreign entities
Cash and Cash Equivalents [Line Items]
Cash and Cash Equivalents, at Carrying Value	54,274	94,415
Held by United States entities
Cash and Cash Equivalents [Line Items]
Cash and Cash Equivalents, at Carrying Value	$ 2,393	$ 1,472

XML

Inventories (Details) - USD ($) $ in Thousands	Dec. 31, 2017	Dec. 31, 2016
Inventories [Abstract]
Raw materials and supplies	$ 60,708	$ 61,630
Work in progress	7,867	6,803
Finished goods	13,587	17,374
Total inventories	$ 82,162	$ 85,807

XML

INTANGIBLE ASSETS Definite-lived Intangible Assets (Details) - USD ($)	Dec. 31, 2017	Dec. 31, 2016
Finite-Lived Intangible Assets [Line Items]
Finite-Lived Intangible Assets, Gross	$ 147,218,000	$ 123,226,000
Finite-Lived Intangible Assets, Accumulated Amortization	71,743,000	(53,491,000)
Finite-Lived Intangible Assets, Net	75,475,000	69,735,000
Indefinite-Lived Trademarks	1,305,000	1,305,000
Indefinite-Lived Intangible Assets (Excluding Goodwill)	1,305,000	1,305,000
Customer Relationships
Finite-Lived Intangible Assets [Line Items]
Finite-Lived Intangible Assets, Gross	59,794,000	47,892,000
Finite-Lived Intangible Assets, Accumulated Amortization	(23,434,000)	(17,519,000)
Unpatented Technology [Member]
Finite-Lived Intangible Assets [Line Items]
Finite-Lived Intangible Assets, Gross	20,160,000	18,461,000
Finite-Lived Intangible Assets, Accumulated Amortization	(5,013,000)	(2,864,000)
Technology
Finite-Lived Intangible Assets [Line Items]
Finite-Lived Intangible Assets, Gross	6,542,000	2,499,000
Finite-Lived Intangible Assets, Accumulated Amortization	(2,213,000)	(1,532,000)
Trade names / trademarks
Finite-Lived Intangible Assets [Line Items]
Finite-Lived Intangible Assets, Gross	22,951,000	18,774,000
Finite-Lived Intangible Assets, Accumulated Amortization	(5,097,000)	(3,826,000)
Backlog
Finite-Lived Intangible Assets [Line Items]
Finite-Lived Intangible Assets, Gross	30,160,000	28,170,000
Finite-Lived Intangible Assets, Accumulated Amortization	(28,695,000)	(21,776,000)
Other Intangible Assets [Member]
Finite-Lived Intangible Assets [Line Items]
Finite-Lived Intangible Assets, Gross	7,611,000	7,430,000
Finite-Lived Intangible Assets, Accumulated Amortization	$ (7,291,000)	$ (5,974,000)

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INTANGIBLE ASSETS Carrying Amount of Intangible Assets (Details) - USD ($) $ in Thousands			12 Months Ended
	Jan. 11, 2017	Jul. 01, 2016	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Finite-Lived Intangible Assets [Line Items]
Intangible Assets, Net (Including Goodwill)			$ 76,780	$ 71,039	$ 37,844
Finite-lived Intangible Assets Acquired	$ 19,500		19,500	55,438
Amortization of Intangible Assets			(18,252)	19,923
Finite Lived Intangible Assets, Foreign Currency Translation Gain (Loss)			$ 4,493	$ (2,320)
SPIG [Member]
Finite-Lived Intangible Assets [Line Items]
Finite-lived Intangible Assets Acquired		$ 55,164

XML

INTANGIBLE ASSETS Estimated Future Intangible Asset Amortization (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016
Finite-Lived Intangible Assets, Net, Amortization Expense, Fiscal Year Maturity [Abstract]
Twelve months ending December 31, 2018	$ 12,423
December 31, 2018	10,371
December 31, 2020	9,077
Twelve months ending December 31, 2021	8,817
December 31, 2021	7,244
Thereafter	27,543
SPIG [Member]
Finite-Lived Intangible Assets [Line Items]
Amortization of Intangible Assets	$ 9,100	$ 13,300

XML

Property, Plant and Equipment (Details) - USD ($) $ in Thousands	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Property, Plant and Equipment [Line Items]
Land	$ 8,859	$ 6,348
Buildings and Improvements, Gross	122,369	114,322
Machinery and Equipment, Gross	217,791	189,489
Construction in Progress, Gross	6,486	22,378
Property, plant and equipment - gross	355,505	332,537
Accumulated Depreciation, Depletion and Amortization, Property, Plant, and Equipment	213,574	198,900
Property, Plant and Equipment, Net	$ 141,931	$ 133,637	$ 145,717

XML

Supplemental Cash Flow Information Income taxes paid (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Debt Instrument [Line Items]
Income Taxes Paid, Net	$ (10,889)	$ 10,781	$ 15,008
US Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Interest Paid	4,909	425	0
Second Lien Term Loan [Member]
Debt Instrument [Line Items]
Interest Paid	$ 7,044	$ 0	$ 0

XML

Supplemental Cash Flow Information Accrued capital expenditures in accounts payable (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Accrued capital expenditures in accounts payable [Abstract]
Accrued capital expenditures in accounts payable	$ 1,383	$ 2,751	$ 568
Accretion Expense	$ 3,226	$ 0	$ 0

XML

Goodwill Goodwill by Segment (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Goodwill [Line Items]
Goodwill	$ 204,398	$ 267,395	$ 201,069
Goodwill, Period Increase (Decrease)	14,413	69,862
Goodwill, Purchase Accounting Adjustments		2,539
Goodwill, Foreign Currency Translation Gain (Loss)		(6,075)
Goodwill impairment charges	(86,903)	0	0
Goodwill, Translation and Purchase Accounting Adjustments	9,493
Power [Member]
Goodwill [Line Items]
Goodwill	47,370	46,220	47,137
Goodwill, Period Increase (Decrease)	0	0
Goodwill, Purchase Accounting Adjustments		0
Goodwill, Foreign Currency Translation Gain (Loss)		(917)
Goodwill impairment charges	0
Goodwill, Translation and Purchase Accounting Adjustments	1,150
Industrial [Domain]
Goodwill [Line Items]
Goodwill	157,028	172,740	104,308
Goodwill, Period Increase (Decrease)	14,413	69,862
Goodwill, Purchase Accounting Adjustments		2,539
Goodwill, Foreign Currency Translation Gain (Loss)		(3,969)
Goodwill impairment charges	36,938
Goodwill, Translation and Purchase Accounting Adjustments	6,813
Renewable [Domain] [Domain]
Goodwill [Line Items]
Goodwill	0	48,435	$ 49,624
Goodwill, Period Increase (Decrease)	0	0
Goodwill, Purchase Accounting Adjustments		0
Goodwill, Foreign Currency Translation Gain (Loss)		$ (1,189)
Goodwill impairment charges	49,965
Goodwill, Translation and Purchase Accounting Adjustments	$ 1,530

XML

Supplemental Cash Flow Information Income tax and interest payments on debt obligations (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Debt Instrument [Line Items]
Income Taxes Paid, Net	$ (10,889)	$ 10,781	$ 15,008
US Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Interest payments on our second lien term loan facility	(4,909)	(425)	0
Second Lien Term Loan [Member]
Debt Instrument [Line Items]
Interest payments on our second lien term loan facility	$ (7,044)	$ 0	$ 0

XML

Goodwill Narrative (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015	Jun. 30, 2017
Goodwill [Line Items]
Goodwill impairment charges	$ (86,903)	$ 0	$ 0
Goodwill	$ 204,398	267,395	201,069
Renewable [Domain] [Domain]
Goodwill [Line Items]
Discounted cash flows percentage	24.00%			15.00%
Goodwill impairment charges	$ 49,965
Goodwill, Impairment Loss, Net of Tax	48,900
Goodwill	$ 0	$ 48,435	$ 49,624

XML

Supplemental Cash Flow Information Interest Expense (Details) - USD ($) $ in Thousands		12 Months Ended
	Jul. 21, 2017	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Interest Expense, Borrowings		$ 13,283	$ 2,516	$ 1,207
Amortization of Deferred Loan Origination Fees, Net		9,496	1,244	1,131
Other Comprehensive Income (Loss), Foreign Currency Transaction and Translation Adjustment, Net of Tax		$ 16,150	$ (24,494)	(19,459)
Common Stock, Shares, Issued		48,871,997	48,698,385
Other interest expense		$ 3,526	$ 36	0
Total interest expense		26,305	3,796	2,338
US Revolving Credit Facility [Member]
Interest Expense, Borrowings		5,051	1,669	1,059
Amortization of Deferred Loan Origination Fees, Net		6,270	1,244	1,131
Second Lien Term Loan [Member]
Interest Expense, Borrowings		7,211	0	0
Amortization of Deferred Loan Origination Fees, Net		3,226	0	0
Foreign Revolving Credit Facility [Member]
Interest Expense, Borrowings		1,021	$ 847	$ 148
ARPA pre-judgment interest [Domain]
Litigation Settlement Interest	$ 4,100	$ 3,000

XML

Goodwill Interim Step 1 Results (Details) - USD ($)	6 Months Ended	12 Months Ended
	Jun. 30, 2017	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Goodwill [Line Items]
Step 1 Percentage using income approach		50.00%
Goodwill impairment charges		$ (86,903,000)	$ 0	$ 0
Goodwill		$ 204,398,000	267,395,000	201,069,000
Renewable [Domain] [Domain]
Goodwill [Line Items]
Discounted cash flows percentage	15.00%	24.00%
Goodwill impairment charges		$ 49,965,000
Goodwill		0	48,435,000	49,624,000
Power [Member]
Goodwill [Line Items]
Goodwill impairment charges		0
Goodwill		$ 47,370,000	$ 46,220,000	47,137,000
SPIG Reporting Unit [Member]
Goodwill [Line Items]
Fair value exceeding carrying value	1.00%		5.00%
SPIG [Member]
Goodwill [Line Items]
Discounted cash flows percentage	13.00%	14.00%
Goodwill		$ 38,300,000.00
Industrial [Domain]
Goodwill [Line Items]
Goodwill impairment charges		36,938,000
Goodwill		$ 157,028,000	$ 172,740,000	$ 104,308,000
MEGTEC Reporting Unit [Member]
Goodwill [Line Items]
Fair value exceeding carrying value		12.00%
Goodwill		$ 104,308,000.00
Construction Reporting Unit [Member]
Goodwill [Line Items]
Fair value exceeding carrying value		98.00%
Goodwill		$ 8,879,000
Power Reporting Unit [Member] [Member]
Goodwill [Line Items]
Fair value exceeding carrying value		0.00%
Goodwill		$ 38,521,000
Universal Reporting Unit [Member]
Goodwill [Line Items]
Fair value exceeding carrying value		18.00%
Goodwill		$ 14,412,000
Revenue and EBITDA from guideline companies [Domain] | Minimum [Member]
Goodwill [Line Items]
Step 1 weighting using market approach		30.00%
Revenue and EBITDA from guideline companies [Domain] | Maximum [Member]
Goodwill [Line Items]
Step 1 weighting using market approach		40.00%
Revenue and EBITDA from recent similar business combinations [Domain] | Minimum [Member]
Goodwill [Line Items]
Step 1 weighting using market approach		20.00%
Revenue and EBITDA from recent similar business combinations [Domain] | Maximum [Member]
Goodwill [Line Items]
Step 1 weighting using market approach		10.00%

XML

Warranty Warranty Expense (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Other Income and Expenses [Abstract]
Standard and Extended Product Warranty Accrual	$ 39,020	$ 40,467	$ 39,847	$ 37,735
Standard and Extended Product Warranty Accrual, Increase for Warranties Issued	23,161	22,472	19,310
Standard and Extended Product Warranty Accrual, Increase (Decrease) for Preexisting Warranties	(13,887)	(10,855)	(982)
Standard and Extended Warranty Accrual, increase from Business Acquisitions	1,060	918	0
Standard and Extended Product Warranty Accrual, Period Increase (Decrease)	(14,110)	(11,089)	(15,215)
Standard and Extended Product Warranty Accrual, Foreign Currency Translation Gain (Loss)	$ 2,329	$ (826)	$ (1,001)

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Warranty POWER Segment Warranty Details (Details) - Power Reporting Unit [Member] [Member] - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016
Reduction of Warranty Expense	$ 9,100	$ 4,400
Reduction of Warranty Accrual from Updated Rate		$ 2,100
Increase in Warranty Accrual from Industrial Steam Projects	$ 7,900

