UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
FORM 10-K
(Mark One)
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| x | ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934 |
For the fiscal year ended December 31, 20172018
OR
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| ¨ | 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)
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| DELAWARE | | 47-2783641 |
| (State or other Jurisdiction of Incorporation or Organization) | | (I.R.S. Employer Identification No.) |
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THE HARRIS BUILDING20 SOUTH VAN BUREN AVENUE | | |
13024 BALLANTYNE CORPORATE PLACE, SUITE 700BARBERTON, OHIO | | |
CHARLOTTE, NORTH CAROLINA | | 2827744203 |
| (Address of Principal Executive Offices) | | (Zip Code) |
Registrant's Telephone Number, Including Area Code: (704) 625-4900(330) 753-4511
Securities Registered Pursuant to Section 12(b) of the Act:
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| 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.
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| Large accelerated filer | | x¨ | | Accelerated filer | | ¨x |
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| Non-accelerated filer | | ¨ (Do not check if a smaller reporting company) | | Smaller reporting company | | ¨ |
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| | | | | 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)29, 2018) was approximately $570$242 million.
The number of shares of the registrant's common stock outstanding at January 31, 2018March 6, 2019 was 44,084,680.168,846,903.
DOCUMENTS INCORPORATED BY REFERENCE
Portions of the registrant's proxy statement for the 20182019 Annual Meeting of Stockholders are incorporated by reference
into Part III of this Form 10-K.
1
BABCOCK & WILCOX ENTERPRISES, INC.
INDEX TO FORM 10-K
TABLE OF CONTENTS
PART 1
I
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 isWe are a leading technology-based provider of advanced steam production from fossil and renewable sources for power generation and other industrial and municipal applications, as well as related environmental equipment that includes a broad suite of boiler products, environmental systems, and services for poweraftermarket parts and industrial uses.services. 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 ash handling equipment, systems and replacement parts;
custom-engineered, comprehensive dry and wet cooling solutions for steam applications; and
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.
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"BWXT" or the "former Parent") approved the spin-off of B&W through the distribution of shares of B&W common stock to holders of BWCBWXT 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 BWCBWXT common stock to holders of BWCBWXT 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 BWCBWXT 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 resultWe face liquidity challenges from losses recognized on our six European Vølund loss contracts described in Note 7 to the Consolidated Financial Statements included in Item 8, which caused us to be out 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 underand resulted in events of default in the agreements governing certain of 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 existeddebt 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 aseach of December 31, 2017, which may be difficultMarch 31, 2018, June 30, 2018, September 30, 2018 and December 31, 2018. Our liquidity is provided under a credit agreement dated May 11, 2015, as amended, with a syndicate of lenders ("Amended Credit Agreement") that governs a revolving credit facility ("U.S. Revolving Credit Facility") and our last out term loan facility ("Last Out Term Loans"). The Amended Credit Agreement is described in more detail in Note 19 and Note 20 to resolvethe Consolidated Financial Statements included in a timely manner. The Second Lien contains a 180 day standstill period beginning on March 1, 2018Item 8. We obtained waivers to resolve the event of defaultAmended Credit Agreement that temporarily waived, prevented or repay the loan. The March 1, 2018 Amendment and the Second Lien are furtherresolved these defaults as described in Note 19 and Note 20, respectively,31 to the consolidated financial statementsConsolidated Financial Statements included in Item 8. The most recent waiver extends through April 5, 2019.
OnTo address our liquidity needs and the going concern uncertainty, we:
raised gross proceeds of $248.4 million on April 30, 2018 through the rights offering as described in Note 22 to the Consolidated Financial Statements included in Item 8 (the "2018 Rights Offering");
repaid on May 4, 2018 the Second Lien Term Loan Facility described in Note 21 to the Consolidated Financial Statements included in Item 8 that had been in default beginning March 1, 2018, we entered into an equity commitment agreement (“Equity Commitment Agreement”) with a group2018;
completed the sale of our existing stockholdersMEGTEC and Universal businesses on October 5, 2018, for $130 million, subject to fully backstopadjustment, resulting in receipt of $112.0 million in cash, net of $22.5 million in cash sold with the businesses, and $7.7 million that was deposited in escrow pending final settlement of working capital and other customary matters;
completed the sale of Palm Beach Resource Recovery Corporation ("PBRRC"), a subsidiary that held two operations and maintenance contracts for waste-to-energy facilities in West Palm Beach, Florida, on September 17, 2018 for $45 million subject to adjustment, resulting in receipt of $38.9 million in cash and $4.9 million, which was deposited in escrow pending final settlement of working capital and other customary matters;
sold our planned Rights Offering (“Rights Offering”equity method investments in Babcock & Wilcox Beijing Company, Ltd. ("BWBC"), a joint venture in China, and Thermax Babcock & Wilcox Energy Solutions Private Limited ("TBWES"), a joint venture in India, and settled related contractual claims, resulting in proceeds of $21.1 million in the second quarter of 2018 and $15.0 million in the third quarter of 2018, respectively;
sold another non-core business for $5.1 million in the purposefirst quarter of providing at least $1822018;
initiated restructuring actions and other additional cost reductions since the second quarter of 2018 that are designed to save approximately $84 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 $182annually;
received $30 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 thein net proceeds from Tranche A-1 of Last Out Term Loans, described in Note 20 to the saleConsolidated Financial Statements included in Item 8, from B. Riley FBR, Inc., a related party, in September and October 2018 (Tranche A-1 was assigned to Vintage Capital Management LLC, another related party, on November 19, 2018);
received $10.0 million in net proceeds from Tranche A-2 of the Company’s common stockLast Out Term Loans, described in Note 31 to the Consolidated Financial Statements included in Item 8, from B. Riley Financial, Inc., a related party on March 20, 2019;
reduced uncertainty and provided better visibility into our future liquidity requirements by turning over four of the six European Vølund loss contracts to the customers and negotiating settlement of the remaining two loss contracts in the Rights Offeringfirst quarter of 2019 as described in Note 7 to the Consolidated Financial Statements included in Item 8; and
entered into several amendments and waivers to avoid default and improve our liquidity under the permitted borrowing capacity provided by our Revolver to extinguish the outstanding balanceterms 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 conditionsAmended Credit Agreement as described in the capital markets and, with respectNote 31 to the Rights Offering, an amendmentConsolidated Financial Statements included in Item 8, the most recent of which extends through April 5, 2019, unless earlier terminated, and waives our compliance with a number of covenants and events of default under, the Amended Credit Agreement.
Management believes it is taking all prudent actions to our existing shelf registration statement that we plan to file in early March 2018 being declared effective byaddress 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, but we cannot assert that it is probable that our plans will fully mitigate the conditions identified. Ifliquidity challenges we cannotface. We are currently dependent upon the waivers granted in our most recent limited waiver to maintain our current compliance with the covenants in the Amended Credit Agreement, and since March 20, 2019, we have also been nearly fully drawn on the U.S. Revolving Credit Facility, such that only minimal additional amounts were available for borrowings or letters of credit.
Based on our forecasts, we will require additional amendments to or waivers under the Amended Credit Agreement and additional financing to fund working capital and the settlements of two of our six European Vølund loss contracts described in Note 7 to the Consolidated Financial Statements included in Item 8 prior to April 5, 2019 to continue as a going concern, material adjustmentsconcern. We are currently in active discussions with the lenders under the Amended Credit Agreement (including certain of our related parties) for additional financing, a waiver of our compliance with covenants in and events of default under the Amended Credit Agreement, a reduction of the minimum liquidity requirements that we must maintain, a reset of future financial covenant ratios and amendments to other covenant requirements in order to allow us to continue to operate as a going concern. Our current discussions have focused around the extension of additional Last Out Term Loans, primarily from related parties, in an amount necessary to fund the settlement of the European Vølund loss contracts and provide liquidity for our operations. In connection with these loans, we have also discussed seeking shareholder approval for a reverse stock split and various other matters that could result in substantial dilution to our shareholders not participating in this financing, such as a rights offering to repay a portion of these additional Last Out Term Loans, the exchange of a portion of our existing Last Out Term Loans for shares of common stock and the issuance of warrants with a de minimis strike price to lenders participating in these additional Last Out Term Loans or other parties. We also discussed whether, as part of any financing transaction, we would provide director nomination rights over some or even a substantial majority of our board of directors to two of the related parties involved in these financing efforts or whether we would add an event of default if we fail to refinance the U.S. Revolving Credit Facility within twelve months following the filing of this annual report. These discussions have not yet resulted, and may never result, in a binding commitment by our lenders. There can be no assurance that our lenders or any other person will commit to provide additional financing consistent with these discussions or at all. If we are able to obtain additional financing, it may be on terms substantially different from our current discussions described above, and may require additional or different commitments by us with regard to other actions we will or will not take. If we fail to obtain necessary financing on acceptable terms or otherwise obtain short-term capital and continuing waivers with approval from our existing lenders, we may be unable to continue operation as a going concern.
In addition to the carrying valuesdiscussions regarding additional financing described above, we continue to evaluate further dispositions, opportunities for additional cost savings and classificationsopportunities for insurance recoveries and other claims where appropriate and available.
NYSE Continued Listing Status
On November 27, 2018, we received written notification (the "NYSE Notice"), from the New York Stock Exchange (the "NYSE"), that we were not in compliance with an NYSE continued listing standard in Rule 802.01C of the NYSE Listed Company Manual because the average closing price of our assetscommon stock fell below $1.00 over a period of 30 consecutive trading days. We informed the NYSE that we intend to seek to cure the price condition by executing our strategic plan, which is expected to result in improved operational and liabilitiesfinancial performance that we expect will ultimately lead to a recovery of our common stock price. We can regain compliance with the minimum per share average closing price standard at any time during the six-month cure period if, on the last trading day of any calendar month during the cure period, we have (i) a closing share price of at least $1.00 and (ii) an average closing share price of at least $1.00 over the 30 trading-day period ending on the last trading day of that month. We informed the NYSE that we are also prepared to consider a reverse stock split to cure the deficiency, should such action be necessary, subject to approval of our shareholders, at our next annual meeting. Our common stock could also be delisted if our average market capitalization over a consecutive 30 trading-day period is less than $15.0 million, in which case we would not have an opportunity to cure the deficiency, our common stock would be suspended from trading on the NYSE immediately, and the reported amounts of incomeNYSE would begin the process to delist our common stock, subject to our right to appeal under NYSE rules. We cannot assure you that any appeal we undertake in these or other circumstances will be successful. While we are considering various options, it may take a significant effort to cure this deficiency and expense couldregain compliance with this continued listing standard, and there can be required.no assurance that we will be able to cure this deficiency or if we will cease to comply with another NYSE continued listing standard.
Business Segments
Our operations are assessed based on three reportable segments, which are summarized as follows:Babcock & Wilcox, Vølund & Other Renewable and SPIG (formerly, the Power, Renewable and Industrial segments, respectively).
PowerBabcock & Wilcox segment
Our Babcock & Wilcox segment (formerly the Power segmentsegment) focuses on the supply of, and aftermarket services for, steam-generating, environmental, and auxiliary equipment for power generation and other industrial applications. The segment providesapplications, which includes a
comprehensive mix of new build, OEM and 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 Babcock & Wilcox segment provides a full suite of product and service offerings including engineering, procurement, specialty manufacturing, construction and commissioning. The segment's product suite includescommissioning of new and retrofit 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.
Our aftermarket 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. We provide aftermarket parts and services both for our own installed base as well as for competitors' equipment.
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 otherothers' 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, environmental control systems, natural gas and oil firedoil-fired package boilers, due in part to lower fuel prices; and
reducing costs through a focus on operational efficiencies.
Our PowerPreviously, our operations in the Babcock & Wilcox segment generated revenues of $821.1 million, $982.0 millionincluded joint ventures that were accounted for using the equity method. In 2018, we sold our interest in our Chinese joint venture, Babcock & Wilcox Beijing Company, Ltd. ("BWBC"), and $1.23 billionour interest in 2017,our Indian joint venture, Thermax Babcock & Wilcox Energy Solutions Private Limited. In 2016, and 2015, respectively, which was 52.7%, 62.2% and 70.3%we sold all of our total revenuesinterest in those years, respectively.our former Australian joint venture, Halley & Mellowes Pty. Ltd. ("HMA"). As of December 31, 2018, we do not have any remaining investments in equity method investees. See further discussion of these former operations and the sale transactions in Note 13 to the Consolidated Financial Statements included in Item 8 to this annual report.
Vølund & Other Renewable segment
Our Vølund & Other Renewable segment (formerly the 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.
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 Vølund & Other Renewable segment generated revenuesalso includes Loibl, a global supplier and manufacturer of $347.2 million, $349.2 millionmaterial solutions, from single belt conveyors to complex bulk material handling systems. Loibl serves a wide range of industrial 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.utility customers.
IndustrialOn September 17, 2018, we sold all of the issued and outstanding capital stock of Palm Beach Resource Recovery Corporation ("PBRRC"), a subsidiary that held two operations and maintenance contracts for waste-to-energy facilities in West Palm Beach, Florida. See further discussion in Note 5 to the Consolidated Financial Statements included in Item 8 to this annual report.
SPIG segment
At December 31, 2017,2018, our SPIG segment was formerly part of the Industrial segment wasand is 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.
business. 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 from core products and geographies in the IndustrialSPIG 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.
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 earlyOn October 5, 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, onecapital stock of our subsidiariesMEGTEC and Thermax Ltd.Universal businesses to Dürr Inc., a boiler manufacturer based in India, formedwholly owned subsidiary of Dürr AG, pursuant to a joint venture to build subcriticalstock purchase agreement executed on June 5, 2018. The MEGTEC and highly efficient supercritical boilers and pulverizers forUniversal businesses are classified as discontinued operations because 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 makedisposal represents a strategic changeshift that had a major effect on our operations; they were previously included in our Industrial segment, which has been renamed the Indian joint venture dueSPIG segment because SPIG is the remaining business of the former Industrial segment. See further discussion in Note 4 to the declineConsolidated Financial Statements included in forecasted market opportunities in India, which reduced the recoverable value of our investment in the joint venture. As a result ofItem 8 to 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.
annual report.
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 amountselling price 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. In the event of a contract deferral or cancellation without cause, 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.
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 or other contractual arrangements. While we carefully select our partners in these arrangements, they can subject us to risks that we may not be able to fully control and may include joint and several liability. An example of this includes BWL Energy Ltd., which was formed to complete the construction of a waste wood fired boiler contract in the United Kingdom (the fifth European Vølund loss contract described in Note 7 to the Consolidated Financial Statements included in Item 8). This joint venture combined 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. However, our partner in BWL Energy Ltd filed for administration (similar to bankruptcy in the U.S.) in late February 2018, and we were required to assume our partner's scope of work.
We generally recognize our contract revenues and related costs on a percentage-of-completion basis.over time using the cost-to-cost input method that uses costs incurred to date relative to total estimated costs at completion to measure progress toward satisfying our performance obligations. Accordingly, we review contractcontractual sales price and cost estimates regularly as the work progresses and reflect adjustments in profit proportionate to the percentage of completionpercentage-of-completion in the period when we revise those estimates. To the extent that these adjustments result in a
reduction or an elimination of previously reported profits with respect to a contract, we would recognize a charge against current earnings, which could be material.
See further description of risks related to our contracting in Risks Relating to Our Industry and Our Businessof our risk factors in Item 1A to this annual report.
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 forproviding cash collateral or other contract security.
In the event of a contract deferral or cancellation,security that we generally wouldmay not be entitledable 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.provide.
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 See further discussion 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 statementsConsolidated Financial Statements included in Item 8 ofto 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 |
|
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 drywet and wetdry 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.markets in Europe, the Middle East and the Americas. Our operations in Scotland and China primarily provide boiler cleaning technologies and systems (such as sootblowers)., primarily to Europe and China, respectively. 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 to customers worldwide. 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. We also own a manufacturing facility in China that produces tube bundles for our cooling solutions.
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. In 2018, we sold our joint venture interests of BWBC and TWBES, located in China and India, respectively.
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 46 to our consolidated financial statementsConsolidated Financial Statements included in Item 8 ofto 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 one customer, Southern Company, which accounted for $138.1 million or 13.0% of our consolidated revenue for the year ended December 31, 2018. We have no customers that individually accounted for more than 10% of our consolidated revenues in the years ended December 31, 2017, 2016 or 2015.2016.
Competition
With over 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:
|
| | |
PowerBabcock & Wilcox segment | Vølund & Other Renewable segment | IndustrialSPIG segment |
| GE | CNIM Group | B&W MEGTEC primary competitors |
Doosan | Hitachi Zosen | Durr, Dustex, CECO, EisenmannHamon |
| Babcock Power | MartinHitachi Zosen | B&W Universal primary competitorsEnexio |
Cleaver-BrooksClyde Bergemann | Martin | Kelvion |
| Enerfab | Keppel Seghers | CECO, Innova, Miratech, American Air Filter |
Sumitomo SHI-FW | Valmet | B&W SPIG primary competitorsPaharpur |
| MH Power Systems | AndritzValmet | Hamon, Enexio, Kelvion, Paharpur, Evapco
SPX Corporation
|
| AECom | Andritz | 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, 2017,2018, we had approximately 4,8004,000 employees worldwide, not including 2,200 joint venture employees.worldwide. Of our hourly employees, approximately 1,300600 are union-affiliated, covered by tenfour union agreements related to active facilities in Canada, China, Denmark, Great Britain, Mexico, the United States of America, the United Kingdom, and United States. MostCanada. Two of our union agreements expire in 2018 or 2019 and one expires in 2020, and we are actively negotiating one new agreements.agreement. 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 forthrough innovations to reduce the markets we serve through: (i) cost reductions resulting inof our products to make them more competitive products in a highly competitive global market and margin improvement; (ii) reducedthrough innovations to reduce performance risk assuringof our products to better 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. expectations.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.
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,financing; our ability to satisfy or obtain waivers of the liquidity and other requirements under the Amended Credit Agreement; our ability to refinance our Second Lien throughpay all pending amounts under the Rights Offering, or otherwise;negotiated settlement of the final two European Vølund loss contracts and obtain a waiver of the termination and rejection clauses contained in these contracts; 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, partners 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 address remaining items
and realize the expected synergies from acquisitions;any warranty obligations within our ability to successfully address productivity and schedule issues inaccrued estimated costs for our Vølund & Other 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;contracts within the Vølund & Other Renewable segment; changes in our effective tax rate and tax positions;positions, including any limitation on our ability to use our net operating loss carryforwards and other tax assets as a result of an "ownership change" under Section 382 of the Internal Revenue Code; 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;to recognize revenue over time; 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;
changes in, or our failure or inability to comply with, laws and government regulations; actual of anticipated changes in governmental regulation, including trade and tariff policies; 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; changes in actuarial assumptions and market fluctuations that affect our limited ability to influencenet pension liabilities and direct the operations of our joint ventures;income; 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; the willingness of customers and suppliers to continue to do business with us on reasonable terms and conditions as well as our ability to successfully consummate strategic alternatives for our MEGTEC and Universal businessesnon-core assets, if we determine to pursue them; and our ability to maintain the other riskslisting of our common stock on the NYSE. These factors include the cautionary statements included in this report and the factors 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,"Financial Information," 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 resultWe are in immediate need 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 andadditional financing to continue as a going concern. Current ongoing discussions with our lenders (including certain of our related parties) to secure additional financing may result in substantial additional indebtedness and significant dilution to our existing shareholders.
We have experienced losses from operations in each of the past twothree years, have had negative operating cash flows during the yearyears ended December 31, 2018 and 2017 and are dependent on our ability to raise capital in the time frametimeframe required in our United States RevolvingAmended Credit Facility ("Revolver")Agreement to refinance prior to its maturity and 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 complianceAmended Credit Agreement. Since June 2016 and with certain financial covenants under our Revolver and our Second Lien Term Loan Facility ("Second Lien") as ofincreasing frequency since December 31, 2017. On March 1, 2018, we obtained an agreement (the “March 1, 2018 Amendment”)have entered into a number of amendments and waivers to amendthe Amended Credit Agreement, which governs 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 OfferingU.S. Revolving Credit Facility 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 aLast Out
Term Loans, to, among other things, provide relief or waiver under certain financial and other covenants and to waive certain events of default thereunder. Since March 20, 2019, we have been nearly fully drawn on the U.S. Revolving Credit Facility, minimal additional amounts were available for borrowings or letters of credit, and we were in compliance with the terms of the Amended Credit Agreement subject to the limited waivers that cumulatively extend through 5:00 p.m., New York City time, on April 5, 2019, as described in Going Concern Considerations in Item 1.
We will require additional amendments to or waivers under the Second Lien followingAmended Credit Agreement and additional financing to fund working capital and the expirationsettlements of the 180 day standstill period. As a result, all indebtedness under the Second Lien could be declared immediately due and payable upon the occurrencetwo 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 ablesix European Vølund loss contracts prior to April 5, 2019 to continue as a going concern. The accompanying consolidatedAs described in Going Concern Considerations in Item 1, we are currently in active discussions with the lenders under the Amended Credit Agreement (including certain of our related parties) for additional financing, a waiver of our compliance with covenants in and events of default under the Credit Agreement, a reduction of the minimum liquidity requirements that we must maintain, a reset of future financial statements are prepared on a going concern basiscovenant ratios and do not include any adjustments that might result from uncertainty about our abilityamendments to other covenant requirements in order to allow us to continue to operate as a going concern,concern. Our current discussions have focused around the extension of additional Last Out Term Loans, primarily from related parties, in an amount necessary to fund the settlement of the European Vølund loss contracts and provide liquidity for our operations. In connection with these loans, we have also discussed seeking shareholder approval for a reverse stock split and various other thanmatters that could result in substantial dilution to our shareholders not participating in this financing, such as a rights offering to repay a portion of these additional Last Out Term Loans, the reclassificationexchange of certain long-term debta portion of our existing Last Out Term Loans for shares of common stock and the issuance of warrants with a de minimis strike price to current liabilities. The reportlenders participating in these additional Last Out Term Loans or other parties. We also discussed whether, as part of any financing transaction, we would provide director nomination rights over some or even a substantial majority of our board of directors to two of the related parties involved in these financing efforts or whether we would add an event of default if we fail to refinance the U.S. Revolving Credit Facility within twelve months following the filing of this annual report. These discussions have not yet resulted, and may never result, in a binding commitment by our lenders. There can be no assurance that our lenders or any other person will commit to provide additional financing consistent with these discussions or at all. If we are able to obtain additional financing, it may be on terms substantially different from our independent registered public accounting firmcurrent discussions described above, and may require additional or different commitments by us with regard to other actions we will or will not take. If we fail to obtain necessary financing on acceptable terms or otherwise obtain short-term capital and continuing waivers with approval from 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 abilityexisting lenders, we may be unable to continue operation as a going concern.concern..
ThereFurther, even if we obtain additional financing as a result of these discussions or otherwise, 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 financingcapital in the future on commercially reasonable terms or at all including, without limitation, our ability to successfully completeor otherwise comply with the Rights Offering and refinance our Second Lien.covenants contained in the Credit Agreement. As a result, our liquidity and ability to timely pay our obligations when due couldwould be adversely affected. Absent additional waivers from the lenders under our Credit Agreement, our lenders could declare all debt outstanding under the Credit Agreement as immediately due and payable. Furthermore, our creditors may resist renegotiation or lengthening of payment and other terms through legal action or otherwise. If we fail to obtain necessary financing on acceptable terms or otherwise obtain short-term capital with approval from our existing lenders or 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 and comply with the covenants under the Credit Agreement, we may not have sufficient liquidity to sustain operations and to continue as a going concern.concern and we could be required to reorganize our company in its entirety, including through bankruptcy proceedings.
We derive substantial revenues from electric power generating companiesIf we obtain financing on the terms currently contemplated above, our shareholders would experience significant dilution as a result of the shares of common stock we would issue in the rights offering, the exchange of Last Out Term Loans for common stock and other steam-using industries, with demandthe exercise of the warrants that will be issued. This dilution, or the perception that it may occur, could materially reduce the market price for our productscommon stock. Further, each contemplated issuance of common stock requires shareholder approval that we may be unable to obtain. If we fail to obtain shareholder approval in a timely manner or at all, we may be subject to increased interest rates or other adverse consequences under the final terms of the additional Last Out Term Loans.
These contemplated issuances of common stock will also likely result in an “ownership change” under Section 382 of the Internal Revenue Code. As a result, our ability to use our net operating losses and services depending on spendingcertain tax credit to reduce future tax payments will likely be limited, which could materially and adversely impact our future results of operations as discussed in these historically cyclical industries. Additionally, recent legislativedetail below.
In addition, certain of our shareholders could exert significant power and regulatory developments relatingcontrol over us and our subsidiaries as a result of the director nomination rights being contemplated as part of the financing contemplated above, including the power to clean air legislationnominate and elect a substantial majority of our directors, set our management policies and exercise overall control over the
Company and subsidiaries. The interests of such significant shareholders may differ from our interests or those of our other shareholders and the concentration of control in our significant shareholders will limit other shareholders’ ability to influence corporate matters. The concentration of ownership and voting power of our significant shareholders may also delay, defer or even prevent an acquisition by a third party or other change of control of the Company and may make some transactions more difficult or impossible without the support of our significant shareholders, even if such events are affecting industry plans for spending on coal-fired power plants withinperceived by the United Statesother shareholders as being in their best interest.
Our Amended Credit Agreement, which governs our U.S. Revolving Credit Facility and elsewhere.out Last Out Term Loans, could restrict our operations or result in an event of default if existing waivers under the U.S. Revolving Credit Facility are not extended.
The demandterms of our Amended Credit Agreement impose various restrictions and covenants on us that could have adverse consequences, including limiting our:
flexibility in planning for, power generation productsor reacting to, changes in our business or economic, regulatory and services depends primarilyindustry conditions;
ability to invest in joint ventures or acquire other companies;
ability to sell assets;
ability to pay dividends to our shareholders;
ability to repurchase shares of our common stock;
ability to borrow additional funds; and
ability to issue additional letters of credit.
In addition, our Amended Credit Agreement 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 no assurance can be provided that we will continue to meet the financial ratios. The covenants of our Amended Credit Agreement also limit the amount of additional contract charges that we are able to incur on specific European Vølund contracts and require us to deliver those contracts by specified dates. In the past, we have been forced to request amendments to the covenants of the Amended Credit Agreement and no assurance can be provided that we will be able to perform under these covenants in the future.
Effective October 11, 2018, our U.S. Revolving Credit Facility is limited to $347.0 million of borrowings or letters of credit under that facility, and as of December 31, 2018, we had approximately $25.0 million available. Since March 20, 2019, we have been nearly fully drawn on the spendingU.S. Revolving Credit Facility, minimal additional amounts were available for borrowings or letters of electric power generating companiescredit, and we were in compliance with the terms of the Amended Credit Agreement subject to the limited waivers that cumulatively extend through 5:00 p.m., New York City time, on April 5, 2019, as described in Going Concern Considerations in Item 1.
Our ability to comply with the covenants and restrictions contained in our Amended Credit Agreement may be affected by events beyond our control, including prevailing macroeconomic, financial and industry conditions. If market or other macroeconomic conditions deteriorate, our ability to comply with these covenants may be impaired. In particular, if the limited waivers expire on April 5, 2019 without an amendment of the Amended Credit Agreement or extension of the limited waivers, we will be in default of our obligations under the Amended Credit Agreement. Even if we are able to obtain additional financing and amendments of the Amended Credit Agreement, we may be unable to comply with the amended covenants in the future. Expiration of the limited waivers or further breach of any of the covenants in the Amended Credit Agreement could result in an event of default under our U.S. Revolving 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 U.S. Revolving Credit Facility and our Last Out Term Loans 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 Agreement 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 Agreement 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 customers, suppliers, vendors, employees and other steam-using industries and expenditures by original equipment manufacturers. These expenditures are influenced by such factors as:third parties with whom we do business may react negatively to the substantial doubt about our ability to continue as a going concern.
prices for electricity, along with the cost of production and distribution;
prices for natural resources such as coal and natural gas;
demand for electricityOur customers, suppliers, vendors, employees and other end productsthird parties with whom we do business may react negatively to the substantial doubt about our ability to continue as a going concern. The inclusion 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 emissionsa "going concern" explanatory paragraph in the future;
level of capacity utilizationauditor's report covering our audited Consolidated Financial Statements contained in this annual report may only heighten these concerns about our financial viability and associated operations and maintenance expenditures of power generating companiesmay discourage existing or new customers, suppliers, vendors and other steam-using facilities;
requirements for maintenancethird parties from entering into business relationships with us on terms that we find acceptable or at all, including by demanding the posting of additional standby letters of credit or surety bonds before engaging in business with us. We may also have difficulty in retaining and upkeep at operating power plants andattracting employees as a result of these concerns. As a result, our management team may need to address these concerns with these various constituencies, which may divert their attention from other steam-using facilities to combat the accumulated effectsimportant business activities. These adverse reactions by each of wear and tear;
abilitythese groups of electric generating companies and other steam users to raise capital; and
relative pricesconstituencies may further impair our financial condition in a re-enforcing cycle. All 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 timethese risks could materially and adversely affect our ability to continue operating as a going concern and we could be required to reorganize our company in its entirety, including through bankruptcy proceedings.
Maintaining adequate bonding and letter of credit capacity is necessary for us to successfully complete, 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 demandapplicable 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, or we could default on contracts that are underway or that have been awarded. 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 U.S. Revolving Credit Facility will continue to be available to us on reasonable terms, and which may reduce the borrowing capacity under our U.S. Revolving Credit Facility. In addition, the inclusion of a "going concern" explanatory paragraph in the auditor's report covering our audited Consolidated Financial Statements contained in this annual report may prevent us from obtaining bonding and letters of credit from sources outside of our contractually committed Amended Credit Agreement on reasonable terms, or at all. Our inability to obtain or maintain 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. The aggregate value of all such letters of credit and bank guarantees opened outside of the U.S. Revolving Credit Facility as of December 31, 2018 and December 31, 2017 was $175.9 million and $269.1 million, respectively. The aggregate value of all such letters of credit and bank guarantees that are partially secured by the U.S. Revolving Credit Facility as of December 31, 2018 was $80.2 million. The aggregate value of the letters of credit provided by the U.S. Revolving Credit Facility in support of letters of credit outside of the United States was $47.6 million as of December 31, 2018.
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. 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, 2018, bonds issued and outstanding under these arrangements in support of contracts totaled approximately $202.7 million. The aggregate value of all surety bonds that are partially secured by the U.S. Revolving Credit Facility as of December 31, 2018 was $75.8 million. The aggregate value of the letters of credit provided by the U.S. Revolving Credit facility in support of surety bonds was $22.6 million.
Our evaluation of strategic alternatives for certain businesses and non-core assets may not be successful.
We continue to evaluate strategic alternatives for our powerbusiness lines and assets 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 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 shareholders. 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 continues, 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.
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 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;
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.
We have recently experienced these risks with several large loss contracts in the Vølund & Other Renewable segment and the SPIG segment. We have also been previously awarded a bid for a project of similar scope to these other large loss contracts in the Vølund & Other Renewable segment, where the customer has experienced challenges in obtaining governmental approvals, and where our civil construction partner for this project entered into administration earlier this year (similar to filing for bankruptcy in the U.S.). We have not been provided a notice to proceed on this proposed project, and accordingly, it is not included in our backlog; therefore, we do not currently have any performance obligations related thereto, and any such obligations may never arise. As of April 2, 2019, we had negotiated to withdraw from this previously awarded bid of a renewable energy plant project in the United Kingdom, subject to certain pending terms; our inability to satisfy the terms of the withdrawal could have a material adverse effect on our results of operations if we were required to proceed with the contract and were unable to perform within the price bid.
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, productsindustrial processes, and/or environmental compliance. The complexity of these contracts generally necessitates the participation of others, 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 had contracts to construct several renewable energy plants in the United Kingdom. These contracts have suffered delays, additional costs 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, 2018, $37 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 of independent technical experts from each. Any insurance coverage may be insufficient, or the timing of any insurance proceeds may not meet our liquidity requirements. In the case of the fifth European Vølund loss contract, where structural failure occurred, the process to agree on the appropriate structural remediation and plan to implement the remediation was lengthy and resulted in a more significant delay.
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, reduced profit, or liquidity challenges.
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 performance issues when and therefore,if required, customers may exercise their rights to terminate a joint contract, exposing us to legal liability, damage to our reputation, reduced profit or liquidity challenges. For example, our joint venture partner for a renewable energy plant in the United Kingdom entered into administration (similar to filing for bankruptcy in the U.S.) in late February 2018. Accordingly, we were required to take over the civil scope of the renewable energy plant project, which resulted in significant delays and materially increased our costs on the project. The same joint venture partner is party to another previously awarded bid, but where notice to proceed has not been provided. As of April 2, 2019, we had negotiated to withdraw from this previously awarded bid of a renewable energy plant project in the United Kingdom, subject to certain pending terms; our inability to satisfy the terms of the withdrawal could have a material adverse effect on our results of operations if we were required to proceed with the contract and were unable to perform within the price bid.
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 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. Coal-fired powerIn some cases, we have joint and several liability with consortium partners in our projects, such as the renewable energy 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 StatesKingdom, and elsewhere has caused manywe may be subject to additional losses if our partners are unable to meet their contractual obligations. For example, in the case of the fifth European Vølund loss contract, our major customers, principally electric utilities,civil construction partner for this project entered into administration earlier this year (similar to delay making substantial expendituresfiling for new plants, as well as upgradesbankruptcy in the U.S.), and we were required to existing power plants.assume their scope of work.
Demand forIn addition, the deterioration of macroeconomic conditions or negative trends in the global credit markets could have a negative impact on relationships with customers and our products and services is vulnerableability to economic downturns and industry conditions.
Demand forcollect on trade receivables, with possible adverse effects on 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 ourfinancial condition, 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 ratesoperations 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.flows.
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 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 subjectaffecting 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 riskscarbon 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 with contractual pricingoperations 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 our industry, including the risk that, if our actual costs exceed the costs we estimate on our fixed-price contracts, our profitability will decline,boilers, compared to prices for fuels used in gas turbines and we may suffer losses.other alternative forms of generation.
We are engaged in a highly competitive industry,estimate that 48%, 43% and we have priced a number52% of our contracts on a fixed-price basis. Our actual costs could exceed our projections, asconsolidated revenues in 2018, 2017 and 2016, respectively, 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 clausescoal-fired power plants. A material decline in customer contracts or other factors that may result in additional costs to us, reductions in revenue, claims or disputes;
our inability to obtain compensation for additional work we perform or expenses we incur as a result of our customers 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 failuresspending 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, qualityelectric power generating companies and other requirements onsteam-using industries over a sustained period of time could materially and adversely affect the demand for our contracts, which could increasepower generation products and services and, therefore, 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, weCoal-fired power plants have jointbeen scrutinized by environmental groups and several liability with consortium partners in our projects, such asgovernment regulators over the renewable energy plantsemissions of potentially harmful pollutants. The recent economic environment and uncertainty concerning new environmental legislation or replacement rules or regulations in the United Kingdom,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.
Demand for our products and services is vulnerable to macroeconomic downturns and industry conditions.
Demand for our products and services has been, and we mayexpect that demand will continue to be, subject to additional losses ifsignificant fluctuations due to a variety of factors beyond our partnerscontrol, including macroeconomic and industry conditions. These factors include, but are unablenot 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 macroeconomic conditions may lead customers to meet their contractual obligations.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, the deterioration of economic conditions or negative trendsour customers may find it more difficult to raise capital in the future due to limitations on the availability of credit, marketsincreases 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 have a negative impact on relationships with customersreduce the demand for our products and services. Any inability to timely collect our abilityinvoices may lead to collect on trade receivables, with possible adverse effects onan increase in our business,borrowing requirements, 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 results of operations and cash flows.
could deteriorate.
Our use of the percentage-of-completion method ofreported financial results may be adversely affected by new accounting pronouncements or changes in existing accounting standards and practices, which could result in volatility in our results of operations.
We prepare our financial statements in conformity with accounting principles 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 incomeaccepted in the period when we revise those estimates. ToU.S. These accounting principles are subject to interpretation or changes by 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 costsFASB and the profitabilitySEC. New accounting pronouncements and varying interpretations of accounting standards and practices have occurred in the past and are expected to occur in the future. New accounting pronouncements or a change in the interpretation of existing accounting standards or practices may have a significant effect on our long-term contracts, although reasonably reliable when made, couldreported financial results and may even affect our reporting of transactions completed before the change as a result of the uncertainties associated with these types of contracts, and if adjustments to overall contract costs are significant, the reductionsis announced or reversals of previously recorded revenue and profits could be material in future periods.effective.