XML

Pension Plans and Postretirement Benefits Pension Plans and Postretirement Benefits - Obligations and funded status (Details) - USD ($) $ in Thousands	1 Months Ended	3 Months Ended		12 Months Ended
	May 31, 2016	Mar. 31, 2017	Sep. 30, 2016	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Curtailments	$ 1,800		$ 0		$ 28,375
Other Comprehensive (Income) Loss, Amortization Adjustment from AOCI, Pension and Other Postretirement Benefit Plans, for Net Prior Service Cost (Credit), before Tax				$ (2,912)	(254)	$ 1,042
Other Postretirement Defined Benefit Plan, Liabilities, Noncurrent				(256,390)	(301,259)
Defined Benefit Plan, Settlements, Benefit Obligation		$ 400	$ 0		28,763
Mark to market gain (loss) included in cost of operations				$ (8,696)	$ 24,110	40,210
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Discount Rate				0.00%	2837500000.00%
Pension benefits
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Benefit Obligation				$ 1,254,802	$ 1,211,720	1,205,163
Defined Benefit Plan, Curtailments				0	266
Defined Benefit Plan, Service Cost				789	1,680	13,677
Defined Benefit Plan, Interest Cost				41,113	40,875	49,501
Defined Benefit Plan, Contributions by Plan Participants				0	0
Other Comprehensive (Income) Loss, Amortization Adjustment from AOCI, Pension and Other Postretirement Benefit Plans, for Net Prior Service Cost (Credit), before Tax				324	432
Other Postretirement Defined Benefit Plan, Liabilities, Noncurrent				0	0
Defined Benefit Plan, Settlements, Benefit Obligation				509	1,453
Mark to market gain (loss) included in cost of operations				8,191	(31,932)	(41,574)
Defined Benefit Plan, Plan Amendments				0	231
Defined Benefit Plan, Actuarial Gain (Loss)				73,403	41,957
Nonmonetary Transaction, Gain (Loss) Recognized on Transfer				0	3,641
Defined Benefit Plan, Foreign Currency Exchange Rate Gain (Loss)				6,222	(5,099)
Defined Benefit Plan, Benefits Paid				78,954	78,447
Defined Benefit Plan, Fair Value of Plan Assets				1,007,002	922,868	923,030
Defined Benefit Plan, Actual Return on Plan Assets				149,449	76,570
Defined Benefit Plan, Contributions by Employer				17,307	3,986
Defined Benefit Plan, Foreign Currency Exchange Rate Changes, Plan Assets				(3,668)	(5,015)
Defined Benefit Plan, Funded Status of Plan				(247,800)	(288,852)
Accrued Employee Benefits				1,930	1,099
Pension and Other Postretirement Defined Benefit Plans, Liabilities, Noncurrent				245,870	287,753
Prepaid Pension Costs				0	0
Defined Benefit Plan, Pension Plans with Accumulated Benefit Obligations in Excess of Plan Assets, Aggregate Projected Benefit Obligation				1,254,802	1,183,345
Defined Benefit Plan, Pension Plans with Accumulated Benefit Obligations in Excess of Plan Assets, Aggregate Accumulated Benefit Obligation				1,272,010	1,206,056
Defined Benefit Plan, Pension Plans with Accumulated Benefit Obligations in Excess of Plan Assets, Aggregate Fair Value of Plan Assets				1,007,002	894,105
Other Postretirement Benefit Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Benefit Obligation				11,029	11,907	31,889
Defined Benefit Plan, Curtailments				0	0
Defined Benefit Plan, Service Cost				15	23	24
Defined Benefit Plan, Interest Cost				319	897	1,143
Defined Benefit Plan, Contributions by Plan Participants				219	574
Other Comprehensive (Income) Loss, Amortization Adjustment from AOCI, Pension and Other Postretirement Benefit Plans, for Net Prior Service Cost (Credit), before Tax				(7,792)	(10,801)
Other Postretirement Defined Benefit Plan, Liabilities, Noncurrent				(9,414)	(10,185)
Defined Benefit Plan, Settlements, Benefit Obligation				0	0
Mark to market gain (loss) included in cost of operations				$ (505)	$ (7,822)	(1,364)
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Discount Rate				0.00%	0.00%
Defined Benefit Plan, Plan Amendments				$ 0	$ (10,801)
Defined Benefit Plan, Actuarial Gain (Loss)				(141)	(7,162)
Nonmonetary Transaction, Gain (Loss) Recognized on Transfer				0	0
Defined Benefit Plan, Foreign Currency Exchange Rate Gain (Loss)				126	50
Defined Benefit Plan, Benefits Paid				1,416	3,563
Defined Benefit Plan, Fair Value of Plan Assets				0	0	$ 0
Defined Benefit Plan, Actual Return on Plan Assets				0	0
Defined Benefit Plan, Contributions by Employer				1,197	2,989
Defined Benefit Plan, Foreign Currency Exchange Rate Changes, Plan Assets				0	0
Defined Benefit Plan, Funded Status of Plan				(11,029)	(11,907)
Accrued Employee Benefits				1,615	1,722
Pension and Other Postretirement Defined Benefit Plans, Liabilities, Noncurrent				0	0
Prepaid Pension Costs				0	0
Defined Benefit Plan, Pension Plans with Accumulated Benefit Obligations in Excess of Plan Assets, Aggregate Projected Benefit Obligation				0	0
Defined Benefit Plan, Pension Plans with Accumulated Benefit Obligations in Excess of Plan Assets, Aggregate Accumulated Benefit Obligation				11,029	11,907
Defined Benefit Plan, Pension Plans with Accumulated Benefit Obligations in Excess of Plan Assets, Aggregate Fair Value of Plan Assets				0	0
Transferor's Continuing Involvement in Transferred Financial Assets, Transfer Description [Member] | Pension benefits
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Assets Transferred to (from) Plan				0	2,744
Transferor's Continuing Involvement in Transferred Financial Assets, Transfer Description [Member] | Other Postretirement Benefit Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Assets Transferred to (from) Plan				$ 0	$ 0

XML

Pension Plans and Postretirement Benefits - Components of Net Periodic Benefit Cost (Detail) - USD ($)
$ in Thousands

12 Months Ended

Dec. 31, 2017

Dec. 31, 2016

Dec. 31, 2015

Defined Benefit Plan Disclosure [Line Items]

Pension and Other Postretirement Benefits Disclosure [Text Block]

PENSION PLANS AND OTHER POSTRETIREMENT BENEFITS

We have historically provided defined benefit retirement benefits to domestic employees under the Retirement Plan for Employees of Babcock & Wilcox Commercial Operations (the "Company Plan"), a noncontributory plan. As of 2006, the Company Plan was closed to new salaried plan entrants. Effective December 31, 2015, benefit accruals for those salaried employees covered by, and continuing to accrue service and salary adjusted benefits under the Company Plan will cease. Furthermore, beginning on January 1, 2016, we began making service-based, cash contributions to a defined contribution 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 6 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. In 2014, benefit accruals under certain hourly Canadian pension plans were ceased with an effective date of January 1, 2015. As part of the spin-off transaction, we split the Canadian defined benefit plans from BWC, which was completed in 2017. We did not present these plans as multi-employer plans because our portion was separately identifiable and we were able to assess the assets, liabilities and periodic expense in the same manner as if it were a separate plan in each period.

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. Funding provisions under the Pension Protection Act accelerate funding requirements to ensure full funding of benefits accrued.

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, and on a limited basis, to future retirees.

Obligations and funded status

	Pension Benefits Year Ended December 31,						Other Postretirement Benefits  Year Ended December 31,
(in thousands)	2017			2016			2017			2016
Change in benefit obligation:
Benefit obligation at beginning of period	$	1,211,720		$	1,205,163		$	11,907		$	31,889
Service cost	789			1,680			15			23
Interest cost	41,113			40,875			319			897
Plan participants’ contributions	—			—			219			574
Curtailments	—			266			—			—
Settlements	509			1,453			—			—
Amendments	—			231			—			(10,801		)
Actuarial loss (gain)	73,403			41,957			(141		)	(7,162		)
Loss (gain) due to transfer	—			3,641			—			—
Foreign currency exchange rate changes	6,222			(5,099		)	126			50
Benefits paid	(78,954		)	(78,447		)	(1,416		)	(3,563		)
Benefit obligation at end of period	$	1,254,802		$	1,211,720		$	11,029		$	11,907
Change in plan assets:
Fair value of plan assets at beginning of period	$	922,868		$	923,030		$	—		$	—
Actual return on plan assets	149,449			76,570			—			—
Employer contribution	17,307			3,986			1,197			2,989
Plan participants' contributions	—			—			219			574
Transfers	—			2,744			—			—
Foreign currency exchange rate changes	(3,668		)	(5,015		)	—			—
Benefits paid	(78,954		)	(78,447		)	(1,416		)	(3,563		)
Fair value of plan assets at the end of period	1,007,002			922,868			—			—
Funded status	$	(247,800	)	$	(288,852	)	$	(11,029	)	$	(11,907	)
Amounts recognized in the balance sheet consist of:
Accrued employee benefits	$	(1,930	)	$	(1,099	)	$	(1,615	)	$	(1,722	)
Accumulated postretirement benefit obligation	—			—			(9,414		)	(10,185		)
Pension liability	(245,870		)	(287,753		)	—			—
Prepaid pension	—			—			—			—
Accrued benefit liability, net	$	(247,800	)	$	(288,852	)	$	(11,029	)	$	(11,907	)
Amount recognized in accumulated comprehensive income (before taxes):
Prior service cost (credit)	$	324		$	432		$	(7,792	)	$	(10,801	)
Supplemental information:
Plans with accumulated benefit obligation in excess of plan assets
Projected benefit obligation	$	1,254,802		$	1,183,345		$	—		$	—
Accumulated benefit obligation	$	1,272,010		$	1,206,056		$	11,029		$	11,907
Fair value of plan assets	$	1,007,002		$	894,105		$	—		$	—
Plans with plan assets in excess of accumulated benefit obligation
Projected benefit obligation	$	—		$	28,375		$	—		$	—
Accumulated benefit obligation	$	—		$	28,375		$	—		$	—
Fair value of plan assets	$	—		$	28,763		$	—		$	—

Components of net periodic benefit cost (benefit) included in net income (loss) are as follows:

	Pension Benefits									Other Benefits
(in thousands)	2017			2016			2015			2017			2016			2015
Service cost	$	789		$	1,680		$	13,677		$	15		$	23		$	24
Interest cost	41,113			40,875			49,501			319			897			1,143
Expected return on plan assets	(59,409		)	(61,939		)	(68,709		)	—			—			—
Amortization of prior service cost	103			250			307			(3,009		)	—			—
Recognized net actuarial loss (gain)	(8,191		)	31,932			41,574			(505		)	(7,822		)	(1,364		)
Net periodic benefit cost (benefit)	$	(25,595	)	$	12,798		$	36,350		$	(3,180	)	$	(6,902	)	$	(197	)

During the first quarter of 2017, lump sum payments from our Canadian pension plan resulted in a plan settlement of $0.4 million, which also resulted in interim mark to market accounting for the pension plan. The mark to market adjustment in the first quarter of 2017 was $0.7 million. The effect of these charges and mark to market adjustments are reflected in the "Recognized net actuarial loss (gain)" in the table above. There were no significant plan settlements or interim mark to market adjustments after the first quarter of 2017.

We terminated the Babcock & Wilcox Retiree Medical Plan (the "Retiree OPEB plan") effective December 31, 2016. The Retiree OPEB plan was originally established to provide secondary medical insurance coverage for retirees that had reached the age of 65, up to a lifetime maximum cost. The Retiree OPEB plan had no plan assets, no accumulated other comprehensive income balance and no active participants as of the termination date. In exchange for terminating the Retiree OPEB plan, the participants had the option to enroll in a third-party health care exchange, which B&W agreed to contribute up to $750 a year for each of the next three years (beginning in 2017), provided the plan participant had not yet reached their lifetime maximum under the terminated Retiree OPEB plan. Based on the number of participants who did not enroll in the new benefit plan, we recognized a settlement gain of $7.2 million on December 31, 2016. Based on the number of participants who did enroll in the new benefit plan, we recognized a curtailment gain of $10.8 million on December 31, 2016 for the actuarially determined difference in the liability for these participants in the Retiree OPEB plan and the new plan. The settlement gain is reported in the "Recognized net actuarial loss" in the table above, and the curtailment gain was deferred in accumulated other comprehensive income and $3.0 million was recognized in 2017, and we expect to recognize the remainder during the periods of 2018 through 2020.