If our co-venturers fail to perform their contractual obligations on a contractAny difficulties in adopting 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. Ifimplementing 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 disagreementsnew accounting standard could result in delays, additional costsour failure to meet our financial reporting obligations, which could result in regulatory discipline and risks of litigation. Our inabilityharm investors’ confidence in us. Finally, if we were to successfully maintain existing collaborative relationships or enter into new collaborative arrangementschange our critical accounting estimates, our operating results could have a material adverse effect on our results of operations.be significantly affected.
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.amounts that could adversely affect our financial position.
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. RecentlyTax reform legislation enacted tax reform legislationin December of 2017 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 the transition of U.S. international taxation from a worldwide tax system to a more generally territorial system, and a one-time transition tax on the mandatory deemed repatriation of foreign earnings. ThisThe legislation has resultedis unclear in many respects and may incould be subject to potential amendments and technical corrections and will be subject to interpretations and implementing regulations by the future result in additional effects on us, someTreasury and Internal Revenue Service, any of which may be adverse. For example,could mitigate or increase certain adverse effects of the reduction in the corporate tax rate has resulted in a revaluation of our existing deferred tax assets, and consequently an increase in ourlegislation. In addition, it is unclear how these U.S. federal income tax expense for 2017. The magnitude of the net impact remains uncertain at this timechanges will affect state and is subject to any other regulatorylocal taxation. Generally, future changes in applicable U.S. or administrative developments, including anyforeign tax laws and regulations, or other guidance promulgated by the United States Internal Revenue Service.their interpretation and application could have an adverse effect on our business, financial conditions and results of operations.
In addition, significantSignificant 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 ability to realize
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 carryforwardsAs of December 31, 2018, the Company and certainits subsidiaries had U.S. federal net operating losses ("NOLs") of approximately $97.6 million. Some or all of the Company's deferred tax credits may become subject to annual limitationassets, consisting primarily of NOLs that are not currently deductible for tax purposes, could expire unused if we experience an "ownership change". In general,are unable to generate sufficient taxable income in the future to take advantage of them or we enter into transactions that limit our right to use them, which includes transactions that result in an "ownership change" occursunder Section 382 of the Internal Revenue Code ("IRC").
As a result of accumulations of the Company's common stock among several large shareholders and the impact of the rights offering as described in Note 22 to the Consolidated Financial Statements included in Item 8 that was completed on April 30, 2018 (the "2018 Rights Offering"), we continue to monitor for the possibility of an ownership change as defined under IRC Section 382. Under IRC Section 382, a company has undergone an ownership change if shareholders owning at least 5% shareholders increaseof the company have increased their collective ownership of our companyholdings by more than 50 percentage points50% during the relevant testingprior three-year period. IfIn general, if an ownership change occurs, our ability to use NOLnet operating loss 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. The determination of whether an ownership change has occurred for purposes of IRC Section 382 is complex and requires significant judgment. Moreover, the number of shares of our common stock outstanding at any particular time for purposes of IRC Section may differ from the number of shares that we report as outstanding in our filings with the SEC. Based on information that is publicly available, the Company does not currently believe it has experienced an ownership change. However, if we obtain additional financing on the terms currently being discussed as described in Going Concern Considerations in Item 1, it is likely that an "ownership change" will result in 2019. Further, even if an "ownership change" does not result from any additional financing we obtain, we cannot provide any assurance that we will not undergo an "ownership change" in the future. Small changes in ownership by shareholders owning at least 5% of the Company could result in an ownership change. By way of example, if we had experienced an ownership change as of December 31, 2018, the future utilization of our then federal net operating loss carryforwards would have been limited to approximately $1.7 million, based upon the approximate value of the Company multiplied by the long-term tax-exempt rate at the time of the ownership change.
net operating loss carryforwards arising in tax years beginning on or before December 31, 2017 has generally not changed under the tax reform legislation enacted in 2017, net operating loss carryforwards arising in tax years beginning after December 31, 2017 may be used to offset only 80% of taxable income. In addition, net operating losses arising in tax years ending after December 31, 2017 may be carried forward indefinitely, as opposed to the 20-year carryforward under prior law.
Our businessThe IRS could be negatively impacted by security threats, including physical and cybersecurity threats, and other disruptions.challenge the amount, timing and/or use of our NOL carry forwards.
We face various security threats, including cyber threats, threats to the physical securityThe amount of our facilities and infrastructure, and threats from terrorist acts,NOL carry forwards has not been audited or otherwise validated by the IRS. Among other things, the IRS could challenge whether an ownership change occurred, as well as the potential for business disruptions associated with these threats. Although weamount, the timing and/or our use of our NOLs. Any such challenge, if successful, could significantly limit our ability to utilize a combinationportion or all of tailoredour NOL carry forwards. In light of the inherent uncertainty involved in calculating whether an ownership change has occurred (both because of the complexity of applying IRC Section 382 and industry standard security measuresbecause of limitations on a publicly-traded company's knowledge as to the ownership of, and transactions in, its securities), the calculation of the amount of our utilizable NOL carry forwards could be changed as a result of a successful challenge by the IRS or as a result of new information about the ownership of, and transactions in, our securities.
A disruption in, or failure of our information technology systems, including those related to monitorcybersecurity, could adversely affect our business operations and mitigate these threats, we cannot guarantee that these measures and technology will be sufficient to prevent security threats from materializing.financial performance.
We are increasingly dependentrely on information technology networks and systems, including the Internet, to process, transmit and store electronic sensitive and financialconfidential information, to manage and support a variety of business processes and activities and to comply with regulatory, legal and tax requirements. While we maintain some of our critical information technology systems, we are also dependent on third parties to provide important information technology services relating to, among other things, human resources, electronic communications and certain finance functions.
We face various threats to our information technology networks and systems, including cyber threats, threats to the physical security of our facilities and infrastructure from natural or man-made incidents or disasters, and threats from terrorist acts, as well as the potential for business disruptions associated with these threats. 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, trickeryphishing scams or other forms of deception. If anyAlthough 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 current and future threats to our significant information technology networks and systems suffer severe damage, disruption,from materializing. Furthermore, we may have little or no oversight with respect to security measures employed by third-party service providers, which may ultimately prove to be ineffective at countering threats.
If these systems are damaged, intruded upon, attacked, shutdown or cease to function properly, whether by planned upgrades, force majeure, telecommunication failures, hardware or software beak-ins or viruses, or other cybersecurity incidents 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, our ability to comply with regulations related to information contained on our information technology networks and systems, our 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, andwith third parties, reputational damage from leakage of confidential information or the software we sell being compromised.compromised, and increased cybersecurity protection and remediation costs due to the increasing sophistication and proliferation of threats. The costs related to cyber or other security threats or disruptions may not be fully insured or indemnified by other means.
In order toTo address risks to our information technology systems, we continue to make investmentsinvest in technologiesour systems and training of company personnel. From time to timeAs required, 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.
Privacy and information security laws are complex, and if we fail to comply with applicable laws, regulations and standards, or if we fail to properly maintain the integrity of our data, protect our proprietary rights to our systems or defend against cybersecurity attacks, we may be subject to government or private actions due to privacy and security breaches, any of which could have a material adverse effect on our business, financial condition and results of operations or materially harm our reputation.
We are subject to a variety of laws and regulations in the United States and other countries that involve matters central to our business, including user privacy, security, rights of publicity, data protection, content, intellectual property, distribution, electronic contracts and other communications, competition, protection of minors, consumer protection, taxation, and online-payment services. These laws can be particularly restrictive in countries outside the United States. Both in the United States and abroad, these laws and regulations constantly evolve and remain subject to significant change. In addition, the application and interpretation of these laws and regulations are often uncertain, particularly in the new and rapidly evolving industry in which we operate. Because we store, process, and use data, some of which contains personal information, we are subject to complex and evolving federal, state, and foreign laws and regulations regarding privacy, data protection, content, and other matters. Many of these laws and regulations are subject to change and uncertain interpretation, and could result in investigations, claims, changes to our business practices, increased cost of operations, and declines in user growth, retention, or engagement, any of which could seriously harm our business.
Several proposals have recently been adopted or are currently pending before federal, state, and foreign legislative and regulatory bodies that could significantly affect our business. The General Data Protection Regulation, or GDPR, in the European Union, which went into effect on May 25, 2018, placed new data protection obligations and restrictions on organizations and may require us to further change our policies and procedures. If we are not compliant with GDPR requirements, we may be subject to significant fines and our business may be seriously harmed. The California Consumer
Privacy Act goes into effect in January 2020, with a lookback to January 2019, and places additional requirements on the handling of personal data.
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.
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
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, or our inability to obtain insurance coverage, 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
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,cybersecurity threats, 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;
tariffs, duties, or trade sanctions and other trade barriers imposed by foreign countries that restrict or prohibit business transactions in certain markets;
changes in applicable laws or policies;
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.
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
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 depend on our ability to outsource various elements of work to third parties, which may expose us to the business risks of our suppliers and subcontractors, which could have a material adverse impact on its business and results of operations.
We depend on third-party suppliers and subcontractors for products, materials, and services. This dependence subjects us to the risk of customer dissatisfaction with the quality or performance of the products or services we sell due to supplier or subcontractor failure. In addition, business difficulties experienced by a third-party supplier or subcontractor could lead to the interruption of our ability to source products, materials, or services and ultimately our inability to supply products, materials, or services to these customers. Third-party supplier and subcontractor business interruptions could include, but are not limited to, work stoppages, union negotiations, other labor disputes and payment disputes. Current or future economic conditions could also impact the ability of suppliers and subcontractors to access credit and, thus, impair their ability to
provide us quality products, materials, or services in a timely manner, or at all. These factors may affect the timing and cost of completion of such projects and could adversely affect our business and results of operations.
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 significantFrom time to time, we execute contracts with partners through joint ventures which contributed income (losses)or other contractual arrangements. We may not be able to control the actions of $(9.9) million, $16.4 millionour partners in these arrangements, 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 somethe actions of these entitiesour partners and the contractual outcomes may be limited. Even in those joint ventures over whichcircumstances where we domay 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.under these arrangements. In any case, differences in views among the joint venture participantspartners may result in delayed decisions or disputes. We also cannot control the actions of our joint venture participants. WeIn these arrangements, 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
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, assimilaterecruit, motivate, and retain trainedqualified personnel in the future, could disrupt our operationsbusiness and result in lossharm our results of revenues or profits.operations.
Our success dependsWe depend on the skills, working relationships, and continued active participationservices of key personnel, including our executive officersmanagement team and key operating personnel. Theothers throughout our organization. We are also dependent on our ability to attract and retain qualified personnel, for whom we compete with other companies both inside and outside our industry. Our business, financial condition or results of operations may be adversely impacted by the unexpected loss of the servicesany 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, retirementmanagement team or other reasons,key personnel, or be unablemore generally if we fail to employ additional or replacement personnel with the requisite level of trainingattract, recruit, motivate 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.retain qualified personnel.
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, protests or other work stoppages were to occur, we could experience a significant disruption of operations. In addition, negotiations with unions could divert managementmanagement's 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, 2017,2018, our defined benefit pension and postretirement benefit plans were underfunded by approximately $258.8$282.2 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
underfunded benefit obligations. See Note 18 to the consolidated financial statementsConsolidated 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%39%, 46%54% and 41%46% of total revenues for the years ended December 31, 2018, 2017 2016 and 2015,2016, 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, 2017,2018, international operations accounted for approximately 51%39% 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, such as war, armed conflicts or terrorist attacks could adversely impactaffect our business.
Natural disasters, such as earthquakes, tsunamis, hurricanes, floods, tornadoes, or other eventsMatters outside of our control could adversely impactaffect demand for or supply of our products. In addition, natural disasters could also cause disruption toproducts or disrupt 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. Insurance for such matters may be unavailable or insufficient. Such matters could include natural disasters, such as earthquakes, tsunamis, hurricanes, floods, tornadoes, war, armed conflicts, or terrorist attacks, among others. 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 inrisks, 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 conflictsgeneral in nature 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 ontargeted at us or our markets may significantly affect our business and results of operations in the future.
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.
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.
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.markets.
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 stockholdersshareholders 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&Wour 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;shareholders;
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.
We are currently out of compliance with the New York Stock Exchange's minimum share price requirement and are at risk of the NYSE delisting our common stock, which would have an adverse impact on the trading volume, liquidity and market price of our common stock.
On November 27, 2018, we received written notification (the "NYSE Notice"), from the New York Stock Exchange (the "NYSE"), that we were not in compliance with an NYSE continued listing standard in Rule 802.01C of the NYSE Listed Company Manual because the average closing price of our common stock fell below $1.00 over a period of 30 consecutive trading days. We informed the NYSE that we intend to seek to cure the price condition by executing our strategic plan, which is expected to result in improved operational and financial performance that we expect will ultimately lead to a recovery of our common stock price. We can regain compliance with the minimum per share average closing price standard at any time during the six-month cure period if, on the last trading day of any calendar month during the cure period, we have (i) a closing share price of at least $1.00 and (ii) an average closing share price of at least $1.00 over the 30 trading-day period ending on the last trading day of that month. We informed the NYSE that we are also prepared to consider a reverse stock split to cure the deficiency, should such action be necessary, subject to approval of our shareholders, at our next annual meeting. Our common stock could also be delisted if our average market capitalization over a consecutive 30 trading-day period is less than $15.0 million, in which case we would not have an opportunity to cure the deficiency, our common stock would be suspended from trading on the NYSE immediately, and the NYSE would begin the process to delist our common stock, subject to our right to appeal under NYSE rules. We cannot assure you that any appeal we undertake in these or other circumstances will be successful. While we are considering various options, it may take a significant effort to cure this deficiency and regain compliance with this continued listing standard, and there can be no assurance that we will be able to cure this deficiency or if we will cease to comply with another NYSE continued listing standard.
A delisting of our common stock from the NYSE could negatively impact us as it would likely reduce the liquidity and market price of our common stock; reduce the number of investors willing to hold or acquire our common stock; and negatively impact our ability to access equity markets and obtain financing.
Substantial sales of our common stock could cause our stock price to decline and issuances by us may dilute our common stockholders'shareholders' ownership in B&W.the Company.
As of December 31, 2017,2018, we have an aggregate of approximately 44.1 million168,790,778 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 (or securities convertible into or exchangeable or exercisable for equity securities) to raise
additional capital in connection with the financing contemplated in Going Concern Considerations in Item 1 to this annual report or otherwise, our stockholders'shareholders' ownership interests in B&Wthe Company 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 stockholdersshareholders 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,the Company, even if that change may be considered beneficial by some stockholders.shareholders.
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&Wthe Company that a stockholdershareholder 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 stockholdersshareholders 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&Wthe Company immune from takeovers. However, these provisions apply even if the offer may be considered beneficial by some stockholdersshareholders and could delay or prevent an acquisition that our board of directors determines is not in the best interests of B&Wthe Company and our stockholders.shareholders.
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,shareholders, 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.
Risks Relating to our 2015 Spin-Off from our Former Parent
We are subject to continuing contingent liabilities of BWXT following the spin-off.
We completed a spin-off from our former parent, now known as BWX Technologies, Inc. ("BWXT"), on June 30, 2015 to become a separate publicly traded company, and BWXT did not retain any ownership interest in the Company. As a result of the spin-off, there are several significant areas where the liabilities of BWXT 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 BWXT 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 BWXT in connection with the spin-off that allocates the responsibility for prior period taxes of BWXT consolidated tax reporting group between us and BWXT and its subsidiaries. However, if BWXT 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 BWXT's historical nuclear operations. For example, BWXT 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 BWXT was unable to pay, we could be required to pay for them.
The spin-off could result in substantial tax liability.
The spin-off was conditioned on BWXT's receipt of an opinion of counsel, in form and substance satisfactory to BWXT, 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 BWXT 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 U.S. 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 was determined not to qualify under Section 355 of the Code, each United States holder of BWXT 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 BWXT generally share responsibility for any taxes imposed on us or BWXT 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 BWXT, we or BWXT, 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 BWXT generally share responsibility for all taxes imposed on us or BWXT 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 BWXT, we or BWXT, 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 certain 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 BWXT'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. 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, BWXT generally is liable for any such tax liabilities. However, we are required to indemnify BWXT 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 to engage in certain strategic or capital raising transactions that our shareholders might consider favorable, or to structure potential transactions in the manner most favorable to us, without certain adverse tax consequences.
Potential indemnification liabilities to BWXT pursuant to the master separation agreement could materially adversely affect the Company.
The master separation agreement with BWXT 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 us and BWXT with respect to and resulting from the spin-off. Among other things, the master separation agreement provides for indemnification obligations designed to make us 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 BWXT assumed by us pursuant to the
master separation agreement. If we are required to indemnify BWXT under the circumstances set forth in the master separation agreement, we may be subject to substantial liabilities.
In connection with our separation from BWXT, BWXT 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 BWXT's ability to satisfy its indemnification obligation will not be impaired in the future.
Pursuant to the master separation agreement, BWXT has agreed to indemnify us for certain liabilities. However, third parties could seek to hold us responsible for any of the liabilities that BWXT agreed to retain, and there can be no assurance that the indemnity from BWXT will be sufficient to protect us against the full amount of such liabilities, or that BWXT will be able to fully satisfy its indemnification obligations. Moreover, even if we ultimately succeed in recovering from BWXT 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 BWXT.
Several members of our board and management own shares of common stock of BWXT and/or options to purchase common stock of BWXT because of their current or prior relationships with BWXT. In addition, two of the current members of our board of directors were members of the BWXT board of directors. This share ownership by these two 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 us and BWXT.
Item 1B. Unresolved Staff Comments
None
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, 2017.2018.
|
| | |
| Business Segment and Location | Principal Use | Owned/Leased (Lease Expiration) |
PowerBabcock & Wilcox segment and Corporate | | |
| Barberton, Ohio | Administrative office / research and development | Owned(1) |
| Charlotte, North Carolina | Administrative office | Leased (2019) |
| 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)(2019) |
| Jingshan, Hubei, China | Manufacturing facility | Owned |
| Vølund & Other Renewable segment | | |
| Copenhagen, Denmark | Administrative office | Leased (2022)(2021) |
| Esbjerg, Denmark | Manufacturing facility / administrative office | Owned |
| Straubing, Germany | Manufacturing facility | Leased (2021) |
IndustrialSPIG segment | | |
De Pere, Wisconsin | Manufacturing facility / administrative office | Owned(1)
|
Stoughton, Wisconsin | Administrative office | Owned(1)
|
Arona,Paruzzaro 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)(2020) |
(1) These properties are encumbered by liens under existing credit facilities.
In September 2018, we relocated our corporate headquarters to Barberton, Ohio from Charlotte, North Carolina. At the same time, we announced that we would consolidate most of our Barberton and Copley, Ohio operations into new, leased office
space in Akron, Ohio in approximately the third quarter of 2019 for our Corporate and Babcock & Wilcox segment functions. The new location in Akron is expected to reduce operating costs, inclusive of rent, and to provide a space that better meets our needs. In connection with our new lease agreement, we have agreed to sell our Barberton facility following the move to the facility in Akron, Ohio. We believe that our other 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 2123 to the consolidated financial statementsConsolidated Financial Statements included in Item 8 of this annual report, which we incorporate by reference into this Item.
27Additionally, the Company has received subpoenas from the staff of the SEC in connection with an investigation into the accounting charges and related matters involving its Vølund & Other Renewable segment in 2016, 2017 and 2018. We are cooperating with the staff of the SEC related to the subpoenas and investigation. We cannot predict the length, scope or results of the investigation, or the impact, if any, of the investigation on our results of operations.
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, 2018,2019, there were approximately 1,8001,700 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, 2017.2018. 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 | | | — | | |
|
| | | | | | | | | | | |
| 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) |
| October 1, 2018 - October 31, 2018 | | 20,581 | | $— | — | | $— |
| November 1, 2018 - November 30, 2018 | | 12,175 | | $— | — | | $— |
| December 1, 2018 - December 31, 2018 | | 14,362 | | $— | — | | $— |
| Total | | 47,118 | | | — | | |
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| |
| (1) | TheIncludes 20,581, 12,175 and 14,362 shares repurchased duringin October, November and December, 2017 shown in the table above are those repurchasedrespectively, pursuant to the provisions of employee benefit plans that require us to repurchase shares to satisfy employee statutory income tax withholding obligations.
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(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. |
The following graph provides a comparison of our cumulative total shareholder return through December 31, 20172018 to the return of the S&P 500, the Russell 2000 and our custom peer group.
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| (1) | Assumes initial investment of $100 on June 30, 2015. |
The peer group used for the comparison above is comprised of the following companies:
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| | |
| 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. | |
Stockholder Matters
29
On November 27, 2018, we received written notification (the "NYSE Notice"), from the New York Stock Exchange (the "NYSE"), that we were not in compliance with an NYSE continued listing standard in Rule 802.01C of the NYSE Listed Company Manual because the average closing price of our common stock fell below $1.00 over a period of 30 consecutive trading days. We informed the NYSE that we intend to seek to cure the price condition by executing our strategic plan, which is expected to result in improved operational and financial performance that we expect will ultimately lead to a recovery of our common stock price. We can regain compliance with the minimum per share average closing price standard at any time during the six-month cure period if, on the last trading day of any calendar month during the cure period, we have (i) a closing share price of at least $1.00 and (ii) an average closing share price of at least $1.00 over the 30 trading-day period ending on the last trading day of that month. We informed the NYSE that we are also prepared to consider a reverse stock
split to cure the deficiency, should such action be necessary, subject to approval of our shareholders, at our next annual meeting. Our common stock could also be delisted if our average market capitalization over a consecutive 30 trading-day period is less than $15.0 million, in which case we would not have an opportunity to cure the deficiency, our common stock would be suspended from trading on the NYSE immediately, and the NYSE would begin the process to delist our common stock, subject to our right to appeal under NYSE rules. We cannot assure you that any appeal we undertake in these or other circumstances will be successful. While we are considering various options, it may take a significant effort to cure this deficiency and regain compliance with this continued listing standard, and there can be no assurance that we will be able to cure this deficiency or if we will cease to comply with another NYSE continued listing standard.
Item 6. Selected Financial Data
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| | | | | | | | | | | | | | | | | | | |
| | 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 |
|
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| | | | | | | | | | | | | | | | | | | |
| | Year Ended December 31, |
| (in thousands, except for per share amounts) | 2018 | | 2017 | | 2016 | | 2015 | | 2014 |
Revenues(1) | $ | 1,062,388 |
| | $ | 1,341,429 |
| | $ | 1,420,941 |
| | $ | 1,573,600 |
| | $ | 1,380,611 |
|
| Income (loss) from continuing operations | (658,460 | ) | | (382,068 | ) | | (122,900 | ) | | 5,820 |
| | (14,951 | ) |
| Income (loss) from discontinued operations, net of tax | (66,832 | ) | | 2,244 |
| | 7,251 |
| | 13,321 |
| | (11,577 | ) |
| Net income (loss) attributable to Babcock & Wilcox Enterprises, Inc. | (725,292 | ) | | (379,824 | ) | | (115,649 | ) | | 19,141 |
| | (26,528 | ) |
| | | | | | | | | | |
| Basic and diluted earnings (loss) per share - continuing operations | (5.18 | ) | | (8.14 | ) | | (2.45 | ) | | 0.11 |
| | (0.28 | ) |
| Basic and diluted earnings (loss) per share - discontinued operations | (0.52 | ) | | 0.05 |
| | 0.14 |
| | 0.25 |
| | (0.21 | ) |
| Basic and diluted earnings (loss) per share | (5.70 | ) | | (8.09 | ) | | (2.31 | ) | | 0.36 |
| | (0.49 | ) |
| | | | | | | | | | |
| Total assets (as of year-end) | $ | 745,497 |
| | $ | 1,322,229 |
| | $ | 1,529,143 |
| | $ | 1,663,045 |
| | $ | 1,516,554 |
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(1)On January 1, 2018, we adopted ASC Topic 606 "Revenue from Contracts with Customers" using the modified retrospective method applied to all contracts that were not completed as of January 1, 2018. Results for reporting periods beginning on or after January 1, 2018 are presented under Topic 606, while prior period amounts are not adjusted and continue to be reported under the accounting standards in effect for the prior period.
Our Renewable segment's resultsThe most significant driver of our losses in each of2018, 2017 and 2016 was the past two years were significantly impacted bycharges for the performance of an operating unit within the segment which recognizedsix European Vølund loss contracts. In 2018, 2017 and 2016, we recorded $233.0 million, $158.5 million and $141.1 million in charges in the years ended December 31, 2017 and 2016,net losses, respectively, related to netinclusive of warranty expense, from changes in the estimated revenues and costs to complete certain renewable energy contracts in Europe.the six European Vølund loss contracts.
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 powerRestructuring 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 estimatedspin 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 $9.6were $16.8 million, $11.6$15.0 million, $38.8 million, $15.0 million and $35.6$20.2 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 31,2018, 2017, 2016, 2015, and 2014 respectively.
OurFinancial advisory service costs were $18.6 million and $2.7 million in 2018 and 2017, resultsrespectively, as were also significantly impacted by the revaluation ofrequired under 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.U.S. Revolving Credit Facility
Other matters that significantly impacted our results over the past five years include the following:
In 2017, we recorded goodwill impairment charges ofGoodwill and other intangible asset impairments were $40.0 million and $86.9 million ($85.8 million net of tax), which included a $50.0 million charge in the Renewable reporting unit2018 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 resultOther-than-temporary impairments of a strategic change in our Indian joint venture due to the decline in forecasted market opportunities in India, we recorded anequity method investments were $18.4 and $18.2 million other-than-temporary-impairment of our investment in TBWES.
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 research2018 and development facilities and equipment dedicated to activities that were determined not to be commercially viable.2017, respectively.
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 2018, 2017, 2016, 2015 2014 and 20132014 and on pre-tax income was a gain (loss) of $(67.5) million, $8.7 million, $(24.1)$(24.2) million, $(40.2)$(40.1) million and $(101.3) million, and $92.1respectively.
In 2018, we recorded $99.6 million respectively.of non-cash income tax charges to increase the valuation allowance against our remaining net deferred tax assets. In 2017, we recorded $62.4 million of income tax expense from the revaluation of our deferred taxes as a result of the December 2017 United States tax reform.
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,"BW," "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 incomeearnings before interest, taxes, depreciation and amortization ("EBITDA"), as reconciled in the table 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 Agreementrecorded operating losses of $426.6 million, $316.4 million and $110.0 million in 2018, 2017 and 2016, respectively. The most significant driver of our operating losses was the charges for the six European Vølund loss contracts. In 2018, 2017 and 2016, we recorded $233.0 million, $158.5 million and $141.1 million in net losses, respectively, inclusive of warranty expense, from changes in the estimated revenues and costs to amend our United States Revolving Credit Facility (describedcomplete the six European Vølund loss contracts. These contracts and their status are described further in Note 197 to the consolidated financial statementsConsolidated Financial Statements included in Item 8)8.
As of March 2019, four of the six Vølund loss contracts had been turned over to the customer, with only punch list or agreed remediation items remaining, some of which are expected to be performed during the customers' scheduled maintenance outages. This applies to the first, third, fourth and sixth loss contracts. The customers for the second and fifth loss contracts are related parties, and a settlement agreement was reached on March 1,29, 2019 to limit our remaining risk related to these contracts. Under that settlement agreement, we agreed to pay a combined £70 million ($88.9 million) by April 5, 2019 in exchange for limiting and further defining our obligations under these second and fifth loss contracts, including waiver of the rejection and termination rights on the fifth loss contract that could have resulted in repayment of all monies paid to us and our former civil construction partner (up to approximately $144 million), and requirement to restore the property to its original state if the customer exercised this contractual rejection right. On the fifth loss contract, we agreed to continue to support construction services to complete certain key systems of the plant by a specified date, for which penalty for failure to complete these systems is limited to the unspent portion of our quoted cost of the activities through that date. The settlement eliminates all historical claims and remaining liquidated damages. Upon completion of these activities in accordance with the settlement, we will have no further obligation related to the fifth loss contract other than customary warranty of core products if the plant is used as a biomass plant as designed. We estimated the portion of this settlement related to waiver of the rejection right on the fifth project was $81.1 million, which was recorded in the fourth quarter of 2018 (the “March 1,as a reduction in the selling price. We are still pursuing insurance recoveries and claims against subcontractors. For the second loss project, the settlement limits the remaining performance obligations and settled historic claims for nonconformance and delays, and we expect to turn over the plant in May 2019 and then begin the operations and maintenance contract that follows turnover of this plant. Additional engineering or core scope services, may be provided by us on the fifth loss contract on commercially acceptable terms. We will provide operations and maintenance services under an existing contract for the fifth loss project if properly notified and the plant is used as a biomass plant as designed. See further discussion of the loss projects in Note 7 to the Consolidated Financial Statements included in Item 8.
Aside from these loss projects, we have one remaining extended scope contract in our Vølund business, for which we continue to expect a small profit; this contract is expected to be turned over to our customer in the third quarter of 2019. 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 do not expect to have further contracts in this business that extend beyond our core technologies.
The SPIG segment contributed to our operating losses with adjusted EBITDA losses of $53.4 million, $29.8 million and EBITDA income of $1.9 million in 2018, Amendment”). The March 1,2017 and 2016, respectively, which were primarily driven by increases in estimated costs to complete new build cooling systems contracts sold under a previous strategy and lower volumes of aftermarket cooling system services. SPIG's 2018 Amendment temporarily waivedresults also include bad debt expense of $9.3 million and legal expenses related to legacy litigation. In 2017, we changed our strategy in the financial covenant defaults associatedSPIG segment to improve profitability by focusing on more selective bidding in core geographies and products. SPIG's new build cooling systems contracts that were sold under the previous strategy are mostly complete as of December 31, 2018; however, included in these few remaining contracts is a loss contract to engineer, procure materials and then construct a dry cooling system for a gas-fired power plant in the U.S. SPIG was previously included in our former Industrial segment with our United States Revolving Credit Facility ("Revolver")former MEGTEC and Universal businesses that existed at December 31, 2017, consentedwere sold on October 5, 2018. Beginning with the second quarter of 2018, the MEGTEC and Universal businesses were presented as
discontinued operations because the disposal represents a strategic shift that had a major effect on our operations. The sale is described further in Note 4 to the Company's planned Rights OfferingConsolidated Financial Statements included in Item 8.
Our Babcock & Wilcox segment has generated adjusted EBITDA $83.6 million, $103.3 million and allows up$130.7 million in 2018, 2017 and 2016, respectively. We anticipated the decline in the global new build market for coal-fired power generation and from lower demand for retrofit projects resulting from previously enacted Coal Combustion Residue regulations in the U.S. and took proactive restructuring actions in the segment largely to $35maintain the gross profit percentage and continue to generate strong EBITDA and cash flow from the segment.
Through our restructuring efforts, we made significant strides to make our cost structure more variable and to reduce costs. We have identified additional initiatives that are underway as of the date of this filing that are expected to further reduce costs, and we expect to continue to explore other cost saving initiatives to improve cash generation and to evaluate additional non-core asset sales to reduce our debt.
Year-over-year comparisons of our results from continuing operations were also affected by:
$39.8 million pre-tax gain in 2018 for the sale of borrowingsPBRRC, a subsidiary that held two operations and maintenance contracts for waste-to-energy facilities in West Palm Beach, Florida. Prior to be usedthe divestiture, PBRRC generated annual revenues of approximately $60 million in conjunction with the Vølund & Other Renewable segment. We received cash proceeds of $38.9 million, net of certain working capital adjustments and $4.9 million deposited in escrow. See further discussion of the Rights Offeringsale in Note 5 to be used to repay the principal portionConsolidated Financial Statements included in Item 8.
$49.2 million debt extinguishment loss from early repayment of the Second Lien Term Loan Facility on May 4, 2018 with $214.9 million of the proceeds from the 2018 Rights Offering that was completed on April 30, 2018. Through the 2018 Rights Offering, we raised $248.4 million of gross proceeds and issued 124.3 million shares of common stock. The extinguishment loss and the 2018 Rights Offering are more fully described in Note 21 and Note 22 to the Consolidated Financial Statements included in Item 8.
$99.6 million of non-cash income tax charges in 2018 to increase the valuation allowance against our remaining net deferred tax assets as described in Note 10 to the Consolidated Financial Statements included in Item 8. In 2017, $62.4 million of deferred tax expense was recorded primarily from the revaluation of our deferred tax balances.
$(67.5) million, $8.7 million and $(24.2) million of actuarially determined mark to market ("Second Lien"MTM"). (losses) gains on our pension and other postretirement benefits in 2018, 2017 and 2016, respectively. MTM gains and losses are further described in Note 18 to the Consolidated Financial Statements included in Item 8.
$40.0 million and $86.9 million of goodwill and other intangible impairments in 2018 and 2017, respectively. The 2018 impairment charges were to fully impair goodwill related to our SPIG reporting unit and to impair other intangibles related to SPIG geographies that will be exited. The 2017 impairment charges fully impaired the goodwill of the Vølund & Other Renewable reporting unit and $36.9 million related to the SPIG reporting unit. See further discussion in Note 14 to the Consolidated Financial Statements included in Item 8.
$18.6 million and $2.7 million of financial advisory services are included in SG&A in 2018 and 2017, respectively, which are required under our U.S. Revolving Credit Facility, as described more fully in Note 19 to the Consolidated Financial Statements included in Item 8.
$16.8 million, $15.0 million and $38.8 million of restructuring and spin-off costs were recognized in 2018, 2017, and 2016, respectively, and are more fully described below and in Note 8 to the Consolidated Financial Statements included in Item 8.
$6.5 million of gain on the sale of our interest in Babcock & Wilcox Beijing Company, Ltd. ("BWBC"), an equity method investment in China, was recognized in the first quarter of 2018 and is included in Equity in income and impairment of investees. The sale was completed in early 2018 with proceeds, net of withholding tax, of $19.8 million.
$18.4 million and $18.2 million of other-than-temporary impairment of our interest in TBWES, an equity method investment in India, in the first quarter of 2018 and the second quarter of 2017, respectively, based on an agreement to sell, preceded by a change in strategy. We completed the sale in July 2018, which generated $15.0 million for the sale and settlement of contractual claims. The impairments are included in Equity in income and impairment of investees. See further discussion in Note 13 to the Consolidated Financial Statements included in Item 8.
$2.9 million of accelerated depreciation expense in the second half of 2018 for fixed assets affected by our September 2018 announcement to consolidate office space and relocate our global headquarters to Akron, Ohio in
mid-2019. We expect a total of $7.0 million of accelerated depreciation to be recognized from the third quarter of 2018 through mid-2019.
$1.5 million to dispose and write off unused IT equipment and cancel in-process IT projects in the second quarter of 2018.
$1.5 million of acquisition and integration costs in 2017 related to the acquisition of SPIG.
$77.8 million of impairment and loss on sale of the MEGTEC and Universal businesses in October 2018, which remains subject to adjustment. The loss is included in Loss from discontinued operations, net of tax and is described further in Note 4 to the Consolidated Financial Statements included in Item 8.
We face liquidity challenges from losses recognized on our six European Vølund loss contracts described in Note 7 to the Consolidated Financial Statements included in Item 8, which caused us to be out of compliance with certain financial covenants and resulted in events of default in the agreements governing certain of our debt at each of December 31, 2017, were due primarilyMarch 31, 2018, June 30, 2018, September 30, 2018 and December 31, 2018. Our liquidity is provided under a credit agreement dated May 11, 2015, as amended, with a syndicate of lenders ("Amended Credit Agreement") that governs a revolving credit facility ("U.S. Revolving Credit Facility") and our last out term loan facility ("Last Out Term Loans"). The Amended Credit Agreement is described in more detail in Note 19 and Note 20 to additional losses we recognizedthe Consolidated Financial Statements included in Item 8. We obtained waivers to the Amended Credit Agreement that temporarily waived, prevented or resolved these defaults as described in Note 19 and Note 31 to the Consolidated Financial Statements included in Item 8. The most recent waiver extends through April 5, 2019.