During 2016, we recorded adjustments to our benefit plan liabilities from pension curtailment and settlement events. Lump sum payments from our Canadian pension plan during 2016 resulted in interim pension plan settlement charges totaling $1.2 million in 2016. Also, in May 2016, the closure of our West Point, Mississippi manufacturing facility resulted in a $1.8 million curtailment charge in the Company Plan. These events also resulted in$27.5 millionin interim MTM losses for these pension plans, the effects of which are reflected in the 2016 "Recognized net actuarial loss (gain)" in the table above along with a$1.4 million loss for the annual MTM adjustment of our pension plans at December 31, 2016.

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. Total net mark to market adjustments for our pension and other postretirement benefit plans were (gains) losses of $(8.7) million, $24.1 million and $40.2 million in the years ended, December 31, 2017, 2016 and 2015, respectively. We have excluded the recognized net actuarial loss from our reportable segments and such amount has been reflected in Note 4 as the mark to market adjustment in the reconciliation of reportable segment income (loss) to consolidated operating losses. The recognized net actuarial (gain) loss was recorded in our consolidated statements of operations in the following line items:

(in thousands)	2017			2016		2015
Cost of operations	$	(8,972	)	$	21,208	$	44,307
Selling, general and administrative expenses	274			2,902		(4,097		)
Other	2			—		—
Total	$	(8,696	)	$	24,110	$	40,210

Assumptions

	Pension Benefits		Other Benefits
	2017	2016	2017	2016
Weighted average assumptions used to determine net periodic benefit obligations at December 31:
Discount rate	3.65%	4.13%	3.33%	3.66%
Rate of compensation increase	0.10%	2.40%	—	—
Weighted average assumptions used to determine net periodic benefit cost for the years ended December 31:
Discount rate	4.11%	4.25%	3.33%	3.66%
Expected return on plan assets	6.64%	6.70%	—%	—%
Rate of compensation increase	0.10%	2.40%	—%	—%

The expected rate of return on plan assets 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 asset class. These rates are then adjusted for anticipated future inflation to determine estimated nominal rates of return for each asset 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 asset classes within the total asset portfolio. We use an expected return on plan assets assumption of 6.89% for the majority of our pension plan assets (approximately 93% of our total pension assets at December 31, 2017).

	2016
Assumed health care cost trend rates at December 31
Health care cost trend rate assumed for next year	8.50	%
Rates to which the cost trend rate is assumed to decline (ultimate trend rate)	4.50	%
Year that the rate reaches ultimate trend rate	2024

During the year ended December 31, 2017, we did not utilize health care cost assumptions as a result of our termination of the Babcock & Wilcox Retiree Medical Plan (the "Retiree OPEB plan") effective December 31, 2016.

Investment goals

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 plans' 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 Company Plan, which is a domestic defined benefit plan. The assets of this plan are held by the Trustee in The Babcock & Wilcox Company Master Trust (the "Master Trust"). For the years ended December 31, 2017 and 2016, the investment return on domestic plan assets of the Master Trust (net of deductions for management fees) was approximately 17% and 9%, respectively.

The following is a summary of the asset allocations for the Master Trust at December 31, 2017 and 2016 by asset category:

	2017		2016
Asset Category:
Fixed Income (excluding United States Government Securities)	33	%	32	%
Commingled and Mutual Funds	41	%	38	%
United States Government Securities	21	%	20	%
Equity Securities	3	%	7	%
Derivatives	1	%	1	%
Other	1	%	2	%

The target asset allocation for the domestic defined benefit plan is 55% fixed income and 45% equities.

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 United Kingdom Plan").

The combined weighted average asset allocations of these plans at December 31, 2017 and 2016 by asset category were as follows:

	2017		2016
Asset Category:
Equity Securities and Commingled Mutual Funds	41	%	44	%
Fixed Income	58	%	55	%
Other	1	%	1	%

The target allocation for 2017 for the foreign plans, by asset class, is as follows:

	Canadian Plans		Diamond UK Plan
Asset Class:
United States Equity	27	%	10	%
Global Equity	23	%	12	%
Fixed Income	50	%	78	%

Fair value of plan assets

See Note 23 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, 2017:

(in thousands)	12/31/2017		Level 1		Level 2
Fixed income	$	352,484	$	—	$	352,484
Equities	33,525		33,525		—
Commingled and mutual funds	413,166		—		413,166
United States government securities	193,249		193,249		—
Cash and accrued items	14,578		12,585		1,993
Total pension and other postretirement benefit assets	$	1,007,002	$	239,359	$	767,643

The following is a summary of total investments for our plans measured at fair value at December 31, 2016:

(in thousands)	12/31/2016		Level 1		Level 2
Fixed income	$	321,847	$	—	$	321,847
Equities	83,441		78,268		5,173
Commingled and mutual funds	349,348		4,609		344,739
United States government securities	156,599		156,599		—
Cash and accrued items	11,633		9,394		2,239
Total pension and other postretirement benefit assets	$	922,868	$	248,870	$	673,998

Expected cash flows

	Domestic Plans				Foreign Plans
(in thousands)	Pension Benefits 1		Other Benefits		Pension Benefits 1		Other Benefits
Expected employer contributions to trusts of defined benefit plans:
2018	$	16,798	$	1,400	$	3,126	$	167
Expected benefit payments:
2018	$	71,881	$	1,463	$	3,003	$	167
2019	72,537		1,342		3,095		167
2020	73,104		854		3,175		169
2021	73,331		802		3,252		163
2022	73,434		746		3,318		146
2023-2027	359,308		2,975		18,576		611

¹ Pension benefit payments are made from their respective plan's trust.

Defined contribution plans

We provide benefits under The B&W Thrift Plan (the "Thrift Plan"). The Thrift Plan generally provides for matching employer contributions of 50% of participants' contributions up to 6% of compensation. These matching employer contributions are typically made in cash. 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 totaled approximately $14.4 million, $13.4 million and $8.9 million in the years ended December 31, 2017, 2016 and 2015, respectively.

We also provide benefits under the MEGTEC Union Plan, a defined contribution plan. The total employer contribution expense for the Union plan was approximately $0.2 million, $0.3 million and $0.3 million in the years ended December 31, 2017, 2016 and 2015, respectively. Matching employer contributions are made in cash.

We also provide benefits under the Universal Defined Contribution Plan (the "Universal Plan"). The total employer contribution expense for the Universal Plan was approximately $0.5 million in the year ended December 31, 2017. Matching employer contributions are made in cash.

Effective December 31, 2016, we merged the MEGTEC Non-union Plan and SPIG 401(k) defined contribution plans into the Thrift Plan. For the MEGTEC Non-union Plan, amounts charged to expense for our contributions were approximately $1.1 million and $1.1 million in the years ended December 31, 2016 and 2015, respectively. Matching employer contributions were made in cash. The SPIG 401(k) plan contributions were also made in cash, and were not material to our consolidated financial statements in 2016.

Also, our salaried Canadian employees are provided with a defined contribution plan. As of and in the periods following January 1, 2012, we made cash, service-based contributions under this arrangement. The amount charged to expense for employer contributions was approximately $0.3 million, $0.4 million and $0.1 million in the years ended December 31, 2017, 2016 and 2015, respectively.

Multi-employer plans

One of our subsidiaries in the Power segment contributes to various multi-employer plans. The plans generally provide defined benefits to substantially all unionized workers in this subsidiary. The following table summarizes our contributions to multi-employer plans for the years covered by this report:

Pension Fund	EIN/PIN	Pension Protection Act Zone Status		FIP/RP  Status Pending/ Implemented	Contributions						Surcharge Imposed	Expiration Date Of Collective Bargaining Agreement
					2017		2016		2015
		2017	2016		(in millions)
Boilermaker-Blacksmith National Pension Trust	48-6168020/ 001	Yellow	Yellow	Yes	$	7.9	$	17.8	$	20.3	No	Described Below
All Other					2.0		3.2		4.6
					$	9.9	$	21.0	$	24.9

Our collective bargaining agreements with the Boilermaker-Blacksmith National Pension Trust (the "Boilermaker Plan") is 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 Boilermaker 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.

See Note 29 for the future expected effect of FASB ASU 2017-07 on the presentation of benefit and expense related to our pension and post retirement plans.

Multi-employer plans

One of our subsidiaries in the Power segment contributes to various multi-employer plans. The plans generally provide defined benefits to substantially all unionized workers in this subsidiary. The following table summarizes our contributions to multi-employer plans for the years covered by this report:

Pension Fund	EIN/PIN	Pension Protection Act Zone Status		FIP/RP  Status Pending/ Implemented	Contributions						Surcharge Imposed	Expiration Date Of Collective Bargaining Agreement
					2017		2016		2015
		2017	2016		(in millions)
Boilermaker-Blacksmith National Pension Trust	48-6168020/ 001	Yellow	Yellow	Yes	$	7.9	$	17.8	$	20.3	No	Described Below
All Other					2.0		3.2		4.6
					$	9.9	$	21.0	$	24.9

Our collective bargaining agreements with the Boilermaker-Blacksmith National Pension Trust (the "Boilermaker Plan") is 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 Boilermaker 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.

The recognized net actuarial (gain) loss was recorded in our consolidated statements of operations in the following line items:

(in thousands)	2017			2016		2015
Cost of operations	$	(8,972	)	$	21,208	$	44,307
Selling, general and administrative expenses	274			2,902		(4,097		)
Other	2			—		—
Total	$	(8,696	)	$	24,110	$	40,210

Mark to market gain (loss) included in cost of operations

$ (8,696)

$ 24,110

$ 40,210

Pension benefits

Defined Benefit Plan Disclosure [Line Items]

Service cost

789

1,680

13,677

Interest cost

(41,113)

(40,875)

(49,501)

Expected return on plan assets

(59,409)

(61,939)

(68,709)

Amortization of prior service cost

103

250

307

Mark to market gain (loss) included in cost of operations

8,191

(31,932)

(41,574)

Net periodic benefit cost (benefit)

(25,595)

12,798

36,350

Other benefits

Defined Benefit Plan Disclosure [Line Items]

Service cost

15

23

24

Interest cost

(319)

(897)

(1,143)

Expected return on plan assets

0

0

0

Amortization of prior service cost

(3,009)

0

0

Mark to market gain (loss) included in cost of operations

(505)

(7,822)

(1,364)

Net periodic benefit cost (benefit)

(3,180)

(6,902)

(197)

Cost of operations

Defined Benefit Plan Disclosure [Line Items]

Mark to market gain (loss) included in cost of operations

8,972

(21,208)

(44,307)

Cost of operations | Pension benefits

Defined Benefit Plan Disclosure [Line Items]

Service cost

804

1,703

13,701

Selling, General and Administrative Expenses

Defined Benefit Plan Disclosure [Line Items]

Mark to market gain (loss) included in cost of operations

(274)

(2,902)

4,097

Other-net

Defined Benefit Plan Disclosure [Line Items]

Mark to market gain (loss) included in cost of operations

(2)

0

0

Other Operating Income (Expense) [Member] | Pension benefits

Defined Benefit Plan Disclosure [Line Items]

Interest cost

(41,432)

(41,772)

(50,644)

Expected return on plan assets

(59,409)

(61,939)

(68,709)

Amortization of prior service cost

(2,906)

250

307

Mark to market gain (loss) included in cost of operations

$ 8,696

$ (24,110)

$ (40,210)

XML

Pension Plans and Postretirement Benefits - Additional Information (Detail) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Defined Benefit Plan Disclosure [Line Items]
Other Comprehensive (Income) Loss, Amortization Adjustment from AOCI, Pension and Other Postretirement Benefit Plans, for Net Prior Service Cost (Credit), Net of Tax	$ (2,955)	$ 150	$ (195)
Mark to market gain (loss) included in cost of operations	(8,696)	24,110	40,210
Pension Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Mark to market gain (loss) included in cost of operations	$ 8,191	$ (31,932)	$ (41,574)

XML

Pension Plans and Postretirement Benefits Curtailments and Settlements (Details) - USD ($) $ in Thousands	1 Months Ended		3 Months Ended					9 Months Ended	12 Months Ended
	Sep. 30, 2016	May 31, 2016	Dec. 31, 2017	Mar. 31, 2017	Dec. 31, 2016	Sep. 30, 2016	Jun. 30, 2016	Sep. 30, 2016	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Defined Benefit Plan, Settlements, Benefit Obligation				$ 400		$ 0				$ 28,763
Canada Q2 Remeasurement				700
Mark to market gain (loss) included in cost of operations									$ (8,696)	24,110	$ 40,210
Defined Benefit Plan, Settlements, Plan Assets	$ 1,200
Defined Benefit Plan, Curtailments		$ 1,800				$ 0				28,375
Defined Benefit Plan, MTM adjustment excluding curtailment and settlements			$ 9,800	$ (1,100)	$ 6,400		$ (30,000)	$ (500)		27,500
Defined Benefit Plan, MTM adjustment excluding curtailment and settlements - Commercial Ops										1,400
Q4 OPEB MTM gain Medical plan										7,200
Defined Benefit Plan, Recognized Net Gain (Loss) Due to Curtailments										10,800
Other Comprehensive (Income) Loss, Amortization Adjustment from AOCI, Pension and Other Postretirement Benefit Plans, for Net Prior Service Cost (Credit), Net of Tax									(2,955)	150	(195)
Pension Plan [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Defined Benefit Plan, Settlements, Benefit Obligation									509	1,453
Mark to market gain (loss) included in cost of operations									8,191	(31,932)	$ (41,574)
Defined Benefit Plan, Curtailments									$ 0	$ 266