To address our liquidity needs and the going concern uncertainty, we:
raised gross proceeds of $248.4 million on April 30, 2018 through the rights offering as described in Note 22 to the Consolidated Financial Statements included in Item 8 (the "2018 Rights Offering");
repaid on May 4, 2018 the Second Lien Term Loan Facility described in Note 21 to the Consolidated Financial Statements included in Item 8that had been in default beginning March 1, 2018;
completed the sale of our MEGTEC and Universal businesses on October 5, 2018, for $130 million, subject to adjustment, resulting in receipt of $112.0 million in cash, net of $22.5 million in cash sold with the businesses, and $7.7 million that was deposited in escrow pending final settlement of working capital and other customary matters;
completed the sale of Palm Beach Resource Recovery Corporation ("PBRRC"), a subsidiary that held two operations and maintenance contracts for waste-to-energy facilities in West Palm Beach, Florida, on September 17, 2018 for $45 million subject to adjustment, resulting in receipt of $38.9 million in cash and $4.9 million, which was deposited in escrow pending final settlement of working capital and other customary matters;
sold our equity method investments in Babcock & Wilcox Beijing Company, Ltd. ("BWBC"), a joint venture in China, and Thermax Babcock & Wilcox Energy Solutions Private Limited ("TBWES"), a joint venture in India, and settled related contractual claims, resulting in proceeds of $21.1 million in the fourthsecond quarter of 2017 related2018 and $15.0 million in the third quarter of 2018, respectively;
sold another non-core business for $5.1 million in the first quarter of 2018;
initiated restructuring actions and other additional cost reductions since the second quarter of 2018 that are designed to an increasesave approximately $84 million annually;
received $30 million 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 Tranche A-1 of Last Out Term Loans, described in Note 20 to the saleConsolidated Financial Statements included in Item 8, from B. Riley FBR, Inc., a related party, in September and October 2018 (Tranche A-1 was assigned to Vintage Capital Management LLC, another related party, on November 19, 2018);
received $10.0 million in net proceeds from Tranche A-2 of the Company’s common stockLast Out Term Loans, described in Note 31 to the Consolidated Financial Statements included in Item 8, from B. Riley Financial, Inc., a related party on March 20, 2019;
reduced uncertainty and provided better visibility into our future liquidity requirements by turning over four of the six European Vølund loss contracts to the customers and negotiating settlement of the remaining two loss contracts in the Rights Offeringfirst quarter of 2019 as described in Note 7 to the Consolidated Financial Statements included in Item 8; and
entered into several amendments and waivers to avoid default and improve our liquidity under the permitted borrowing capacity provided by our Revolver to extinguish the outstanding balanceterms 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 conditionsAmended Credit Agreement as described in the capital markets and, with respectNote 31 to the Rights Offering, an amendmentConsolidated Financial Statements included in Item 8, the most recent of which extends through April 5, 2019, unless earlier terminated, and waives our compliance with a number of covenants and events of default under, the Amended Credit Agreement.
Management believes it is taking all prudent actions to our existing shelf registration statement that we plan to file in early March 2018 being declared effective byaddress 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, but we cannot assert that it is probable that our plans will fully mitigate the conditions identified. Ifliquidity challenges we cannotface. We are currently dependent upon the waivers granted in our most recent limited waiver to maintain our current compliance with the covenants in the Amended Credit Agreement, and since March 20, 2019, we have also been nearly fully drawn on the U.S. Revolving Credit Facility, such that only minimal additional amounts were available for borrowings or letters of credit.
Based on our forecasts, we will require additional amendments to or waivers under the Amended Credit Agreement and additional financing to fund working capital and the settlements of two of our six European Vølund loss contracts described in Note 7 to the Consolidated Financial Statements included in Item 8 prior to April 5, 2019 to continue as a going concern, material adjustments toconcern. We are currently in active discussions with the carrying values and classificationslenders under the Amended Credit Agreement (including certain of our assetsrelated parties) for additional financing, a waiver of our compliance with covenants in and liabilitiesevents of default under the Amended Credit Agreement, a reduction of the minimum liquidity requirements that we must maintain, a reset of future financial covenant ratios and amendments to other covenant requirements in order to allow us to continue to operate as a going concern. Our current discussions have focused around the extension of additional Last Out Term Loans, primarily from related parties, in an amount necessary to fund the settlement of the European Vølund loss contracts and provide liquidity for our operations. In connection with these loans, we have also discussed seeking shareholder approval for a reverse stock split and various other matters that could result in substantial dilution to our shareholders not participating in this financing, such as a rights offering to repay a portion of these additional Last Out Term Loans, the exchange of a portion of our existing Last Out Term Loans for shares of common stock and the reported amountsissuance of incomewarrants with a de minimis strike price to lenders participating in these additional Last Out Term Loans or other parties. We also discussed whether, as part of any financing transaction, we would provide director nomination rights over some or even a substantial majority of our board of directors to two of the related parties involved in these financing efforts or whether we would add an event of default if we fail to refinance the U.S. Revolving Credit Facility within twelve months following the filing of this annual report. These discussions have not yet resulted, 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
extent that these adjustmentsmay never result, in a reduction of previously reported profits from a contract, we recognize a charge against current earnings. Changes in the estimated results ofbinding commitment by 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, therelenders. There can be no assurance that unanticipated schedule delays in the futureour lenders or any other person will commit to provide additional financing consistent with these discussions or at all. If we are able to obtain additional financing, it may be on terms substantially different from our current discussions described above, and may require additional or different commitments by us with regard to other actions we will or will not result in additional contract lossestake. If we fail to obtain necessary financing on acceptable terms or liquidated damages. Going forward,otherwise obtain short-term capital and continuing waivers with approval from our Renewable segment will focus primarily on its core technologies, with the balance of plant and civil construction scope being executed byexisting lenders, we may be unable to continue operation as 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.going concern.
The net decrease in cash in 2017 was $39.2 million. Net borrowings on our Revolver were $84.5 million, which includedIn addition to 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 primarilydiscussions regarding additional financing described above, we continue to fund progress on our Renewable segment contracts, acquire Universalevaluate further dispositions, opportunities for additional cost savings 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 lossesopportunities for insurance recoveries 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 Liquidityother claims where appropriate and capital resources.available.
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.
RESULTS OF OPERATIONS – YEARS ENDED DECEMBER 31, 2018, 2017 2016 and 20152016
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 |
|
Beginning in 2018, we changed our primary measure of segment profitability from gross profit to adjusted EBITDA. The presentation of the components of our revenues and gross profit and adjusted EBITDA in the table above istables below are consistent with the way our chief operating decision maker reviews the results of our operations and makes strategic decisions about our business. Items such as gains or losses on asset sales, MTM pension adjustments, restructuring and spin costs, impairments, losses on debt extinguishment, costs related to financial consulting required under Amendments 3 and 5 to our U.S. Revolving Credit Facility and other costs that may not be directly controllable by segment management are not allocated to the segment. Adjusted EBITDA for each segment is presented below with a reconciliation to net income. Adjusted EBITDA is not a recognized term under GAAP and should not be considered in isolation or as an alternative to net earnings (loss), operating profit (loss) or as an alternative to cash flows from operating activities as a measure of our liquidity. Adjusted EBITDA as presented below differs from the calculation used to compute our leverage ratio and interest coverage ratio as defined by our U.S. Revolving Credit Facility. Because all companies do not use identical calculations, the amounts presented for Adjusted EBITDA may not be comparable to other similarly titled measures of other companies.
|
| | | | | | | | | |
| | Year Ended December 31, |
| (In thousands) | 2018 | 2017 | 2016 |
| Revenues: | | | |
| Babcock & Wilcox segment | $ | 754,576 |
| $ | 821,062 |
| $ | 981,978 |
|
| Vølund & Other Renewable segment | 181,182 |
| 347,198 |
| 349,172 |
|
| SPIG segment | 153,625 |
| 181,485 |
| 96,291 |
|
| Eliminations | (26,995 | ) | (8,316 | ) | (6,500 | ) |
| | 1,062,388 |
| 1,341,429 |
| 1,420,941 |
|
Gross profit (loss)(1): | | | |
| Babcock & Wilcox segment | 141,054 |
| 171,008 |
| 213,541 |
|
| Vølund & Other Renewable segment | (238,125 | ) | (128,205 | ) | (68,109 | ) |
| SPIG segment | (25,113 | ) | (7,967 | ) | 8,026 |
|
| Intangible amortization expense included in cost of operations | (6,055 | ) | (10,618 | ) | (15,192 | ) |
| Inventory reserve for strategic change in China | (1,405 | ) | — |
| — |
|
| | (129,644 | ) | 24,218 |
| 138,266 |
|
| Selling, general and administrative ("SG&A") expenses | (198,200 | ) | (218,060 | ) | (216,486 | ) |
| Financial advisory services included in SG&A | (18,625 | ) | (2,659 | ) | — |
|
| Trade receivable reserve in SG&A for Chinese operations | (5,845 | ) | — |
| — |
|
| Intangible amortization expense included in SG&A | (661 | ) | (426 | ) | (598 | ) |
| Goodwill and other intangible asset impairment | (40,046 | ) | (86,903 | ) | — |
|
| Restructuring activities and spin-off transaction costs | (16,758 | ) | (15,039 | ) | (38,813 | ) |
| Research and development costs | (3,780 | ) | (7,614 | ) | (8,849 | ) |
| (Loss) gain on asset disposals, net | (1,438 | ) | (13 | ) | 25 |
|
| Equity in income and impairment of investees | (11,603 | ) | (9,867 | ) | 16,440 |
|
| Operating loss | $ | (426,600 | ) | $ | (316,363 | ) | $ | (110,015 | ) |
(1) Intangible amortization is not allocated to the segments' gross profit, but depreciation is allocated to the segments' gross profit.
|
| | | | | | | | | |
| | Year Ended December 31, |
| (in thousands) | 2018 | 2017 | 2016 |
| Adjusted EBITDA | | | |
Babcock & Wilcox segment(1) | $ | 83,640 |
| $ | 103,294 |
| $ | 130,735 |
|
| Vølund & Other Renewable segment | (276,266 | ) | (170,344 | ) | (105,102 | ) |
| SPIG segment | (53,406 | ) | (29,792 | ) | 1,862 |
|
Corporate(2) | (26,876 | ) | (36,147 | ) | (35,343 | ) |
| Research and development costs | (3,780 | ) | (7,614 | ) | (8,849 | ) |
| Foreign exchange | (28,542 | ) | (4,751 | ) | (1,944 | ) |
| Other – net | 259 |
| (698 | ) | (616 | ) |
| | | | |
| Depreciation & amortization | (28,521 | ) | (30,449 | ) | (34,523 | ) |
| Interest expense, net | (49,364 | ) | (25,426 | ) | (2,900 | ) |
| Loss on debt extinguishment | (49,241 | ) | — |
| — |
|
| Restructuring activities and spin-off transaction costs | (16,758 | ) | (15,039 | ) | (38,813 | ) |
| Financial advisory services included in SG&A | (18,625 | ) | (2,659 | ) | — |
|
| Acquisition and integration costs included in SG&A | — |
| (1,522 | ) | — |
|
| Reserves for strategic change in China | (7,250 | ) | — |
| — |
|
| MTM gain (loss) from benefit plans | (67,474 | ) | 8,706 |
| (24,159 | ) |
| Goodwill and other intangible asset impairment | (40,046 | ) | (86,903 | ) | — |
|
| Impairment of equity method investment in TBWES | (18,362 | ) | (18,193 | ) | — |
|
| Gain on sale of equity method investment in BWBC | 6,509 |
| — |
| — |
|
| Gain on sale of business | 39,815 |
| — |
| — |
|
| (Loss) gain on asset disposal | (1,513 | ) | (13 | ) | 25 |
|
| Loss before income tax expense | (555,801 | ) | (317,550 | ) | (119,627 | ) |
| Income tax expense (benefit) | 102,224 |
| 63,709 |
| 2,706 |
|
| Loss from continuing operations | (658,025 | ) | (381,259 | ) | (122,333 | ) |
| Income (loss) from discontinued operations, net of tax | (66,832 | ) | 2,244 |
| 7,251 |
|
| Net loss | (724,857 | ) | (379,015 | ) | (115,082 | ) |
| Net income attributable to noncontrolling interest | (435 | ) | (809 | ) | (567 | ) |
| Net loss attributable to stockholders | $ | (725,292 | ) | $ | (379,824 | ) | $ | (115,649 | ) |
(1) Babcock & Wilcox segment adjusted EBITDA includes $25.4 million, $21.0 million and $20.0 million of net benefit from pension and other postretirement benefit plans excluding MTM adjustments in the years ended December 31, 2018, 2017 and 2016, respectively.
(2) Allocations are excluded from discontinued operations. Accordingly, allocations previously absorbed by the MEGTEC and Universal businesses in the SPIG segment have been included with other unallocated costs in Corporate, and totaled $11.4 million, $8.8 million and $4.3 million in the years ended December 31, 2018, 2017 and 2016, respectively.
2018 vs 2017 Consolidated Results
Revenues decreased by $279.0 million to $1.06 billion in 2018 as compared to $1.34 billion in 2017. Revenue in the Vølund & Other Renewable segment decreased by $166.0 million primarily due to the effect of the March 29, 2019 settlement described above, other estimated contract progress changes and increases in estimated liquidated damages on the six European Vølund loss contracts and from lower levels of activity as progress is made on these loss projects, as well as lower volume in other profitable contracts and lines of business in the Vølund & Other Renewable segment. Revenue in the Babcock & Wilcox segment decreased by $66.5 million primarily due to anticipated lower demand in the global market for new build coal-fired power generation and from lower demand for retrofit projects driven in previous periods by the Coal Combustion Residue regulations in the U.S. Revenue in the SPIG segment declined $27.9 million due to lower volume of new build cooling systems services following a 2017 change in strategy to improve profitability by focusing on more selective bidding in core geographies and products and a lower volume of aftermarket cooling system services.
Gross profit decreased by $153.9 million, to a loss of $129.6 million in 2018 as compared to a profit of $24.2 million in 2017. In 2018 and 2017 we recorded $233.0 million and $158.5 million in net losses, respectively, from changes in the estimated
revenues and costs to complete the six European Vølund loss contracts, as described in greater detail in Note 7 to the Consolidated Financial Statements included in Item 8 and inclusive of the effect of the March 29, 2019 settlement described above. In addition to the losses in the Vølund & Other Renewable segment's gross profit included increased warranty accruals, lower volume in its profitable portfolio of equipment-only contracts and aftermarket lines of business, as well as higher costs under its operations and maintenance contracts and increased levels of support costs as we progress the loss contracts to completion and recording a $12.3 million (DKK $80.0 million) reserve for an insurance receivable described more fully below. Gross profit in the Babcock & Wilcox segment decreased due to lower volume of revenue, increases in estimated costs on certain projects in 2018, favorable results in closing out contracts in the second quarter of 2017, and a reduction of employee benefits that occurred in the second quarter of 2017. The SPIG segment gross profit decrease was primarily due to increases in estimated costs to complete new build cooling systems contracts sold under the previous strategy and lower volume of aftermarket cooling system services. SPIG's new build cooling systems contracts that were sold under the previous strategy are mostly complete as of December 31, 2018; however, included in these few remaining contracts is the loss contract described in Note 7 to the Consolidated Financial Statements included in Item 8.
Operating losses increased $110.2 million to $426.6 million in 2018 from $316.4 million in 2017, primarily due to the decline in gross profit described above. SG&A benefits from our restructuring and cost control initiatives were more than offset by the financial advisory services required under the terms of our U.S. Revolving Credit Facility during 2018 and increases in the allowance for doubtful accounts. Gross profit declines were also offset by lower levels of goodwill impairment. Goodwill impairment charges, restructuring expenses, intangible asset amortization expense and income and other-than-temporary impairments of equity method investees are discussed in further detail in the sections below.
2017 vs 2016 Consolidated resultsResults
Revenues decreased by $20.5$79.5 million to $1.56$1.34 billion in 2017 as compared to $1.58$1.42 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 PowerBabcock & Wilcox segment. Partially offsetting the decline in PowerBabcock & Wilcox segment revenues were increases in revenues of $144.2$85.2 million in the IndustrialSPIG segment resulting from the acquisitionsacquisition of Universal on January 11, 2017 and SPIG on July 1, 2016.
In 2017, we had consolidated gross profit of $99.9decreased $114.0 million which compares to consolidated gross profit of $179.1$24.2 million compared to $138.3 million in 2016, a decrease of $79.2 million.2016. The primary drivers of the decrease were the six uncompleted European Vølund loss contracts described in Note 7 to the Renewable segment (see Note 6 in the consolidated financial statementsConsolidated Financial Statements included in Item 8),8, the volume impact of the decline in the PowerBabcock & Wilcox 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.SPIG segment.
Our consolidated operating losses were $281.6$316.4 million and $102.8$110.0 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-impairmentother-than-temporary impairment of our investment in TBWES (a joint venture in India), $15.4 million more SG&A expenses primarily related to acquired
businesses, and $8.1 million less income from equity method investees.investees excluding the impairment. Partially offsetting these declines were a $25.4$23.8 million reduction inlower 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.
PowerBabcock & Wilcox segment
Our Babcock & Wilcox segment (formerly named the Power segmentsegment) 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 boilerutility 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 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 otherothers' 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, environmental control systems, natural gas and oil firedoil-fired package boilers, due in part to lower fuel prices; and
reducing costs through a focus on operational efficiencies.
Power segment resultsBabcock & Wilcox Segment Results
| | | | Year Ended December 31, | | | Year Ended December 31, | | Year Ended December 31, | | Year Ended December 31, |
| (In thousands) | 2017 | 2016 | $ Change | | 2016 | 2015 | $ Change | 2018 | 2017 | $ Change | | 2017 | 2016 | $ Change |
| Revenues | $ | 821,062 |
| $ | 981,978 |
| $ | (160,916 | ) | | $ | 981,978 |
| $ | 1,234,997 |
| $ | (253,019 | ) | $ | 754,576 |
| $ | 821,062 |
| $ | (66,486 | ) | | $ | 821,062 |
| $ | 981,978 |
| $ | (160,916 | ) |
| Gross profit | $ | 191,999 |
| $ | 233,550 |
| $ | (41,551 | ) | | $ | 233,550 |
| $ | 247,632 |
| $ | (14,082 | ) | $ | 141,054 |
| $ | 171,008 |
| $ | (29,954 | ) | | $ | 171,008 |
| $ | 213,541 |
| $ | (42,533 | ) |
| Gross margin % | 23 | % | 24 | % | | | 24 | % | 20 | % | | |
| Adjusted EBITDA | | $ | 83,640 |
| $ | 103,294 |
| $ | (19,654 | ) | | $ | 103,294 |
| $ | 130,735 |
| $ | (27,441 | ) |
| Gross profit % | | 18.7 | % | 20.8 | % | | | 20.8 | % | 21.7 | % | |
2018 vs 2017 results
Revenues in the Babcock & Wilcox segment decreased 8%, or $66.5 million, to $754.6 million in 2018, compared to $821.1 million in 2017. The revenue decrease is attributable to the continued decline in the global new build market for coal-fired power generation and from lower demand for retrofit projects resulting from previously enacted Coal Combustion Residue regulations in the U.S.
Gross profit in the Babcock & Wilcox segment decreased 18%, or $30.0 million, to $141.1 million in 2018, compared to $171.0 million in 2017. The decrease in gross profit is related to lower volume of revenue, increases in estimated costs on certain projects in 2018, favorable results in closing out contracts in the second quarter of 2017 and a reduction of employee benefits that occurred in the second quarter of 2017. Our gross profit percentage was also affected by lower margin services sold on an intercompany basis to SPIG and our former MEGTEC business in an effort to expand their markets. Benefits from restructuring initiatives have otherwise largely held gross profit percentages in the segment, and we expect to continue evaluating our cost structure in the segment to maintain an appropriately sized organization for our business and to improve margins where possible.
Adjusted EBITDA in the Babcock & Wilcox segment decreased 19%, or $19.7 million, to $83.6 million in 2018, compared to $103.3 million in 2017. The adjusted EBITDA decrease is attributable to the decrease in gross profit discussed above. Babcock & Wilcox segment SG&A also decreased year-over-year as a result of cost savings initiatives, partially offset by a $5.9 million increase in bad debt expense for China's receivable accounts resulting from a change in selling and collection strategy in that region.
A new accounting standard for pension and other postretirement benefits became effective in 2018, and as a result, Babcock & Wilcox segment gross profit has been adjusted retrospectively to reflect the change in presentation from this new standard.
Only service costs are included in Babcock & Wilcox segment gross profit while all other components of the net cost of/benefit from pension and other postretirement benefit plans, excluding MTM adjustments totaling $25.4 million and $21.0 million in 2018 and 2017, respectively, are included in Babcock & Wilcox segment adjusted EBITDA. See detail of pension and other postretirement benefit plan charges and benefits in Note 18 to the Consolidated Financial Statements included in Item 8.
2017 vs 2016 results
Revenues in the Babcock & Wilcox segment decreased 16%, or $160.9 million, to $821.1 million in 2017 from2018, compared to $982.0 million in 2016.2017. 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%20%, or $41.6$42.5 million, to $192.0$171.0 million in 2017 from $233.6$213.5 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 yearin 2017 versus last year.2016.
2016 vs 2015 results
RevenuesAdjusted EBITDA in the Babcock & Wilcox segment decreased 20%,21% or $253.0$27.4 million, to $982.0$103.3 million in 2016 from $1.23 billion2017 compared to $130.7 million in 2015.2017. The adjusted EBITDA decrease inis attributable to lower gross profit discussed above, and the segment's revenues reflectSG&A decreased consistently with 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 decreasechange 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 theour restructuring effortsinitiatives.
A new accounting standard for pension and other postretirement benefits became effective 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 20162018, and 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.
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 presentBabcock & Wilcox segment gross profit and operating income upon adoption. Because almosthas been adjusted retrospectively to reflect the change in presentation from this new standard. Only service costs are included in Babcock & Wilcox segment gross profit while all of our retirement benefit plans are in the Power segment, the reclassification of allother components of the net periodic retirement cost/benefit componentsfrom pension and other than service cost from cost of operations to other income in the statement of operations will result in reclassification ofpostretirement benefit plans, excluding MTM adjustments totaling $21.0 million and $20.0 million in 2017 and $17.9 million2016, respectively, are included in Babcock & Wilcox segment adjusted EBITDA. See detail of net periodic retirementpension and other postretirement benefit gains from the Power segment's gross profit for 2017, 2016plan charges and 2015, respectively, which will resultbenefits in restated gross margins of 21%, 22% and 19%, respectively. See Note 2918 to the consolidated financial statementsConsolidated Financial Statements included in Item 8 for more information about the new accounting standard.8.
Vølund & Other Renewable segment
Our Vølund & Other Renewable segment (formerly named the 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.
InBeginning 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 RenewableVølund renewable energy contracts that involved our European resources duringsince 2017 as we workedwork through our existingthen-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, asand we continue to see numerous opportunities around the globe, although the rate of this growth is dependent on many external factors.
Vølund & Other Renewable segment resultsSegment Results
| | | | Year Ended December 31, | | | Year Ended December 31, | | Year Ended December 31, | | Year Ended December 31, |
| (in thousands, except percentages) | 2017 | 2016 | $ Change | | 2016 | 2015 | $ Change | |
| (in thousands) | | 2018 | 2017 | $ Change | | 2017 | 2016 | $ Change |
| Revenues | $ | 347,198 |
| $ | 349,172 |
| $ | (1,974 | ) | | $ | 349,172 |
| $ | 338,603 |
| $ | 10,569 |
| $ | 181,182 |
| $ | 347,198 |
| $ | (166,016 | ) | | $ | 347,198 |
| $ | 349,172 |
| $ | (1,974 | ) |
| Gross profit (loss) | $ | (128,204 | ) | $ | (68,109 | ) | $ | (60,095 | ) | | $ | (68,109 | ) | $ | 57,682 |
| $ | (125,791 | ) | $ | (238,125 | ) | $ | (128,205 | ) | $ | (109,920 | ) | | $ | (128,205 | ) | $ | (68,109 | ) | $ | (60,096 | ) |
| % of revenues | (37 | )% | (20 | )% | | | (20 | )% | 17 | % | | |
| Adjusted EBITDA | | $ | (276,266 | ) | $ | (170,344 | ) | $ | (105,922 | ) | | $ | (170,344 | ) | $ | (105,102 | ) | $ | (65,242 | ) |
| Gross profit % | | (131.4 | )% | (36.9 | )% | | | (36.9 | )% | (19.5 | )% | |
On September 17, 2018, we divested PBRRC, a subsidiary that held two operations and maintenance contracts for waste-to-energy facilities in West Palm Beach, Florida. Prior to the divestiture, PBRRC generated annual revenues of approximately $60 million. The $39.8 million pre-tax gain on sale was not allocated to the segment. The divestiture is more fully described in Note 5 to the Consolidated Financial Statements included in Item 8.
2018 vs 2017 results
Revenues in the Vølund & Other Renewable segment decreased 48%, or $166.0 million to $181.2 million in 2018, compared to $347.2 million in 2017. As described above, 2018 revenue reflects the effect of the settlement of the second and fifth European Vølund loss contracts. We estimated the portion of this settlement related to waiver of the rejection right on the fifth project was $81.1 million, which was recorded in the fourth quarter of 2018 as a reduction in the selling price. Beyond the effect of the settlement, in 2018, several of the European Vølund loss contracts were in the final stages of the completion, when fewer costs are incurred relative to the main construction phases that were underway in the year-ago period, and as a result, revenues were lower. Additionally, the decision to limit bidding on Vølund renewable energy contracts negatively affected our revenue in 2018 and may result in lower revenue in 2019.
Gross profit in the Vølund & Other Renewable segment decreased $109.9 million to a loss of $238.1 million in 2018, compared to a loss of $128.2 million in 2017. In 2018 and 2017, we recorded $233.0 million and $158.5 million in net losses, respectively, resulting from changes in the estimated revenues and costs to complete the six European loss contracts. As described above, 2018 revenue reflects the effect of the settlement of the second and fifth European Vølund loss contracts. We estimated the portion of this settlement related to waiver of the rejection right on the fifth project was $81.1 million, which was recorded in the fourth quarter of 2018 as a reduction in the selling price. Beyond the effect of the settlement, the lower level of losses in the Vølund & Other Renewable segment's gross profit was more than offset primarily by increased warranty accruals, lower volume in its profitable portfolio of equipment-only contracts and aftermarket lines of business, as well as higher costs under its operations and maintenance contracts and increased levels of support costs as we progress the loss contracts to completion. Additionally, in 2018, we recorded a $12.3 million (DKK 80.0 million) reserve for an insurance receivable as a result of our insurer disputing our $15.5 million (DKK 100.0 million) insurance claim to recover a portion of the losses on the first project. The insurance receivable was established in 2016. We believe that the dispute from the insurer is without merit and continue to believe we are entitled to the full value of the claim. We intend to aggressively pursue full recovery under the policy, and we filed for arbitration in July 2018. However, an allowance for the receivable was recorded in 2018 based upon the dispute by the insurer, which is considered contradictory evidence in the accounting probability assessment of this loss recovery, even if it is believed to be without merit.
Adjusted EBITDA in the Vølund & Other Renewable segment decreased $105.9 million to a loss of $276.3 million in 2018, compared to a loss of $170.3 million in 2017. The decrease in adjusted EBITDA was primarily due to the changes in gross profit described above, partly offset by lower SG&A, which reflects the benefits of restructuring, lower proposal costs and active reductions in discretionary spend.
Additional information about the changes in the estimated revenue and costs to complete these European Vølund loss contracts, the March 29, 2019 settlement of the second and fifth loss contracts, changes in the warranty accruals and the insurance receivable is included in Note 7 to the Consolidated Financial Statements included in Item 8.
2017 vs 2016 results
Revenues in the Vølund & Other Renewable segment 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 Vølund renewable energy projects in Europe during both periods.
Gross profit in the Vølund & Other Renewable segment hadwere 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 revenue and cost to complete certain renewable energythe European Vølund loss 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
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 fromAdditional information about changes in the estimated forecastedrevenue and cost to complete certain renewable energythe European Vølund loss 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 detailsis included in Note 67 to the consolidated financial statementsConsolidated Financial Statements included in Item 8 of this annual report.8.
Adjusted EBITDA in the Vølund & Other Renewable segment were losses $170.3 million and $105.1 million in 2017 and 2016, respectively, primarily due to the changes in the estimated revenue and cost to complete the European Vølund loss contracts.
IndustrialSPIG 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. ItSPIG provides custom-engineered cooling systems for steam applications, as well as related services and aftermarket products. SPIG’sSPIG'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 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 from core products and geographies in the IndustrialSPIG 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,On October 5, 2018, we also announced that we are evaluating strategic alternatives forsold all of the capital stock of our MEGTEC and Universal businesses to Dürr Inc., a wholly owned subsidiary of Dürr AG, pursuant to a stock purchase agreement executed on June 5, 2018. The MEGTEC and Universal businesses are classified as discontinued operations because the disposal represents a strategic shift that had a major effect on our operations; they were previously included in orderour Industrial segment, which has been renamed the SPIG segment because SPIG is the remaining business of the former Industrial segment. Accordingly, we recorded $77.8 million of impairment and loss on sale of the MEGTEC and Universal businesses, which remains subject to enhanceadjustment. The loss is included in Loss from discontinued operations, net of tax in our financial flexibility. Though our outlook remains favorable for these businesses, we believe itConsolidated Statements of Operations and is prudentdescribed further in Note 4 to explore alternatives for these parts of our company, providing greater optionality if needed.the Consolidated Financial Statements included in Item 8.
Industrial segment resultsSPIG Segment Results
| | | | Year Ended December 31, | | | Year Ended December 31, | | Year Ended December 31, | | Year Ended December 31, |
| (In thousands) | 2017 | 2016 | $ Change | | 2016 | 2015 | $ Change | 2018 | 2017 | $ Change | | 2017 | 2016 | $ Change |
| Revenues | $ | 397,791 |
| $ | 253,613 |
| $ | 144,178 |
| | $ | 253,613 |
| $ | 183,695 |
| $ | 69,918 |
| $ | 153,625 |
| $ | 181,485 |
| $ | (27,860 | ) | | $ | 181,485 |
| $ | 96,291 |
| $ | 85,194 |
|
| Gross profit | $ | 41,383 |
| $ | 50,726 |
| $ | (9,343 | ) | | $ | 50,726 |
| $ | 54,826 |
| $ | (4,100 | ) | |
| Gross margin % | 10 | % | 20 | % |
|
| | 20 | % | 30 | % |
| |
| Gross profit (loss) | | $ | (25,113 | ) | $ | (7,967 | ) | $ | (17,146 | ) | | $ | (7,967 | ) | $ | 8,026 |
| $ | (15,993 | ) |
| Adjusted EBITDA | | $ | (53,406 | ) | $ | (29,792 | ) | $ | (23,614 | ) | | $ | (29,792 | ) | $ | 1,862 |
| $ | (31,654 | ) |
| Gross profit % | | (16.3 | )% | (4.4 | )% | | | (4.4 | )% | 8.3 | % |
|
|
2018 vs 2017 results
Revenues in the SPIG segment decreased 15%, or $27.9 million, to $153.6 million in 2018 from $181.5 million in 2017. The decrease is primarily due to lower volume of new build cooling systems services following a 2017 change in strategy to improve profitability by focusing on more selective bidding in core geographies and products and a lower volume of aftermarket cooling system services.
Gross profit in the SPIG segment decreased $17.1 million, to a loss of $25.1 million in 2018, compared to a loss of $8.0 million in 2017. The decrease was primarily due to increases in estimated costs to complete new build cooling systems contracts sold under the previous strategy and lower volume of aftermarket cooling system services. SPIG's new build
cooling systems contracts that were sold under the previous strategy are mostly complete as of December 31, 2018; however, included in these few remaining contracts is the loss contract described in Note 7 to the Consolidated Financial Statements included in Item 8.
Adjusted EBITDA in the SPIG segment decreased $23.6 million to a loss of $53.4 million in 2018, compared to a loss of $29.8 million in 2017. The decrease primarily reflects increases in estimated costs to complete legacy new build cooling systems contracts, bad debt expense of $9.3 million and legal expenses related to legacy litigation.
2017 vs 2016 results
Revenues increased 57%, or $144.2$85.2 million,, to $397.8$181.5 million in 2017 from $253.6$96.3 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.SPIG.
Gross profit decreased 18%, or $9.3$16.0 million, to $41.4a loss of $8.0 million in the year ended December 31, 2017, compared to $50.7 million in 2016. In 2017, Universal contributed $14.5$8.0 million of gross profit.profit in 2016. 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.mix. 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
Adjusted EBITDA decreased $31.7 million to a loss of $29.8 million in 2017, compared to income of $1.9 million as a result of the Industrial segment'schanges in 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.increases in SG&A support costs.
2016 vs 2015 resultsBookings and backlog are our measure of remaining performance obligations under our sales contracts. It is possible that our methodology for determining bookings and backlog may not be comparable to methods used by other companies.
Revenues increased 38.1%,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 customers to payment for work performed. Backlog may not be indicative of future operating results, and contracts in our backlog may be canceled, modified or $69.9 million, to $253.6 millionotherwise altered by customers. Additionally, because we operate globally, our backlog is also affected by changes in 2016 from $183.7 million in 2015. The increase in revenues is primarily the resultforeign currencies each period. We do not include orders of our acquisition of SPIG on July 1, 2016, which contributed $96.3 million of revenueunconsolidated joint ventures in backlog.
Bookings represent changes to the Industrial segment during the second halfbacklog. Bookings include additions from booking new business, subtractions from customer cancellations or modifications, changes in estimates of 2016. Our MEGTEC business experiencedliquidated damages that affect selling price and revaluation of backlog denominated in foreign currency. We believe comparing bookings on a declinequarterly basis or for periods less than one year is less meaningful than for longer periods, and that shorter-term changes in revenues in 2016 across each of its product lines caused by the decline in demandbookings may not necessarily indicate a material trend.
|
| | | | | | |
| | Year Ended December 31, |
| (In millions) | 2018 | 2017 |
| Babcock & Wilcox | $ | 688 |
| $ | 656 |
|
Vølund & Other Renewable(1) | (501 | ) | 115 |
|
| SPIG | 65 |
| 183 |
|
| Other/eliminations | (2 | ) | (46 | ) |
| Bookings | $ | 250 |
| $ | 908 |
|
(1) Vølund & Other Renewable bookings in the United States.
Gross profit decreased 7.5%, or $4.1year ended December 31, 2018 includes a reduction of approximately $467 million from the sale of PBRRC, as described in Note 5 to $50.7the Consolidated Financial Statements included in Item 8 and $81 million from the settlement of the fifth loss project as described in Note 7 to the Consolidated Financial Statements included in Item 8. Vølund & Other Renewable bookings also include the revaluation of backlog denominated in currency other than U.S. dollars, which was $(21.5) million and $64.3 million, in the year ended December 31, 2016, compared2018, and 2017, respectively.
|
| | | | | | |
| | Year Ended December 31, |
| (In approximate millions) | 2018 | 2017 |
| Babcock & Wilcox | $ | 386 |
| $ | 453 |
|
Vølund & Other Renewable(1)(2) | 327 |
| 1,008 |
|
| SPIG | 87 |
| 175 |
|
| Other/eliminations | (18 | ) | (43 | ) |
| Backlog | $ | 782 |
| $ | 1,593 |
|
(1) Vølund & Other Renewable backlog at December 31, 2018, includes $233 million related to $54.8 million in 2015. The SPIG business contributed gross profitlong-term operation and maintenance contracts for renewable energy plants, with remaining durations extending until 2034. Generally, such contracts have a duration 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 able10-20 years and include options 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 declineextend.
(2) Vølund & Other Renewable bookings in the 2016 gross margin percentageyear ended December 31, 2018 includes a reduction of approximately $467 million from the sale of PBRRC, as described in Note 5 to the segment.Consolidated Financial Statements included in Item 8.
Of the backlog at December 31, 2018, we expect to recognize revenues as follows:
|
| | | | | | | | | | | | |
| (In approximate millions) | 2019 | 2020 | Thereafter | Total |
| Babcock & Wilcox | $ | 290 |
| $ | 71 |
| $ | 25 |
| $ | 386 |
|
| Vølund & Other Renewable | 109 |
| 24 |
| 194 |
| 327 |
|
| SPIG | 38 |
| — |
| 49 |
| 87 |
|
| Other/eliminations | (18 | ) | — |
| — |
| (18 | ) |
| Expected revenue from backlog | $ | 419 |
| $ | 95 |
| $ | 268 |
| $ | 782 |
|
Goodwill impairmentCorporate
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 managementCorporate costs include SG&A expenses that are described in Note 15not allocated to the consolidated financial statements included in Item 8. The third quarter 2017 impairment charges eliminated allreportable segments. These costs include certain executive, compliance, strategic, reporting and legal expenses associated with governance of the Renewable reporting unit's goodwill balance at September 30, 2017,total organization 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 $15.4being an SEC registrant. Corporate costs decreased $9.3 million to $255.5$26.9 million in 2018, as compared to $36.1 million in 2017, from $240.2 million in 2016. The primary reason for the increase is $24.3 million of combined SG&A expenses attributableprimarily due to the recently acquired SPIGbenefits of restructuring, lower incentive and Universal businesses. In addition, SG&A expensesstock-based compensation and reductions in our Renewable segmentdiscretionary spend. Corporate costs increased by $17.5$0.8 million to $36.1 million in 2017, as compared to support ongoing renewable energy projects$35.3 million in Europe. These increases are partially2016, primarily due to the benefits of restructuring and lower stock-based and incentive compensation being offset by the savingshigher indirect support costs related to owning MEGTEC and Universal. Allocations are excluded from our restructuring initiatives, which provided $30.6discontinued operations, and accordingly, these indirect costs that were previously absorbed by the MEGTEC and Universal businesses have been included with other unallocated costs in Corporate, and total $11.4 million, of benefit to our Power segment$8.8 million and $4.3 million in 2017, and reductions in incentive compensation accruals in both2018, 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.respectively.