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Pension Plans and Postretirement Benefits Assumptions (Details)	3 Months Ended	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2017	Dec. 31, 2016
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Expected Long-term Return on Assets	93.00%		6.89%
Pension Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Discount Rate Support, Methodology and Source Data		0.0365	0.0413
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Rate of Compensation Increase	2.40%	0.10%	2.40%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Discount Rate		4.11%	4.25%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Expected Long-term Return on Assets		6.64%	6.70%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Rate of Compensation Increase		0.10%	2.40%
Other Postretirement Benefit Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Discount Rate Support, Methodology and Source Data		0.0333	0.0366
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Rate of Compensation Increase	0.00%	0.00%	0.00%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Discount Rate		3.33%	3.66%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Expected Long-term Return on Assets		0.00%	0.00%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Rate of Compensation Increase		0.00%	0.00%

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Pension Plans and Postretirement Benefits Investment Goals (Details) - USD ($)	Dec. 31, 2017	Dec. 31, 2016
Defined Benefit Plan Disclosure [Line Items]
Percentage of investment return on domestic plan assets	17.00%	9.00%
United States Equity [Member]
Defined Benefit Plan Disclosure [Line Items]
Canadian Plan - Asset Class	$ 0.27
Geographic Distribution, Domestic [Member]
Defined Benefit Plan Disclosure [Line Items]
Diamond UK Plan - Asset Class		$ 0.10
Global Equity [Member]
Defined Benefit Plan Disclosure [Line Items]
Canadian Plan - Asset Class	0.23
Diamond UK Plan - Asset Class		0.12
Bonds [Member]
Defined Benefit Plan Disclosure [Line Items]
Canadian Plan - Asset Class	$ 0.50
Diamond UK Plan - Asset Class		$ 0.78

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Pension Plans and Postretirement Benefits Canadian Pension Plan Settlement (Details) - USD ($) $ in Thousands	3 Months Ended		12 Months Ended
	Mar. 31, 2017	Sep. 30, 2016	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Postemployment Benefits [Abstract]
Mark to market gain (loss) included in cost of operations			$ (8,696)	$ 24,110	$ 40,210
Defined Benefit Plan, Settlements, Benefit Obligation	$ 400	$ 0		$ 28,763
Canada Q2 Remeasurement	$ 700

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Pension Plans and Postretirement Benefits Recognized Net Actuarial Loss (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Defined Benefit Plan, Actuarial Gain (Loss), Mark to Market Adjustment	$ (8,696)	$ 24,110	$ 40,210
Cost of operations
Defined Benefit Plan, Actuarial Gain (Loss), Mark to Market Adjustment	8,972	(21,208)	(44,307)
Selling, General and Administrative Expenses
Defined Benefit Plan, Actuarial Gain (Loss), Mark to Market Adjustment	(274)	(2,902)	4,097
Other-net
Defined Benefit Plan, Actuarial Gain (Loss), Mark to Market Adjustment	$ (2)	$ 0	$ 0

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Pension Plans and Postretirement Benefits Assumed Health Care Cost Trend (Details)	12 Months Ended
	Dec. 31, 2016
Postemployment Benefits [Abstract]
Defined Benefit Plan, Health Care Cost Trend Rate Assumed for Next Fiscal Year	8.50%
Defined Benefit Plan, Ultimate Health Care Cost Trend Rate	4.50%
Defined Benefit Plan, Year that Rate Reaches Ultimate Trend Rate	2024

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Pension Plans and Postretirement Benefits Allocation of Plan Assets (Details)	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016
Fixed Income Investments [Member]
Defined Benefit Plan, Actual Plan Asset Allocations	33.00%	32.00%
Mutual Funds [Member]
Defined Benefit Plan, Actual Plan Asset Allocations	41.00%	38.00%
US Government Agencies Debt Securities [Member]
Defined Benefit Plan, Actual Plan Asset Allocations	21.00%	20.00%
Equity Securities [Member]
Defined Benefit Plan, Actual Plan Asset Allocations	3.00%	7.00%
Partnership Interest [Member]
Defined Benefit Plan, Actual Plan Asset Allocations	1.00%	1.00%
Derivative [Member]
Defined Benefit Plan, Actual Plan Asset Allocations	1.00%	2.00%
Equity Securities [Member]
Defined Benefit Plan, Target Allocation Percentage	0.45
Fixed Income Funds [Member]
Defined Benefit Plan, Target Allocation Percentage	0.55

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Pension Plans and Postretirement Benefits Foreign Plan - Allocation of Plan Assets (Details) - USD ($)	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016
Equity Securities [Member]
Defined Benefit Plan, Investment Strategies, Investment Fund Category	0.41	0.44
Fixed Income Investments [Member]
Defined Benefit Plan, Investment Strategies, Investment Fund Category	0.58	0.55
Other Investments [Member]
Defined Benefit Plan, Investment Strategies, Investment Fund Category	0.01	0.01
United States Equity [Member]
Canadian Plan - Asset Class	$ 0.27
Geographic Distribution, Domestic [Member]
Diamond UK Plan - Asset Class		$ 0.10
Global Equity [Member]
Canadian Plan - Asset Class	0.23
Diamond UK Plan - Asset Class		0.12
Bonds [Member]
Canadian Plan - Asset Class	$ 0.50
Diamond UK Plan - Asset Class		$ 0.78

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Pension Plans and Postretirement Benefits Fair Value of Investments (Details) - USD ($) $ in Thousands	Dec. 31, 2017	Dec. 31, 2016
Fixed Income Funds [Member]
Schedule of Fair Value of Separate Accounts by Major Category of Investment, Fair Value	$ 352,484	$ 321,847
Equity Funds [Member]
Schedule of Fair Value of Separate Accounts by Major Category of Investment, Fair Value	33,525	83,441
Mutual Fund [Member]
Schedule of Fair Value of Separate Accounts by Major Category of Investment, Fair Value	413,166	349,348
US Treasury and Government [Member]
Schedule of Fair Value of Separate Accounts by Major Category of Investment, Fair Value	193,249	156,599
Cash and Cash Equivalents [Member]
Schedule of Fair Value of Separate Accounts by Major Category of Investment, Fair Value	14,578	11,633
Assets, Total [Member]
Schedule of Fair Value of Separate Accounts by Major Category of Investment, Fair Value	1,007,002	922,868
Fair Value, Inputs, Level 2 [Member] | Fixed Income Funds [Member]
Schedule of Fair Value of Separate Accounts by Major Category of Investment, Fair Value	352,484	321,847
Fair Value, Inputs, Level 2 [Member] | Equity Funds [Member]
Schedule of Fair Value of Separate Accounts by Major Category of Investment, Fair Value	0	5,173
Fair Value, Inputs, Level 2 [Member] | Mutual Fund [Member]
Schedule of Fair Value of Separate Accounts by Major Category of Investment, Fair Value	413,166	344,739
Fair Value, Inputs, Level 2 [Member] | US Treasury and Government [Member]
Schedule of Fair Value of Separate Accounts by Major Category of Investment, Fair Value	0	0
Fair Value, Inputs, Level 2 [Member] | Cash and Cash Equivalents [Member]
Schedule of Fair Value of Separate Accounts by Major Category of Investment, Fair Value	1,993	2,239
Fair Value, Inputs, Level 2 [Member] | Assets, Total [Member]
Schedule of Fair Value of Separate Accounts by Major Category of Investment, Fair Value	767,643	673,998
Fair Value, Inputs, Level 1 [Member] | Fixed Income Funds [Member]
Schedule of Fair Value of Separate Accounts by Major Category of Investment, Fair Value	0	0
Fair Value, Inputs, Level 1 [Member] | Equity Funds [Member]
Schedule of Fair Value of Separate Accounts by Major Category of Investment, Fair Value	33,525	78,268
Fair Value, Inputs, Level 1 [Member] | Mutual Fund [Member]
Schedule of Fair Value of Separate Accounts by Major Category of Investment, Fair Value	0	4,609
Fair Value, Inputs, Level 1 [Member] | US Treasury and Government [Member]
Schedule of Fair Value of Separate Accounts by Major Category of Investment, Fair Value	193,249	156,599
Fair Value, Inputs, Level 1 [Member] | Cash and Cash Equivalents [Member]
Schedule of Fair Value of Separate Accounts by Major Category of Investment, Fair Value	12,585	9,394
Fair Value, Inputs, Level 1 [Member] | Assets, Total [Member]
Schedule of Fair Value of Separate Accounts by Major Category of Investment, Fair Value	$ 239,359	$ 248,870

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Pension Plans and Postretirement Benefits Defined Contribution Plan (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
MEGTEC Union [Member]
Defined Contribution Plan, Employer Discretionary Contribution Amount	$ 0.2	$ 0.3	$ 0.3
Universal [Member]
Defined Contribution Plan, Employer Discretionary Contribution Amount	$ 0.5
Thrift [Member]
Defined Contribution Plan, Employer Matching Contribution, Percent of Match	50.00%
Defined Contribution Plan, Maximum Annual Contributions Per Employee, Percent	6.00%
Defined Contribution Plan, Employer Discretionary Contribution Amount	$ 14.4	13.4	8.9
MEGTEC Non-union [Member]
Defined Contribution Plan, Employer Discretionary Contribution Amount		1.1	1.1
Canada Defined Contribution [Member]
Defined Contribution Plan, Employer Discretionary Contribution Amount	$ 0.3	$ 0.4	$ 0.1

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Pension Plans and Postretirement Benefits Cash Flows (Details) - USD ($) $ in Thousands	3 Months Ended		12 Months Ended
	Dec. 31, 2017	Mar. 31, 2017	Dec. 31, 2017	Dec. 31, 2016
UNITED STATES
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plans, Estimated Future Employer Contributions in Next Fiscal Year	$ 16,798
Expected benefit payment 2018		$ 71,881
Expected benefit payment 2019		72,537
Expected benefit payment 2020		73,104
Expected benefit payment 2021		73,331
Expected benefit payment 2022				$ 73,434
Expected benefit payment 2022-2026			$ 359,308
United States - Other [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plans, Estimated Future Employer Contributions in Next Fiscal Year	1,400
Expected benefit payment 2018		1,463
Expected benefit payment 2019		1,342
Expected benefit payment 2020		854
Expected benefit payment 2021		802
Expected benefit payment 2022				$ 746
Expected benefit payment 2022-2026			2,975
Foreign - Other [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plans, Estimated Future Employer Contributions in Next Fiscal Year	3,126
Expected benefit payment 2018		3,003
Expected benefit payment 2019		3,095
Expected benefit payment 2020		3,175
Expected benefit payment 2021		3,252
Expected benefit payment 2022-2026		3,318	18,576
Foreign [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plans, Estimated Future Employer Contributions in Next Fiscal Year	$ 167
Expected benefit payment 2018		167
Expected benefit payment 2019		167
Expected benefit payment 2020		169
Expected benefit payment 2021		163
Expected benefit payment 2022-2026		$ 146	$ 611

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Pension Plans and Postretirement Benefits Multi-Employer Plans (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Multiemployer Plans [Line Items]
Multiemployer Plan, Period Contributions	$ 9,900	$ 21,000	$ 24,900
Boilermaker-Blacksmith National Pension Trust [Member]
Multiemployer Plans [Line Items]
Multiemployer Plan, Period Contributions	7,900	17,755	20,300
Other [Domain]
Multiemployer Plans [Line Items]
Multiemployer Plan, Period Contributions	$ 2,000	$ 3,161	$ 4,600

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Contingencies - Additional Information (Detail) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Loss Contingencies [Line Items]
Payments for Legal Settlements	$ 4,200
Standard and Extended Product Warranty Accrual, Increase (Decrease) for Preexisting Warranties	$ (13,887)	$ (10,855)	$ (982)
Standard Product Warranty Accrual, Increase for Warranties Issued		(1,900)
ARPA Trial [Member]
Loss Contingencies [Line Items]
Standard and Extended Product Warranty Accrual, Increase (Decrease) for Preexisting Warranties		$ 2,300