Research and development expensesDevelopment
Our research and development activities are related to improving our products through innovations to reduce the cost of our products to make them more competitive and through innovations to reduce performance risk of our products to better meet our and our customers' expectations.Research and development costs unrelated to specific contracts are expensed as incurred. 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 $9.4totaled $3.8 million, $10.4$7.6 million and $16.5$8.8 million in the years ended December 31, 2018, 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. 2016. The reductions resulted from cost control initiatives.
Restructuring
In 2018, we expectbegan to implement a series of cost restructuring actions in our researchU.S., European, Canadian and development expensesAsian operations, and corporate functions. These actions were intended to continueappropriately size our operations and support functions in response to decline.the continuing decline in global markets for new build coal-fired power generation, the announcement of the MEGTEC and Universal sale and our liquidity needs. Severance cost associated with these actions taken through December 31, 2018 is expected to total approximately $9.1 million, of which $7.2 million was recorded in the year ended December 31, 2018 and the remainder will be recorded mainly in 2019 over the remaining service periods. Severance payments are expected to extend through mid-2019. In addition, executive severance totaling $5.3 million in 2018 related to the elimination of the SVP and Chief Business Development Officer role and the transition of two CEO roles in 2018. Executive severance payments are expected to extend through late-2019. In February 2019, we implemented additional severance actions, primarily in our U.S. operations and corporate functions, and cost associated with these actions is expected to be approximately $3.3 million. Our restructuring actions and other additional cost reductions since the second quarter of 2018 are designed to save approximately $84 million annually.
Restructuring
2017 Restructuring activities
InThe remainder of the restructuring costs in 2018, primarily relate to actions from the second half of 2017 we announced plans to implement restructuring actionsthat were intended to improve our global cost structure and increase our financial flexibility. TheThese restructuring actions includeincluded 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 includeincluded the reduction of approximately 30% of B&W Vølund's workforce which will right-size its workforce to operate underalign with a new execution model focused on B&W'sVølund'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
In 2017 and the estimated annual savings are expected2016, restructuring costs relate primarily to be approximately $45 million in 2018.
Pre-2017 Restructuring activities
Oura series of restructuring activities that took place prior to 2017 that were intended to help us maintain margins, make our costs more variablevolume-variable and allow our business to be more flexible. These actions were primarily in the Babcock & Wilcox segment in advance of lower projected demand for power generation from coal in the United States. 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, ourUntil the second quarter of 2018, these restructuring actions also benefitachieved the Renewable and Industrial segments to a lesser degree. As demonstrated in our Power segment's gross margin percentages, we have achieved our objectivegoal of maintaining gross margins in the Babcock & Wilcox segment. Quantification of cost savings, however, is significantly dependent upon volume assumptions that have changed since the restructuring actions were initiated. In 2016, we recorded cash restructuring charges of $19.9 million that impacted the accrued restructuring liability and $15.0 million of non-cash restructuring expense related to losses on the disposals of long-lived assets.
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 costsSpin-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 (nownow known as BWX Technologies, Inc.) or "BWXT". In the years ended December 31, 2018, 2017 2016 and 2015,2016, we recognized spin-off costs of $0.3 million, $1.2 million, $3.8 million,and $3.8 million respectively. In each of the years ended December 31, 2018 and 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.
Goodwill and Other Intangible Asset Impairments
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 $2.2We recorded goodwill impairments totaling $37.5 million and $3.1$86.9 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 of2018 and 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.respectively. As a result of this strategic change, we recognized a $18.2 million other-than-temporary-impairment of our investment in TBWESthese impairments, the only remaining goodwill is included in the second quarter of 2017.Babcock & Wilcox segment. In 2017, the impairment included a $50.0 million charge to fully impair goodwill in the Vølund & Other Renewable reporting unit and a $36.9 million charge in the SPIG reporting unit. The impairment charge was based onin 2018 represented the differenceremainder of the goodwill in the carrying value of our investment in TBWESSPIG reporting unit. The reasons for the impairment charges 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 furtherrelated assumptions to determine these charges are described in Note 714 to the consolidated financial statementsConsolidated Financial Statements included in Item 8.
In the fourth quarter of 2018, a strategic decision was made to exit certain geographies of the SPIG segment, and as a result, $2.5 million of the customer relationship and other intangible assets related to these geographies were impaired.
Equity in Income (Loss) of Investees
|
| | | | | | | | | |
| | Year Ended December 31, |
| | 2018 | 2017 | 2016 |
| Our share of income from equity method investees | $ | 250 |
| $ | 8,326 |
| $ | 8,116 |
|
| Gain on sale of BWBC | 6,509 |
| — |
| — |
|
| Gain on sale of HMA | — |
| — |
| 8,324 |
|
| Other-than-temporary impairment of TBWES | (18,362 | ) | (18,193 | ) | — |
|
| | $ | (11,603 | ) | $ | (9,867 | ) | $ | 16,440 |
|
As of December 31, 2018, we do not have investments in equity method investees. In the first quarter of 2018, we sold all of our interest in BWBCBWBW to our joint venture partner in China for approximately $21 million, which will result in a gain of approximately $4 million during$21.1 million. In the firstthird quarter of 2018. The sale of2018, we sold our BWBCinterest in TBWES to our joint venture partner in China is further describedIndia for approximately $15.0 million, including settlement of outstanding claims. In the fourth quarter of 2016, we sold our interest in Halley & Mellowes Pty. Ltd ("HMA") to our joint
venture partner in Australia for $18.0 million. The sales of BWBC and HMA resulted in gains, as shown in the table above. We recognized other-than-temporary impairments on TBWES as shown in the table above; in 2017 the impairment related to a change in business strategy, and in 2018, the impairment was based on the preliminary selling price. Refer to Note 7 to13 in the consolidated financial statementsConsolidated Financial Statements included in Item 8. BWBC contributed8 for further information regarding our former 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.method investments.
Depreciation and Intangible asset amortization expenseAsset Amortization
We recorded $18.3Depreciation expense was $21.8 million, $19.9$19.4 million and $11.4$18.7 million of expense duringin the years ended December 31, 2018, 2017 and 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 expectrecorded intangible asset amortization expense will be approximately $12.4of $6.7 million, $11.0 million and $15.8 million in 2018.the years ended December 31, 2018, 2017and 2016, respectively.
In September 2018, we relocated our global corporate headquarters to Barberton, Ohio from Charlotte, North Carolina. At the same time, we announced that we would consolidate most of our Barberton and Copley, Ohio operations into new, leased office space in Akron, Ohio, in the third quarter of 2019. The new location in Akron is expected to reduce operating costs, net of rent, and to provide a space that better meets our needs. We acquired $55.2do not expect to incur significant relocation costs; however, we expect $7.0 million of intangible assetsaccelerated depreciation to be recognized through mid-2019, of which $2.9 million was recognized 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 2017.2018.
Mark to market adjustmentsMarket Adjustments of Pension and Retirement Plans
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.other income (expense) in our Consolidated Statements of Operations. These mark to market ("MTM") adjustments for our pension and other postretirement plans resulted in net (losses) gains (losses) of $(67.5) million, $8.7 million, $(24.1)and $(24.2) million in 2018, 2017 and 2016, respectively.
While we retained the pension liability related to employees of PBRRC after the September 2018 sale of this business, the status change of these participants in the Retirement Plan for Employees of Babcock & Wilcox Commercial Operations (the "Commercial Operations Plan") resulted in a $3.5 million curtailment loss in the third quarter of 2018, which also triggered an interim MTM of the Commercial Operations Plan assets and liabilities that was a gain of $7.7 million in the third quarter of 2018. Additionally, in 2018, lump sum payments from our Canadian pension plan resulted in a plan settlement gain of $0.1 million and $(40.2)
$0.4 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 8.2018.
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 loss of $0.4 million and an interim mark to market remeasurement for the Canadian pension plan. The mark to market adjustmentMTM loss of $0.7 million in the first quarter of 2017 was $0.7 million.2017.
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 OPEBMedical plan") effective December 31, 2016. The Retiree OPEB planMedical 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,Medical Plan, the participants had the option to enroll in a third-party health care exchange, to which B&Wthe Company agreed to contribute up to $750 a year for each of the next three years (beginning in 2017) to a health reimbursement account ("HRA"), provided the plan participant had not yet reached his or hertheir lifetime maximum under the terminated Retiree OPEB plan.Medical Plan. Based on the number of participants who did not enrollenrolled in the new benefit plan, we recognized a settlementcurtailment gain of $7.2$10.8 million on December 31, 2016 (which is includedfor the actuarially determined difference in the liability for these participants in the Retiree Medical Plan and the new plan. The curtailment gain was deferred in accumulated other comprehensive income and was being recognized as partincome through 2020. Participants in the Retiree Medical Plan filed a class action lawsuit against the Company in 2017 asserting that the change in health care coverage breached the Company's obligations under collective bargaining agreements. In April 2018, the court approved a settlement whereby the Company will contribute $1,000 a year for 2018 and 2019, and $1,100 a year thereafter for the life of a participant to an HRA. As a result of the MTM adjustment).settlement, the revised Retiree Medical Plan
was actuarially remeasured as of April 1, 2018. The unamortized balance of the curtailment gain of $5.2 million and the related deferred tax of $1.3 million was reversed from AOCI and we recorded $5.2 million in other accumulated postretirement benefit liabilities for the actuarial value of the Retiree Medical Plan. 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 marketMTM accounting for the respective benefit plans in 2016, which totaled $27.5 million.
The net MTM loss in 2015 was primarily relatedRefer to actual return on assets that fell short of the expected long-term rate of return assumption, offset by an increaseNote 18 in the discount rate used to measureConsolidated Financial Statements included in Item 8 for further information regarding our benefit plans liabilities.pension and other postretirement plans.
ProvisionForeign Exchange
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 taxes(loss). We report foreign currency transaction gains and losses in income.
|
| | | | | | | | | |
| | 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 | % |
Income Taxes
We operate in numerous countries that have statutory tax rates below that ofdifferent than the United StatesU.S. federal statutory tax rate of 35% that was in effect through December 31, 2017.21%. 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%19% and approximately 30%. In addition,We have also established full valuation allowances against our deferred tax assets, and changes in valuation allowance may partly or entirely offset any income tax expense or benefit in a given jurisdiction depending on the jurisdictional mixnature of the income or expense and the deferred tax position in that jurisdiction. As a result, we expect our effective income (loss)tax rate to vary, potentially significantly, from period to period.
Loss before tax can be significantly affected by mark to market adjustments related to our pension and postretirement plans, which have been primarilyprovision for income taxes generated in the United States and foreign locations for years ended December 31, 2018, 2017 and 2016 is presented in the impacttable below. |
| | | | | | | | | |
| | Year Ended December 31, |
| (in thousands) | 2018 | 2017 | 2016 |
| United States | $ | (166,269 | ) | $ | (46,673 | ) | $ | (10,208 | ) |
| Other than the United States | (389,532 | ) | (270,877 | ) | (109,419 | ) |
Loss before income taxes
| (555,801 | ) | (317,550 | ) | (119,627 | ) |
| Income tax expense | 102,224 |
| 63,709 |
| 2,706 |
|
| Effective tax rate | (18.4 | )% | (20.1 | )% | (2.3 | )% |
In 2018, we had a pretax loss in the United States after MTM adjustments as well as an aggregate pretax loss in our foreign jurisdictions. Our effective tax rate was (18.4)% and was significantly impacted by net unfavorable discrete items of approximately $100.0 million that decreased the effective rate by 18.0%. These unfavorable discrete items.items included a non-cash charge of $99.6 million to increase the valuation allowance against our remaining net deferred tax assets as described in Note 10 to the Consolidated Financial Statements included in Item 8. The portion of this charge that related to the net deferred tax assets in the United States was $96.1 million. In 2018, we continued to have significant losses in certain foreign jurisdictions that were subject to valuation allowances and therefore did not give rise to tax benefits. These losses were primarily attributable to Vølund and SPIG.
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 significantOur effective tax rate was (20.1)% and was significantly impacted by losses whichin certain foreign jurisdictions that 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.
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,The foreign losses for which benefit was not recorded were primarily attributable to operating losses at Vølund. In addition, we recorded nondeductible goodwill impairment charges that impacted our effective tax rate. The net unfavorable discrete items decreased the effective tax rate by 22.5%. Our discrete items22.6% and primarily consist of unfavorable discrete itemsconsisted of $62.4 million related to changes to deferred taxes resulting from the enactment of newtax rate reduction included in the United States tax reform legislation enacted in the fourth quarter (see further discussionDecember of 2017 as described in Note 10 to the consolidated financial statementsConsolidated Financial Statements included in Item 8), an unfavorable discrete item for8, 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 a pretax loss in the United States after MTM adjustments as well as an aggregate pretax loss in our foreign jurisdictions. Our effective tax rate was (2.3)% and was significantly impacted by losses in certain foreign jurisdictions that were subject to a valuation allowance and therefore did not give rise to a tax benefit, as well as net unfavorable discrete items of approximately $32.2 million. With a pretax loss in 2016,The foreign losses for which benefit was not recorded were primarily attributable to operating losses at Vølund. The unfavorable discrete items decreased the effective tax rate by 29.8%. Our discrete items26.9% and primarily consistconsisted of a $15.7 million increase in the valuation allowance against deferred tax assets related to one of our foreign businessesVølund 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 statementsConsolidated 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 2017.2017 and the impact to the Company if an ownership change should occur under Section 382 of the Internal Revenue Code ("IRC"). The terms of the financing under active discussion on April 2, 2019, the date of this annual report, as described in Note 1 to the Consolidated Financial Statements included in Item 8 would likely result in an "ownership change" under IRC Section 382 if completed as described.
Liquidity and capital resourcesCapital Resources
AdditionalLiquidity
We face liquidity challenges from losses we recognized on our six European Vølund loss contracts described in Note 7 to the fourth quarter of 2017 related to an increaseConsolidated Financial Statements included 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 2017Item 8, which caused us to be out of compliance with certain financial covenants and resulted in events of default in the agreements governing certain of our lending arrangementsdebt at each of December 31, 2017.2017, March 31, 2018, June 30, 2018, September 30, 2018 and December 31, 2018. Our liquidity is provided under a credit agreement dated May 11, 2015, as amended, with a syndicate of lenders ("Amended Credit Agreement") that governs a revolving credit facility ("U.S. Revolving Credit Facility") and our last out term loan facility ("Last Out Term Loans"). The Amended Credit Agreement is described in more detail in Note 19 and Note 20 to the Consolidated Financial Statements included in Item 8. We obtained an amendmentwaivers to our United States Revolvingthe Amended Credit Facility on March 1, 2018Agreement that temporarily waived, the financial covenantprevented or resolved these 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 capital19 and Note 31 to the Consolidated Financial Statements included in Item 8. The most recent waiver extends through a rights offeringApril 5, 2019.
To address our liquidity needs and other sources before the endgoing concern uncertainty, we:
raised gross proceeds of the standstill period, which will depend$248.4 million on conditions in the capital markets and, with respect toApril 30, 2018 through the rights offering an amendmentas described in Note 22 to our existing shelf registration statementthe Consolidated Financial Statements included in Item 8 (the "2018 Rights Offering");
repaid on May 4, 2018 the Second Lien Term Loan Facility described in Note 21 to the Consolidated Financial Statements included in Item 8 that we plan to filehad been in earlydefault beginning March 2018 being declared effective by1, 2018;
completed the Securities and Exchange Commission ("SEC"), which are matters that are outsidesale of our control.MEGTEC and Universal businesses on October 5, 2018, for $130 million, subject to adjustment, resulting in receipt of $112.0 million in cash, net of $22.5 million in cash sold with the businesses, and $7.7 million that was deposited in escrow pending final settlement of working capital and other customary matters;
completed the sale of Palm Beach Resource Recovery Corporation ("PBRRC"), a subsidiary that held two operations and maintenance contracts for waste-to-energy facilities in West Palm Beach, Florida, on September 17,
2018 for $45 million subject to adjustment, resulting in receipt of $38.9 million in cash and $4.9 million, which was deposited in escrow pending final settlement of working capital and other customary matters;
We have sold our equity method investments in Babcock & Wilcox Beijing Company, Ltd. ("BWBC"), a joint venture in China, and Thermax Babcock & Wilcox Energy Solutions Private Limited ("TBWES"), a joint venture in India, and settled related contractual claims, resulting in proceeds of $21.1 million in the second quarter of 2018 and $15.0 million in the third quarter of 2018, respectively;
sold another non-core business for $5.1 million in the first quarter of 2018;
initiated stepsrestructuring actions and other additional cost reductions since the second quarter of 2018 that are designed to remedysave approximately $84 million annually;
received $30 million in net proceeds from Tranche A-1 of Last Out Term Loans, described in Note 20 to the going concern uncertainty, which include, but are not limited to:Consolidated Financial Statements included in Item 8, from B. Riley FBR, Inc., a related party, in September and October 2018 (Tranche A-1 was assigned to Vintage Capital Management LLC, another related party, on November 19, 2018);
secured an equity commitment agreementreceived $10.0 million in net proceeds from Tranche A-2 of the Last Out Term Loans, described in Note 31 to the Consolidated Financial Statements included in Item 8, from B. Riley Financial, Inc., a related party on March 1, 201820, 2019;
reduced uncertainty and provided better visibility into our future liquidity requirements by turning over four of the six European Vølund loss contracts to the customers and negotiating settlement of the remaining two loss contracts in the first quarter of 2019 as described in Note 7 to the Consolidated Financial Statements included in Item 8; and
entered into several amendments and waivers to avoid default and improve our liquidity under the terms of our Amended Credit Agreement as described in Note 31 to the Consolidated Financial Statements included in Item 8, the most recent of which extends through April 5, 2019, unless earlier terminated, and waives our compliance with a groupnumber of our existing stockholders to fully backstop our planned rights offering forcovenants and events of default under, 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;Amended Credit 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 theManagement believes it is taking all prudent actions summarized above are more likely than not to address the substantial doubt about our ability to continue as a going concern, but we cannot assert that it is probable that our plans will fully mitigate the conditions identified. Ifliquidity challenges we cannotface. We are currently dependent upon the waivers granted in our most recent limited waiver to maintain our current compliance with the covenants in the Amended Credit Agreement, and since March 20, 2019, we have also been nearly fully drawn on the U.S. Revolving Credit Facility, such that only minimal additional amounts were available for borrowings or letters of credit.
Based on our forecasts, we will require additional amendments to or waivers under the Amended Credit Agreement and additional financing to fund working capital and the settlements of two of our six European Vølund loss contracts described in Note 7 to the Consolidated Financial Statements included in Item 8 prior to April 5, 2019 to continue as a going concern, material adjustmentsconcern. We are currently in active discussions with the lenders under the Amended Credit Agreement (including certain of our related parties) for additional financing, a waiver of our compliance with covenants in and events of default under the Amended Credit Agreement, a reduction of the minimum liquidity requirements that we must maintain, a reset of future financial covenant ratios and amendments to other covenant requirements in order to allow us to continue to operate as a going concern. Our current discussions have focused around the extension of additional Last Out Term Loans, primarily from related parties, in an amount necessary to fund the settlement of the European Vølund loss contracts and provide liquidity for our operations. In connection with these loans, we have also discussed seeking shareholder approval for a reverse stock split and various other matters that could result in substantial dilution to our shareholders not participating in this financing, such as a rights offering to repay a portion of these additional Last Out Term Loans, the exchange of a portion of our existing Last Out Term Loans for shares of common stock and the issuance of warrants with a de minimis strike price to lenders participating in these additional Last Out Term Loans or other parties. We also discussed whether, as part of any financing transaction, we would provide director nomination rights over some or even a substantial majority of our board of directors to two of the related parties involved in these financing efforts or whether we would add an event of default if we fail to refinance the U.S. Revolving Credit Facility within twelve months following the filing of this annual report. These discussions have not yet resulted, and may never result, in a binding commitment by our lenders. There can be no assurance that our lenders or any other person will commit to provide additional financing consistent with these discussions or at all. If we are able to obtain additional financing, it may be on terms substantially different from our current discussions described above, and may require additional or different commitments by us with regard to other actions we will or will not take. If we fail to obtain necessary financing on acceptable terms or otherwise obtain short-term capital and continuing waivers with approval from our existing lenders, we may be unable to continue operation as a going concern.
In addition to the carrying valuesdiscussions regarding additional financing described above, we continue to evaluate further dispositions, opportunities for additional cost savings and classificationsopportunities for insurance recoveries and other claims where appropriate and available.
On November 27, 2018, we received written notification (the "NYSE Notice"), from the New York Stock Exchange (the "NYSE"), that we were not in compliance with an NYSE continued listing standard in Rule 802.01C of the NYSE Listed Company Manual because the average closing price of our assetscommon stock fell below $1.00 over a period of 30 consecutive trading days. We informed the NYSE that we intend to seek to cure the price condition by executing our strategic plan, which is expected to result in improved operational and liabilitiesfinancial performance that we expect will ultimately lead to a recovery of our common stock price. We can regain compliance with the minimum per share average closing price standard at any time during the six-month cure period if, on the last trading day of any calendar month during the cure period, we have (i) a closing share price of at least $1.00 and (ii) an average closing share price of at least $1.00 over the 30 trading-day period ending on the last trading day of that month. We informed the NYSE that we are also prepared to consider a reverse stock split to cure the deficiency, should such action be necessary, subject to approval of our shareholders, at our next annual meeting. Our common stock could also be delisted if our average market capitalization over a consecutive 30 trading-day period is less than $15.0 million, in which case we would not have an opportunity to cure the deficiency, our common stock would be suspended from trading on the NYSE immediately, and the reported amounts of incomeNYSE would begin the process to delist our common stock, subject to our right to appeal under NYSE rules. We cannot assure you that any appeal we undertake in these or other circumstances will be successful. While we are considering various options, it may take a significant effort to cure this deficiency and expense couldregain compliance with this continued listing standard, and there can be required.no assurance that we will be able to cure this deficiency or if we will cease to comply with another NYSE continued listing standard.
Events Subsequent to December 31, 2018
Subsequent to December 31, 2018, we have entered into a series of limited waivers (described below) to avoid default under our U.S. Revolving Credit Facility and Last Out Term Loans while we negotiated the settlement of the final two European Vølund loss contracts described in Note 7 to the Consolidated Financial Statements included in Item 8 and negotiated terms for financing and the related further amendment to our Amended Credit Agreement to allow for that financing. On March 20, 2019, we borrowed $10.0 million of additional funding in the form of a Tranche A-2 Last Out Term Loan (described below) to support working capital needs. Since March 20, 2019, we have been nearly fully drawn on the U.S. Revolving Credit Facility, minimal additional amounts were available for borrowings or letters of credit, and we were in compliance with the terms of the Amended Credit Agreement subject to the limited waivers that cumulatively extend through April 5, 2019. The waivers are described in more detail in Note 31 to the Consolidated Financial Statements included in Item 8.
As of April 2, 2019, the settlement of the final two European Vølund loss contracts has been completed pending payment of amounts due under the settlement. Binding agreement of this settlement, subject to payment, was a requirement of the lending group of the Amended Credit Agreement for further amendment. The additional financing required to make those settlement payments and to provide additional funding of working capital has not been yet been committed; however, as of April 2, 2019, negotiation for additional financing continues with the lending group under the Amended Credit Agreement, including related parties, and with interested third parties. The status and risks associated with our financing plans are described more fully above.
On March 19, 2019, we entered into an amendment and limited waiver (the "15th Amendment") to our Amended Credit Agreement, which replaced in full the First Limited Waiver, and extended the waivers of our compliance with covenants in the Amended Credit Agreement and certain events of default through March 29, 2019. The 15th Amendment also made certain other modifications to the Amended Credit Agreement. Specifically, the 15th Amendment provided $10.0 million in additional commitments from B. Riley Financial, Inc. under a Tranche A-2 of Last Out Term Loans, which were fully borrowed on March 20, 2019. This borrowing under Tranche A-2 of Last Out Term Loans was generally made on terms, including interest rate, maturity and prepayment, that are the same as our Tranche A-1 of the Last Out Term Loans.
Certain of the lenders, as well as certain of their respective affiliates, have performed and may in the future perform for us and our subsidiaries, various commercial banking, investment banking, lending, underwriting, trust services, financial advisory and other financial services, for which they have received and may in the future receive customary fees and expenses. B. Riley is a significant stockholder, owning approximately 6.43% of our outstanding common stock. See also Note 27 to the Consolidated Financial Statements included in Item 8.
Cash and Cash Flow as of and for the Years Ended December 31, 2018, 2017 and 2016
At December 31, 2017,2018, our unrestricted cash and cash equivalents totaled $56.7$43.2 million and we had $263.6total debt of $176.2 million. Our foreign business locations held $35.5 million at December 31, 2018. Our U.S. Revolving Credit Facility allows for nearly immediate borrowing of total borrowings ($299.3 million face value before debt discounts).available capacity to fund cash requirements in the normal course of business, meaning that U.S. cash on hand is minimized to reduce borrowing costs. In general, our foreign cash balances are not available to fund our United StatesU.S. operations unless the funds are repatriated or used to repay intercompany loans made from the United StatesU.S. 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 asU.S. At December 31, 2018, we believe that our United States liquidity is sufficienthad approximately $25.0 million available for borrowings or to meet letter of credit requirements primarily based on our overall facility size, our borrowing sublimit and giving effect to the anticipated cash requirements of our United States operations.
Historically, our primary sources of liquiditylimited waivers described above. Since March 20, 2019, we have been cash from operations, borrowings under our United Statesnearly fully drawn on the U.S. Revolving Credit Facility, ("Revolver")minimal additional amounts were available for borrowings or letters of credit, and borrowings under foreign revolving credit facilities. Our borrowing capacity underwe were in compliance with the terms of the Amended Credit Agreement subject to the limited waivers that cumulatively extend through April 5, 2019. As a result, the U.S. Revolving Credit Facility balance as of December 31, 2018 is presented as a current liability in our Revolver is primarily limited by the financial covenants, which are most significantly affected by our trailing 12 months EBITDA (as definedConsolidated Balance Sheets.
Net operating cash flow was a use of $281.9 million in the credit agreement governingyear ended December 31, 2018, which was primarily due to funding progress on the facility). The significantsix European Vølund loss accruals we recordedcontracts, corporate overhead, interest, pension and other postretirement benefits. Operating cash flows in the second quarteryear ended December 31, 2018 are primarily represented in the operating loss of continuing operations before non-cash impairments of goodwill, equity method investments and fourth quartersa valuation allowance for deferred taxes. Additionally, the effect of the settlement of the final two European Vølund loss contracts described above was included in operating income but is expected to be paid in 2019. In the year ended December 31, 2017, reduced our trailing 12 months EBITDAcash used in operations was $189.8 million and primarily related funding progress on the six European Vølund loss contracts in turn, our abilitythe Vølund & Other Renewable segment. Cash flows in the year ended December 31, 2017 are also primarily represented in the operating loss of continuing operations before non-cash impairments of goodwill and equity method investments, partly offset by improvements to comply with our financial covenants. Accordingly, we amended our Revolver on February 28, 2017, August 9, 2017working capital and March 1, 2018 to, among other things, provide covenant relief.an income tax refund.
To provide additional liquidity, we entered intoCash flows from investing activities provided net cash of $179.2 million in the year ended December 31, 2018, primarily from asset sales, including the sales of MEGTEC and Universal for $112.0 million in cash, net of $22.5 million in cash sold with the businesses, the sale of PBRRC for $38.9 million, the sales of two equity method investments, BWBC and TBWES, for $28.8 million, and the sale of a small emissions monitoring business for $5.1 million, which were offset by $5.5 million of capital expenditures. In the year ended December 31, 2017, net cash used by investing activities was $63.9 million, primarily related to $52.5 million for the Universal acquisition and $14.3 million of capital expenditures.
Cash flows from financing activities provided net cash of $82.6 million in the year ended December 31, 2018, primarily related to $50.6 million of net borrowings from the U.S. Revolving Credit Facility and the $30.0 million of borrowings from Tranche A-1 of the Last Out Term Loans for working capital purposes. Gross proceeds received from the 2018 Rights Offering were $248.4 million, of which $214.9 million were used to repay the Second Lien Term Loan, Facility ("Second Lien") on August 9, 2017including $2.3 million of accrued interest, with an affiliate of American Industrial Partners ("AIP"). The Second Lien consists of a second lien term loanthe remainder used to fund operations. Cost associated with financing activity in the principal amount of $175.9 million, all of which we borrowed on August 9, 2017, and a delayed draw term loanyear ended December 31, 2018 totaled $25.6 million. Net cash provided by financing activities in the principal amountyear ended December 31, 2017 was $206.1 million and included $84.5 million of $20.0 million,net borrowings under the U.S. Revolving Credit Facility, which was drawnwere used to fund our working capital needs and the Universal acquisition. Net cash provided by financing activities in a single draw onthe year ended December 13, 2017. On August 9,31, 2017 we used $125.0 millionalso included proceeds from the issuance 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.
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 $16.716.7 million of shares of common stock from a related party, fund debt issuance costs and repay a portion of our Revolver. The net cash usedU.S. revolving credit facility. Cost associated with financing activity in financing activities in 2016 is primarily attributablethe year ended December 31, 2017 totaled $15.0 million.
2018 Rights Offering
On March 19, 2018, we distributed to repurchases of $78.4 millionholders of our common stock.stock one nontransferable subscription right to purchase 1.4 common shares for each common share held as of 5:00 p.m., New York City time, on March 15, 2018 at a price of $3.00 per common share. On April 10, 2018, we extended the expiration date and amended certain other terms regarding the 2018 Rights Offering. As amended, each right entitled holders to purchase 2.8 common shares at a price of $2.00 per share. The 2018 Rights Offering expired on April 30, 2018. The Company did not issue fractional rights or pay cash in lieu of fractional rights. The 2018 Rights Offering did not include an oversubscription privilege.
In 2017, we also experienced increased levels of cash paid for interest based on higher borrowing levels, which we expect to increase further in 2018.54
United States
The 2018 Rights Offering concluded on April 30, 2018, resulting in the issuance of 124.3 million common shares on April 30, 2018. Gross proceeds from the 2018 Rights Offering were $248.4 million. Of the proceeds received, $214.9 million was used to fully repay the Second Lien Credit Agreement, including $2.3 million of accrued interest, and the remainder was used for working capital purposes. Direct costs of the 2018 Rights Offering totaled $3.3 million.
U.S. Revolving Credit Facility ("Revolver")as of December 31, 2018
On May 11, 2015, we entered into a credit agreement with a syndicate of lenders ("(as amended, the "Amended Credit Agreement") in connection with our spin-off from The Babcock & Wilcox Company. TheCompany (now BWX Technologies, Inc.) which governs the U.S. Revolving Credit Facility and the Last Out Term Loans. Since June 2016, we have entered into a number of waivers and amendments ("the Amendments") to the Amended Credit Agreement, which isincluding those to avoid default. The U.S. Revolving Credit Facility as in effect at December 31, 2018 was scheduled to mature on June 30, 2020 providesand provided for a senior secured revolving credit facility initially in an aggregate amount of up to $600 million.$347.0 million, as amended and adjusted for completed asset sales. The proceeds offrom loans under the U.S. Revolving Credit AgreementFacility 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.credit, subject to the limits specified in the amendment described below.
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 theThe Amended Credit Agreement and our obligations under certain hedging agreements and cash management agreements with our lenders and their affiliates continue to exclude: up to $98.1 millionbe (1) guaranteed by substantially all 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, realizedour wholly owned domestic subsidiaries 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, but excluding our captive insurance subsidiary, and (2) secured by first-priority liens on certain assets owned by us and the guarantors. The U.S. Revolving Credit Facility 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 guarantee and provide collateral for our obligations under the United States credit facility, (19)notice requirements. The U.S. Revolving Credit Facility requires certain prepayments on any outstanding revolving loans after receipt of cash proceeds from certain asset sales or other events, subject to certain exceptions. Such prepayments may 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 ofreduce 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 fullU.S. Revolving Credit Facility by a corresponding 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.prepayments.
After giving effect to the Amendments through December 31, 2018, revolving loans outstanding under the AmendedU.S. Revolving Credit AgreementFacility 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. The components of our interest expense are detailed in Note 26. A commitment fee of 1.0% per annum is charged on the unused portions of the revolving credit facility.U.S. Revolving Credit Facility. 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. A deferred fee of 2.5% was charged until October 9, 2018 and decreased to 1.5% effective October 10, 2018 due to achieving certain asset sales. A letter of credit fee of 2.50%2.5% 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%1.5% 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 within the time period required by the March 1, 2018 Amendment, theThese include a maximum permitted senior debt leverage ratio and a minimum consolidated interest coverage ratio, each as defined in the Amended Credit Agreement is:
8.50:1.0 for the quarter endedAgreement. Compliance with these ratios were waived as of 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 fornew ratios were established in the quarter endingsubsequent amendments described in Note 31, as we would not have otherwise been in compliance at 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.2018.
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, 2017,2018, borrowings under the AmendedU.S. Revolving Credit Agreement and foreign facilities totaled $103.5Facility consisted of $144.9 million at an effectivea weighted average interest rate of 6.89%7.82%. Usage under the AmendedU.S. Revolving Credit AgreementFacility consisted of $94.3$144.9 million of borrowings, $7.4$29.1 million of financial letters of credit and $123.7$146.8 million of performance letters of credit. After giving effect to the March 1, 2018 amendment, atAt December 31, 20172018, we had approximately $221.4$25.0 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),our overall facility size, our borrowing sublimit 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 closestgiving effect 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 covenantslimited waivers 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,Note 31. Since March 20, 2019, we have what we believe is adequate capacity to providebeen nearly fully drawn on the U.S. Revolving Credit Facility, minimal additional amounts were available for borrowings or letters of credit, and secure surety bondswe were in supportcompliance with the terms 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.
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 Lienthe limited waivers that cumulatively extend through April 5, 2019. As a result, the U.S. Revolving Credit AgreementFacility balance as of December 31, 2018 is generally less restrictive than the Amended Credit Agreement.presented as a current liability in our Consolidated Balance Sheets.
Foreign revolving credit facilitiesRevolving Credit Facilities
Outside of the United States, we have revolving credit facilities in Turkey and, until the first quarter of 2018, in India that are used to provide working capital to local operations. At December 31, 2018 and 2017, we had aggregate borrowings under these facilities of $0.6 million and $9.2 million respectively. Our weighted average interest rate on these facilities was 40.00% and 6.07% at December 31, 2018 and 2017, respectively. In 2018, our operationsbanking counterparties in each country. TheseTurkey began requiring the conversion of these revolving credit facilities to Turkish lira denomination from euro denomination, resulting in correspondingly higher market interest rates. As of January 4, 2019, the foreign revolving credit facilities allow us to borrow up to $9.2 millionwere paid in aggregatefull 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%.closed.
Letters of credit, bank guaranteesCredit, Bank Guarantees and surety bondsSurety 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 associatedin association with contracting activity. The aggregate value of all such letters of credit and bank guarantees not secured byopened outside of the United States credit facilityU.S. Revolving Credit Facility as of December 31, 20172018 and December 31, 20162017 was $269.1$175.9 million and $255.2$269.1 million, respectively. The aggregate value of all such letters of credit and bank guarantees that are partially secured by the RevolverU.S. Revolving Credit Facility as of December 31, 20172018 was $114.2$80.2 million. The aggregate value of the letters of credit provided by the RevolverU.S. Revolving Credit Facility in support of letters of credit outside of the United States was $40.4$47.6 million as of December 31, 2017.2018.
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, theseThese 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, 2017,2018, bonds issued and outstanding under these arrangements in support of contracts totaled approximately $378.8$202.7 million. The aggregate value of the letters of credit provided by the U.S. Revolving Credit facility in support of surety bonds was $22.6 million.
Our ability to obtain and maintain sufficient capacity under our U.S. Revolving Credit Facility is essential to allow us to support the issuance of letters of credit, bank guarantees and surety bonds. Without sufficient capacity, our ability to support contract security requirements in the future will be diminished.
Last Out Term Loans as of December 31, 2018
As referenced above, our Amended Credit Agreement required us to draw $30.0 million of net proceeds under Tranche A-1 of the Last Out Term Loans ("Tranche A-1"), which were borrowed from B. Riley FBR, Inc., a related party, in September and October 2018. On November 19, 2018, Tranche A-1 was assigned from B. Riley FBR, Inc., a related party, to Vintage Capital Management LLC, also a related party. The face principal amount of Tranche A-1 is $30.0 million, which excludes a $2.0 million up-front fee that was added to the principal balance on the first funding date, transaction expenses, paid-in-kind interest, and original issue discounts of 10.00% for each draw under Tranche A-1. Tranche A-1 is incurred under our Amended Credit Agreement and shares on a pari passu basis with the U.S. Revolving Credit Facility. Tranche A-1 matures and is payable in full on July 1, 2020, the day after the maturity date of the U.S. Revolving Credit Facility. Tranche A-1 may be prepaid, subject to the subordination provisions, but not re-borrowed.
Tranche A-1 bears interest at a rate per annum equal to (i) if designated a eurocurrency rate loan, the then-applicable U.S. LIBOR rate plus 14.00%, with 5.50% of such interest rate to be paid in cash and the remaining 8.50% payable in kind by adding such accrued interest to the principal amount of Tranche A-1 and (ii) if designated a base rate loan, the then applicable prime rate set by the Administrative Agent plus 13.00%, with 4.50% of such interest rate to be paid in cash and the remaining 8.50% payable in kind by adding such accrued interest to the principal amount of Tranche A-1. Subject to the subordination provisions, Tranche A-1 shall be subject to all of the other same representations and warranties, covenants and events of default under the Amended Credit Agreement. The total effective interest rate of Tranche A-1 was 25.38% on December 31, 2018. The effective rate of the Tranche A-1 may fluctuate over the life of the loan due to changes in LIBOR, the prime rates or any repayments. Interest expense associated with Tranche A-1 is detailed in Note 26.
As of December 31, 2018, the Tranche A-1 net carrying value of $30.6 million is presented as a current liability in our Consolidated Balance Sheets as a result of the limited waivers that extend through April 5, 2019.
Long-term benefit obligations
Second Lien Term Loan Extinguished in 2018
On August 9, 2017, we entered into the Second Lien Term Loan Facility with an affiliate of AIP, a related party. The Second Lien Term Loan Facility consisted 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 up to $20.0 million, which was drawn in a single draw on December 13, 2017. Through March 7, 2018, the interest rates were 10% and 12% per annum under the second lien term loan and the delayed draw term loan, respectively; each increased by 200 basis points to 12% and 14% per annum, respectively, beginning March 7, 2018, and in each case, interest was payable quarterly.
Using $212.6 million of the proceeds from the 2018 Rights Offering, we fully repaid the Second Lien Term Loan Facility on May 4, 2018, plus accrued interest of $2.3 million. A loss on extinguishment of this debt of approximately $49.2 million was recognized in the second quarter of 2018 as a result of the remaining $32.5 million unamortized debt discount on the date of the repayment, $16.2 million of make-whole interest, and $0.5 million of fees associated with the extinguishment.
Long-Term Benefit Obligations
Our unfunded pension and postretirement benefit obligations totaled $258.8$282.2 million at December 31, 2017.2018. For the year ended December 31, 2017,2018, we made required contributions to our pension plans totaling $17.3$20.1 million and to our postretirement plans of $1.2$1.3 million. In 2018,2019, we expect to make $21$6 million to $23$22 million of contributions to our benefit plans. We have applied for relief in the U.S. through pension contribution waivers that were filed with the IRS in January 2019, which would defer minimum pension contributions for approximately one year to then be repaid over a five-year period. If the temporary hardship waivers are not fully granted, required contributions could approach the high end of this range. See additional information on our long-term benefit obligations in Note 18 to our consolidated financial statementsConsolidated Financial Statements included in Item 8 of this annual report.
Contractual obligationsObligations
Our cash requirements as of December 31, 20172018 under current contractual obligations were as follows:
| | | (in thousands) | Total | Less than 1 Year | 1-3 Years | 3-5 Years | After 5 Years | 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 |
| $ | 19,381 |
| $ | 6,748 |
| $ | 8,580 |
| $ | 3,261 |
| $ | 792 |
|
| United States revolving credit facility | $ | 94,300 |
| $ | — |
| $ | 94,300 |
| $ | — |
| $ | — |
| |
| Second lien notes facility | $ | 195,884 |
| $ | — |
| $ | 195,884 |
| $ | — |
| $ | — |
| |
United States revolving credit facility (1) | | $ | 144,900 |
| $ | 144,900 |
| $ | — |
| $ | — |
| $ | — |
|
Last Out Term Loan (1)(2) | | $ | 42,675 |
| $ | 42,675 |
| $ | — |
| $ | — |
| $ | — |
|
Foreign revolving credit facility | $ | 9,173 |
| $ | 9,173 |
| $ | — |
| $ | — |
| $ | — |
| $ | 606 |
| $ | 606 |
| $ | — |
| $ | — |
| $ | — |
|
| ARPA litigation settlement | $ | 7,000 |
| $ | 2,500 |
| $ | 4,500 |
| $ | — |
| $ | — |
| $ | 4,500 |
| $ | 2,500 |
| $ | 2,000 |
| $ | — |
| $ | — |
|
| |
(1) | The maturity date of the U.S. Revolving Credit Facility and the Last Out Term Loans are in 2020. However, as of December 31, 2018, the U.S. Revolving Credit Facility and the Last Out Term Loan amounts are presented as a current liability in our Consolidated Balance Sheets as a result of the limited waivers that extend through April 5, 2019. |
| |
(2) | Based on initial principle of $30,000, $5,000 of fees, and payment-in-kind interest totaling $7,675 interest over the scheduled term of the loan with an effective interest rate of 25.65%. |
| |
(3) | As of January 4, 2019, the foreign revolving credit facilities were paid in full and closed. |
In September 2018, we announced that we would consolidate most of our Barberton and Copley, Ohio operations into new, leased office space in Akron, Ohio in approximately the third quarter of 2019. As of December 31, 2018, the operating lease agreement for the office space in Akron had not yet commenced; it will commence when it is ready for occupation. The lease has an initial term of fifteen years, with an option to extend up to two additional ten year terms. Base rent will increase two percent annually, making the total future minimum payments during the initial term of the lease approximately $55 million. This amount is not included in the table above.
The table above also 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, 20172018 expire as follows (in thousands):
| | | Total | Less than 1 Year | 1-3 Years | 3-5 Years | Thereafter | Less than 1 Year | 1-3 Years | 3-5 Years | Thereafter |
| $779,082 | $368,357 | $374,566 | $35,072 | $1,088 | |
| $556,029 | | $317,893 | $169,250 | $68,033 | $853 |
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 arrangementsOff-Balance Sheet Arrangements
There were no significant off-balance sheet arrangements at December 31, 2017.2018.
EFFECTS OF INFLATION AND CHANGING PRICES
Our consolidated financial statementsConsolidated 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.
CRITICAL ACCOUNTING POLICIES AND ESTIMATES
The consolidated financial statementsConsolidated Financial Statements included in Item 8 to this annual report 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
On January 1, 2018, we adopted ASC Topic 606 "Revenue from Contracts with Customers" using the modified retrospective method applied to all contracts that were not completed as of January 1, 2018. Results for reporting periods beginning on or after January 1, 2018 are presented under Topic 606, while prior period amounts are not adjusted and continue to be reported under the accounting standards in effect for the prior period. We determinerecorded a $0.5 million net increase to opening retained earnings as of January 1, 2018 from the appropriate accounting methodcumulative effect of adopting Topic 606 that primarily related to transitioning the timing of certain sales commissions expense. The effect on revenue from adopting Topic 606 was not material for eachthe year ended December 31, 2018.
A significant portion of our long-term contracts before work begins. We generally recognize contract revenues and related costs on a percentage-of-completion ("POC")revenue is recognized over time using the cost-to-cost input method, for individual contracts or combinationswhich involves significant estimates. This method 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 onrevenue recognition uses costs incurred to date as a percentage ofrelative to total estimated costs.costs at completion to measure progress toward satisfying our performance obligations. Incurred cost represents work performed, which corresponds with, and thereby best depicts, the transfer of control to the customer. Contract costs include labor, material, overhead, warranty and, when appropriate, SG&A expenses. Variable consideration in these contracts includes estimates of liquidated damages, contractual bonuses and penalties, and contract modifications.
We review contract price and cost estimates each reporting period as the work progresses and reflect adjustments proportionate to the costs incurred to date relative to total estimated costs at completion in income in the period when those estimates are revised. These changes in estimates can be material. 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 when determined. Itthrough the statement of operations and an accrual for the estimated loss on the uncompleted contract is possible thatincluded in other 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 reflectedliabilities in the quarterlyConsolidated Balance Sheets. In addition, when we determine that an uncompleted contract will not be completed on-time and annual earnings we report. For parts orders and certain aftermarket services activities,the contract has liquidated damages provisions, we recognize revenuesthe estimated liquidated damages we will incur and record them as goodsa reduction of the estimated selling price in the period the change in estimate occurs. This includes the effect of the settlement of the customer's rejection and termination rights on the fifth European Vølund loss contract described in Note 7 to the Consolidated Financial Statements included in Item 8. Losses accrued in advance of the completion of a contract are delivered and work is performed.included in other accrued liabilities, a current liability, in our Consolidated Balance Sheets.
InContract modifications are routine in the years ended December 31, 2017, 2016 and 2015, we recognized netperformance of our contracts. Contracts are often modified to account for changes in estimates related to long-term contractsthe contract specifications or requirements. In most instances, contract modifications are for goods or services that are not distinct and, therefore, are accounted for onas part of 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 costsexisting contract, with cumulative adjustment 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.revenue.
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 we have an enforceable right to the following accountingmodification or claim and the amount can be estimated reliably, and its realization is probable. In evaluating these 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. |
we consider the contractual/legal basis for enforcing the claim, the cause of any additional costs incurred and whether those costs are identifiable or otherwise determinable, the nature and reasonableness of those costs, the objective evidence available to support the amount of the claim, and our relevant history with the counter-party that supports our expectations about their willingness and ability to pay for the additional cost along with a reasonable margin. In our consolidated balance sheets, we had noConsolidated Balance Sheets, accrued claims receivable at December 31, 20172018 and at December 31, 2016.2017 were not significant.
Business combinationsOur revenue recognition policies, assumptions, changes in estimates and significant loss contracts are described in greater detail in Note 2 in the Consolidated Financial Statements included in Item 8 to this annual report.
We account for acquisitions in accordance with Financial Accounting Standards Board ("FASB") Topic WarrantyBusiness 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
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 foraccrue estimated expense included in cost of operations on our Consolidated Statements of Operations to satisfy contractual warranty requirements when we recognize the acquisitions of SPIG and Universal using the acquisition method. All of the assets acquired and liabilities assumed were recognized at their fair valueassociated revenues on the acquisition date. Any excessrelated 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 the purchase price over the estimated fair valueswarranty costs include prior history of the net assets acquired was recorded as goodwill. Acquisition-relatedwarranty claims and our estimates of future costs were recorded as selling, generalof materials and administrative expenses inlabor. Such changes could have a material effect on our consolidated financial statements.condition, results of operations and cash flows. Warranty expense in the year ended December 31, 2018 includes a $14.2 million increase in expected warranty costs for the six European Vølund loss contracts based on experience from the startup and commissioning activities in the second quarter of 2018 and $4.3 million of specific provisions on certain contracts in the Babcock & Wilcox segment for specific technical matters and customer requirements.
Pension and other postretirement benefit plans
We utilizeuse actuarial and other assumptions in calculating the cost and benefit obligations of our pension and postretirement benefits. TheThese 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. Theretirement rates. These 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.assets. 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 marketMTM adjustment. This new method was adopted because it more accurately applies each year’syear'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, 2017:2018:
| | | (In millions) | 0.25% increase | | 0.25% decrease | 0.25% increase | | 0.25% decrease |
Discount rate: | | | | | | |
Effect on ongoing net periodic benefit cost(1) | $ | (31.1 | ) | | $ | 32.4 |
| $ | (26.2 | ) | | $ | 27.4 |
|
| Effect on projected benefit obligation | (32.7 | ) | | 34.2 |
| (28.7 | ) | | 30.1 |
|
| Return on assets: |
| |
| | | |
| Effect on ongoing net periodic benefit cost | $ | (2.2 | ) | | $ | 2.2 |
| $ | (2.4 | ) | | $ | 2.4 |
|
(1) Excludes effect of annual MTM adjustment.
A 25 basis point change in the assumed discount rate and 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, 20172018 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 2123 to the consolidated financial statementsConsolidated Financial Statements included in Item 8 to this annual report for a discussion of this litigation. As
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 impairment
As of December 31, 2018, we had $38.2 million and long-lived asset impairment$8.9 million of goodwill remaining in our Babcock & Wilcox and Construction reporting units, respectively, both of which are within the Babcock & Wilcox segment. Impairments in 2018 and 2017 fully impaired goodwill in our SPIG reporting unit and our Vølund & Other Renewable reporting unit.
Each year as of October 1, 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 compareswe compare 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 withinBeginning April 1, 2018, we adopted ASU 2017-04, Intangibles - Goodwill and Other (Topic 350): Simplifying the first step of ourTest for Goodwill Impairment. Goodwill impairment test could cause a reduction or elimination of excess fair value over carrying value, resulting in potential recognition of impairment. Iftests after April 1, 2018 recognize impairment for the amount that the carrying amountvalue of a reporting unit exceeds its fair value up to the remaining amount of goodwill. Interim impairment testing as of June 30, 2018 was performed for the SPIG reporting unit due to lower bookings in the second stepquarter of 2018 than previously forecasted, which resulted in a reduction in the forecast for the reporting unit. As a result of the goodwill impairment test, iswe recognized a $37.5 million impairment of goodwill in the SPIG reporting unit at June 30, 2018. After the impairment, the SPIG reporting unit did not have any remaining goodwill. Impairment testing was also performed as of October 1, 2018 (annual impairment test) and December 31, 2018 (interim impairment test due to the decline in our market capitalization) for the remaining goodwill in the Babcock & Wilcox and Construction reporting units. No impairment was indicated. Because the Babcock & Wilcox reporting unit had a negative carrying value, reasonable changes in the assumptions would not indicate impairment. Reasonable changes in assumptions for our Construction reporting unit also would not indicate impairment because of the 118% and 98% headroom indicated by the tests at October 1, 2018 and December 31, 2018, respectively.
In impairment tests prior to April 1, 2018, if the carrying amount of a reporting unit exceeded its fair value, a second step was performed to measure the amount of the impairment loss, if any. The second step comparescompared the implied fair value of the reporting unit's goodwill with the carrying amount of that goodwill.
Our annual Calculating the implied fair value of the reporting unit's 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 estimateinvolved estimating the fair value of the SPIGidentifiable assets and liabilities of the reporting unitunit. In 2017, we recorded $50.0 million of impairment charges in the income valuation approach could resultVølund & Other Renewable segment due to significant charges incurred that attributed to a significant decline in anour market capitalization. Also, in 2017, our SPIG segment recorded a $36.9 million impairment assuming no significant changecharge due to a short-term decrease in theprofitability attributable to specific, then-current contracts and changes in SPIG's market strategy.
our impairment tests is included in Note 14 to the Consolidated Financial Statements included in Item 8 of this annual report.
forecasted cash flows. Additionally, a decline in SPIG's forecasted cash flows would result in anLong-lived asset 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.
We evaluate our long-lived assets whenever circumstances indicate impairment could exist. SPIG's financial results and goodwill impairments triggered evaluations of long-lived assets, including the identifiable intangible assets, in the SPIG asset group as of December 31, 2018, June 30, 2018 and September 30, 2017. The SPIG reporting unit was determined to be the asset group with the lowest level of identifiable cash flows for purposes of our impairment evaluation, other than described below. In periods when goodwill remained on that reporting unit, we tested the SPIG asset group for impairment in accordance with ASC 360-10 before testing goodwill for impairment at the SPIG reporting unit in accordance with ASC 350-20. The first step of the ASC 360 impairment test is to compare the carrying value of the asset group to the sum of the undiscounted cash flows attributable to the asset group and the residual values of the assets at the end of the life of the primary assets. In our tests as of December 31, 2018, June 30, 2018 and September 30, 2017, the sum of the undiscounted
cash flows and the residual value of the primary assets exceeded the carrying value of the SPIG asset group and no impairment was indicated. In each of these tests, reasonable changes in the assumptions used to develop the future cash flow would not have indicated impairment. In the fourth quarter of 2018, a strategic decision was made to exit certain geographies of the SPIG segment, and as a result, $2.5 million of the customer relationship and other intangible assets related to these geographies were impaired. SPIG did not have significant property, plant and equipment in these geographies.
In September 2018, we relocated our corporate headquarters to Barberton, Ohio from Charlotte, North Carolina. At the same time, we announced that we would consolidate most of our Barberton and Copley, Ohio operations into new, leased office space in Akron, Ohio in the third quarter of 2019. The new location in Akron is expected to reduce operating costs, net of rent, and to provide a space that better meets our needs. We do not expect to incur significant relocation costs; however, we expect $7.0 million of accelerated depreciation to be recognized through mid-2019, of which $2.9 million was recognized in the year ended December 31, 2018.
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’sout one coal-fired power plant located in Ebensburg, Pennsylvania.Pennsylvania, which was subsequently sold in 2017. 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 isare calculated on pre-tax income based on currentthe 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.Weliabilities. 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. ShouldIn determining the need for a valuation allowance, the historical and projected financial performance of the entity recording the net deferred tax asset is considered along with all other relevant positive and negative evidence. As of December 31, 2018, we conclude in the future that any or all ofhave recorded a valuation allowance on our net deferred tax assets arein the U.S., as we do not believe it is more likely than not tothat a portion of our U.S. deferred tax assets will be realized, we would establish additional valuation allowances and any changes to our estimated valuation allowance could be material to our consolidated financial statements. realized.
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 theour 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 inon our consolidated statementsConsolidated Statements of operations.Operations.
On December 22, 2017, the Tax Cuts and Jobs ActAs a result of 2017 (the “Tax Act”) was signed into law making significant changes to the United States Federal Internal Revenue Code. Changes include: (1) reductionaccumulations 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;Company's common stock among several large shareholders 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,2018 Rights Offering that was completed on April 30, 2018, we continue to monitor for the possibility of an ownership change as defined under Internal Revenue Code ("IRC") Section 382. Under IRC Section 382, a company has undergone an ownership change if shareholders owning at least 5% of the Company have recordedincreased their collective holdings by more than 50% during the prior three-year period. Based on information that is publicly available, the Company does not currently believe it has experienced an increaseownership change. Small changes in tax expenseownership by shareholders owning at least 5% of the Company could result in an ownership change. The terms of the period endingfinancing under active discussion on April 2, 2019, the date of this annual report, as described in Note 1 to the Consolidated Financial Statements included in Item 8 would likely result in an "ownership change" under IRC Section 382 if completed as described. If we had experienced an "ownership change" as of December 31, 2017; however, we have not completed2018, the future utilization of our accounting forfederal net operating loss and credit carryforwards would be limited to approximately $1.7 million annually, but quantification is dependent upon the income tax effects of certain elementsvalue of the Tax Act. If we were able to make reasonable estimatesCompany multiplied by the long-term tax-exempt rate at the time 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,ownership change.
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 changehave not changed materially from those disclosed here 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, 2017,2018, its principal balance was $94.3 million.$144.9 million, and the weighted average interest rate was 7.82%. Our Last Out Term Loans are also variable-rate debt and it has a paid-in-kind interest feature which is additive to the principal balance. The variable interest rate plus the paid-in-kind interest feature are primarily determined by liquidity risk, and that market interest rates risk is not believed to be a significant indication of fair value of the Last Out Term Loans. On December 31, 2018, the principal balance of Tranche A-1 of the Last Out Term Loans was $35.2 million inclusive of original issue discount costs, transaction expenses, and paid-in-kind interest, and the weighted average interest rate was 25.38%. If the balances of the United States revolving credit facility and the Last Out Term Loans at December 31, 2018 were to remain constant, a 100 basis points change in market interest rates would impact our cash flow by an estimated $1.8 million per year.
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. Foreign currency transaction gains and losses on intercompany loans that are not designated as permanent loans are recorded in earnings. Our primary foreign currency exposures are Danish kroner,krone, 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.
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, 20172018 and 2016,2017, the related consolidated and combined statements of operations, comprehensive income (loss), stockholders' (deficit) equity, and cash flows, for each of the three years in the period ended December 31, 2017,2018, and the related notes and the schedule listed in the Index at Item 15 (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, 20172018 and 2016,2017, and the results of its operations and its cash flows for each of the three years in the period ended December 31, 2017,2018, in conformity with accounting principles generally accepted in the United States.States of America.
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, 2017,2018, 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,April 2, 2019 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 that 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 thesecertain matters are also described in Note 1. These mattersexist which 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 CarolinaCleveland, Ohio
March 1, 2018April 2, 2019
We have served as the Company’s auditor since 2014.
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.
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.
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.
BABCOCK & WILCOX ENTERPRISES, INC.
CONSOLIDATED AND COMBINED STATEMENTSTATEMENTS OF STOCKHOLDERS' EQUITYOPERATIONS
|
| | | | | | | | | | | | | | | | | | | | | | | | | | |
| | 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 |
|
|
| | | | | | | | | |
| | Year Ended December 31, |
| (in thousands, except per share amounts) | 2018 | 2017 | 2016 |
| Revenues | $ | 1,062,388 |
| $ | 1,341,429 |
| $ | 1,420,941 |
|
| Costs and expenses: | | | |
| Cost of operations | 1,192,032 |
| 1,317,211 |
| 1,282,675 |
|
| Selling, general and administrative expenses | 223,331 |
| 221,145 |
| 217,084 |
|
| Goodwill and other intangible asset impairment | 40,046 |
| 86,903 |
| — |
|
| Restructuring activities and spin-off transaction costs | 16,758 |
| 15,039 |
| 38,813 |
|
| Research and development costs | 3,780 |
| 7,614 |
| 8,849 |
|
| Loss (gain) on asset disposals, net | 1,438 |
| 13 |
| (25 | ) |
| Total costs and expenses | 1,477,385 |
| 1,647,925 |
| 1,547,396 |
|
| Equity in income and impairment of investees | (11,603 | ) | (9,867 | ) | 16,440 |
|
| Operating loss | (426,600 | ) | (316,363 | ) | (110,015 | ) |
| Other income (expense): | | | |
| Interest income | 244 |
| 507 |
| 802 |
|
| Interest expense | (49,613 | ) | (25,933 | ) | (3,702 | ) |
| Gain on sale of business | 39,815 |
| — |
| — |
|
| Loss on debt extinguishment | (49,241 | ) | — |
| — |
|
| Benefit plans, net | (42,123 | ) | 29,688 |
| (4,152 | ) |
| Foreign exchange | (28,542 | ) | (4,751 | ) | (1,944 | ) |
| Other – net | 259 |
| (698 | ) | (616 | ) |
| Total other income (expense) | (129,201 | ) | (1,187 | ) | (9,612 | ) |
| Loss before income tax expense | (555,801 | ) | (317,550 | ) | (119,627 | ) |
| Income tax expense | 102,224 |
| 63,709 |
| 2,706 |
|
| Loss from continuing operations | (658,025 | ) | (381,259 | ) | (122,333 | ) |
| (Loss) income from discontinued operations, net of tax | (66,832 | ) | 2,244 |
| 7,251 |
|
| Net loss | (724,857 | ) | (379,015 | ) | (115,082 | ) |
| Net income attributable to noncontrolling interest | (435 | ) | (809 | ) | (567 | ) |
| Net loss attributable to stockholders | $ | (725,292 | ) | $ | (379,824 | ) | $ | (115,649 | ) |
| | | | |
| Basic and diluted loss per share - continuing operations | $ | (5.18 | ) | $ | (8.14 | ) | $ | (2.45 | ) |
| Basic and diluted (loss) earnings per share - discontinued operations | (0.52 | ) | 0.05 |
| 0.14 |
|
| Basic and diluted loss per share | $ | (5.70 | ) | $ | (8.09 | ) | $ | (2.31 | ) |
|
|
|
|
| |
| Shares used in the computation of earnings per share: | | | |
| Basic and diluted | 127,158 |
| 46,935 |
| 50,129 |
|
See accompanying notes to consolidated financial statements.Consolidated Financial Statements.
BABCOCK & WILCOX ENTERPRISES, INC.
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) |
| | | | | | | | | |
| | Year Ended December 31, |
| (in thousands) | 2018 | 2017 | 2016 |
| Net loss | $ | (724,857 | ) | $ | (379,015 | ) | $ | (115,082 | ) |
| Other comprehensive income: | | | |
| Currency translation adjustments (CTA), net of taxes | 16,452 |
| 16,150 |
| (24,494 | ) |
| | | | |
| Reclassification of CTA to net loss | 551 |
| — |
| — |
|
| | | | |
| Derivative financial instruments: | | | |
| Unrealized losses on derivative financial instruments | 1,074 |
| 3,346 |
| 2,208 |
|
| Income tax benefit | 184 |
| 142 |
| 162 |
|
| Unrealized losses on derivative financial instruments, net of taxes | 890 |
| 3,204 |
| 2,046 |
|
| Derivative financial instrument gains reclassified into net income | (1,623 | ) | (2,503 | ) | (3,598 | ) |
| Income tax expense | (358 | ) | (234 | ) | (568 | ) |
| Reclassification adjustment for gains included in net loss, net of taxes | (1,265 | ) | (2,269 | ) | (3,030 | ) |
| | | | |
| Benefit obligations: | | | |
| Unrealized (losses) gains on benefit obligations, net of taxes | (22 | ) | (152 | ) | 7,692 |
|
| | | | |
| Amortization of benefit plan benefits | (3,941 | ) | (2,912 | ) | (254 | ) |
| Income tax benefit (expense) | 1,630 |
| 43 |
| (404 | ) |
| Amortization of benefit plan (benefits) costs, net of taxes | (5,571 | ) | (2,955 | ) | 150 |
|
| | | | |
| Other | (38 | ) | 75 |
| 7 |
|
| | | | |
| Other comprehensive income (loss) | 10,997 |
| 14,053 |
| (17,629 | ) |
| Total comprehensive loss | (713,860 | ) | (364,962 | ) | (132,711 | ) |
| Comprehensive income attributable to noncontrolling interest | (229 | ) | (778 | ) | (575 | ) |
| Comprehensive loss attributable to stockholders | $ | (714,089 | ) | $ | (365,740 | ) | $ | (133,286 | ) |
See accompanying notes to Consolidated Financial Statements.
BABCOCK & WILCOX ENTERPRISES, INC.
CONSOLIDATED BALANCE SHEETS |
| | | | | | |
| | Year Ended December 31, |
| (in thousands, except per share amount) | 2018 | 2017 |
| Cash and cash equivalents | $ | 43,214 |
| $ | 43,717 |
|
| Restricted cash and cash equivalents | 17,065 |
| 25,980 |
|
| Accounts receivable – trade, net | 197,203 |
| 252,508 |
|
| Accounts receivable – other | 44,662 |
| 78,813 |
|
| Contracts in progress | 144,727 |
| 135,811 |
|
| Inventories | 61,323 |
| 72,917 |
|
| Other current assets | 41,425 |
| 34,039 |
|
| Current assets of discontinued operations | — |
| 88,472 |
|
| Total current assets | 549,619 |
| 732,257 |
|
| Net property, plant and equipment | 90,892 |
| 114,707 |
|
| Goodwill | 47,108 |
| 85,678 |
|
| Deferred income taxes | — |
| 97,467 |
|
| Investments in unconsolidated affiliates | — |
| 43,278 |
|
| Intangible assets | 30,793 |
| 42,065 |
|
| Other assets | 27,085 |
| 25,741 |
|
| Noncurrent assets of discontinued operations | — |
| 181,036 |
|
| Total assets | $ | 745,497 |
| $ | 1,322,229 |
|
| | | |
| Foreign revolving credit facilities | $ | 606 |
| $ | 9,173 |
|
| U.S. revolving credit facility | 144,900 |
| — |
|
| Last out term loan | 30,649 |
| — |
|
| Second lien term loan facility | — |
| 160,141 |
|
| Accounts payable | 199,882 |
| 205,396 |
|
| Accrued employee benefits | 19,319 |
| 27,058 |
|
| Advance billings on contracts | 149,367 |
| 171,997 |
|
| Accrued warranty expense | 45,117 |
| 33,514 |
|
| Other accrued liabilities | 122,149 |
| 89,549 |
|
| Current liabilities of discontinued operations | — |
| 47,499 |
|
| Total current liabilities | 711,989 |
| 744,327 |
|
| U.S. revolving credit facility | — |
| 94,300 |
|
| Pension and other accumulated postretirement benefit liabilities | 281,647 |
| 250,002 |
|
| Other noncurrent liabilities | 29,158 |
| 29,897 |
|
| Noncurrent liabilities of discontinued operations | — |
| 13,000 |
|
| Total liabilities | 1,022,794 |
| 1,131,526 |
|
| Commitments and contingencies |
|
|
| Stockholders' (deficit) equity: | | |
| Common stock, par value $0.01 per share, authorized 200,000 shares; issued and outstanding 168,791 and 44,065 shares at December 31, 2018 and December 31, 2017, respectively | 1,748 |
| 499 |
|
| Capital in excess of par value | 1,047,062 |
| 800,968 |
|
| Treasury stock at cost, 5,872 and 5,681 shares at December 31, 2018 and December 31, 2017, respectively | (105,590 | ) | (104,785 | ) |
| Accumulated deficit | (1,217,914 | ) | (492,150 | ) |
| Accumulated other comprehensive loss | (11,432 | ) | (22,429 | ) |
| Stockholders' (deficit) equity attributable to shareholders | (286,126 | ) | 182,103 |
|
| Noncontrolling interest | 8,829 |
| 8,600 |
|
| Total stockholders' (deficit) equity | (277,297 | ) | 190,703 |
|
| Total liabilities and stockholders' (deficit) equity | $ | 745,497 |
| $ | 1,322,229 |
|
See accompanying notes to Consolidated Financial Statements.
BABCOCK & WILCOX ENTERPRISES, INC.
CONSOLIDATED AND COMBINEDSTATEMENT OF STOCKHOLDERS' (DEFICIT) EQUITY
|
| | | | | | | | | | | | | | | | | | | | | | | |
| | Common Stock | Capital In
Excess of
Par Value | Treasury Stock | Accumulated Deficit | Accumulated
Other
Comprehensive
Income (Loss) | Noncontrolling
Interest | Total
Stockholders’
(Deficit) Equity |
| |
| | Shares | Par Value |
| | | (in thousands, except share and per share amounts) |
| December 31, 2015 Balance | 52,481 |
| $ | 540 |
| $ | 790,464 |
| $ | (25,408 | ) | $ | 965 |
| $ | (18,853 | ) | $ | 719 |
| $ | 748,427 |
|
| Net loss | — |
| — |
| — |
| — |
| (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 loss | — |
| $ | — |
| $ | — |
| $ | — |
| $ | (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 |
|
| | | | | | | | | |
| Net loss | — |
| — |
| — |
| — |
| (725,292 | ) | — |
| 435 |
| $ | (724,857 | ) |
| Revenue recognition standard adoption | — |
| — |
| — |
| — |
| (472 | ) | — |
| — |
| (472 | ) |
| Currency translation adjustments | — |
| — |
| — |
| — |
| — |
| 17,003 |
| (206 | ) | 16,797 |
|
| Derivative financial instruments | — |
| — |
| — |
| — |
| — |
| (375 | ) | — |
| (375 | ) |
| Defined benefit obligations | — |
| — |
| — |
| — |
| — |
| (5,593 | ) | — |
| (5,593 | ) |
| Available-for-sale investments | — |
| — |
| — |
| — |
| — |
| (38 | ) | — |
| (38 | ) |
| Rights offering, net | 124,256 |
| 1,243 |
| 243,846 |
| — |
| — |
| — |
| — |
| 245,089 |
|
| Stock-based compensation charges | 470 |
| 6 |
| 2,248 |
| (805 | ) | — |
| — |
| — |
| 1,449 |
|
| December 31, 2018 Balance | 168,791 |
| $ | 1,748 |
| $ | 1,047,062 |
| $ | (105,590 | ) | $ | (1,217,914 | ) | $ | (11,432 | ) | $ | 8,829 |
| $ | (277,297 | ) |
See accompanying notes to Consolidated Financial Statements.
BABCOCK & WILCOX ENTERPRISES, INC.
CONSOLIDATED STATEMENTS OF CASH FLOWS
| | | | Year Ended December 31, | | Year Ended December 31, |
| (in thousands) | 2017 | 2016 | 2015 | | 2018 | 2017 | 2016 |
| Cash flows from operating activities: | | | | | |
| Net income (loss) | $ | (379,015 | ) | $ | (115,082 | ) | $ | 19,337 |
| |
| Non-cash items included in net income (loss): | | |
| Net loss | | | $ | (724,857 | ) | $ | (379,015 | ) | $ | (115,082 | ) |
| Adjustments to reconcile net loss to net cash provided by (used in) operating activities: | | | |
| Depreciation and amortization of long-lived assets | 40,138 |
| 39,583 |
| 34,932 |
| | 32,003 |
| 40,138 |
| 39,583 |
|
| 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 |
| — |
| — |
| |
| Amortization of deferred financing costs, debt discount and payment-in-kind interest | | | 25,727 |
| 6,407 |
| 1,244 |
|
| Gain on sale of business, net | | | (33,919 | ) | (1,064 | ) | — |
|
| Loss on debt extinguishment | | | 49,241 |
| — |
| — |
|
| Goodwill impairment of discontinued operations | | | 72,309 |
| — |
| — |
|
| Goodwill and other intangible asset impairment | | | 40,046 |
| 86,903 |
| — |
|
| Income from equity method investees | | | (6,758 | ) | (8,326 | ) | (16,440 | ) |
| Other-than-temporary impairment of equity method investment in TBWES | | | 18,362 |
| 18,193 |
| — |
|
| Losses on asset disposals and impairments | 807 |
| 14,938 |
| 16,881 |
| | 1,313 |
| 1,871 |
| 14,938 |
|
| Write-off of accrued claims receivable, net | — |
| — |
| 7,832 |
| |
| Provision for (benefit from) deferred income taxes | 50,304 |
| (9,000 | ) | (32,121 | ) | |
| Provision for (benefit from) deferred income taxes, including valuation allowances | | | 98,060 |
| 50,304 |
| (9,000 | ) |
| Mark to market losses (gains) and prior service cost amortization for pension and postretirement plans | (11,608 | ) | 36,346 |
| 40,611 |
| | 63,511 |
| (11,608 | ) | 36,346 |
|
| Stock-based compensation, net of associated income taxes | 11,813 |
| 16,129 |
| 7,773 |
| | 2,254 |
| 11,813 |
| 16,129 |
|
| Changes in assets and liabilities, net of effects of acquisitions: | | |
| Changes in assets and liabilities: | | | |
| Accounts receivable | 9,414 |
| 46,755 |
| (54,807 | ) | | 80,376 |
| 9,414 |
| 46,755 |
|
| Dividends from equity method investees | 50,134 |
| 12,160 |
| 20,830 |
| | 890 |
| 50,134 |
| 12,160 |
|
| Accrued insurance receivable | — |
| (15,000 | ) | — |
| | 12,300 |
| — |
| (15,000 | ) |
| Contracts in progress and advance billings on contracts | (24,001 | ) | (13,259 | ) | 62,971 |
| | (28,644 | ) | (24,001 | ) | (13,259 | ) |
| Inventories | 11,874 |
| 2,869 |
| 6,060 |
| | 10,337 |
| 11,874 |
| 2,869 |
|
| Income taxes | 26,618 |
| 22,593 |
| 9,275 |
| | (5,342 | ) | 26,618 |
| 22,593 |
|
| Accounts payable | (14,664 | ) | 4,542 |
| 17,863 |
| | (4,360 | ) | (14,664 | ) | 4,542 |
|
| Accrued and other current liabilities | (12,450 | ) | 25,110 |
| 11,464 |
| | 38,734 |
| (30,049 | ) | 5,959 |
|
| Accrued contract losses | | | 21,531 |
| 17,599 |
| 19,151 |
|
| Pension liabilities, accrued postretirement benefits and employee benefits | (44,584 | ) | (46,973 | ) | (2,336 | ) | | (38,976 | ) | (44,584 | ) | (46,973 | ) |
| Other, net | (7,790 | ) | (4,242 | ) | 2,970 |
| | (6,023 | ) | (7,790 | ) | (4,242 | ) |
| Net cash from operating activities | (189,833 | ) | 2,273 |
| 170,399 |
| | (281,885 | ) | (189,833 | ) | 2,273 |
|
| 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 | ) | | (5,473 | ) | (14,278 | ) | (22,450 | ) |
| Acquisition of business, net of cash acquired | (52,547 | ) | (144,780 | ) | — |
| | — |
| (52,547 | ) | (144,780 | ) |
| Proceeds from sale of equity method investment in a joint venture | — |
| 17,995 |
| — |
| |
| Proceeds from sale of businesses, net of cash sold | | | 155,016 |
| — |
| — |
|
| Proceeds from sale of equity method investments in joint ventures | | | 28,764 |
| — |
| 17,995 |
|
| Investment in equity method investee | | | — |
| — |
| (26,256 | ) |
| Purchases of available-for-sale securities | (29,252 | ) | (45,217 | ) | (14,008 | ) | | (34,836 | ) | (29,252 | ) | (45,217 | ) |
| Sales and maturities of available-for-sale securities | 35,484 |
| 29,846 |
| 5,266 |
| | 35,220 |
| 31,435 |
| 29,846 |
|
| Other, net | 708 |
| 646 |
| (587 | ) | | 534 |
| 708 |
| 646 |
|
| Net cash from investing activities | $ | (62,144 | ) | $ | (180,842 | ) | $ | (45,852 | ) | | 179,225 |
| (63,934 | ) | (190,216 | ) |
| | | |
| | | |
| | | |
| | | |
| | | |
| | | |
| | | |
|
| | | | | | | | | | |
| | 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 |
|
|
| | | | | | | | | | |
| | | Year Ended December 31, |
| (in thousands) | | 2018 | 2017 | 2016 |
| Cash flows from financing activities: | | | | |
| Borrowings under our U.S. revolving credit facility | | 565,200 |
| 629,722 |
| 205,600 |
|
| Repayments of our U.S. revolving credit facility | | (514,600 | ) | (545,222 | ) | (195,800 | ) |
| Borrowings under our last out term loan from related party | | 30,000 |
| — |
| — |
|
| Proceeds from our second lien term loan facility, net of $34.2 million discount | | — |
| 161,674 |
| — |
|
| Repayments of our second lien term loan facility | | (212,590 | ) | — |
| — |
|
| Borrowings under our foreign revolving credit facilities | | — |
| 273 |
| 5,674 |
|
| Repayments of our foreign revolving credit facilities | | (7,322 | ) | (6,597 | ) | (20,248 | ) |
| Common stock repurchase from related party | | — |
| (16,674 | ) | — |
|
| Proceeds from rights offering | | 247,132 |
| — |
| — |
|
| Costs related to rights offering | | (3,286 | ) | — |
| — |
|
| Debt issuance costs | | (22,360 | ) | (15,002 | ) | — |
|
| Issuance of common stock | | 1,243 |
| — |
| — |
|
| Shares of our common stock returned to treasury stock | | (805 | ) | (967 | ) | (78,410 | ) |
| Other, net | | — |
| (1,082 | ) | (246 | ) |
| Net cash from financing activities | | 82,612 |
| 206,125 |
| (83,430 | ) |
| Effects of exchange rate changes on cash | | (2,320 | ) | 6,632 |
| (7,306 | ) |
| Net decrease in cash, cash equivalents and restricted cash | | (22,368 | ) | (41,010 | ) | (278,679 | ) |
| Less net increase (decrease) in cash and cash equivalents of discontinued operations | | (12,950 | ) | 4,489 |
| 8,461 |
|
| Net decrease in cash, cash equivalents and restricted cash of continuing operations | | (9,418 | ) | (45,499 | ) | (287,140 | ) |
| Cash, cash equivalents and restricted cash of continuing operations, beginning of period | | 69,697 |
| 115,196 |
| 402,336 |
|
| Cash, cash equivalents and restricted cash of continuing operations, end of period | | $ | 60,279 |
| $ | 69,697 |
| $ | 115,196 |
|
See accompanying notes to consolidated financial statements.Consolidated Financial Statements.