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Contingencies ARPA Settlement (Details) - USD ($) $ in Thousands					12 Months Ended
	Jul. 01, 2020	Jul. 01, 2019	Jul. 01, 2018	Jul. 21, 2017	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Loss Contingencies [Line Items]
ARPA post-judgment interest rate					1.00%
Payments for Legal Settlements					$ 4,200
Standard and Extended Product Warranty Accrual, Increase (Decrease) for Preexisting Warranties					(13,887)	$ (10,855)	$ (982)
Standard Product Warranty Accrual, Increase for Warranties Issued						1,900
ARPA pre-judgment interest [Domain]
Loss Contingencies [Line Items]
Litigation Settlement Interest				$ 4,100	3,000
ARPA Trial [Member]
Loss Contingencies [Line Items]
Payments for Legal Settlements	$ 2,000	$ 2,500	$ 2,500		7,000
Discounted the liability					600
Reduction in accrual					1,600
Other Current Liabilities [Member]
Loss Contingencies [Line Items]
Litigation Settlement Interest					3,700
ARPA Trial [Member]
Loss Contingencies [Line Items]
Standard and Extended Product Warranty Accrual, Increase (Decrease) for Preexisting Warranties						$ 2,300
ARPA Trial [Member] | Other Current Liabilities [Member]
Loss Contingencies [Line Items]
Standard and Extended Product Warranty Accrual, Increase (Decrease) for Preexisting Warranties					2,500
ARPA Trial [Member] | Other Noncurrent Liabilities [Member]
Loss Contingencies [Line Items]
Standard and Extended Product Warranty Accrual, Increase (Decrease) for Preexisting Warranties					$ 3,900

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Derivative Financial Instruments - Additional Information (Detail) - USD ($)	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Net gains deferred on derivative financial instruments in accumulated other comprehensive income (loss)	$ 1,800,000	$ 800,000
Cash Flow Hedging | Designated as Hedging Instrument | FX Forward Contracts
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Notional amount of foreign currency forward contracts	$ 63,000,000.0

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Derivative Financial Instruments - Summary of Derivative Financial Instruments (Detail) - USD ($)	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016
Derivatives, Fair Value [Line Items]
Derivative Instruments, Gain (Loss) Reclassification from Accumulated OCI to Income, Estimated Net Amount to be Transferred	$ 1,800,000	$ 800,000
Designated as Hedging Instrument | FX Forward Contracts | Accounts receivable-other
Derivatives, Fair Value [Line Items]
Asset Derivatives	1,088,000	3,805,000
Designated as Hedging Instrument | FX Forward Contracts | Other assets
Derivatives, Fair Value [Line Items]
Asset Derivatives	312,000	665,000
Designated as Hedging Instrument | FX Forward Contracts | Accounts payable
Derivatives, Fair Value [Line Items]
Derivative Liability	105,000	1,012,000
Derivatives Not Designated as Hedges | FX Forward Contracts | Accounts receivable-other
Derivatives, Fair Value [Line Items]
Asset Derivatives	7,000	105,000
Derivatives Not Designated as Hedges | FX Forward Contracts | Accounts payable
Derivatives, Fair Value [Line Items]
Derivative Liability	1,722,000	403,000
Derivatives Not Designated as Hedges | FX Forward Contracts | Other Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative Liability	12,000	$ 7,000
Cash Flow Hedging | Designated as Hedging Instrument | FX Forward Contracts
Derivatives, Fair Value [Line Items]
Notional amount of foreign currency forward contracts	$ 63,000,000.0

XML

Derivative Financial Instruments - Schedule of Effect of Derivative Instruments on Statements of Financial Performance (Detail) - FX Forward Contracts - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016
Designated as Hedging Instrument | Cash Flow Hedging
Derivative Instruments, Gain (Loss) [Line Items]
Amount of gain (loss) recognized in other comprehensive income	$ 3,346	$ 2,208
Designated as Hedging Instrument | Cash Flow Hedging | Revenues
Derivative Instruments, Gain (Loss) [Line Items]
Effective portion of gain (loss) reclassified from accumulated other comprehensive income into earnings	10,059	4,624
Designated as Hedging Instrument | Cash Flow Hedging | Cost of operations
Derivative Instruments, Gain (Loss) [Line Items]
Effective portion of gain (loss) reclassified from accumulated other comprehensive income into earnings	(118)	195
Designated as Hedging Instrument | Cash Flow Hedging | Other-net
Derivative Instruments, Gain (Loss) [Line Items]
Effective portion of gain (loss) reclassified from accumulated other comprehensive income into earnings	(7,438)	(1,221)
Portion of gain (loss) recognized in income that is excluded from effectiveness testing	(5,277)	4,518
Derivatives Not Designated as Hedges | Other-net
Derivative Instruments, Gain (Loss) [Line Items]
Gain (loss) recognized in income	(3,436)	(872)
Other Accounts Receivable [Member] | Designated as Hedging Instrument
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Asset	1,088	3,805
Other Accounts Receivable [Member] | Derivatives Not Designated as Hedges
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Asset	7	105
Other Assets [Member] | Designated as Hedging Instrument
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Asset	312	665
Other Liabilities [Member] | Designated as Hedging Instrument
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Liability	0	213
Accounts Payable [Member] | Designated as Hedging Instrument
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Liability	105	1,012
Accounts Payable [Member] | Derivatives Not Designated as Hedges
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Liability	1,722	403
Other Liabilities [Member] | Derivatives Not Designated as Hedges
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Liability	$ 12	$ 7

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Fair Value Measurements - Summary of Available-for-Sale Securities Measured at Fair Value (Detail) - USD ($) $ in Thousands	Dec. 31, 2017	Dec. 31, 2016
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale securities measured at fair value	$ 15,809	$ 17,991
Commercial Paper [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale securities measured at fair value	1,895	6,734
Certificates of Deposit [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale securities measured at fair value	2,398	2,251
Mutual Fund [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale securities measured at fair value	1,331	1,152
Corporate Bond Securities [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale securities measured at fair value	4,447	750
US Government Corporations and Agencies Securities [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale securities measured at fair value	5,738	7,104
Fair Value, Inputs, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale securities measured at fair value	10,185	7,854
Fair Value, Inputs, Level 1 [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	0	0
Fair Value, Inputs, Level 1 [Member] | Certificates of Deposit [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale securities measured at fair value	0	0
Fair Value, Inputs, Level 1 [Member] | Mutual Fund [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale securities measured at fair value	0	0
Fair Value, Inputs, Level 1 [Member] | Corporate Bond Securities [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale securities measured at fair value	4,447	750
Fair Value, Inputs, Level 1 [Member] | US Government Corporations and Agencies Securities [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale securities measured at fair value	5,738	7,104
Fair Value, Inputs, Level 3 [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	0	0
Fair Value, Inputs, Level 3 [Member] | Certificates of Deposit [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale securities measured at fair value	0	0
Fair Value, Inputs, Level 3 [Member] | Mutual Fund [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale securities measured at fair value	0	0
Fair Value, Inputs, Level 3 [Member] | Corporate Bond Securities [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale securities measured at fair value		0
Fair Value, Inputs, Level 3 [Member] | US Government Corporations and Agencies Securities [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale securities measured at fair value	0	0
Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale securities measured at fair value	5,624	10,137
Fair Value, Inputs, 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	1,895	6,734
Fair Value, Inputs, Level 2 [Member] | Certificates of Deposit [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale securities measured at fair value	2,398	2,251
Fair Value, Inputs, Level 2 [Member] | Mutual Fund [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale securities measured at fair value	1,331	1,152
Fair Value, Inputs, Level 2 [Member] | Corporate Bond Securities [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale securities measured at fair value		0
Fair Value, Inputs, Level 2 [Member] | US Government Corporations and Agencies Securities [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale securities measured at fair value	0	0
Fair Value, Inputs, Level 2 [Member] | FX Forward Contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair value of foreign currency forward contracts	$ (432)	$ 2,940

XML

Fair Value Measurements - Additional Information (Detail) - USD ($) $ in Thousands	Dec. 31, 2017	Dec. 31, 2016
Fair Value, Inputs, Level 2 [Member] | FX Forward Contracts
Fair Values Of Financial Instruments [Line Items]
Fair value of foreign currency forward contracts	$ (432)	$ 2,940

XML

Revolving Debt Schedule of Revolving Debt (Details) - USD ($) $ in Thousands	Dec. 31, 2017	Dec. 31, 2016
Debt Instrument [Line Items]
Revolving debt	$ 103,473	$ 24,041
Senior Secured Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Revolving debt	94,300	9,800
Foreign Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Revolving debt	$ 9,173	$ 14,241

XML

Revolving Debt United States Revolving Credit Facility (Details)	1 Months Ended	3 Months Ended				6 Months Ended	9 Months Ended	12 Months Ended			15 Months Ended
	Aug. 07, 2017	Dec. 31, 2017 USD ($)	Sep. 30, 2017 USD ($)	Jun. 30, 2017 USD ($)	Dec. 31, 2016 USD ($)	Jun. 30, 2016	Dec. 31, 2018	Dec. 31, 2017 USD ($)	Dec. 31, 2016 USD ($)	Dec. 31, 2015 USD ($)	Sep. 30, 2018 USD ($)	Jun. 30, 2015 USD ($)
Debt Instrument [Line Items]
Letters of credit and bank guarantees partially covered by the US Credit Facility		$ 114,200,000						$ 114,200,000
Line of Credit Facility, Maximum Borrowing Capacity		221,400,000						221,400,000
Change in construction cost estimates		$ (34,700,000)	$ 30,100,000	$ (115,200,000)	$ (98,100,000)			(158,500,000)	$ (141,100,000)
Line of Credit Facility Possible Increase in Capacity Leverage Ratio						200.00%
Amortization of Deferred Loan Origination Fees, Net								$ 9,496,000	1,244,000	$ 1,131,000
Line of Credit Facility, Collateral Fees								0.015
Line of Credit Facility, Collateral Fees, Amount								$ 1,500,000
Ratio of Indebtedness to Net Capital		2.59						2.59
Interest Coverage Ratio		2.50						2.50
Capital Expenditure limit								$ 27,500,000
Revolving debt		$ 103,473,000			24,041,000			$ 103,473,000	24,041,000
Debt Instrument, Interest Rate, Effective Percentage	18.00%	6.90%						6.90%
Letters of Credit Outstanding, Amount		$ 40,400,000						$ 40,400,000
Maximum [Member]
Debt Instrument [Line Items]
Line of Credit Facility, Covenant Terms	450							600
Minimum [Member]
Debt Instrument [Line Items]
Covenant terms, liquidity		$ 75,000,000.0						$ 75,000,000.0
Covenant description, sale of assets								$ 100,000,000
Quarter ended September 30, 2018 [Domain] | Minimum [Member]
Debt Instrument [Line Items]
Interest Coverage Ratio		0.85						0.85
Quarter ended December 31, 2018 [Domain]
Debt Instrument [Line Items]
Ratio of Indebtedness to Net Capital		4.75						4.75
Quarter ended December 31, 2018 [Domain] | Minimum [Member]
Debt Instrument [Line Items]
Interest Coverage Ratio		1.25						1.25
Quarter ended March 31, 2019 [Domain]
Debt Instrument [Line Items]
Ratio of Indebtedness to Net Capital		3.00						3.00
Quarter ended March 31, 2019 [Domain] | Minimum [Member]
Debt Instrument [Line Items]
Interest Coverage Ratio		1.50						1.50
Quarter ended December 31, 2017 [Domain]
Debt Instrument [Line Items]
Change in construction cost estimates		$ 38,700,000.00
Ratio of Indebtedness to Net Capital		8.50						8.50
Quarter ended December 31, 2017 [Domain] | Minimum [Member]
Debt Instrument [Line Items]
Interest Coverage Ratio		1.25						1.25
Quarter ended March 31, 2018 [Domain]
Debt Instrument [Line Items]
Ratio of Indebtedness to Net Capital		7.00						7.00
Quarter ended March 31, 2018 [Domain] | Minimum [Member]
Debt Instrument [Line Items]
Interest Coverage Ratio		1.15						1.15
Quarter ended June 30, 2018 [Domain] | Minimum [Member]
Debt Instrument [Line Items]
Interest Coverage Ratio		1.00						1.00
Quarters ended June 30, 2018 and September 30, 2018 [Domain]
Debt Instrument [Line Items]
Ratio of Indebtedness to Net Capital		6.50						6.50
Quarters ending June 30 and September 30, 2019 [Domain]
Debt Instrument [Line Items]
Ratio of Indebtedness to Net Capital		2.75						2.75
Quarter ended December 31, 2019 and each quarter thereafter [Domain]
Debt Instrument [Line Items]
Ratio of Indebtedness to Net Capital		2.50						2.50
Quarters ended September 30, 2019 and thereafter [Domain]
Debt Instrument [Line Items]
Change in construction cost estimates											$ 4,000,000.00
Quarters ended June 30, 2019 and thereafter [Domain] | Minimum [Member]
Debt Instrument [Line Items]
Interest Coverage Ratio		2.00						2.00
Senior Secured Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity												$ 600,000,000
Line of Credit Facility Possible Increase in Capacity Amount												$ 200,000,000
Revolving debt		$ 94,300,000			$ 9,800,000			$ 94,300,000	9,800,000
Senior Secured Revolving Credit Facility [Member] | London Interbank Offered Rate (LIBOR) [Member] | Maximum [Member]
Debt Instrument [Line Items]
Debt Instrument, Basis Spread on Variable Rate								1.00%
Senior Secured Revolving Credit Facility [Member] | London Interbank Offered Rate (LIBOR) [Member] | Twelve months ended December 31, 2018 [Member]
Debt Instrument [Line Items]
Debt Instrument, Basis Spread on Variable Rate								5.00%
Senior Secured Revolving Credit Facility [Member] | London Interbank Offered Rate (LIBOR) [Member] | March 1 through September 1, 2018 [Member]
Debt Instrument [Line Items]
Debt Instrument, Basis Spread on Variable Rate								7.00%
Senior Secured Revolving Credit Facility [Member] | London Interbank Offered Rate (LIBOR) [Member] | Twelve months ended December 31, 2019 [Member] [Member]
Debt Instrument [Line Items]
Debt Instrument, Basis Spread on Variable Rate								6.00%
Senior Secured Revolving Credit Facility [Member] | London Interbank Offered Rate (LIBOR) [Member] | Twelve months ended December 31, 2020 [Member] [Member]
Debt Instrument [Line Items]
Debt Instrument, Basis Spread on Variable Rate								7.00%
Senior Secured Revolving Credit Facility [Member] | Base Rate [Member] | Maximum [Member]
Debt Instrument [Line Items]
Debt Instrument, Basis Spread on Variable Rate								0.50%
Senior Secured Revolving Credit Facility [Member] | Base Rate [Member] | Twelve months ended December 31, 2018 [Member]
Debt Instrument [Line Items]
Debt Instrument, Basis Spread on Variable Rate								4.00%
Senior Secured Revolving Credit Facility [Member] | Base Rate [Member] | March 1 through September 1, 2018 [Member]
Debt Instrument [Line Items]
Debt Instrument, Basis Spread on Variable Rate								6.00%
Senior Secured Revolving Credit Facility [Member] | Base Rate [Member] | Twelve months ended December 31, 2019 [Member] [Member]
Debt Instrument [Line Items]
Debt Instrument, Basis Spread on Variable Rate								5.00%
Senior Secured Revolving Credit Facility [Member] | Base Rate [Member] | Twelve months ended December 31, 2020 [Member] [Member]
Debt Instrument [Line Items]
Debt Instrument, Basis Spread on Variable Rate								6.00%
Financial Letter of Credit outstanding [Domain]
Debt Instrument [Line Items]
Line of Credit Facility, Collateral Fees								0.025
US Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Amortization of Deferred Loan Origination Fees, Net								$ 6,270,000	$ 1,244,000	$ 1,131,000
Credit Facility [Domain] | Senior Secured Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Interest Expense, Debt								11,321,000.000
Financial Standby Letter of Credit [Member] | During Covenant Relief Period [Member] | Maximum [Member]
Debt Instrument [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity		30,000,000						30,000,000
Amended Credit Agreement [Member] | During Covenant Relief Period [Member]
Debt Instrument [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity		250,000,000						$ 250,000,000
Covenant Relief Period [Domain] | Senior Secured Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Debt Instrument, Fee								0.01
Letter of Credit [Member] | Senior Secured Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Letters of Credit Outstanding, Amount		123,700,000						$ 123,700,000
Letter of Credit [Member] | Financial Standby Letter of Credit [Member]
Debt Instrument [Line Items]
Letters of Credit Outstanding, Amount		$ 7,400,000						$ 7,400,000
Volund [Member] | Maximum [Member]
Debt Instrument [Line Items]
Debt Instrument, Covenant Description							15

XML

Revolving Debt Foreign Revolving Credit Facilities (Details) - USD ($) $ in Thousands	Dec. 31, 2017	Aug. 07, 2017	Dec. 31, 2016
Debt Instrument [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity	$ 221,400
Revolving debt	$ 103,473		$ 24,041
Debt Instrument, Interest Rate, Effective Percentage	6.90%	18.00%
Foreign Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity	$ 9,200
Revolving debt	$ 9,173		$ 14,241
Debt Instrument, Interest Rate, Effective Percentage	6.07%

XML

Revolving Debt Other Credit Arrangements (Details) - USD ($) $ in Millions	Dec. 31, 2017	Dec. 31, 2016
Debt Instrument [Line Items]
Letters of credit not secured by the US Credit Facility	$ 269.1	$ 255.2
Letters of Credit Outstanding, Amount	40.4
Guarantor Obligations, Current Carrying Value	$ 378.8

XML

Stock-Based Compensation 2015 Long-Term Incentive Plan (Details) shares in Thousands	12 Months Ended
	Dec. 31, 2017 shares
2015 Long-Term Incentive Plan [Abstract]
Share-based Compensation Arrangement by Share-based Payment Award, Number of Additional Shares Authorized	2,500
Share-based Compensation Arrangement by Share-based Payment Award, Number of Shares Authorized	8,300
Share-based Compensation Arrangement by Share-based Payment Award, Number of Shares Available for Grant	200

XML

Stock-Based Compensation Company Stock Options Fair Value (Details) - Employee Stock Option [Member]	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Fair Value Assumptions, Risk Free Interest Rate	1.14%	1.38%
Share-based Compensation Arrangement by Share-based Payment Award, Fair Value Assumptions, Expected Volatility Rate	25.00%	28.00%
Share-based Compensation Arrangement by Share-based Payment Award, Fair Value Assumptions, Expected Dividend Rate	0.00%	0.00%

XML

Stock-Based Compensation Stock Options Rollforward (Details) - Employee Stock Option [Member] - USD ($) $ / shares in Units, shares in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Options, Outstanding, Number	2,478	2,652
Share-based Compensation Arrangement by Share-based Payment Award, Options, Outstanding, Weighted Average Exercise Price	$ 18.28	$ 18.27
Share-based Compensation Arrangement by Share-based Payment Award, Options, Grants in Period, Gross	0
Share-based Compensation Arrangements by Share-based Payment Award, Options, Grants in Period, Weighted Average Exercise Price	$ 0.00
Share-based Compensation Arrangement by Share-based Payment Award, Options, Exercises in Period	(24)
Share-based Compensation Arrangements by Share-based Payment Award, Options, Exercises in Period, Weighted Average Exercise Price	$ 15.04
Share-based Compensation Arrangement by Share-based Payment Award, Options, Forfeitures in Period	(150)
Share-based Compensation Arrangements by Share-based Payment Award, Options, Forfeitures in Period, Weighted Average Exercise Price	$ 18.50
Share-based Compensation Arrangement by Share-based Payment Award, Options, Outstanding, Intrinsic Value	$ 5.46
Share-based Compensation Arrangement by Share-based Payment Award, Options, Exercisable, Number	1,844
Share-based Compensation Arrangement by Share-based Payment Award, Options, Exercisable, Weighted Average Exercise Price	$ 18.14
Share-based Compensation Arrangement by Share-based Payment Award, Options, Exercisable, Intrinsic Value	$ 4.69

XML

Stock-Based Compensation Stock Options Narrative (Details) - USD ($) $ / shares in Units, $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Options, Exercises in Period, Intrinsic Value	$ 0.7	$ 2.3
Share-based Compensation Arrangement by Share-based Payment Award, Options, Grants in Period, Weighted Average Grant Date Fair Value	$ 4.03	$ 4.80
Employee Stock Option [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Employee Service Share-based Compensation, Tax Benefit Realized from Exercise of Stock Options	$ 0.3

XML

Stock-Based Compensation Restricted Stock Unit Rollforward (Details) - Restricted Stock [Member] - $ / shares shares in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number	2,227	712
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value	$ 7.63	$ 19.14
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period	1,902
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period, Weighted Average Grant Date Fair Value	$ 5.35
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period	(282)
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period, Weighted Average Grant Date Fair Value	$ 18.48
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Forfeited in Period	(105)
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Forfeitures, Weighted Average Grant Date Fair Value	$ 15.00

XML

Stock-Based Compensation Restricted Stock Unit Narrative (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016
Restricted Stock [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Employee Service Share-based Compensation, Tax Benefit Realized from Exercise of Stock Options	$ 1.1	$ 2.7

XML

Stock-Based Compensation Company PRSU Fair Value (Details) - Performance based restricted stock [Member]	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Fair Value Assumptions, Risk Free Interest Rate	1.54%	0.96%
Share-based Compensation Arrangement by Share-based Payment Award, Fair Value Assumptions, Expected Volatility Rate	42.00%	25.00%
Share-based Compensation Arrangement by Share-based Payment Award, Fair Value Assumptions, Expected Dividend Rate	0.00%	0.00%

XML

Stock-Based Compensation PRSU Rollforward (Details) - Performance based restricted stock [Member] - $ / shares shares in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number	1,135	451
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value	$ 12.75	$ 19.29
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period	828
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period, Weighted Average Grant Date Fair Value	$ 9.74
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period	(3)
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period, Weighted Average Grant Date Fair Value	$ 9.67
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Forfeited in Period	(141)
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Forfeitures, Weighted Average Grant Date Fair Value	$ 14.07

XML

Stock-Based Compensation PRSU Cash Settled Units Rollforward (Details) - Performance-based cash settled units [Member] - $ / shares shares in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number	1,799	32
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value	$ 4.53	$ 18.53
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period	1,908
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period, Weighted Average Grant Date Fair Value	$ 2.90
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period	(7)
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period, Weighted Average Grant Date Fair Value	$ 0.00
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Forfeited in Period	(134)
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Forfeitures, Weighted Average Grant Date Fair Value	$ 3.93

XML

Acquisitions Universal (Details) - USD ($) $ in Thousands		3 Months Ended								12 Months Ended
	Jan. 11, 2017	Dec. 31, 2017	Sep. 30, 2017	Jun. 30, 2017	Mar. 31, 2017	Dec. 31, 2016	Sep. 30, 2016	Jun. 30, 2016	Mar. 31, 2016	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Business Acquisition [Line Items]
Payments to Acquire Businesses, Net of Cash Acquired										$ 52,547	$ 144,780	$ 0
Cash Acquired from Acquisition	$ 4,379
Revolving debt		$ 103,473				$ 24,041				103,473	24,041
Revenues		408,099	$ 408,703	$ 349,829	$ 391,104	379,984	$ 410,955	$ 383,208	$ 404,116	1,557,735	1,578,263	1,757,295
Gross Profit		$ 45,513	$ 47,287	$ (55,822)	62,900	$ (848)	$ 73,757	$ 26,052	$ 80,156	99,878	$ 179,117	$ 308,157
Universal [Member]
Business Acquisition [Line Items]
Payments to Acquire Businesses, Net of Cash Acquired					$ 52,500
Business Acquisition, Transaction Costs	200
Revolving debt	55,000
Amortization of Intangible Assets										3,100
Acquisition employee number	$ 0
Business Combination, Acquisition Related Costs										$ 1,700

XML

Acquisitions Universal Purchase Price Allocation (Details) - USD ($) $ in Thousands		3 Months Ended								12 Months Ended
	Jan. 11, 2017	Dec. 31, 2017	Sep. 30, 2017	Jun. 30, 2017	Mar. 31, 2017	Dec. 31, 2016	Sep. 30, 2016	Jun. 30, 2016	Mar. 31, 2016	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Business Acquisition [Line Items]
Revenues		$ 408,099	$ 408,703	$ 349,829	$ 391,104	$ 379,984	$ 410,955	$ 383,208	$ 404,116	$ 1,557,735	$ 1,578,263	$ 1,757,295
Gross Profit		$ 45,513	$ 47,287	$ (55,822)	$ 62,900	$ (848)	$ 73,757	$ 26,052	$ 80,156	99,878	179,117	$ 308,157
Cash	$ 4,379
Accounts receivable	11,270
Contracts in progress	3,167
Inventories	4,585
Other assets	579
Property, plant and equipment	16,692
Goodwill	14,413
Identifiable intangible assets	19,500									$ 19,500	$ 55,438
Deferred income tax assets	935
Current liabilities	(10,833)
Other noncurrent liabilities	(1,423)
Deferred income tax liabilities	(6,338)
Net acquisition cost	56,926
Universal [Member]
Business Acquisition [Line Items]
Acquisition employee number	$ 0