BABCOCK & WILCOX ENTERPRISES, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
DECEMBER 31, 20172018
NOTE 1 – BASIS OF PRESENTATION AND GOING CONCERN CONSIDERATIONS
BasisThe 2018, 2017 and 2016 Consolidated Financial Statements of presentation
Babcock & Wilcox Enterprises, Inc. ("B&W", "we", "us"&W," "we," "us," "our" or "our""the Company") 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 dollarsbeen prepared 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 statementsConsolidated Financial Statements on the basis of continuing operations, unless otherwise stated.
On June 8, 2015, BWC'sBWXT's board of directors approved the spin-off of B&W through the distribution of shares of B&W common stock to holders of BWCBWXT common stock (the "spin-off"). On June 30, 2015, B&W became a separate publicly-traded company, and BWCBWXT 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 considerationsConcern Considerations
The accompanying consolidated financial statementsConsolidated 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 statementsConsolidated 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.uncertainty.
AdditionalWe face liquidity challenges from losses we recognized on our six European Vølund loss contracts described 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 2017Note 7, which caused us to be out of compliance with certain financial covenants and resulted in events of default in the agreements governing certain of our lending arrangementsdebt at each of December 31, 2017.2017, March 31, 2018, June 30, 2018, September 30, 2018 and December 31, 2018. Our liquidity is provided under a credit agreement dated May 11, 2015, as amended, with a syndicate of lenders ("Amended Credit Agreement") that governs a revolving credit facility ("U.S. Revolving Credit Facility") and our last out term loan facility ("Last Out Term Loans"). The Amended Credit Agreement is described in more detail in Note 19 and Note 20. We obtained an amendmentwaivers to our United States Revolvingthe Amended Credit Facility on March 1, 2018Agreement that temporarily waived, prevented or resolved these defaults as described in Note 19 and Note 31. The most recent waiver extends through April 5, 2019.
To address our liquidity needs and the financial covenant defaults that existed at December 31, 2017. We face liquidity challenges related to our non-compliance withgoing concern uncertainty, we:
raised gross proceeds of $248.4 million on April 30, 2018 through the financial covenants associated with ourrights offering as described in Note 22 (the "2018 Rights Offering");
repaid on May 4, 2018 the Second Lien Term Loan Facility at Decemberdescribed in Note 21 that had been in default beginning March 1, 2018;
completed the sale of our MEGTEC and Universal businesses on October 5, 2018, for $130 million, subject to adjustment, resulting in receipt of $112.0 million in cash, net of $22.5 million in cash sold with the businesses, and $7.7 million that was deposited in escrow pending final settlement of working capital and other customary matters;
completed the sale of Palm Beach Resource Recovery Corporation ("PBRRC"), a subsidiary that held two operations and maintenance contracts for waste-to-energy facilities in West Palm Beach, Florida, on September 17, 2018 for $45 million subject to adjustment, resulting in receipt of $38.9 million in cash and $4.9 million, which was deposited in escrow pending final settlement of working capital and other customary matters;
sold our equity method investments in Babcock & Wilcox Beijing Company, Ltd. ("BWBC"), a joint venture in China, and Thermax Babcock & Wilcox Energy Solutions Private Limited ("TBWES"), a joint venture in India, and settled related contractual claims, resulting in proceeds of $21.1 million in the second quarter of 2018 and $15.0 million in the third quarter of 2018, respectively;
sold another non-core business for $5.1 million in the first quarter of 2018;
initiated restructuring actions and other additional cost reductions since the second quarter of 2018 that are designed to save approximately $84 million annually;
received $30 million in net proceeds from Tranche A-1 of Last Out Term Loans, described in Note 20, from B. Riley FBR, Inc., a related party, in September and October 2018 (Tranche A-1 was assigned to Vintage Capital Management LLC, another related party, on November 19, 2018);
received $10.0 million in net proceeds from Tranche A-2 of the Last Out Term Loans, described in Note 31, 2017, which may be difficult to resolve infrom B. Riley Financial, Inc., a timely manner. Our Second Lien Term Loan Agreement contains a 180-day standstill period beginningrelated party on March 1, 2018 to resolve the event of default or repay the loan as described in Note20, 2019;
20. Our financing plan includes raising additional capital through a rights offeringreduced uncertainty and other sources before the endprovided better visibility into our future liquidity requirements by turning over four of the standstill period, which will depend on conditionssix European Vølund loss contracts to the customers and negotiating settlement of the remaining two loss contracts in the capital marketsfirst quarter of 2019 as described in Note 7; and with respect
entered into several amendments and waivers to avoid default and improve our liquidity under 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 outsideterms of our control.Amended Credit Agreement as described in Note 31, the most recent of which extends through April 5, 2019, unless earlier terminated, and waives our compliance with a number of covenants and events of default under, the Amended Credit Agreement.
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 theManagement believes it is taking all prudent actions summarized above are more likely than not to address the substantial doubt about our ability to continue as a going concern, but we cannot assert that it is probable that our plans will fully mitigate the conditions identified. Ifliquidity challenges we cannotface. We are currently dependent upon the waivers granted in our most recent limited waiver to maintain our current compliance with the covenants in the Amended Credit Agreement, and since March 20, 2019, we have also been nearly fully drawn on the U.S. Revolving Credit Facility, such that only minimal additional amounts were available for borrowings or letters of credit.
Based on our forecasts, we will require additional amendments to or waivers under the Amended Credit Agreement and additional financing to fund working capital and the settlements of two of our six European Vølund loss contracts described in Note 7 prior to April 5, 2019 to continue as a going concern, material adjustmentsconcern. We are currently in active discussions with the lenders under the Amended Credit Agreement (including certain of our related parties) for additional financing, a waiver of our compliance with covenants in and events of default under the Amended Credit Agreement, a reduction of the minimum liquidity requirements that we must maintain, a reset of future financial covenant ratios and amendments to other covenant requirements in order to allow us to continue to operate as a going concern. Our current discussions have focused around the extension of additional Last Out Term Loans, primarily from related parties, in an amount necessary to fund the settlement of the European Vølund loss contracts and provide liquidity for our operations. In connection with these loans, we have also discussed seeking shareholder approval for a reverse stock split and various other matters that could result in substantial dilution to our shareholders not participating in this financing, such as a rights offering to repay a portion of these additional Last Out Term Loans, the exchange of a portion of our existing Last Out Term Loans for shares of common stock and the issuance of warrants with a de minimis strike price to lenders participating in these additional Last Out Term Loans or other parties. We also discussed whether, as part of any financing transaction, we would provide director nomination rights over some or even a substantial majority of our board of directors to two of the related parties involved in these financing efforts or whether we would add an event of default if we fail to refinance the U.S. Revolving Credit Facility within twelve months following the filing of this annual report. These discussions have not yet resulted, and may never result, in a binding commitment by our lenders. There can be no assurance that our lenders or any other person will commit to provide additional financing consistent with these discussions or at all. If we are able to obtain additional financing, it may be on terms substantially different from our current discussions described above, and may require additional or different commitments by us with regard to other actions we will or will not take. If we fail to obtain necessary financing on acceptable terms or otherwise obtain short-term capital and continuing waivers with approval from our existing lenders, we may be unable to continue operation as a going concern.
In addition to the carrying valuesdiscussions regarding additional financing described above, we continue to evaluate further dispositions, opportunities for additional cost savings and classificationsopportunities for insurance recoveries and other claims where appropriate and available.
NYSE Continued Listing Status
On November 27, 2018, we received written notification (the "NYSE Notice"), from the New York Stock Exchange (the "NYSE"), that we were not in compliance with an NYSE continued listing standard in Rule 802.01C of the NYSE Listed Company Manual because the average closing price of our assetscommon stock fell below $1.00 over a period of 30 consecutive trading days. We informed the NYSE that we currently intend to seek to cure the price condition by executing our strategic plan, which is expected to result in improved operational and liabilitiesfinancial performance that we expect will ultimately lead to a recovery of our common stock price. We can regain compliance with the minimum per share average closing price standard at any time during the six-month cure period if, on the last trading day of any calendar month during the cure period, we have (i) a closing share price of at least $1.00 and (ii) an average closing price of at least $1.00 over the 30 trading-day period ending on the last trading day of that month. We informed the NYSE that we are also prepared to consider a reverse stock split to cure the deficiency, should such action be necessary, subject to approval of our shareholders, at our next annual meeting. Our common stock could also be delisted if our average market capitalization over a consecutive 30 trading-day period is less than $15.0 million, in which case we would not have an opportunity to cure the deficiency, our common stock would be suspended from trading on the NYSE immediately, and the reported amounts of incomeNYSE would begin the process to delist our common
stock, subject to our right to appeal under NYSE rules. We cannot assure you that any appeal we undertake in these or other circumstances will be successful. While we are considering various options, it may take in a significant effort to cure this deficiency and expense couldregain compliance with this continued listing standard, and there can be required.no assurance that we will be able to cure this deficiency or if we will cease to comply with another NYSE continued listing standard.
NOTE 2– SIGNIFICANT ACCOUNTING POLICIES
Reportable segments
We operate in three reportable segments. Our reportable segments are as follows:
•
PowerBabcock & Wilcox segment: Focusedfocused on technologiesthe supply of and aftermarket services for steam-generating, environmental and auxiliary equipment for power generation and other industrial applications. This segment was formerly named the Power segment.
Vølund & Other Renewable segment: Focusedfocused on the supply of steam-generating systems, environmental and auxiliary equipment and operations and maintenance services for the waste-to-energy and biomass power generation industries. This segment was formerly named the Renewable segment.
IndustrialSPIG segment: Focusedfocused on the supply of custom-engineered cooling environmental, acoustic, emission and filtration solutions, other industrial equipment andsystems for steam applications along with related aftermarket services. SPIG was formerly part of the Industrial segment.
For financial information about our segments see Note 46 to our consolidated financial statements.Consolidated Financial Statements.
Use of estimates
We use estimates and assumptions to prepare our consolidated financial statementsConsolidated 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, a related party (see Note 20)21), 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 statementsConsolidated 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
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 relate to our wholly owned insurance subsidiary. Our investments, which are 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 sheetsConsolidated 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 statementsConsolidated Statements of operations.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 StatesU.S. 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)losses of $2.9$(28.5) million, $(5.4)$(4.8) million and $(0.1)$(1.9) million in the years ended December 31, 2018, 2017 and 2016, respectively, in foreign exchange in our Consolidated Statements of Operations. These foreign exchange net gains and 2015, respectively.losses are primarily related to transaction gains or losses from unhedged intercompany loans when the loan is denominated in a currency different than the participating entity's functional currency.
Contracts and revenueRevenue recognition
WeA performance obligation is a contractual promise to transfer a distinct good or service to the customer. A contract's transaction price is allocated to each distinct performance obligation and is recognized as revenue when (point in time) or as (over time) the performance obligation is satisfied.
Revenue from goods and services transferred to customers at a point in time, which includes certain aftermarket parts and services primarily in the Babcock & Wilcox and SPIG segments, accounted for 19%, 18% and 18% of our revenue for the years ended December 31, 2018, 2017 and 2016, respectively. Revenue on these contracts is recognized when the customer obtains control of the asset, which is generally recognize contract revenuesupon shipment or delivery and relatedacceptance by the customer. Standard commercial payment terms generally apply to these sales.
Revenue from products and services transferred to customers over time accounted for 81%, 82% and 82% of our revenue for the years ended December 31, 2018, 2017 and 2016, respectively. Revenue recognized over time primarily relates to customized, engineered solutions and construction services from all three of our segments. Typically, revenue is recognized over time using the cost-to-cost input method that uses costs on a percentage-of-completion method for individual contracts or combinations of contracts based onincurred to date relative to total estimated costs at completion to measure progress toward satisfying our performance obligations. Incurred cost represents work performed, man hours or a cost-to-cost method, as applicablewhich corresponds with, and thereby best depicts, the transfer of control to the product or activity involved. We recognize estimatedcustomer. Contract costs include labor, material, overhead and, when appropriate, SG&A expenses. Variable consideration in these contracts includes estimates of liquidated damages, contractual bonuses and penalties, and contract modifications. Substantially all of our revenue and resulting income based onrecognized over time under the measurementcost-to-cost input method contains a single performance obligation as the interdependent nature of the extent of progress completion as a percentagegoods and services provided prevents them from being separately identifiable within the contract. Generally, we try to structure contract milestones to mirror our expected cash outflows over the course of the total contract. We include revenuescontract; however, the timing of milestone receipts can greatly affect our overall cash position 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,have in our consolidated balance sheets based on the life cycle of the associated contracts. Most long-term contracts contain provisionsVølund & Other Renewable segment. Refer to Note 6 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 amountsour disaggregation 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.by product line.
As of December 31, 2017,2018, 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.using a cost-to-cost input method. 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
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.
Contract modifications are routine in the performance of our contracts. Contracts are often modified to account for changes in the contract specifications or requirements. In most instances, contract modifications are for goods or services that are not distinct and, therefore, are accounted for as part of the existing contract, with cumulative adjustment to revenue.
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 we have an enforceable right to the following accountingmodification or claim and the amount can be estimated reliably, and its realization is probable. In evaluating these criteria, have been met:we consider the contractual/legal basis for enforcing the claim, the cause of any additional costs incurred and whether those costs are identifiable or otherwise determinable, the nature and reasonableness of those costs, the objective evidence available to support the amount of the claim, and our relevant history
| |
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. |
with the counter-party that supports our expectations about their willingness and ability to pay for the additional cost along with a reasonable margin.
We generally recognize sales commissions in equal proportion as revenue is recognized. Our sales agreements are structured such that commissions are only payable upon receipt of payment, thus a capitalized asset at contract inception has not been recorded for sales commission as a liability has not been incurred at that point.
Contract Balances
Contracts in progress, a current asset in our Consolidated Balance Sheets, includes revenues and related costs so recorded, plus accumulated contract costs that exceed amounts invoiced to customers under the terms of the contracts. Advance billings, a current liability in our Consolidated Balance Sheets, includes advance billings on contracts invoices that exceed accumulated contract costs and revenues and costs recognized under the cost-to-cost input method. Those balances are classified as current 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 the collection of all amounts for unbilled revenues is deemed probable. We review contract price and cost estimates each reporting period as the work progresses and reflect adjustments proportionate to the costs incurred to date relative to total estimated costs at 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 through the statement of operations and an accrual for the estimated loss on the uncompleted contract is included in other current liabilities in the Consolidated Balance Sheets. 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. Losses accrued in advance of the completion of a contract are included in other accrued liabilities, a current liability, in our Consolidated Balance Sheets.
Warranty expense
We accrue estimated expense included in cost of operations on our consolidated statementsConsolidated Statements of operationsOperations 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 improving our products through innovations to reduce the developmentcost of our products to make them more competitive and improvementthrough innovations to reduce performance risk of newour products to better meet our and existing products, services and equipment. our customers' expectations.Research and development activities totaled $9.4$3.8 million, $10.4$7.6 million and $16.5$8.8 million in the years ended December 31, 2018, 2017 and 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 StatesU.S., Canadian and internationalU.K. 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 developingWe use an alternative spot rate method for discounting the discount rate frombenefit obligation rather than 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.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.
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.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 statementsConsolidated Statements of operations.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. We record cash and cash equivalents as restricted when we are unable to freely use such cash and cash equivalents for our general operating purposes.
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’smanagement'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.balances and any other known factors specific to a receivable. Accounts receivable are charged to the allowance when it is determined they are no longer collectible. Our allowance for doubtful accounts was $11.0$21.4 million and $9.4$11.6 million at December 31, 2018 and 2017, respectively. In the fourth quarter of 2018, we increased the allowance for doubtful accounts by $5.9 million for the Chinese operations of the Babcock & Wilcox segment. Additionally in the fourth quarter of 2018, SPIG increased its allowance for doubtful accounts by $9.3 million related to projects in the Middle East. Amounts charged to selling, general and 2016, respectively.administrative expenses were $15.5 million for the year ended December 31, 2018. 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 2015.2016.
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 PowerBabcock & Wilcox segment, for whichwhere we use the last-in, first-out ("LIFO") method. We determined the cost of approximately 16%22% and 18% of our total inventories using the LIFO method at December 31, 20172018 and 2016,2017, respectively, and our total LIFO reserve at December 31, 20172018 and 20162017 was approximately $7.0$7.6 million and $7.0 million, respectively. Our obsolete inventory reserve was $7.9 million and $6.3 million at December 31, 2018 and 2017, respectively. In the fourth quarter of 2018, we increased our inventory reserve by $1.4 million for the Chinese operations of the Babcock & Wilcox segment as a result of a strategic change in that business unit. The components of inventories can be found in Note 13.12.
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$21.8 million, $19.7$19.4 million and $23.5$18.7 million for the years ended December 31, 2018, 2017 2016 and 2015,2016, respectively. We expense the costs of maintenance, repairs and renewals that do not materially prolong the useful life of an asset as we incur them.
Property, plant and equipment 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.
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,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.
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.annually or when impairment indicators are present. 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 utilizeperform a two-step quantitative impairment test to identify potential goodwill impairment and measure the amount of any goodwill impairment. Beginning April 1, 2018, we adopted ASU 2017-04, Intangibles - Goodwill and Other (Topic 350): Simplifying the Test for Goodwill Impairment. Goodwill impairment tests after April 1, 2018 recognize impairment for the amount that the carrying value of a reporting unit exceeds its fair value up to the remaining amount of goodwill. Prior to April 1, 2018, we used a two-step impairment test. The first step of the test comparescompared the fair value of a reporting unit with its carrying amount, including goodwill. If the carrying amount of a reporting unit exceedsexceeded its fair value, the second step of the goodwill impairment test iswas performed to measure the amount of the impairment loss, if any. The second step comparescompared 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 quantitatively 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.testing at least annually or in interim periods when impairment indicators are present. 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 sheetsConsolidated 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 – netforeign exchange on our consolidated statementsConsolidated Statements of operations.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 – netforeign exchange in our consolidated statementsConsolidated Statements of operations.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 sheetsConsolidated Balance Sheets are reserves for self-insurance totaling $23.1$21.6 million and $24.1$23.1 million at the years ended December 31, 20172018 and 2016,2017, 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
litigation, as discussed in Note 21.23. 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, theThe 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 fairFair 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 fairFair 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, 20172018 and 20162017 that contain a Relative Total Shareholder Return vesting criteria and for stock appreciation rights, 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 or a Monte Carlo simulation 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, weWe recognize expense net of an estimated forfeiture rate, for all share-basedstock-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 requiresFor liability-classified awards, changes in fair value are recognized through cumulative catch-ups each period. Excess tax benefits on stock-based compensation expenseare 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 reportedpresented 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
DuringEffective January 1, 2018, we adopted ASU 2014-09, Revenue from Contracts with Customers using the yearmodified retrospective method applied to all contracts that were not completed as of January 1, 2018. The new accounting standard provides a comprehensive model to use in accounting for revenue from contracts with customers. 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. Results for reporting periods beginning on or after January 1, 2018 are presented under Topic 606, while prior period amounts are not adjusted and continue to be reported under the accounting standards in effect for the prior period. See Note 7 for additional accounting policy disclosures.
Effective January 1, 2018, we prospectively adopted ASU 2016-1, Financial Instruments-Overall: Recognition and Measurement of Financial Assets and Financial Liabilities, which resulted in an immaterial impact on our financial results. 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.
Effective January 1, 2018, we adopted ASU 2016-15, Statement of Cash Flows (Topic 230): Classification of Certain Cash Receipts and Cash Payments, which resulted in an immaterial impact on our financial results. 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 requires 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 did not change our historical statement of cash flows.
Effective January 1, 2018, we retrospectively adopted ASU 2016-18, Statement of Cash Flows (Topic 230): Restricted Cash. The new guidance requires the changes in the total of cash, cash equivalents and restricted cash to be shown together in the statement of cash flows and no longer presenting transfers between cash and cash equivalents and restricted cash in the statement of cash flows. Historically, we have presented the transfer of cash to restricted cash and cash equivalents in the investing section of the statement of cash flows. With the adoption of ASU 2016-18, changes in restricted cash are also included in statement of cash flows based on the nature of the change together with unrestricted cash flows. The only meaningful effect on our financial statements is related to the restricted cash received from the sale of BWBC as described in Note 13, which is reflected as investing cash flow. All other effects of adopting this new standard were immaterial. The detail of cash, cash equivalents, and restricted cash is included in Note 26.
Effective January 1, 2018, we retrospectively adopted 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. Upon adoption, this affected not only how we present net periodic benefit cost, but also Babcock & Wilcox segment gross profit. The changes in the classification of the historical components of net periodic benefit costs from operating expense to other expense for the years ended December 31, 2017 and 2016 amounted to $29.7 million and $4.2 million, respectively, and are reflected in our Consolidated Statements of Operations. The components of cost and benefit from our pension and other postretirement plans are detailed together with the Companylocation in our Consolidated Statements of Operations in Note 18.
Effective April 1, 2018, we early adopted ASU 2016-09,2017-04, Intangibles - Goodwill and Other (Topic 350): Simplifying the Test for Goodwill Impairment. The standard simplifies the subsequent measurement of goodwill by removing the requirement to perform a hypothetical purchase price allocation to compute the implied fair value of goodwill to measure impairment. Instead, goodwill impairment is measured as the difference between the fair value of the reporting unit and the carrying value of the reporting unit. The standard also clarifies the treatment of the income tax effect of tax-deductible goodwill when measuring goodwill impairment loss. See Note 14 for further discussion of the goodwill impairment we recognized in 2018.
Effective October 1, 2018, we early adopted ASU 2018-14, Compensation - Stock Compensation (Topic 718)Retirement Benefits - Defined Benefit Plans - General (Subtopic 715-20): ImprovementsDisclosure Framework - Changes to Employee Share-based Payment Accountingthe Disclosure Requirements for Defined Benefit Plans. ThisThe 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 priorguidance provides modifications to the adoption of this new accounting standard, inventory was measured at the lower of cost or market, where market wasdisclosure requirements for employers that sponsor defined as replacement cost, with a ceiling of net realizable valuebenefit pension 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.
other postretirement plans. Included in these modifications is the removal of five disclosure requirements for public entities. The adoption of this ASU did not have a material impact on our financial statements or disclosures.
Effective October 1, 2018, we early adopted ASU 2018-13, Disclosure Framework - Changes to the Disclosure Requirements for Fair Value Measurement (Topic 820). The new guidance provides modifications to the disclosure requirements in Topic 820, primarily related to assets measured at fair value under Level 3 of the fair value hierarchy. The adoption of this ASU did not have a material impact on our financial statements or disclosures.
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 |
|
|
| | | | | | | | | |
| | Year Ended December 31, |
| (in thousands, except per share amounts) | 2018 | 2017 | 2016 |
| Loss from continuing operations | $ | (658,460 | ) | $ | (382,068 | ) | $ | (122,900 | ) |
| (Loss) income from discontinued operations, net of tax | (66,832 | ) | 2,244 |
| 7,251 |
|
| Net loss attributable to shareholders | $ | (725,292 | ) | $ | (379,824 | ) | $ | (115,649 | ) |
| | | | |
| Weighted average shares used to calculate basic and diluted earnings per share | 127,158 |
| 46,935 |
| 50,129 |
|
| | | | |
| Basic and diluted loss per share - continuing operations | $ | (5.18 | ) | $ | (8.14 | ) | $ | (2.45 | ) |
| Basic and diluted (loss) earnings per share - discontinued operations | (0.52 | ) | 0.05 |
| 0.14 |
|
| Basic and diluted loss per share | $ | (5.70 | ) | $ | (8.09 | ) | $ | (2.31 | ) |
Because we incurred a net loss in the years ended December 31, 2018, 2017 and 2016, basic and diluted shares are the same.
If we had net income in the years ended December 31, 2018, 2017, and 2016, diluted shares would include an additional 0.7 million, 0.4 million and 0.5 million shares, respectively.
We excluded 2.9 million, 2.0 million 3.4 million and 1.33.4 million shares related to stock options from the diluted share calculation for the years ended December 31, 2018, 2017 2016 and 2015,2016, respectively, because their effect would have been anti-dilutive.
NOTE 4– SEGMENT REPORTINGDISCONTINUED OPERATIONS
OurOn October 5, 2018, we sold all of the capital stock of our MEGTEC and Universal businesses to Dürr Inc., a wholly owned subsidiary of Dürr AG, pursuant to a stock purchase agreement executed on June 5, 2018 for $130.0 million, subject to adjustment. We received $112.0 million in cash, net of $22.5 million in cash sold with the businesses, and $7.7 million, which was deposited in escrow pending final settlement of working capital and other customary matters. The escrow matters are expected to be resolved within 18 months from the closing date. We primarily used proceeds from the transaction to reduce outstanding balances under our U.S. Revolving Credit Facility and for working capital purposes.
Subsequent to October 5, 2018, changes in estimated working capital and other items have resulted in an estimated loss on sale and is presented in the table below in loss on sale of business.
Beginning with June 30, 2018, the MEGTEC and Universal businesses are classified as discontinued operations are assessed basedbecause the disposal represents a strategic shift that had a major effect on three reportable segments,our operations; they were previously included in our Industrial segment, which are summarizedhas been renamed the SPIG segment because SPIG is the remaining business of the former Industrial segment. We recorded a $72.3 million non-cash impairment charge in June 2018 to reduce the carrying value of the MEGTEC and Universal businesses to the fair value, less an amount of estimated sale costs; the non-cash impairment charge is included in Loss from discontinued operations, net of tax, in our Consolidated Statements of Operations and is presented below as follows:goodwill impairment.
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.
The following table presents selected financial information regarding the discontinued operations included in the Consolidated Statements of Operations:
|
| | | | | | | | | |
| | Year Ended December 31, |
| (in thousands) | 2018 | 2017 | 2016 |
| Revenue | $ | 170,908 |
| $ | 216,306 |
| $ | 157,322 |
|
| Cost of operations | 134,057 |
| 170,501 |
| 115,362 |
|
| Selling, general and administrative | 26,596 |
| 38,380 |
| 27,063 |
|
| Goodwill impairment | 72,309 |
| — |
| — |
|
| Restructuring charge | — |
| 408 |
| 1,994 |
|
| Research and development | 1,224 |
| 1,798 |
| 1,557 |
|
| Loss (gain) on asset disposals | (1,991 | ) | 2 |
| (7 | ) |
| Operating (loss) income | (61,287 | ) | 5,217 |
| 11,353 |
|
| Loss on sale of business | (5,521 | ) | — |
| — |
|
| Income tax (benefit) expense | (233 | ) | 1,107 |
| 4,237 |
|
| Net (loss) income | (66,832 | ) | 2,244 |
| 7,251 |
|
An analysisThe following table presents the major classes of assets that have been presented as assets and liabilities of discontinued operations in our Consolidated Balance Sheets:
|
| | | |
| (in thousands) | December 31, 2017 |
| Cash and cash equivalents | $ | 12,950 |
|
| Accounts receivable – trade, net | 39,196 |
|
| Accounts receivable – other | 157 |
|
| Contracts in progress | 25,409 |
|
| Inventories | 9,245 |
|
| Other current assets | 1,515 |
|
| Current assets of discontinued operations | 88,472 |
|
| Net property, plant and equipment | 27,224 |
|
| Goodwill | 118,720 |
|
| Deferred income taxes | 359 |
|
| Intangible assets | 34,715 |
|
| Other assets | 18 |
|
| Noncurrent assets of discontinued operations | 181,036 |
|
| Total assets of discontinued operations | $ | 269,508 |
|
| | |
| Accounts payable | $ | 19,838 |
|
| Accrued employee benefits | 3,095 |
|
| Advance billings on contracts | 9,073 |
|
| Accrued warranty expense | 5,506 |
|
| Other accrued liabilities | 9,987 |
|
| Current liabilities of discontinued operations | 47,499 |
|
| Pension and other accumulated postretirement benefit liabilities | 6,388 |
|
| Other noncurrent liabilities | 6,612 |
|
| Noncurrent liabilities of discontinued operations | 13,000 |
|
| Total liabilities of discontinued operations | $ | 60,499 |
|
The significant components of discontinued operations by segment isincluded in our Consolidated Statements of Cash Flows are 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 |
|
|
| | | | | | | | | |
| | Year Ended December 31, |
| (in thousands) | 2018 | 2017 | 2016 |
| Depreciation and amortization | $ | 3,482 |
| $ | 9,688 |
| $ | 5,060 |
|
| Goodwill impairment | 72,309 |
| — |
| — |
|
| Loss (gain) on asset disposals | (1,991 | ) | 2 |
| (7 | ) |
| Loss on sale of business | 5,521 |
| — |
| — |
|
| Benefit from deferred income taxes | (944 | ) | (359 | ) | (255 | ) |
| Purchase of property, plant equipment | (77 | ) | (1,254 | ) | (175 | ) |
| Acquisition of Universal, net of cash acquired | — |
| (52,547 | ) | — |
|
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 |
|
NOTE 5 – DIVESTITURES AND ACQUISITIONS
Divestiture
Palm Beach Resource Recovery Corporation ("PBRRC")
On September 17, 2018, we sold all of the issued and outstanding capital stock of PBRRC, a subsidiary that held two operations and maintenance contracts for waste-to-energy facilities in West Palm Beach, Florida, to Covanta Pasco, Inc., a wholly owned subsidiary of Covanta Holding Company for $45 million, subject to adjustment. We received $38.9 million in cash and $4.9 million that was deposited in escrow pending final settlement of working capital and other customary matters. The escrow is available to resolve any submitted claims or adjustments up to 18 months from the closing date and was primarily recorded in non-current other assets as of December 31, 2018. We recognized a $39.8 million pre-tax gain on sale of this business in 2018, net of $0.8 million of transaction costs. PBRRC was formerly part of the Vølund & Other Renewable segment and represented most of the operations and maintenance revenue for the years ended December 31, 2018, 2017 and 2016.
We continue to evaluate further dispositions and additional opportunities for cost savings, as well as other alternatives to increase our financial flexibility as we progress towards completion on our Vølund loss projects, as described in Note 7.
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$55 million under the United States revolving credit facilityU.S. 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. During 2018, Universal met the criteria for classification as a discontinued operation and was subsequently sold on October 5, 2018. See Note 4 for additional information about discontinued operations and the sale of Universal.
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 statementConsolidated Statement of operations.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 statementConsolidated Statement of operationsOperations 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 | Year Ended |
| (in thousands) | December 31, 2016 | December 31, 2016 |
| Revenues | $ | 1,660,986 |
| $ | 1,660,986 |
|
| Net income (loss) attributable to B&W | (113,940 | ) | |
| Net loss attributable to B&W | | (113,940 | ) |
| Basic earnings per common share | (2.27 | ) | (2.27 | ) |
| Diluted earnings per common share | (2.27 | ) | (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 was subject 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$8.0 million of gross profit to the Industrial segment.profit.
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 can provide from its wide scope of engineered cooling and service offerings and customer base. None of this goodwill is expected to be deductible for tax purposes. Also, see Note 1514 for the results of our subsequent goodwill impairment assessmentsassessments.
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 $5.2 million, $9.1 million and $13.3 million of intangible asset amortization expense in the years ended December 31, 2018, 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 statementConsolidated Statement of operationsOperations for the years ended December 31, 2017 and 2016, respectively.
The following unaudited pro forma financial information below represents our results of operations for yearsyear ended December 31, 2016and 2015 had the SPIG acquisition occurred on January 1, 2015.2016. 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, 2015.2016. This information should not be taken as representative of our future consolidated results of operations.
| | | | | Year Ended December 31, | | Year Ended December 31, |
| (in thousands) | | 2016 | | 2015 | | 2016 |
| Revenues | | $ | 1,663,126 |
| | $ | 1,941,987 |
| | $ | 1,663,126 |
|
| Net income (loss) attributable to B&W | | (111,500 | ) | | 12,047 |
| |
| Net loss attributable to B&W | | | (111,500 | ) |
| Basic earnings per common share | | (2.22 | ) | | 0.23 |
| | (2.22 | ) |
| Diluted earnings per common share | | (2.22 | ) | | 0.22 |
| | (2.22 | ) |
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 yearsyear ended December 31, 2016 and 2015, respectively.2016.
Elimination of the historical interest expense recognized by SPIG of $0.5 million and $0.7 million in the years endedyear ended December 31, 2016 and 2015, respectively.2016.
Elimination of $3.5 million and $0.2 million in transaction related costs recognized in the yearsyear ended December 31, 2016 and 2015, respectively.2016.
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.
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.
NOTE 76 – EQUITY METHOD INVESTMENTSSEGMENT REPORTING
Our equity method investment in operations are assessed based on three reportable segments which are summarized as follows:
Babcock & Wilcox Beijing Company, Ltd.segment: focused on the supply of and aftermarket services for steam-generating, environmental and auxiliary equipment for power generation and other industrial applications. This segment was formerly named the Power segment.
Vølund & Other Renewable segment: focused on the supply of steam-generating systems, environmental and auxiliary equipment and operations and maintenance services for the waste-to-energy and biomass power generation industries. This segment was formerly named the Renewable segment.
SPIG segment: focused on the supply of custom-engineered cooling systems for steam applications along with related aftermarket services. This segment was formerly part of the Industrial segment.
The segment information presented in the table below 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 Babcock & Wilcox segment elimination is revenue associated with construction services. The primary component of total eliminations is associated with Babcock & Wilcox segment construction services provided to the SPIG segment. An analysis of our operations by segment is as follows:
|
| | | | | | | | | |
| | Year Ended December 31, |
| (in thousands) | 2018 | 2017 | 2016 |
| Revenues: | | | |
| Babcock & Wilcox segment | | | |
| Retrofits | $ | 223,516 |
| $ | 306,758 |
| $ | 392,854 |
|
| New build utility and environmental | 155,695 |
| 155,886 |
| 292,302 |
|
| Aftermarket parts and field engineering services | 271,028 |
| 277,129 |
| 292,535 |
|
| Industrial steam generation | 129,648 |
| 123,127 |
| 107,267 |
|
| Eliminations | (25,311 | ) | (41,838 | ) | (102,980 | ) |
| | 754,576 |
| 821,062 |
| 981,978 |
|
| Vølund & Other Renewable segment | | | |
| Renewable new build and services | 137,565 |
| 282,228 |
| 284,684 |
|
| Operations and maintenance services | 44,507 |
| 64,970 |
| 65,814 |
|
| Eliminations | (890 | ) | — |
| (1,326 | ) |
| | 181,182 |
| 347,198 |
| 349,172 |
|
| SPIG segment | | | |
| New build cooling systems | 112,758 |
| 126,674 |
| 19,961 |
|
| Aftermarket cooling system services | 40,867 |
| 54,811 |
| 76,330 |
|
| | 153,625 |
| 181,485 |
| 96,291 |
|
| | | | |
| Eliminations | (26,995 | ) | (8,316 | ) | (6,500 | ) |
| | $ | 1,062,388 |
| $ | 1,341,429 |
| $ | 1,420,941 |
|
Beginning in 2018, we changed our primary measure of segment profitability from gross profit to adjusted earnings before interest, tax, depreciation and amortization ("BWBC"EBITDA"). The presentation of the components of our gross profit and adjusted EBITDA in the tables below are consistent with the way our chief operating decision maker reviews the results of our operations and makes strategic decisions about our business. Items such as gains or losses on asset sales, mark to market ("MTM") contributed $6.1pension adjustments, restructuring and spin costs, impairments, losses on debt extinguishment, costs related to financial consulting required under our U.S. Revolving Credit Facility and other costs that may not be directly controllable by segment management are not allocated to the segment. Adjusted EBITDA for each segment is presented below with a reconciliation to net income. Adjusted EBITDA is not a recognized term under GAAP and should not be considered in isolation or as an alternative to net earnings (loss), operating profit (loss) or as an alternative to cash flows from operating activities as a measure of our liquidity. Adjusted EBITDA as presented below differs from the calculation used to compute our leverage ratio and interest coverage ratio as defined by our U.S. Revolving Credit Facility. Because all companies do not use identical calculations, the amounts presented for Adjusted EBITDA may not be comparable to other similarly titled measures of other companies.
|
| | | | | | | | | |
| | Year Ended December 31, |
| (in thousands) | 2018 | 2017 | 2016 |
Gross profit (loss)(1): | | | |
| Babcock & Wilcox segment | $ | 141,054 |
| $ | 171,008 |
| $ | 213,541 |
|
| Vølund & Other Renewable segment | (238,125 | ) | (128,205 | ) | (68,109 | ) |
| SPIG segment | (25,113 | ) | (7,967 | ) | 8,026 |
|
| Intangible amortization expense included in cost of operations | (6,055 | ) | (10,618 | ) | (15,192 | ) |
| Inventory reserve for strategic change in China | (1,405 | ) | — |
| — |
|
| (129,644 | ) | 24,218 |
| 138,266 |
|
| | | | |
| Selling, general and administrative ("SG&A") expenses | (198,200 | ) | (218,060 | ) | (216,486 | ) |
| Financial advisory services included in SG&A | (18,625 | ) | (2,659 | ) | — |
|
| Trade receivable reserve in SG&A for Chinese operations | (5,845 | ) | — |
| — |
|
| Intangible amortization expense included in SG&A | (661 | ) | (426 | ) | (598 | ) |
| Goodwill and other intangible asset impairment | (40,046 | ) | (86,903 | ) | — |
|
| Restructuring activities and spin-off transaction costs | (16,758 | ) | (15,039 | ) | (38,813 | ) |
| Research and development costs | (3,780 | ) | (7,614 | ) | (8,849 | ) |
| (Loss) gain on asset disposals, net | (1,438 | ) | (13 | ) | 25 |
|
| Equity in income and impairment of investees | (11,603 | ) | (9,867 | ) | 16,440 |
|
| Operating loss | $ | (426,600 | ) | $ | (316,363 | ) | $ | (110,015 | ) |
(1) Intangible amortization is not allocated to the segments' gross profit, but depreciation is allocated to the segments' gross profit.
|
| | | | | | | | | |
| Year Ended December 31, |
| (in thousands) | 2018 | 2017 | 2016 |
| Adjusted EBITDA |
|
|
|
| |
Babcock & Wilcox segment(1) | $ | 83,640 |
| $ | 103,294 |
| $ | 130,735 |
|
| Vølund & Other Renewable segment | (276,266 | ) | (170,344 | ) | (105,102 | ) |
| SPIG segment | (53,406 | ) | (29,792 | ) | 1,862 |
|
Corporate(2) | (26,876 | ) | (36,147 | ) | (35,343 | ) |
| Research and development costs | (3,780 | ) | (7,614 | ) | (8,849 | ) |
| Foreign exchange | (28,542 | ) | (4,751 | ) | (1,944 | ) |
| Other – net | 259 |
| (698 | ) | (616 | ) |
| (304,971 | ) | (146,052 | ) | (19,257 | ) |
|
|
|
|
| |
| Depreciation & amortization | (28,521 | ) | (30,449 | ) | (34,523 | ) |
| Interest expense, net | (49,364 | ) | (25,426 | ) | (2,900 | ) |
| Loss on debt extinguishment | (49,241 | ) | — |
| — |
|
| Restructuring activities and spin-off transaction costs | (16,758 | ) | (15,039 | ) | (38,813 | ) |
| Financial advisory services included in SG&A | (18,625 | ) | (2,659 | ) | — |
|
| Acquisition and integration costs included in SG&A | — |
| (1,522 | ) | — |
|
| Reserves for strategic change in China | (7,250 | ) | — |
| — |
|
| MTM (loss) gain from benefit plans | (67,474 | ) | 8,706 |
| (24,159 | ) |
| Goodwill and other intangible asset impairment | (40,046 | ) | (86,903 | ) | — |
|
| Impairment of equity method investment in TBWES | (18,362 | ) | (18,193 | ) | — |
|
| Gain on sale of equity method investment in BWBC | 6,509 |
| — |
| — |
|
| Gain on sale of business | 39,815 |
| — |
| — |
|
| (Loss) gain on asset disposal | (1,513 | ) | (13 | ) | 25 |
|
| Loss before income tax expense | (555,801 | ) | (317,550 | ) | (119,627 | ) |
| Income tax expense (benefit) | 102,224 |
| 63,709 |
| 2,706 |
|
| Loss from continuing operations | (658,025 | ) | (381,259 | ) | (122,333 | ) |
| (Loss) income from discontinued operations, net of tax | (66,832 | ) | 2,244 |
| 7,251 |
|
| Net loss | (724,857 | ) | (379,015 | ) | (115,082 | ) |
| Net income attributable to noncontrolling interest | (435 | ) | (809 | ) | (567 | ) |
| Net loss attributable to stockholders | $ | (725,292 | ) | $ | (379,824 | ) | $ | (115,649 | ) |
(1) Babcock & Wilcox segment adjusted EBITDA includes $25.4 million, $4.5$21.0 million and $4.9$20.0 million of net benefit from pension and other postretirement benefit plans, excluding MTM adjustments, in the years ended December 31, 2018, 2017 and 2016, respectively.
(2) Allocations are excluded from discontinued operations. Accordingly, allocations previously absorbed by the MEGTEC and Universal businesses in the SPIG segment have been included with other unallocated costs in Corporate, and total $11.4 million, $8.8 million and $4.3 million in incomethe years ended December 31, 2018, 2017 and 2016, respectively.
|
| | | | | | | | | |
| | Year Ended December 31, |
| (in thousands) | 2018 | 2017 | 2016 |
| DEPRECIATION AND AMORTIZATION | | | |
| Babcock & Wilcox segment | $ | 16,047 |
| $ | 13,871 |
| $ | 15,906 |
|
| Vølund & Other Renewable segment | 4,301 |
| 4,633 |
| 3,979 |
|
| SPIG segment | 7,092 |
| 11,126 |
| 14,014 |
|
| Segment depreciation and amortization | 27,440 |
| 29,630 |
| 33,899 |
|
| Corporate | 1,081 |
| 819 |
| 624 |
|
| Total depreciation and amortization | $ | 28,521 |
| $ | 30,449 |
| $ | 34,523 |
|
We do not separately identify or report our assets by segment as our chief operating decision maker does not consider assets by segment to be a critical measure by which performance is measured.
We provide our results from operationsproducts and services to a diverse customer base that includes utilities and other power producers located around the world. We have one customer in the Babcock & Wilcox segment, Southern Company, with revenues of $138.1 million that accounted for 13% of our consolidated revenue for the year ended December 31, 2018. We have no customers that individually accounted for more than 10% of our consolidated revenues in the years ended December 31, 2017, or 2016.
Information about our consolidated operations in different geographic areas |
| | | | | | | | | |
| | Year Ended December 31, |
| (in thousands) | 2018 | 2017 | 2016 |
REVENUES(1) | | | |
| United States | $ | 652,879 |
| $ | 615,089 |
| $ | 771,453 |
|
| United Kingdom | 64,465 |
| 183,755 |
| 196,000 |
|
| Canada | 90,459 |
| 95,763 |
| 62,822 |
|
| Sweden | 34,578 |
| 36,284 |
| 21,049 |
|
| China | 23,432 |
| 48,161 |
| 27,423 |
|
| Germany | 14,690 |
| 21,867 |
| 25,020 |
|
| Italy | 14,164 |
| 11,112 |
| 6,004 |
|
| Denmark | 12,426 |
| 82,058 |
| 53,824 |
|
| Nigeria | 12,211 |
| 6,754 |
| — |
|
| Taiwan - Republic of China | 11,690 |
| 528 |
| 718 |
|
| Finland | 10,161 |
| 6,808 |
| 5,434 |
|
| Brazil | 9,042 |
| 2,927 |
| 1,806 |
|
| Belgium | 8,226 |
| 288 |
| 300 |
|
| Saudi Arabia | 8,035 |
| 13,648 |
| 791 |
|
| Vietnam | 5,764 |
| 15,762 |
| 54,691 |
|
| South Korea | 5,678 |
| 41,217 |
| 44,657 |
|
| India | 5,642 |
| 3,116 |
| 4,254 |
|
| Chile | 5,597 |
| 3,403 |
| 3,721 |
|
| Bahrain | 5,286 |
| 7 |
| — |
|
| Egypt | 2,133 |
| 43,122 |
| 35,833 |
|
Aggregate of all other countries, each with less than $5 million in revenues | 65,830 |
| 109,760 |
| 105,141 |
|
| | $ | 1,062,388 |
| $ | 1,341,429 |
| $ | 1,420,941 |
|
(1) We allocate geographic revenues based on the location of the customer's operations.
|
| | | | | | | | | |
| | Year Ended December 31, |
| (in thousands) | 2018 | 2017 | 2016 |
| NET PROPERTY, PLANT AND EQUIPMENT | | | |
| United States | $ | 43,070 |
| $ | 60,611 |
| $ | 67,249 |
|
| Mexico | 20,458 |
| 21,950 |
| 22,594 |
|
| China | 8,720 |
| 10,093 |
| 13,460 |
|
| United Kingdom | 5,671 |
| 6,498 |
| 6,237 |
|
| Denmark | 7,372 |
| 7,954 |
| 6,749 |
|
Aggregate of all other countries, each with less than $5 million of net property, plant and equipment | 5,601 |
| 7,601 |
| 5,683 |
|
| | $ | 90,892 |
| $ | 114,707 |
| $ | 121,972 |
|
NOTE 7 – REVENUE RECOGNITION AND CONTRACTS
Adoption of Accounting Standards Codification ("ASC") Topic 606, Revenue from Contracts with Customers ("Topic 606")
On January 1, 2018, we adopted Topic 606 using the modified retrospective method applied to all contracts that were not completed as of January 1, 2018. Results for reporting periods beginning on or after January 1, 2018 are presented under Topic 606, while prior period amounts are not adjusted and continue to be reported under the accounting standards in effect for the prior period. We recorded a $0.5 million net increase to opening retained earnings as of January 1, 2018 from the cumulative effect of adopting Topic 606 that primarily related to transitioning the timing of certain sales commissions expense. The effect on revenue from adopting Topic 606 was not material for the year ended December 31, 2018.
Contract Balances
The following represents the components of our contracts in progress and advance billings on contracts included in our consolidated balance sheets:
|
| | | | | | | | | | | |
| | Year Ended December 31, | | |
| (in thousands) | 2018 | 2017 | $ Change | % Change |
| Contract assets - included in contracts in progress: | | | | |
| Costs incurred less costs of revenue recognized | $ | 49,910 |
| $ | 69,577 |
| $ | (19,667 | ) | (28 | )% |
| Revenues recognized less billings to customers | 94,817 |
| 66,234 |
| 28,583 |
| 43 | % |
| Contracts in progress | $ | 144,727 |
| $ | 135,811 |
| $ | 8,916 |
| 7 | % |
| Contract liabilities - included in advance billings on contracts: | | | | |
| Billings to customers less revenues recognized | $ | 140,933 |
| $ | 168,880 |
| $ | (27,947 | ) | (17 | )% |
| Costs of revenue recognized less cost incurred | 8,434 |
| 3,117 |
| 5,317 |
| 171 | % |
| Advance billings on contracts | $ | 149,367 |
| $ | 171,997 |
| $ | (22,630 | ) | (13 | )% |
| | | | | |
| Net contract balance | $ | (4,640 | ) | $ | (36,186 | ) | $ | 31,546 |
| (87 | )% |
| | | | | |
| Accrued contract losses | $ | 61,651 |
| $ | 40,634 |
| $ | 21,017 |
| 52 | % |
The impact of adopting Topic 606 on components of our contracts in progress and advance billings on contracts was not material at January 1, 2018. The change in our net contract balance was primarily driven by revenues recognized during 2018 that were included in contract liabilities at the beginning of the period and exceeded the receipt of new advanced payments from customers.
Backlog
On December 31, 2018 we had $782 million of remaining performance obligations, which we also refer to as total backlog. We expect to recognize approximately 54%, 12% and 34% of our remaining performance obligations as revenue in the remainder of 2019, 2020 and thereafter, respectively. Backlog reduced by approximately $467 million in September 2018 as a result of the sale of PBRRC described in Note 5.
Changes in Contract Estimates
In the years ended December 31, 2018, 2017 and 2016, and 2015, respectively. BWBC has a manufacturing facilitywe 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) | 2018 | 2017 | 2016 |
| Increases in gross profits for changes in estimates for over time contracts | $ | 18,183 |
| $ | 21,638 |
| $ | 42,368 |
|
| Decreases in gross profits for changes in estimates for over time contracts | (262,389 | ) | (174,906 | ) | (149,169 | ) |
| Net changes in gross profits for changes in estimates for over time contracts | $ | (244,206 | ) | $ | (153,268 | ) | $ | (106,801 | ) |
Vølund Loss Contracts
We had four Vølund contracts for renewable energy facilities in Europe that designs, manufactures, produces and sells various power plant and industrial boilers primarily in China. Our investment in BWBCwere loss contracts at December 31, 2016. During 2017, two additional Vølund contracts in Europe became loss contracts. In the years ended December 31, 2018, 2017, and 2016, was $16.6we recorded $233.0 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$158.5 million and $(8.2)$141.1 million in income (losses)net losses, respectively, inclusive of warranty expense as described in Note 17, resulting from changes in the estimated revenues and costs to our results from operations (excludingcomplete the impairment charge discussed below)six European Vølund loss contracts. These changes in estimates in the years ended December 31, 2018, 2017 and 2016 included increases in our estimates of anticipated liquidated damages that reduced revenue associated with these six contracts by $11.5 million, $41.3 million and 2015,$35.8 million, respectively. TBWESThe total anticipated liquidated damages associated with these six contracts were $88.6 million and $77.1 million at December 31, 2018 and December 31, 2017, respectively. During the year ended December 31, 2017 there were corrections that reduced (increased) estimated contract losses at completion by $1.0 million, $(6.0) million and $1.1 million relating to the three months ended December 31, 2016, March 31, 2017 and June 30, 2017, respectively. Management has determined these amounts are immaterial to the consolidated financial statements in both previous periods.
As of March 2019, four of the six Vølund loss contracts had been turned over to the customer, with only punch list or agreed remediation items remaining, some of which are expected to be performed during the customers' scheduled maintenance outages. This applies to the first, third, fourth and sixth loss contracts. The customers for the second and fifth loss contracts are related parties, and a manufacturing facilitysettlement agreement was reached on March 29, 2019 to limit our remaining risk related to these contracts. Under that produces boiler partssettlement agreement, we agreed to pay a combined £70 million ($88.9 million) by April 5, 2019 in exchange for limiting and equipment intended primarilyfurther defining our obligations under these second and fifth loss contracts, including waiver of the rejection and termination rights on the fifth loss contract that could have resulted in repayment of all monies paid to us and our former civil construction partner (up to approximately $144 million), and requirement to restore the property to its original state if the customer exercised this contractual rejection right. On the fifth loss contract, we agreed to continue to support construction services to complete certain key systems of the plant by a specified date, for new build coal boilerwhich penalty for failure to complete these systems is limited to the unspent portion of our quoted cost of the activities through that date. The settlement eliminates all historical claims and remaining liquidated damages. Upon completion of these activities in accordance with the settlement, we will have no further obligation related to the fifth loss contract other than customary warranty of core products if the plant is used as a biomass plant as designed. We estimated the portion of this settlement related to waiver of the rejection right on the fifth project was $81.1 million, which was recorded in the fourth quarter of 2018 as a reduction in the selling price. We are still pursuing insurance recoveries and claims against subcontractors. For the second loss project, the settlement limits the remaining performance obligations and settled historic claims for nonconformance and delays, and we expect to turn over the plant in May 2019 and then begin the operations and maintenance contract that follows turnover of this plant. Additional engineering or core scope services, may be provided by us on the fifth loss contract on commercially acceptable terms. We will provide operations and maintenance services under an existing contract for the fifth loss project if properly notified and the plant is used as a biomass plant as designed.
As of December 31, 2018, the status of these six loss contracts was as follows:
The first contract, a waste-to-energy plant in India. DuringDenmark, became a loss contract in the second quarter of 2016. As of December 31, 2018, this contract is approximately 95% complete and construction activities are complete as of the date of this report. The unit became operational during the second quarter of 2017, both we and our joint venture partner decidedas of December 31, 2018 was only pending customer agreement that contractual trial operations and takeover activities and requirements had been met. A settlement was reached with the customer to make a strategic changeachieve takeover on January 31, 2019, after which only punch list items and other agreed to remediation items remain, most of which are expected to be performed during the customer's scheduled maintenance outages. As of January 31, 2019, the contract is in the Indian joint venture due towarranty phase. During the decline in forecasted market opportunities in India, which reducedyear ended December 31, 2018, we recognized additional contract losses of $31.8 million on the expected recoverable value of our investment in the joint venture. Ascontract as a result of this strategic change,differences in actual and
estimated costs, schedule delays and issues encountered during preparation for and completion of formal trial operations. Losses in the year ended December 31, 2018 also related to increases in expected warranty costs. Our estimate at completion as of December 31, 2018 includes $9.2 million of total expected liquidated damages. As of December 31, 2018, the reserve for estimated contract losses recorded in "other accrued liabilities" in our consolidated balance sheet was $4.9 million. In the year ended December 31, 2017, we recognized additional contract losses of $20.8 million as a $18.2result of differences in actual and estimated costs and schedule delays. As of December 31, 2017, this contract had $1.6 million other-than-temporary-impairment of accrued losses and was 98% complete. 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 contract, a biomass plant in the United Kingdom, became a loss contract in the fourth quarter of 2016. As of December 31, 2018, this contract was approximately 95% complete. Startup of the unit occurred in April 2018, and synchronization to the electrical grid while firing on biomass fuel occurred in September 2018. Trial operations are expected to begin in early April 2019 and takeover by the customer is expected in May 2019. This project is subject to the March 29, 2019 settlement agreement described above. During the year ended December 31, 2018, we recognized additional contract losses of $21.7 million on this contract as a result of repairs required during startup commissioning activities, additional expected punch list and other commissioning costs, and changes in construction cost estimates. Losses in the year ended December 31, 2018 also related to increases in expected warranty costs and subcontractor productivity being lower than previous estimates. Our estimate at completion as of December 31, 2018 includes $19.0 million of total expected liquidated damages due to schedule delays. Our estimates at completion as of December 31, 2018 and 2017 also include contractual bonus opportunities for guaranteed higher power output (discussed further below). As of December 31, 2018, the reserve for estimated contract losses recorded in "other accrued liabilities" in our investmentconsolidated balance sheet was $3.9 million. In the year ended December 31, 2017, we recognized contract losses of $47.8 million from changes in TBWESthe expected selling price, construction cost estimates and schedule delays, and as of December 31, 2017, this contract had $12.8 million of accrued losses and was 81% complete. 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 contract, a biomass plant in Denmark, became a loss contract in the fourth quarter of 2016. As of December 31, 2018, this contract was approximately 99% complete and construction activities are complete as of the date of this report. The unit became operational during the second quarter of 2017, and partial takeover was achieved in March 2018. We agreed with the customer to a full takeover at the end of October 2018 and scheduled a time line for remaining punch list activities to be completed around the customer's future planned outages. The contract is now in the warranty phase. During the year ended December 31, 2018, we recognized additional contract losses of $6.9 million as a result of changes in the estimated costs at completion. Our estimate at completion as of December 31, 2018 includes $6.8 million of total expected liquidated damages due to schedule delays. As of December 31, 2018, the reserve for estimated contract losses recorded in "other accrued liabilities" in our consolidated balance sheet was $0.5 million. In the year ended December 31, 2017, we recognized charges of $10.2 million from changes in our estimate at completion, and as of December 31, 2017, this contract had $0.7 million of accrued losses and was 98% complete. 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 contract, a biomass plant in the United Kingdom, became a loss contract in the fourth quarter of 2016. As of December 31, 2018, this contract was approximately 96% complete. Commissioning activities began in the first quarter of 2018, and construction was substantially complete at June 30, 2018. Startup of the unit occurred in May 2018, and synchronization to the electrical grid while firing on biomass fuel occurred in July 2018. Trial operations began in November 2018 and takeover by the customer occurred in February 2019, after which only punch list items remain, most of which are expected to be performed during the customer's scheduled maintenance outages. During the year ended December 31, 2018, we revised our estimated revenue and costs at completion for this loss contract, which resulted in $31.3 million of additional contract losses due to challenges in startup commissioning activities, additional expected punch list and other commissioning costs, additional subcontractor costs and estimated liquidated damages. Losses in the year ended December 31, 2018 also include increases in expected warranty costs and subcontractor productivity being lower than previous estimates. Our estimate at completion as of December 31, 2018 includes $21.2 million of total expected liquidated damages due to schedule delays. Our estimates at completion as of December 31, 2018 and December 31, 2017 also include contractual bonus opportunities for guaranteed higher power output (discussed further below). As of December 31, 2018, the reserve for estimated contract losses recorded in "other accrued liabilities" in our consolidated balance sheet was $2.1 million. In the year ended December 31, 2017, we recognized contract losses of $26.0 million from changes in the expected selling price, changes in construction cost estimates and schedule delays, and as of December 31, 2017, this contract had $4.7 million of accrued losses and was 85% complete. 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 contract, a biomass plant in the United Kingdom, became a loss contract in the second quarter of 2017,2017. As of December 31, 2018, this contract was approximately 76% complete. This project is subject to the March 29, 2019 settlement agreement described above. We estimated the portion of this settlement related to waiver of the rejection right on the fifth project was $81.1 million, which was classified in in equity income of investees. The impairment charge was based on the differencerecorded in the carrying valuefourth quarter of 2018 as a reduction in the selling price. Under the settlement, our investment in TBWES and our shareremaining performance obligations were limited to support construction services to complete certain key systems of the estimated fair value of TBWES's net assets. Our investment in TBWES atplant by a specified date. The settlement also eliminates all historical claims and remaining liquidated damages. During the twelve months ended December 31, 20172018, we revised our estimated revenue and 2016 was $26.0costs at completion for this loss contract which resulted in $119.5 million and $40.6 million, respectively. The TBWES joint venture is now idle as we andof additional contract losses, including waiver of rejection rights, estimated costs of taking over the civil scope in the first quarter of 2018 from our joint venture partner, explore strategic alternativeswho entered administration (similar to filing for its assets.bankruptcy in the U.S.) in late February 2018 and receipt of regulatory release later than expected in previous estimates to begin repairs to failed steel beam that failed in September 2017, which are described in more detail below. Losses in the twelve months ended December 31, 2018 also reflect an extended schedule from greater challenges in restarting work on a site that had been idle pending repairs on the failed steel beam, including the extent of items that had been damaged from weather exposure, and increases in expected warranty costs. Our estimate at completion as of December 31, 2018, includes $13.3 million of total expected liquidated damages due to schedule delays. As of December 31, 2018, the reserve for estimated contract losses recorded in "other accrued liabilities" in our consolidated balance sheet was $36.8 million. In the year ended December 31, 2017, we recognized charges of $40.2 million, respectively from changes in our estimate at completion, and as of December 31, 2017, this contract had $14.3 million of accrued losses and was 64% complete.
OnThe sixth contract, a waste-to-energy plant in the United Kingdom, became a loss contract in the second quarter of 2017. As of December 22, 2016,31, 2018, this contract was approximately 95% complete. Commissioning activities began in the first quarter of 2018, construction was substantially completed in July 2018, startup of the unit occurred in July 2018. Trial operations began in December 2018 and customer takeover occurred on January 25, 2019, after which only punch list items remain, most of which are expected to be performed during the customer's scheduled maintenance outages. The contract is in the warranty phase. During the year ended December 31, 2018, we sold allrevised our estimated revenue and costs at completion for this loss contract, which resulted in additional contract losses of $22.0 million due to challenges in startup commissioning activities. Losses in the year ended December 31, 2018 also included the effects of schedule delays, inclusive of liquidated damages, estimated claim settlements, and increases in expected warranty costs. Our estimate at completion as of December 31, 2018 includes $19.1 million of total expected liquidated damages due to schedule delays. As of December 31, 2018, the reserve for estimated contract losses recorded in "other accrued liabilities" in our consolidated balance sheet was $1.4 million. In the year ended December 31, 2017, we recognized additional contract losses of $18.5 million from changes in our estimate at completion, and as of December 31, 2017, this contract had $2.5 million of accrued losses and was 76% complete.
In September 2017, we identified the failure of a structural steel beam on the fifth contract, which stopped work in the boiler building and other areas pending corrective actions to stabilize the structure. Provisional regulatory approval to begin structural repairs to the failed beam was obtained on March 29, 2018 (later than previously estimated), and full approval to proceed with repairs was obtained in April 2018. Full access to the site was obtained on June 6, 2018 after completion of the repairs to the structure. The engineering, design and manufacturing of the steel structure were the responsibility of our interestsubcontractors. A similar design was also used on the second and fourth contracts, and although no structural failure occurred on these two other contracts, work was also stopped in our former Australian joint venture, Halley & Mellowes Pty. Ltd. ("HMA") for $18.0 million. The sale of HMAcertain restricted areas while we added reinforcement to the structures, which also resulted in an $8.3delays that lasted until late January 2018. The total costs related to the structural steel issues on these three contracts, including contract delays, are estimated to be approximately $37 million, gain, which is included in the December 31, 2018 estimated losses at completion for these three contracts.
Also, during the third quarter of 2017, we implemented a design change in three of the 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, and this positive change in estimated cost to complete was classifiedfully recognized in equity income of investees in 2016. HMA contributed income of $2.2 million and $3.1 million to our results from operations in2017 because each was a loss contract.
During the years ended December 31, 2018, 2017 and 2016, we recognized losses of $2.3 million, $2.5 million and 2015.
Our investment in equity method investees$14.2 million, respectively, on our other Vølund renewable energy projects that are not loss contracts. Accrued liquidated damages associated with these projects was not significantly different from our underlying equity in the net assets of those investees based on stated ownership percentages$9.0 million at December 31, 2017. All of our investments in equity method investees are included in our Power segment.
2016.
During the third quarter of 2016, we determined it was probable that we would receive a $15.5 million (DKK 100.0 million) insurance recovery for a portion of the losses on the first Vølund contract discussed above. In May 2018, our insurer disputed coverage on our insurance claim. We believe that the dispute from the insurer is without merit and continue to believe we are entitled to the full value of the claim. We intend to aggressively pursue full recovery under the policy, and we filed for arbitration in July 2018. However, an allowance for the receivable was recorded in 2018 based upon the dispute by the insurer, which is considered contradictory evidence in the accounting probability assessment of this loss recovery, even if it is believed to be without merit. The undistributed earningsinsurance recovery of $15.5 million is recorded in accounts receivable - other in our equity method investees were $7.9consolidated balance sheet, offset by a $12.3 million and $59.6 millionreserve at December 31, 20172018.
SPIG U.S. Loss Contract
At December 31, 2018, SPIG had one significant loss contract, a contract to engineer, procure materials and 2016, respectively. Summarized belowthen construct a dry cooling system for a gas-fired power plant in the U.S. At December 31, 2018, the design and procurement are substantially complete, and the construction is underway. Overall, the contract is 69% complete and it is expected be fully complete in mid-2019. Total losses of $14.8 million were recorded in 2018, of which $9.1 million were recorded in the fourth quarter of 2018, from changes in estimated cost to complete primarily from schedule delays, lower construction labor productivity and material quality. As of December 31, 2018, the reserve for estimated contract losses recorded in "other accrued liabilities" in our consolidated balance sheet and statement of operations information for investments accounted for underwas $4.6 million related to this contract. Construction is being performed by 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 taxesBabcock & Wilcox segment, but the contract loss is based on the tax laws and ratesincluded 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).
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.SPIG segment.
NOTE 8 – RESTRUCTURING ACTIVITIES AND SPIN-OFF TRANSACTION COSTS
Restructuring liabilitiesIn the years ended December 31, 2018, 2017 and 2016, we recognized restructuring activities and spin-off transaction costs of $16.8 million, $15.0 million and $38.8 million, respectively. The following tables summarize the restructuring activity and spin-off costs incurred by segment.
|
| | | | | | | | | | | | | | | |
| (in thousands) | | | | | |
| Year ended December 31, 2018 | Severance and related costs | Exit costs | Impairment costs | Spin-off transaction costs | Total |
| Babcock & Wilcox segment | $ | 7,616 |
| $ | 177 |
| $ | — |
| $ | — |
| $ | 7,793 |
|
| Vølund & Other Renewable segment | 469 |
| — |
| — |
| — |
| 469 |
|
| SPIG segment | 2,506 |
| — |
| — |
| — |
| 2,506 |
|
| Corporate | 5,461 |
| 199 |
| — |
| 330 |
| 5,990 |
|
| | $ | 16,052 |
| $ | 376 |
| $ | — |
| $ | 330 |
| $ | 16,758 |
|
|
| | | | | | | | | | | | | | | |
| (in thousands) | | | | | |
| Year ended December 31, 2017 | Severance and related costs | Exit costs | Impairment costs | Spin-off transaction costs | Total |
| Babcock & Wilcox segment | $ | 7,788 |
| $ | 1,708 |
| $ | 731 |
| $ | — |
| $ | 10,227 |
|
| Vølund & Other Renewable segment | 2,997 |
| — |
| — |
| — |
| 2,997 |
|
| SPIG segment | 65 |
| — |
| — |
| — |
| 65 |
|
| Corporate | 547 |
| — |
| — |
| 1,203 |
| 1,750 |
|
| | $ | 11,397 |
| $ | 1,708 |
| $ | 731 |
| $ | 1,203 |
| $ | 15,039 |
|
|
| | | | | | | | | | | | | | | |
| (in thousands) | | | | | |
| Year ended December 31, 2016 | Severance and related costs | Exit costs | Impairment costs | Spin-off transaction costs | Total |
| Babcock & Wilcox segment | $ | 14,311 |
| $ | 3,972 |
| $ | 14,907 |
| $ | — |
| $ | 33,190 |
|
| Vølund & Other Renewable segment | 608 |
| — |
| — |
| — |
| 608 |
|
| SPIG segment | 31 |
| — |
| — |
| — |
| 31 |
|
| Corporate | 351 |
| 816 |
| — |
| 3,817 |
| 4,984 |
|
| | $ | 15,301 |
| $ | 4,788 |
| $ | 14,907 |
| $ | 3,817 |
| $ | 38,813 |
|
In 2018, we began to implement a series of cost restructuring actions, primarily in our U.S., European, Canadian and Asian operations, and corporate functions. These actions were intended to appropriately size our operations and support functions in response to the continuing decline in global markets for new build coal-fired power generation, the announcement of the MEGTEC and Universal sale and our liquidity needs. Severance cost associated with these actions taken through December 31, 2018 is expected to total approximately $9.1 million, of which $7.2 million was recorded in the year ended December 31, 2018 and the remainder will be recorded mainly in 2019 over the remaining service periods. Severance payments are expected to extend through mid-2019. In addition, executive severance totaling $5.3 million in the year ended December 31, 2018 related to the elimination of the SVP and Chief Business Development Officer role and the transition of two CEO roles in 2018. Severance payments are expected to extend through late-2019.
The remainder of the restructuring costs in the year ended December 31, 2018, primarily relate to actions from the second half of 2017 that were intended to improve our global cost structure and increase our financial flexibility. These restructuring actions included 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 included reduction of approximately 30% of Vølund's workforce to align with a new execution model focused on Vølund's core boiler, grate and environmental equipment technologies, with the balance-of-plant and civil construction scope being executed by a partner.
In the years ended December 31, 2017 and 2016, restructuring costs relate primarily to a series of activities that took place prior to 2017 that were intended to help us maintain margins, make our costs more volume-variable and allow our business to be more flexible. These actions were primarily in the Babcock & Wilcox segment in advance of lower projected demand for power generation from coal in the United States. 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. Until the second quarter of 2018, these restructuring actions achieved the goal of maintaining gross margins in the Babcock & Wilcox segment. Quantification of cost savings, however, is significantly dependent upon volume assumptions that have changed since the restructuring actions were initiated.
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, | Year Ended December 31, |
| (in thousands) | 2017 | 2016 | 2018 | 2017 |
Balance at beginning of period | $ | 2,253 |
| $ | 740 |
| $ | 2,244 |
| $ | 1,809 |
|
| Restructuring expense | 13,923 |
| 21,939 |
| 16,415 |
| 13,515 |
|
| Payments | (13,857 | ) | (20,426 | ) | (11,300 | ) | (13,080 | ) |
| Balance at December 31 | $ | 2,319 |
| $ | 2,253 |
| $ | 7,359 |
| $ | 2,244 |
|
For the year ended December 31, 2016, we recorded cash restructuring charges of $19.9 million that impacted the accrued restructuring liability.
Accrued restructuring liabilities at December 31, 20172018 and 20162017 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. We did not recognize non-cash restructuring expense in 2018. 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 costsSpin-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 (nownow known as BWX Technologies, Inc.) or "BWXT". In the years ended December 31, 2018, 2017, and 2016, we recognized spin-off costs of $0.3 million, $1.2 million, and $3.8 million respectively. DuringIn each of the years ended December 31, 2018 and 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 from our former parent, BWXT, executive officers, key employees, members of the board of directors and consultants of B&Wthe Company were eligible to participate in the 2010 Long-Term Incentive Plan of The Babcock & Wilcox Company (the "BWC"BWXT Plan"). Effective June 30, 2015, executive officers, key employees, members of the board of directors and consultants of B&Wthe Company are eligible to participate in the 2015 Long-Term Incentive Plan of Babcock & Wilcox Enterprises, Inc. (the "Plan""BW Plan"). The BW Plan permits grants of nonqualified stock options, incentive stock options, stock appreciation rights, restricted stock, restricted stock units, performance shares, performance units, and cash incentive awards. The BW Plan was amended and restated in 2018 and 2016 to increase the number of shares available for issuance by 1.0 million shares and 2.5 million shares.shares, respectively. The number of shares available for award grants under the BW Plan, as amended and restated, is 8.39.3 million, of which 0.23.7 million remain available as of December 31, 2017.2018.