XML

Acquisitions Universal Intangible Assets (Details) - USD ($) $ in Thousands			12 Months Ended
	Jan. 11, 2017	Jul. 01, 2016	Dec. 31, 2017
Business Acquisition [Line Items]
Indefinite-lived Intangible Assets (Excluding Goodwill), Fair Value Disclosure		$ 55,164
Customer Relationships
Business Acquisition [Line Items]
Indefinite-lived Intangible Assets (Excluding Goodwill), Fair Value Disclosure		$ 12,217
Acquired Finite-lived Intangible Assets, Weighted Average Useful Life		9 years
Backlog
Business Acquisition [Line Items]
Indefinite-lived Intangible Assets (Excluding Goodwill), Fair Value Disclosure		$ 17,769
Acquired Finite-lived Intangible Assets, Weighted Average Useful Life		2 years
Tradename [Member]
Business Acquisition [Line Items]
Indefinite-lived Intangible Assets (Excluding Goodwill), Fair Value Disclosure		$ 8,885
Acquired Finite-lived Intangible Assets, Weighted Average Useful Life		20 years
Patented Technology [Member]
Business Acquisition [Line Items]
Indefinite-lived Intangible Assets (Excluding Goodwill), Fair Value Disclosure		$ 14,438
Acquired Finite-lived Intangible Assets, Weighted Average Useful Life		10 years
Universal [Member]
Business Acquisition [Line Items]
Amortization of Intangible Assets			$ 3,100
Indefinite-lived Intangible Assets (Excluding Goodwill), Fair Value Disclosure	$ 19,500
Business Combination, Acquisition Related Costs			$ 1,700
Universal [Member] | Customer Relationships
Business Acquisition [Line Items]
Indefinite-lived Intangible Assets (Excluding Goodwill), Fair Value Disclosure	$ 10,800
Acquired Finite-lived Intangible Assets, Weighted Average Useful Life	15 years
Universal [Member] | Backlog
Business Acquisition [Line Items]
Indefinite-lived Intangible Assets (Excluding Goodwill), Fair Value Disclosure	$ 1,700
Acquired Finite-lived Intangible Assets, Weighted Average Useful Life	1 year
Universal [Member] | Tradename [Member]
Business Acquisition [Line Items]
Indefinite-lived Intangible Assets (Excluding Goodwill), Fair Value Disclosure	$ 3,000
Acquired Finite-lived Intangible Assets, Weighted Average Useful Life	20 years
Universal [Member] | Patented Technology [Member]
Business Acquisition [Line Items]
Indefinite-lived Intangible Assets (Excluding Goodwill), Fair Value Disclosure	$ 4,000
Acquired Finite-lived Intangible Assets, Weighted Average Useful Life	7 years

XML

Acquisitions Universal Pro Forma (Details) - USD ($) $ / shares in Units, $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Business Acquisition [Line Items]
Interest Expense	$ 26,305	$ 3,796	$ 2,338
Business Acquisition, Pro Forma Earnings Per Share, Basic		$ (2.22)
Business Acquisition, Pro Forma Earnings Per Share, Diluted		$ (2.22)
Universal [Member]
Business Acquisition [Line Items]
Business Acquisition, Pro Forma Revenue		$ 1,661,000
Amortization		2,800
Interest Expense		(400)
Acquisition Costs, Period Cost		2,100
Business Acquisition, Pro Forma Net Income (Loss)		$ (113,900)
Business Acquisition, Pro Forma Earnings Per Share, Basic		$ 0
Business Acquisition, Pro Forma Earnings Per Share, Diluted		$ 0

XML

Acquisitions SPIG (Details) $ / shares in Units, $ in Thousands, € in Millions	3 Months Ended								12 Months Ended
	Dec. 31, 2017 USD ($)	Sep. 30, 2017 USD ($)	Jun. 30, 2017 USD ($)	Mar. 31, 2017 USD ($)	Dec. 31, 2016 USD ($)	Sep. 30, 2016 USD ($)	Jun. 30, 2016 USD ($)	Mar. 31, 2016 USD ($)	Dec. 31, 2017 USD ($)	Dec. 31, 2016 USD ($) $ / shares	Dec. 31, 2015 USD ($) $ / shares	Sep. 30, 2016 EUR (€)	Jul. 01, 2016 USD ($)	Jul. 01, 2016 EUR (€)
Business Acquisition [Line Items]
Revenues	$ 408,099	$ 408,703	$ 349,829	$ 391,104	$ 379,984	$ 410,955	$ 383,208	$ 404,116	$ 1,557,735	$ 1,578,263	$ 1,757,295
Gross Profit	$ 45,513	$ 47,287	$ (55,822)	$ 62,900	(848)	73,757	$ 26,052	$ 80,156	$ 99,878	$ 179,117	308,157
Business Acquisition, Pro Forma Earnings Per Share, Basic | $ / shares										$ (2.22)
Business Acquisition, Pro Forma Earnings Per Share, Diluted | $ / shares										$ (2.22)
SPIG [Member]
Business Acquisition [Line Items]
Finalized purchase price allocation increase in goodwill					$ 2,500					$ 2,500
Business Acquisition, Pro Forma Revenue										1,663,126	1,941,987
Payments to acquire business, Euro | €														€ 155.0
Payments to acquire business, US Dollars													$ 172,100
Business combination transaction price returned to company based on difference between actual working capital and pre-close estimates						$ 2,900						€ 2.6
Business Acquisition, Transaction Costs													$ 300
Revenues										96,300
Gross Profit										7,800
Business Acquisition, Pro Forma Net Income (Loss)										$ (111,500)	$ 12,047
Business Acquisition, Pro Forma Earnings Per Share, Basic | $ / shares											$ 0.23
Business Acquisition, Pro Forma Earnings Per Share, Diluted | $ / shares											$ 0.22

XML

Acquisitions SPIG Pro Forma (Details) - USD ($) $ / shares in Units, $ in Thousands			12 Months Ended
	Jan. 11, 2017	Jul. 01, 2016	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Business Acquisition [Line Items]
Interest Expense			$ 26,305	$ 3,796	$ 2,338
Cash Acquired from Acquisition	$ 4,379
Noncash or Part Noncash Acquisition, Accounts Receivable Acquired	11,270
Business combination, recognized identifiable assets and liabilities assumed contracts in progress	3,167
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Inventory	4,585
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Current Assets, Other	579
Property, plant and equipment	16,692
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Intangible Assets, Other than Goodwill	14,413
Finite-lived Intangible Assets Acquired	19,500		19,500	$ 55,438
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Current Liabilities	10,833
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Noncurrent Liabilities, Other	1,423
Acquisition Costs, Cumulative	$ 56,926
Business Acquisition, Pro Forma Earnings Per Share, Basic				$ (2.22)
Business Acquisition, Pro Forma Earnings Per Share, Diluted				$ (2.22)
SPIG [Member]
Business Acquisition [Line Items]
Amortization				$ 6,500	18,600
Interest Expense				500	700
Business Combination, Integration Related Costs			$ 1,600	3,500
Business Acquisition, Pro Forma Revenue				1,663,126	1,941,987
Cash Acquired from Acquisition		$ 25,994
Noncash or Part Noncash Acquisition, Accounts Receivable Acquired		58,843
Business combination, recognized identifiable assets and liabilities assumed contracts in progress		61,155
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Inventory		2,554
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Current Assets, Other		7,341
Property, plant and equipment		6,104
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Intangible Assets, Other than Goodwill		72,401
Finite-lived Intangible Assets Acquired		55,164
Business combination, recognized identifiable assets and liabilities assumed deferred income taxes		5,550
Business combination, recognized identifiable revolving debt assumed		27,530
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Current Liabilities		56,323
Business combination, recognized identifiable assets and liabilities - advance billings on contracts		15,226
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Noncurrent Liabilities, Other		379
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Deferred Tax Liabilities Noncurrent		17,120
Business combination, recognized idetnfiable assets and liabilities assumed - noncontrolling interest in joint venture		7,754
Acquisition Costs, Cumulative		$ 170,800
Business Acquisition, Pro Forma Net Income (Loss)				$ (111,500)	$ 12,047
Business Acquisition, Pro Forma Earnings Per Share, Basic					$ 0.23
Business Acquisition, Pro Forma Earnings Per Share, Diluted					$ 0.22
Acquisition Costs, Period Cost					$ 200

XML

Acquisitions SPIG Purchase Price Allocation (Details) - USD ($) $ in Thousands			12 Months Ended
	Jan. 11, 2017	Jul. 01, 2016	Dec. 31, 2017	Dec. 31, 2016
Business Acquisition [Line Items]
Cash	$ 4,379
Accounts receivable	11,270
Contracts in progress	3,167
Inventories	4,585
Other assets	579
Property, plant and equipment	16,692
Goodwill	14,413
Identifiable intangible assets	19,500		$ 19,500	$ 55,438
Current liabilities	(10,833)
Other noncurrent liabilities	(1,423)
Net acquisition cost	$ 56,926
SPIG [Member]
Business Acquisition [Line Items]
Finalized purchase price allocation increase in goodwill				$ 2,500
Cash		$ 25,994
Accounts receivable		58,843
Contracts in progress		61,155
Inventories		2,554
Other assets		7,341
Property, plant and equipment		6,104
Goodwill		72,401
Identifiable intangible assets		55,164
Deferred income tax assets		5,550
Revolving debt		(27,530)
Current liabilities		(56,323)
Advance billings on contracts		(15,226)
Other noncurrent liabilities		(379)
Deferred income tax liabilities		(17,120)
Noncontrolling interest in joint venture		(7,754)
Net acquisition cost		$ 170,800

XML

Acquisitions SPIG Intangible Assets (Details) - USD ($) $ in Thousands		12 Months Ended
	Jul. 01, 2016	Dec. 31, 2017	Dec. 31, 2016
Business Acquisition [Line Items]
Indefinite-lived Intangible Assets (Excluding Goodwill), Fair Value Disclosure	$ 55,164
Customer Relationships
Business Acquisition [Line Items]
Indefinite-lived Intangible Assets (Excluding Goodwill), Fair Value Disclosure	$ 12,217
Acquired Finite-lived Intangible Assets, Weighted Average Useful Life	9 years
Backlog
Business Acquisition [Line Items]
Indefinite-lived Intangible Assets (Excluding Goodwill), Fair Value Disclosure	$ 17,769
Acquired Finite-lived Intangible Assets, Weighted Average Useful Life	2 years
Tradename [Member]
Business Acquisition [Line Items]
Indefinite-lived Intangible Assets (Excluding Goodwill), Fair Value Disclosure	$ 8,885
Acquired Finite-lived Intangible Assets, Weighted Average Useful Life	20 years
Patented Technology [Member]
Business Acquisition [Line Items]
Indefinite-lived Intangible Assets (Excluding Goodwill), Fair Value Disclosure	$ 14,438
Acquired Finite-lived Intangible Assets, Weighted Average Useful Life	10 years
Noncompete Agreements [Member]
Business Acquisition [Line Items]
Indefinite-lived Intangible Assets (Excluding Goodwill), Fair Value Disclosure	$ 1,666
Acquired Finite-lived Intangible Assets, Weighted Average Useful Life	3 years
Software Development [Member]
Business Acquisition [Line Items]
Indefinite-lived Intangible Assets (Excluding Goodwill), Fair Value Disclosure	$ 189
Acquired Finite-lived Intangible Assets, Weighted Average Useful Life	3 years
SPIG [Member]
Business Acquisition [Line Items]
Amortization of Intangible Assets		$ 9,100	$ 13,300
Business Combination, Integration Related Costs		$ 1,600	$ 3,500

XML

Quarterly Financial Data (Details) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended								12 Months Ended
	Dec. 31, 2017	Sep. 30, 2017	Jun. 30, 2017	Mar. 31, 2017	Dec. 31, 2016	Sep. 30, 2016	Jun. 30, 2016	Mar. 31, 2016	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Quarterly Financial Information Disclosure [Abstract]
Revenues	$ 408,099	$ 408,703	$ 349,829	$ 391,104	$ 379,984	$ 410,955	$ 383,208	$ 404,116	$ 1,557,735	$ 1,578,263	$ 1,757,295
Gross Profit	45,513	47,287	(55,822)	62,900	(848)	73,757	26,052	80,156	99,878	179,117	308,157
Operating Income (Loss)	(23,373)	(104,748)	(144,646)	(8,798)	(58,587)	11,133	(72,585)	17,266	(281,565)	(102,773)	21,861
Equity in income (loss) of investees	3,513	1,234	(15,232)	618	11,553	2,827	(616)	2,676	(9,867)	16,440	(242)
Net income (loss) attributable to shareholders	$ (107,478)	$ (114,302)	$ (150,999)	$ (7,045)	$ (71,560)	$ 8,894	$ (63,490)	$ 10,507	$ (379,824)	$ (115,649)	$ 19,141
Basic earnings (loss) per share from continuing operations	$ (2.44)	$ (2.48)	$ (3.09)	$ (0.14)	$ (1.47)	$ 0.18	$ (1.25)	$ 0.20	$ (8.09)	$ (2.31)	$ 0.31
Diluted earnings (loss) per share from Continuing operations	$ (2.44)	$ (2.48)	$ (3.09)	$ (0.14)	$ (1.47)	$ 0.18	$ (1.25)	$ 0.20	$ (8.09)	$ (2.31)	$ 0.30

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Quarterly Financial Data Quarterly Results Details (Details) - USD ($) $ in Thousands	3 Months Ended				9 Months Ended	12 Months Ended
	Dec. 31, 2017	Mar. 31, 2017	Dec. 31, 2016	Jun. 30, 2016	Sep. 30, 2016	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Quarterly Financial Information Disclosure [Abstract]
Defined Benefit Plan, MTM adjustment excluding curtailment and settlements	$ (9,800)	$ 1,100	$ (6,400)	$ 30,000	$ 500		$ (27,500)
Goodwill impairment charges						$ (86,903)	$ 0	$ 0
Additional tax expense from New Tax Act						$ 62,400

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Related Party Transactions Transactions with Former Parent (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Acquisition of business, net of cash acquired	$ (52,547)	$ (144,780)	$ 0
Cash pooling and general financing activities	$ (1,082)	$ (246)	(491)
Former Parent [Member]
Sales to former Parent			911
Corporate administrative expense			35,343
Income tax allocation			11,872
Acquisition of business, net of cash acquired			0
Cash pooling and general financing activities			(91,015)
Cash contribution received at spin-off			125,300
Net transfer from former Parent per statement of cash flows			80,589
Net transfer of assets and liabilities			44,706
Distribution of Nuclear Energy segment			(47,839)
Net transfer from former Parent per statement of shareholders' equity			$ 77,456

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Discontinued Operations (Details) - USD ($) $ in Thousands	6 Months Ended	12 Months Ended
	Jun. 30, 2015	Dec. 31, 2015
Nuclear Energy Segment [Member]
Revenues	$ 53,064
Income (loss) before income tax expense	3,358
Income tax expense (benefit)	555
Income (loss) from discontinued operations, net of tax	$ 2,803
Former Parent [Member]
Proceeds from Contributions from Parent		$ 2,700

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Taxes Reconciliation of Unrecognized Tax Benefits (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Income Tax Contingency [Line Items]
Unrecognized Tax Benefits	$ 1,204	$ 884	$ 1,141	$ 3,321
Unrecognized Tax Benefits, Increase Resulting from Current Period Tax Positions	277	178	88
Unrecognized Tax Benefits, Increase Resulting from Prior Period Tax Positions	56	230	248
Unrecognized Tax Benefits, Decrease Resulting from Prior Period Tax Positions	(13)	0	(1,161)
Unrecognized Tax Benefits, Decrease Resulting from Settlements with Taxing Authorities	0	(665)	(1,355)
Unrecognized Tax Benefits, Reduction Resulting from Lapse of Applicable Statute of Limitations	$ 0	$ 0	$ 0

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Taxes Components of Deferred Tax Assets and Liabilities (Details) - USD ($) $ in Thousands	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Tax Credit Carryforward [Line Items]
Deferred Tax Assets, Tax Deferred Expense, Compensation and Benefits, Pensions	$ 58,810	$ 105,426
Deferred Tax Assets, Tax Deferred Expense, Reserves and Accruals, Warranty Reserves	5,262	11,628
Deferred Tax Assets, Tax Deferred Expense, Compensation and Benefits, Compensated Absences	996	4,792
Deferred Tax Assets, Tax Deferred Expense, Reserves and Accruals, Self Insurance	3,910	6,596
Deferred Tax Assets, Tax Deferred Expense, Reserves and Accruals, Accrued Liabilities	4,950	8,334
Deferred Tax Assets, Equity Method Investments	10,422	10,742
Deferred Tax Assets, Deferred Income	6,801	10,318
Deferred Tax Assets, Tax Deferred Expense, Reserves and Accruals, Legal Settlements	1,579	2,110
Deferred Tax Assets, Inventory	1,842	2,445
Deferred Tax Assets, Property, Plant and Equipment	0	1,587
Deferred Tax Assets, Operating Loss Carryforwards	95,715	33,187
Deferred Tax Assets, Operating Loss Carryforwards, State and Local	21,658	15,372
Deferred Tax Assets, Tax Credit Carryforwards, Foreign	7,150	3,870
Deferred Tax Assets, Tax Credit Carryforwards, Other	5,678	737
Deferred Tax Assets, Other	4,980	7,852
Deferred Tax Assets, Gross	229,753	224,996
Deferred Tax Assets, Valuation Allowance	(108,100)	40,484	$ (10,077)	$ (9,216)
Deferred Tax Assets, Net of Valuation Allowance	121,648	184,512
Deferred Tax Liabilities, Deferred Expense	569	3,601
Deferred Tax Liabilities, Intangible Assets	21,215	21,892
Deferred Tax Liabilities, Property, Plant and Equipment	2,835	0
Deferred Tax Liabilities, Undistributed Foreign Earnings	1,314	500
Deferred Tax Liabilities, Goodwill	0	1,125
Deferred Tax Liabilities, Other	2,445	2,885
Deferred Tax Liabilities, Gross	28,378	30,003
Deferred Tax Assets, Net	$ 93,270	$ 154,509

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Taxes Valuation Allowance for Deferred Tax Assets (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Valuation Allowance [Line Items]
Deferred Tax Assets, Valuation Allowance	$ (108,100)	$ 40,484	$ (10,077)	$ (9,216)
Valuation Allowances and Reserves, Additions for Charges to Cost and Expense	61,021	29,307	861
Valuation Allowances and Reserves, Additions for Charges to Other Accounts	$ 6,600	$ 1,100	$ 0

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Taxes Income before Provision for Income Taxes (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Income before Provision for Income Taxes [Abstract]
Income (Loss) before provision for Income Taxes, Domestic	$ (44,835)	$ 1,280	$ (20,748)
Income (Loss) before provision for Income Taxes, Foreign	(269,364)	(109,419)	40,953
Income (Loss) before provision for Income Taxes	$ (314,199)	$ (108,139)	$ 20,205

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Taxes Components of Provision for Income Tax (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Income Tax Disclosure [Line Items]
Current Federal Tax Expense (Benefit)	$ 100	$ 284	$ 24,084
Current State and Local Tax Expense (Benefit)	397	(415)	3,458
Current Foreign Tax Expense (Benefit)	8,612	4,504	8,250
Current Income Tax Expense (Benefit)	9,109	4,373	35,792
Deferred Federal Income Tax Expense (Benefit)	58,203	11,512	(35,888)
Deferred State and Local Income Tax Expense (Benefit)	2,546	6,365	(111)
Deferred Foreign Income Tax Expense (Benefit)	(5,042)	(15,307)	3,878
Income tax expense	64,816	6,943	3,671
Includes SPIG consolidated [Member]
Income Tax Disclosure [Line Items]
Deferred Income Tax Expense (Benefit)	$ 55,707	$ 2,570	$ (32,121)

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Taxes Reconciliation of U.S. Statutory Federal Tax Rate (Details) - USD ($)	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Reconciliation of U.S. Statutory Federal Tax Rate [Abstract]
Effective Income Tax Rate Reconciliation, at Federal Statutory Income Tax Rate, Percent	35.00%	35.00%	35.00%
Effective Income Tax Rate Reconciliation, State and Local Income Taxes, Percent	0.20%	(3.50%)	13.80%
Effective Income Tax Rate Reconciliation, Foreign Income Tax Rate Differential, Percent	(9.50%)	(12.80%)	(13.10%)
Effective Income Tax Rate Reconciliation, Change in Enacted Tax Rate, Amount	$ (0.199)	$ 0.000	$ 0.000
Effective Income Tax Rate Reconciliation, Tax Credit, Percent	(0.90%)	(3.00%)	(14.70%)
Effective Income Tax Rate Reconciliation, Deduction, Dividend, Percent	(1.80%)	(0.20%)	1.70%
Effective Income Tax Rate Reconciliation, Change in Deferred Tax Assets Valuation Allowance, Percent	(17.90%)	(28.10%)	4.30%
Effective Income Tax Rate Reconciliation, Tax Contingency, Percent	0.00%	0.30%	(6.60%)
Effective Income Tax Rate Reconciliation, Nondeductible Expense, Percent	0.20%	(1.80%)	2.40%
Effective Income Tax Rate Reconciliation, Deduction, Qualified Production Activity, Percent	(0.00%)	(0.00%)	(2.50%)
Effective Income Tax Rate Reconciliation, Other Adjustments, Percent	(0.80%)	1.70%	(2.10%)
Effective Income Tax Rate Reconciliation, Percent	(20.60%)	(6.40%)	18.20%

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Taxes Narrative (Details) - USD ($) $ in Thousands	3 Months Ended	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Valuation Allowance [Line Items]
Deferred Tax Assets, Operating Loss Carryforwards, Foreign	$ 75,000	$ 75,000
Operating loss carryforward expiration year range start		2019
Operating loss carryforward expiration year range end		2026
Valuation Allowances and Reserves, Balance	66,000	$ 66,000
Deferred Tax Assets, Operating Loss Carryforwards, Domestic	20,700	20,700
Deferred Tax Assets, Tax Credit Carryforwards, Foreign	7,150	7,150	$ 3,870
Deferred Tax Assets, Operating Loss Carryforwards, State and Local	21,658	21,658	15,372
Tax Credit Carryforward, Valuation Allowance	21,600	21,600
Undistributed Earnings of Foreign Subsidiaries	4,400	4,400
Income Tax Expense (Benefit)		64,816	$ 6,943	$ 3,671
2019 to 2026 [Domain] [Domain]
Valuation Allowance [Line Items]
Deferred Tax Assets, Operating Loss Carryforwards, Subject to Expiration	1,700	1,700
ASU 2016-09 [Member]
Valuation Allowance [Line Items]
Income Tax Expense (Benefit)	$ 100	$ 1,600

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Taxes New Tax Act - Deferred Tax Effect (Details) $ in Millions	12 Months Ended
	Dec. 31, 2017 USD ($)
Operating Loss Carryforwards [Line Items]
Additional tax expense from New Tax Act	$ 62.4
Deferred Income Tax Expense (Benefit)	7.2
Deferred income tax expense	54.4
Deferred tax expense - Executive Compensation	$ 0.8

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Leases & Debt Obligations Operating Leases (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Lease Obligations [Abstract]
Operating Leases, Rent Expense, Net	$ 10,500	$ 8,300	$ 13,500
Operating Leases, Future Minimum Payments Due	$ 3,337			$ 2,258	$ 2,741	$ 3,553	$ 5,100	$ 6,814

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Leases & Debt Obligations Long-term borrowings obligations (Details) $ in Thousands	Dec. 31, 2017 USD ($)
Long-term debt obligations [Abstract]
Long-term Debt, Maturities, Repayments of Principal in Next Twelve Months	$ 9,173
Long-term Debt, Maturities, Repayments of Principal in Year Three	$ 290,184

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Second Lien Term Loan Facility Interest Expense (Details) - Second Lien Term Loan [Member] - USD ($)	3 Months Ended
	Dec. 31, 2017	Sep. 30, 2017
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	465700000.00%	255400000.00%
Amortization of Debt Issuance Costs and Discounts	$ 2,131,000	$ 1,095,000

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Basis of Presentation (Details) $ in Millions	Mar. 01, 2018 USD ($)
Subsequent Event [Line Items]
Capital from backstopped Rights Offering Agreement	$ 182

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Basis of Presentation Going Concern (Details) $ in Millions	Mar. 01, 2018 USD ($)
Capital from backstopped Rights Offering Agreement	$ 182
Borrowings from US Revolving Credit Facility to pay down Second Lien Term Loan facility	$ 35