In connection to the 2018 Rights Offering, as described in Note 22, eligible participants of the BWXT Plan with outstanding stock options, restricted stock units, and performance-based share awards were awarded with additional corresponding shares to preserve the value of the employees outstanding equity.
In connection with the spin-off, outstanding stock options and restricted stock units granted under the BWCBWXT Plan prior to 2015 were replaced with both an adjusted BWCBWXT award and a new B&WBW 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 BWCBWXT 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 BWCBWXT common stock and B&WBW common stock, determined by reference to the ratio of one share of B&WBW common stock being distributed for every two shares of BWCBWXT common stock in the spin-off, in each case with the same vesting terms as the original awards.
Company stockStock options
Stock options were awarded in 2018 and 2016. There were no stock options awarded in 2017. The fair value of each option grant awarded in 20162018 and 20152016 was estimated at the date of grant using Black-Scholes, with the following weighted-average assumptions:
| | | | Year Ended December 31, | Year Ended December 31, |
| | 2016 | 2015 | 2018 | 2016 |
| Risk-free interest rate | 1.14 | % | 1.38 | % | 2.69 | % | 1.14 | % |
| Expected volatility | 25 | % | 28 | % | 64 | % | 25 | % |
| Expected life of the option in years | 3.95 |
| 3.96 |
| 3.95 |
| 3.95 |
|
| 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 20162018 and 20152016 because we did not expect to pay dividends on the dates the 20162018 and 20152016 stock options were awarded.
The following table summarizes activity for our stock options the year ending December 31, 2017:2018:
| | | (share data in thousands) | Number of Shares | Weighted-Average Exercise Price | Weighted-Average Remaining Contractual Term (in years) | Aggregate Intrinsic Value (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 |
| | | 2,478 |
| $ | 18.28 |
| | |
| Granted | — |
| — |
| | | 445 |
| 4.67 |
| | |
| Exercised | (24 | ) | 15.04 |
| | | — |
| — |
| | |
| Cancelled/expired/forfeited | (150 | ) | 18.50 |
| | | (877 | ) | 7.99 |
| | |
| Rights offering equitable adjustment | | 2,346 |
| — |
| | |
| Outstanding at end of period | 2,478 |
| $ | 18.28 |
| 5.46 |
| $ | — |
| 4,392 |
| $ | 10.54 |
| 6.04 | $ | — |
|
| Exercisable at end of period | 1,844 |
| $ | 18.14 |
| 4.69 |
| $ | — |
| 3,390 |
| $ | 12.03 |
| 5.12 | $ | — |
|
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, 2017.2018. 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 yearsyear ended December 31, 2016 and 2015, was $4.03 and $4.80, respectively.$4.03.
During the years endedAs of December 31, 2017, 2016 and 2015, the total intrinsic value of stock options exercised was not significant, and was $0.7 million and $2.3 million, respectively.as of December 31, 2016. The actual tax benefits realized related to the stock options exercised duringfor the yearsyear ended December 31, 2017 and 2016 were not significant and were $0.3 million respectively.for the year ended December 31, 2016.
Company restrictedRestricted stock units
Nonvested restricted stock units activity for the year ending December 31, 20172018 was as follows:
| | | (share data in thousands) | Number of Shares | Weighted-Average Grant Date Fair Value | Number of Shares | Weighted-Average Grant Date Fair Value |
| Nonvested at beginning of period | 712 |
| $ | 19.14 |
| 2,227 |
| $ | 7.63 |
|
| Granted | 1,902 |
| 5.35 |
| 216 |
| 5.76 |
|
| Vested | (282 | ) | 18.48 |
| (665 | ) | 12.42 |
|
| Cancelled/forfeited | (105 | ) | 15.00 |
| (1,528 | ) | 5.45 |
|
| Rights offering equitable adjustment | | 683 |
| — |
|
| Nonvested at end of period | 2,227 |
| $ | 7.63 |
| 933 |
| $ | 5.33 |
|
The actual tax benefits realized related to the restricted stock units vested during the year ended December 31, 2018, 2017 and 2016 were $0.6 million, $1.1 million and $2.7 million, respectively.
Company performance-based98
Performance-based restricted stock units
During 2017 and 2016, we granted certain B&W employees performance-based restricted stock units ("PSUs") under the BW 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)("ROIC"), cumulative earnings per share (EPS)("EPS") and total shareholder return (TSR)("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 | 2017 | 2016 |
| Risk-free interest rate | 1.54 | % | 0.96 | % | 1.54 | % | 0.96 | % |
| Expected volatility | 42 | % | 25 | % | 42 | % | 25 | % |
| Expected life of the option in years | 2.83 |
| 2.83 |
| 2.83 |
| 2.83 |
|
| Expected dividend yield | — | % | — | % | — | % | — | % |
PSU activity for the year ending December 31, 20172018 was as follows:
| | | (share data in thousands) | Number of Shares | Weighted-Average Grant Date Fair Value | Number of Shares | Weighted-Average Grant Date Fair Value |
| Nonvested at beginning of period | 451 |
| $ | 19.29 |
| 1,135 |
| $ | 12.75 |
|
| Granted | 828 |
| 9.74 |
| — |
| — |
|
| Vested | (3 | ) | 9.67 |
| — |
| — |
|
| Cancelled/forfeited | (141 | ) | 14.07 |
| (618 | ) | 9.36 |
|
| Rights offering equitable adjustment | | 402 |
| — |
|
| Nonvested at end of period | 1,135 |
| $ | 12.75 |
| 919 |
| $ | 9.74 |
|
Company performance-based,Performance-based, cash settled units
In 2017, we granted certain B&W employees cash-settled performance units under the BW 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, 20172018 was as follows:
| | | (share data in thousands) | Number of Shares | Weighted-Average Grant Date Fair Value | Number of Shares | Weighted-Average Grant Date Fair Value |
| Nonvested at beginning of period | 32 |
| $ | 18.53 |
| 1,799 |
| $ | 4.53 |
|
| Granted | 1,908 |
| 2.90 |
| — |
| — |
|
| Vested | (7 | ) | — |
| (707 | ) | 3.16 |
|
| Cancelled/forfeited | (134 | ) | 3.93 |
| (357 | ) | 2.21 |
|
| Rights offering equitable adjustment | | 9 |
| — |
|
| Nonvested at end of period | 1,799 |
| $ | 4.53 |
| 744 |
| $ | 4.73 |
|
Stock Appreciation Rights
In December 2018, we granted stock appreciation rights to certain employees ("Employee SARs") and to a non-employee related party, BRPI Executive Consulting, LLC, ("Non-employee SARs"). The Employee SARs and Non-employee SARs both expire ten years after the grant date and primarily vest 100% upon completion after the required years of service. Upon vesting, the Employee SARs and Non-employee SARs may be exercised within ten business days following the end of any calendar quarter during which the volume weighted average share price is greater than the share price goal. Upon exercise of the SARs, holders receive a cash-settled payment equal to the number of SARs that are being exercised multiplied by the difference between the stock price on the date of exercise minus the SARs base price. Employee SARs are issued under the BW Plan, and Non-employee SARs are issued under a Non-employee SARs agreement. The liability method is used to
recognize the accrued compensation expense with cumulatively adjusted revaluations to the then current fair value at each reporting date through final settlement.
We used the following assumptions to determine the fair value of the SARs granted to employees and non-employee in 2018:
|
| | |
| Year Ended December 31, 2018 |
| Risk-free interest rate | 2.80 | % |
| Expected volatility | 46 | % |
| Expected life in years | 9.50 |
|
| Suboptimal exercise factor | 2.0x |
|
In making these assumptions, we based estimated volatility on the historical returns of the Company's stock price and selected guideline companies. We based risk-free rates on the corresponding U.S. Treasury spot rates for the expected duration at the date of grant, which we convert to a continuously compounded rate. We relied upon a suboptimal exercise factor, representing the ratio of the base price to the stock price at the time of exercise, to account for potential early exercise prior to the expiration of the contractual term. With consideration to the executive level of the SARs holders, a suboptimal exercise multiple of 2.0x was selected. Subject to vesting conditions, should the stock price achieve a value of 2.0x above the base price, we assume the holders will exercise prior to the expiration of the contractual term of the SARs. The expected term for the SARs is an output of our valuation model in estimating the time period that the SARs are expected to remain unexercised. Our valuation model assumes the holders will exercise their SARs prior to the expiration of the contractual term of the SARs.
The following table presents the changes in our outstanding Employee SARs and Non-employee SARs for the year ending December 31, 2018 and the associated weighted average values:
|
| | | | | | | | | | | | |
| (share data in thousands) | Number of Employee SARs | Number of Non-Employee SARs | Total Number of SARs | Weighted-Average Value | Weighted Average Exercise Price |
| Nonvested at beginning of period | — |
| — |
| — |
| $ | — |
| $ | — |
|
| Granted | 2,531 |
| 8,435 |
| 10,966 |
| 0.18 |
| 2.34 |
|
| Vested | — |
| — |
| — |
| — |
| — |
|
| Nonvested at end of period | 2,531 |
| 8,435 |
| 10,966 |
| $ | 0.18 |
| $ | 2.34 |
|
As of December 31, 2018, the total intrinsic value of the SARs was $2.3 million.
NOTE 10 – PROVISION FOR INCOME TAXES
We are subject to federal income tax in the United States and incomenumerous countries that have statutory tax rates different than the U.S. federal statutory rate of multiple state21%. The most significant of these foreign operations are located in Canada, Denmark, Germany, Italy, Mexico, Sweden and international jurisdictions.the United Kingdom with effective tax rates ranging between 19% and approximately 30%. 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 2013.2014. The United States Internal Revenue Service has completed examinations of the federal tax returns of BWCour former parent, BWXT, 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:
| | | | | | | | | Year Ended December 31, |
| (in thousands) | 2017 | 2016 | 2015 | 2018 | 2017 | 2016 |
| Balance at beginning of period | $ | 884 |
| $ | 1,141 |
| $ | 3,321 |
| $ | 1,204 |
| $ | 884 |
| $ | 1,141 |
|
| Increases based on tax positions taken in the current year | 277 |
| 178 |
| 88 |
| 588 |
| 277 |
| 178 |
|
| Increases based on tax positions taken in the prior years | 56 |
| 230 |
| 248 |
| 51 |
| 56 |
| 230 |
|
| Decreases based on tax positions taken in the prior years | (13 | ) | — |
| (1,161 | ) | — |
| (13 | ) | — |
|
| Decreases due to settlements with tax authorities | — |
| (665 | ) | (1,355 | ) | (140 | ) | — |
| (665 | ) |
| Decreases due to lapse of applicable statute of limitation | — |
| — |
| — |
| (203 | ) | — |
| — |
|
| Balance at end of period | $ | 1,204 |
| $ | 884 |
| $ | 1,141 |
| $ | 1,500 |
| $ | 1,204 |
| $ | 884 |
|
The $1.2Subject to the impact of valuation allowances discussed more fully below, the $1.5 million balance of unrecognized tax benefits at December 31, 20172018 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, | Year Ended December 31, |
| (in thousands) | 2017 | 2016 | 2018 | 2017 |
| Deferred tax assets: | | |
| Pension liability | $ | 58,810 |
| $ | 105,426 |
| $ | 66,652 |
| $ | 58,810 |
|
| Accrued warranty expense | 5,262 |
| 11,628 |
| 2,943 |
| 5,262 |
|
| Accrued vacation pay | 996 |
| 4,792 |
| 98 |
| 996 |
|
| Accrued liabilities for self-insurance (including postretirement health care benefits) | 3,910 |
| 6,596 |
| 4,653 |
| 3,910 |
|
| Accrued liabilities for executive and employee incentive compensation | 4,950 |
| 8,334 |
| 4,473 |
| 4,950 |
|
| Investments in joint ventures and affiliated companies | 10,422 |
| 10,742 |
| — |
| 10,422 |
|
| Long-term contracts | 6,801 |
| 10,318 |
| 27,623 |
| 6,801 |
|
| Accrued Legal Fees | 1,579 |
| 2,110 |
| 1,058 |
| 1,579 |
|
| Inventory Reserve | 1,842 |
| 2,445 |
| 1,595 |
| 1,842 |
|
| Property, plant and equipment | — |
| 1,587 |
| 1,200 |
| — |
|
| Net operating loss carryforward | 95,715 |
| 33,187 |
| 143,401 |
| 95,715 |
|
| State tax net operating loss carryforward | 21,658 |
| 15,372 |
| 21,017 |
| 21,658 |
|
| Capital loss carryforward | | 3,744 |
| — |
|
| Interest disallowance carryforward | | 21,550 |
| — |
|
| Foreign tax credit carryforward | 7,150 |
| 3,870 |
| 2,535 |
| 7,150 |
|
| Other tax credits | 5,678 |
| 737 |
| 6,642 |
| 5,678 |
|
| Other | 4,980 |
| 7,852 |
| 10,755 |
| 4,980 |
|
| Total deferred tax assets | 229,753 |
| 224,996 |
| 319,939 |
| 229,753 |
|
| Valuation allowance for deferred tax assets | (108,105 | ) | (40,484 | ) | (313,094 | ) | (108,105 | ) |
| Net, total deferred tax assets | 121,648 |
| 184,512 |
| 6,845 |
| 121,648 |
|
| | | |
| Deferred tax liabilities: | | |
| Investments in joint ventures and affiliated companies | | 30 |
| — |
|
| Long-term contracts | 569 |
| 3,601 |
| — |
| 569 |
|
| Intangibles | 21,215 |
| 21,892 |
| 9,595 |
| 21,215 |
|
| Property, plant and equipment | 2,835 |
| — |
| — |
| 2,835 |
|
| Undistributed foreign earnings | 1,314 |
| 500 |
| — |
| 1,314 |
|
| Goodwill | — |
| 1,125 |
| |
| Other | 2,445 |
| 2,885 |
| — |
| 2,445 |
|
| Total deferred tax liabilities | 28,378 |
| 30,003 |
| 9,625 |
| 28,378 |
|
| Net deferred tax assets | $ | 93,270 |
| $ | 154,509 |
| |
| Net deferred tax (liabilities) assets | | $ | (2,780 | ) | $ | 93,270 |
|
At December 31, 2017,2018, we had a valuation allowance of $108.1$313.1 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 thatIn the three months ended September 30, 2018, we recognized income tax expense of $94.3 million, which included $99.6 million of non-cash income tax charges to increase the valuation allowance against our remaining net deferred tax assets. Deferred tax assets are evaluated each period to determine whether it is more likely than not realizable through carrybacks, future reversalsthat those deferred tax assets will be realized in the future. This evaluation is performed under the framework of existing taxable temporary differencesASC 740, Income Taxes, and estimatesconsiders all positive and negative evidence. In our analysis at September 30, 2018, our weighing of future taxable income. Shouldpositive and negative evidence included an assessment of historical income by jurisdiction adjusted for recent dispositions and other nonrecurring items, as well as an evaluation of other qualitative factors such as the amendments to covenants in our U.S Revolving Credit Facility as described in Note 19 and our current and prior plans to mitigate our liquidity challenges as described in Note 1. The changes in circumstances in the third quarter of 2018 also included, among other items, the September 2018 sale of PBRRC, which had been generating income in the U.S. In reporting periods prior to the third quarter of 2018, our plans to
mitigate the liquidity challenges created by losses in the Vølund & Other Renewable segment primarily focused on the non-core asset sales and financing activities described in Note 1, but in October 2018, our plans to mitigate our liquidity challenges primarily depended upon realizing projected cost savings from our previously announced restructuring actions and achievement of our forecasted cash generation from our core operations. These third quarter 2018 changes in circumstances were reflected in the weight assigned to each piece of evidence considered and resulted in the judgment that a full valuation allowance against our remaining net deferred tax assets should be recorded at September 30, 2018, when we concludeassigned more weight to our liquidity challenges. We continue to have a full valuation allowance against our remaining net deferred tax assets as of December 31, 2018, as our assessment and conclusions remain unchanged from September 30, 2018. We will continue to weigh and assess the positive and negative evidence that exists as of each measurement date and the valuation allowances may be reversed in the future that any or allif sufficient positive evidence exists to outweigh the negative evidence. Any reversal 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 the income or loss for the period in which our consolidated financial statements. assessment changes. Valuation allowances do not limit our ability to use deferred tax assets in the future.
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 | Beginning
balance | Charges to costs
and expenses | Charged to
other accounts | Ending
balance |
| Year Ended December 31, 2018 | | $ | (108,105 | ) | $ | (204,727 | ) | $ | (262 | ) | $ | (313,094 | ) |
| Year Ended December 31, 2017 | $ | (40,484 | ) | $ | (61,021 | ) | $ | (6,600 | ) | $ | (108,105 | ) | (40,484 | ) | (61,021 | ) | (6,600 | ) | (108,105 | ) |
| Year Ended December 31, 2016 | (10,077 | ) | (29,307 | ) | (1,100 | ) | (40,484 | ) | (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%. IncomeLoss before the provision for income taxes was as follows: | | | | Year Ended December 31, | Year Ended December 31, |
| (in thousands) | 2017 | 2016 | 2015 | 2018 | 2017 | 2016 |
| United States | $ | (44,835 | ) | $ | 1,280 |
| $ | (20,748 | ) | $ | (166,269 | ) | $ | (46,673 | ) | $ | (10,208 | ) |
| Other than the United States | (269,364 | ) | (109,419 | ) | 40,953 |
| (389,532 | ) | (270,877 | ) | (109,419 | ) |
| Income before provision for income taxes | $ | (314,199 | ) | $ | (108,139 | ) | $ | 20,205 |
| |
| Loss before provision for income taxes | | $ | (555,801 | ) | $ | (317,550 | ) | $ | (119,627 | ) |
The provision for income taxes consisted of:
| | | | Year Ended December 31, | Year Ended December 31, |
| (in thousands) | 2017 | 2016 | 2015 | 2018 | 2017 | 2016 |
| Current: | | |
| United States – federal | $ | 100 |
| $ | 284 |
| $ | 24,084 |
| $ | 1,817 |
| $ | (239 | ) | $ | 284 |
|
| United States – state and local | 397 |
| (415 | ) | 3,458 |
| (276 | ) | 397 |
| (415 | ) |
| Other than in the United States | 8,612 |
| 4,504 |
| 8,250 |
| 3,339 |
| 8,215 |
| 4,504 |
|
| Total current | 9,109 |
| 4,373 |
| 35,792 |
| 4,880 |
| 8,373 |
| 4,373 |
|
| Deferred: | | |
| United States – Federal | 58,203 |
| 11,512 |
| (35,888 | ) | 84,203 |
| 57,475 |
| 7,287 |
|
| United States – state and local | 2,546 |
| 6,365 |
| (111 | ) | 10,020 |
| 2,903 |
| 6,353 |
|
| Other than in the United States | (5,042 | ) | (15,307 | ) | 3,878 |
| 3,121 |
| (5,042 | ) | (15,307 | ) |
| Total deferred (benefit) provision | 55,707 |
| 2,570 |
| (32,121 | ) | 97,344 |
| 55,336 |
| (1,667 | ) |
| Provision for income taxes | $ | 64,816 |
| $ | 6,943 |
| $ | 3,671 |
| $ | 102,224 |
| $ | 63,709 |
| $ | 2,706 |
|
The following is a reconciliation of the United States statutory federal tax rate (35%(21%) to the consolidated effective tax rate:
| | | | Year Ended December 31, | Year Ended December 31, |
| | 2017 | 2016 | 2015 | 2018 | 2017 | 2016 |
| United States federal statutory rate | 35.0 | % | 35.0 | % | 35.0 | % | 21.0 | % | 35.0 | % | 35.0 | % |
| State and local income taxes | 0.2 |
| (3.5 | ) | 13.8 |
| 0.5 |
| 0.3 |
| (3.1 | ) |
| Foreign rate differential | (9.5 | ) | (12.8 | ) | (13.1 | ) | 1.3 |
| (9.5 | ) | (11.8 | ) |
| Deferred Taxes - Change in Tax Rate | (19.9 | ) | — |
| — |
| 0.4 |
| (19.6 | ) | — |
|
| Tax credits | 0.9 |
| 3.0 |
| (14.7 | ) | (0.7 | ) | 0.9 |
| 2.7 |
|
| Dividends and deemed dividends from affiliates | (1.8 | ) | (0.2 | ) | 1.7 |
| — |
| (1.8 | ) | (0.2 | ) |
| Valuation allowances | (17.9 | ) | (28.1 | ) | 4.3 |
| (36.8 | ) | (17.7 | ) | (25.3 | ) |
| Goodwill impairment | (7.0 | ) | — |
| — |
| (1.4 | ) | (6.9 | ) | — |
|
| Uncertain tax positions | — |
| 0.3 |
| (6.6 | ) | — |
| — |
| 0.3 |
|
| Non-deductible expenses | 0.2 |
| (1.8 | ) | 2.4 |
| (0.6 | ) | 0.2 |
| (1.6 | ) |
| Manufacturing deduction | — |
| — |
| (2.5 | ) | |
| Other | (0.8 | ) | 1.7 |
| (2.1 | ) | (2.1 | ) | (1.0 | ) | 1.7 |
|
| Effective tax rate | (20.6 | )% | (6.4 | )% | 18.2 | % | (18.4 | )% | (20.1 | )% | (2.3 | )% |
We have tax effected foreign net operating loss benefits after taxcarryforwards ("NOLs") of $75.0$122.9 million available to offset future taxable income in certain foreign jurisdictions. Of thethese foreign net operating loss benefits, $1.7NOLs, $117.8 million is scheduleddo not expire and will be available indefinitely. The remaining foreign NOLs begin 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.
2020.
At December 31, 2017,2018, we have a tax effected United States federal net operating loss of $20.7$20.5 million. The$17.8 million of the United States federal net operating loss will begin to expire in 2037,2031 and we expect to fully utilize this net operating loss in future periods.the balance has an unlimited life. At December 31, 2017,2018, we have foreign tax credit carryovers of $7.2 million, against which we have a full valuation allowance.$2.5 million. At December 31, 2017,2018, we have tax effected state net operating loss benefits after tax of $21.7$21.0 million available to offset future taxable income in various states, against which we have $21.6 million of valuation allowance.states. Our state net operating loss carryforwards begin to expire in the year 2019.
All deferred tax assets, including NOLs, have also been fully offset by valuation allowances as of September 30, 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$2.3 million but U.S. income taxes would generally not be imposed upon such distributions. We have not established deferred taxes for these withholding taxes.
DuringAs a result of accumulations of the twelve months endedCompany's common stock among several large shareholders and the impact of the 2018 Rights Offering that was completed on April 30, 2018, we continue to monitor for the possibility of an ownership change as defined under Internal Revenue Code ("IRC") Section 382. Under IRC Section 382, a company has undergone an ownership change if shareholders owning at least 5% of the Company have increased their collective holdings by more than 50% during the prior three-year period. Based on information that is publicly available, the Company does not currently believe it has experienced an ownership change. However, a relatively small increase in ownership by any of our shareholders owning at least 5% of the Company could result in an ownership change. To illustrate, if we had experienced an ownership change as of December 31, 2017, we prospectively adopted Financial Accounting Standards Board ("FASB") Accounting Standards Update ("ASU") 2016-09, Compensation - Stock Compensation (Topic 718): Improvements2018, the future utilization of our federal NOLs would become limited to Employee Share-based Payment Accountingapproximately $1.7 million annually ($0.4 million tax effected). AdoptingThe actual determination of the new accounting standard resulted in a net $0.1 million income tax expense and $1.6 million income tax benefit inannual Section 382 limitation would be dependent upon the three and twelve months ending December 31, 2017, respectively, associated withvalue of the income tax effects of vested and exercised share-based compensation awards.Company multiplied by the long-term tax-exempt rate at the time the ownership change occurred.
New Tax Act
The United States Tax Cuts and Jobs Act (the “Tax Act”) was enacted on December 22, 2017 and introducesintroduced significant changes to the United States income tax law. Beginning in 2018, the Tax Act reducesreduced the United States statutory corporate income tax rate from 35% to 21% and createscreated 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 addition to the tax rate reduction and changes to the territorial nature of the US tax system, the Tax Act introduced a new limitation on interest deductions, a Foreign Derived Intangible Income (“FDII”) and new minimum tax on foreign sourced income, Global Low Taxed Intangible
Income (“GILTI”). The Company will account for GILTI as a period cost in the year the tax is incurred. In 2018, we did not report any FDII benefit or GILTI taxes but did incur an interest limitation of approximately $94.8 million. This disallowed interest expense will be available for carryforward and is not subject to expiration but can only be used in a future year when the net interest expense for that period (including carryforward amounts) exceeds the relevant annual limitation.
In connection with the transition to a modified territorial system, the Tax Act also establishesestablished a mandatory one-time deemed repatriation transition tax on currently deferred foreign earnings.
The SEC staff issued Staff Accounting Bulletin ("SAB 118"), which providesprovided 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 finalizecompleted our estimatesaccounting related to these items as described in SAB 118, with no changes to the provisional amounts recorded in 2017. The 2018 as we collect and analyze necessary data, and interpret additional guidance that becomes available.
Provisional amounts foreffective tax rate reconciliation reflects the following income tax effects ofcorporate rate reductions enacted by the Tax Act have been recorded as of December 31, 2017:Act.
Deferred tax effects
We
At December 31, 2017, we remeasured our deferred taxes and recorded a deferred tax expense of $62.4 million. ThisThe fourth quarter 2017 amount consistsconsisted 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.carryforwards.
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,determined, 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 becauseBecause we havehad estimated an E&P deficit, we havedid not recordedrecord a Transition Tax. We are continuing to gather additional information to more precisely compute final E&P, including the computationTax at December 31, 2017 and as stated above, we completed our analysis and did not revise that estimate as of 2017 current year E&P which we will finalize with the 2017 tax return.December 31, 2018.
NOTE 11 – COMPREHENSIVE INCOME
Gains and losses deferred in accumulated other comprehensive income (loss) ("AOCI") are reclassified and recognized in the consolidated statementsConsolidated Statements of operationsOperations once they are realized. The changes in the components of AOCI, net of tax, for the years ended December 31, 2018, 2017 2016 and 20152016 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 | ) |
|
| | | | | | | | | | | | | | | |
| (in thousands) | Currency translation gain (loss) | Net unrealized gain (loss) on investments (net of tax) | Net unrealized gain (loss) on derivative instruments | Net unrecognized gain (loss) related to benefit plans (net of tax) | Total |
| 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 | ) |
| Reclassified from AOCI to net income (loss) | — |
| — |
| (3,030 | ) | 150 |
| (2,880 | ) |
| Net 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 |
|
| Reclassified from AOCI to net income (loss) | — |
| (24 | ) | (2,269 | ) | (2,955 | ) | (5,248 | ) |
| Net 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 | ) |
ASU 2016-1 cumulative adjustment(1) | — |
| (38 | ) | — |
| — |
| (38 | ) |
| Other comprehensive income (loss) before reclassifications | 16,452 |
| — |
| 890 |
| (22 | ) | 17,320 |
|
| Reclassified from AOCI to net income (loss) | 551 |
| — |
| (1,265 | ) | (2,740 | ) | (3,454 | ) |
Amounts reclassified from AOCI to pension and other accumulated postretirement benefit liabilities and deferred income taxes(2) | — |
| — |
| — |
| (2,831 | ) | (2,831 | ) |
| Net other comprehensive income (loss) | 17,003 |
| (38 | ) | (375 | ) | (5,593 | ) | 10,997 |
|
| Balance at December 31, 2018 | $ | (10,834 | ) | $ | — |
| $ | 1,362 |
| $ | (1,960 | ) | $ | (11,432 | ) |
(1) ASU 2016-1, Financial Instruments-Overall: Recognition and Measurement of Financial Assets and Financial Liabilities, requires investments to be measured at fair value through earnings each reporting period as opposed to changes in fair value being reported in other comprehensive income. The standard is effective as of January 1, 2018 and requires application by means of a cumulative-effect adjustment to the balance sheet as of the beginning of the fiscal year of adoption.
(2)Includes the reclassification of the unamortized balance of the curtailment gain, net of tax as described in Note 18.
The amounts reclassified out of AOCI by component and the affected consolidated statementsConsolidated Statements of operationsOperations 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, | Line items in the Consolidated Statements of Operations affected by reclassifications from AOCI | Year Ended December 31, |
| 2017 | 2016 | 2015 | 2018 | 2017 | 2016 |
| Release of currency translation gain with the sale of equity method investment | | Equity in income and impairment of investees | $ | (551 | ) | $ | — |
| $ | — |
|
| | | Provision for income taxes |
|
| — |
| — |
|
| | | Net loss | $ | (551 | ) | $ | — |
| $ | — |
|
| | | | |
| Derivative financial instruments | Revenues | $ | 10,059 |
| $ | 4,624 |
| $ | 546 |
| Revenues | $ | 1,638 |
| $ | 10,059 |
| $ | 4,624 |
|
| | Cost of operations | (118 | ) | 195 |
| 155 |
| Cost of operations | (15 | ) | (118 | ) | 195 |
|
| | Other-net | (7,438 | ) | (1,221 | ) | (24 | ) | Other-net | — |
| (7,438 | ) | (1,221 | ) |
| | Total before tax | 2,503 |
| 3,598 |
| 677 |
| Total before tax | 1,623 |
| 2,503 |
| 3,598 |
|
| | Provision for income taxes | 234 |
| 568 |
| 149 |
| Provision (benefit) for income taxes | 358 |
| 234 |
| 568 |
|
| | Net income | $ | 2,269 |
| $ | 3,030 |
| $ | 528 |
| Net income | $ | 1,265 |
| $ | 2,269 |
| $ | 3,030 |
|
| | | | | |
| Amortization of prior service cost on benefit obligations | Cost of operations | $ | 2,912 |
| $ | 254 |
| $ | (1,475 | ) | Benefit plans, net | $ | 3,002 |
| $ | 2,912 |
| $ | 254 |
|
| | Provision for income taxes | (43 | ) | 404 |
| (1,168 | ) | Provision (benefit) for income taxes | 262 |
| (43 | ) | 404 |
|
| | Net income (loss) | $ | 2,955 |
| $ | (150 | ) | $ | (307 | ) | Net income (loss) | $ | 2,740 |
| $ | 2,955 |
| $ | (150 | ) |
| | | | | |
| Realized gain on investments | Other-net | $ | 38 |
| $ | — |
| $ | (42 | ) | Other-net | $ | — |
| $ | 38 |
| $ | — |
|
| | Provision for income taxes | 14 |
| — |
| (15 | ) | Provision for income taxes | — |
| 14 |
| — |
|
| | Net income (loss) | $ | 24 |
| $ | — |
| $ | (27 | ) | Net income | $ | — |
| $ | 24 |
| $ | — |
|
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:
| | | | | | | Year Ended December 31, |
| (in thousands) | December 31, 2017 | December 31, 2016 | 2018 | 2017 |
| Raw materials and supplies | $ | 60,708 |
| $ | 61,630 |
| $ | 44,833 |
| $ | 54,291 |
|
| Work in progress | 7,867 |
| 6,803 |
| 5,348 |
| 6,918 |
|
| Finished goods | 13,587 |
| 17,374 |
| 11,142 |
| 11,708 |
|
| Total inventories | $ | 82,162 |
| $ | 85,807 |
| $ | 61,323 |
| $ | 72,917 |
|
NOTE 13 – EQUITY METHOD INVESTMENTS
As of December 31, 2018, we do not have any remaining investments in equity method investees. During the first quarter of 2018, we sold our interest in BWBC to our joint venture partner in China for approximately $21.1 million, resulting in a gain of approximately $6.5 million, which was classified in equity income of investees in the Consolidated Statement of Operations. Proceeds from this sale, net of $1.3 million of withholding tax, were $19.8 million. Our former equity method investment in BWBC had a manufacturing facility that designed, manufactured, produced and sold various power plant and industrial boilers, primarily in China.
In July 2018, we completed the sale of our investment in TBWES together with the settlement of related contractual claims and received $15.0 million in cash, of which $7.7 million related to our investment in TBWES and $7.3 million of proceeds were used to pay outstanding claims. In July 2018, the AOCI related to cumulative currency translation loss from our
investment in TBWES of $2.6 million was also recognized as a loss and is included in foreign exchange with other income (expense) in our consolidated statement of operations. TBWES had a manufacturing facility that produced 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, at which time we recorded in an $18.2 million other-than-temporary-impairment to the expected recoverable value of our investment in the joint venture. During the first quarter of 2018, based on a preliminary agreement to sell our investment in TBWES, we recognized an additional $18.4 million other-than-temporary-impairment. The impairment charge was based on the difference in the carrying value of our investment in TBWES and the preliminary sale price. These other-than-temporary-impairment losses were classified in equity income of investees in the Consolidated Statements of Operations.
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 the Consolidated Statement of Operations.
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 |
| Current assets | $ | 322,956 |
|
| Noncurrent assets | 137,081 |
|
| Total assets | $ | 460,037 |
|
| Current liabilities | $ | 342,178 |
|
| Noncurrent liabilities | 24,474 |
|
| Owners' equity | 93,385 |
|
| Total liabilities and equity | $ | 460,037 |
|
|
| | | | | | |
| | Year Ended December 31, |
| (in thousands) | 2017 | 2016 |
| Revenues | $ | 346,459 |
| $ | 488,101 |
|
| Gross profit | 32,682 |
| 76,986 |
|
| | | |
| (Loss) income before provision for income taxes | (10,626 | ) | 19,529 |
|
| Provision for income taxes | 1,907 |
| 3,715 |
|
| Net (loss) income | $ | (12,533 | ) | $ | 15,814 |
|
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) | 2018 | 2017 | 2016 |
| Equity income based on stated ownership percentages | $ | 250 |
| $ | 7,530 |
| $ | 7,898 |
|
| TBWES other-than-temporary impairment | (18,362 | ) | (18,193 | ) | — |
|
| Gain on sale of our interest in BWBC | 6,509 |
| — |
| — |
|
| 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 |
|
| Equity in income (loss) of investees | $ | (11,603 | ) | $ | (9,867 | ) | $ | 16,440 |
|
Our transactions with unconsolidated affiliates were as follows:
|
| | | | | | | | | |
| | Year Ended December 31, |
| (in thousands) | 2018 | 2017 | 2016 |
| Sales to | $ | — |
| $ | 7,143 |
| $ | 17,220 |
|
| Purchases from | — |
| 12,470 |
| 32,490 |
|
Dividends received (1) | 890 |
| 50,134 |
| 12,160 |
|
Capital contributions (2) | — |
| — |
| 26,256 |
|
NOTE 14(1) – INTANGIBLE ASSETSincludes $48.1 million, $6.0 million in dividends received from BWBC in 2017 and 2016, 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 intangible assets are as follows:accounts receivable-other includes receivables from these unconsolidated affiliates of $5.8 million at December 31, 2017. |
| | | | | | |
| (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 |
|
NOTE 14 - GOODWILL
The following summarizes the changes in the carrying amount of intangible assets:goodwill as of December 31, 2018: |
| | | | | | |
| | 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 |
|
|
| | | | | | | | | | | | |
| (in thousands) | Babcock & Wilcox | Vølund & Other Renewable | SPIG | Total |
Balance at December 31, 2016 (1) (2) | $ | 46,220 |
| $ | 48,435 |
| $ | 68,432 |
| $ | 163,087 |
|
| Currency translation adjustments | 1,150 |
| 1,530 |
| 6,814 |
| 9,494 |
|
| 2017 impairment charges | — |
| (49,965 | ) | (36,938 | ) | (86,903 | ) |
Balance at December 31, 2017 (1) (2) | $ | 47,370 |
| $ | — |
| $ | 38,308 |
| $ | 85,678 |
|
| Currency translation adjustments | (262 | ) | — |
| (768 | ) | (1,030 | ) |
| 2018 impairment charges | — |
| — |
| (37,540 | ) | (37,540 | ) |
Balance at December 31, 2018 (2) | $ | 47,108 |
| $ | — |
| $ | — |
| $ | 47,108 |
|
(1) Goodwill for MEGTEC and Universal are included in noncurrent assets of discontinued operations. See Note 4.
The January 11, 2017 acquisition(2) Accumulated goodwill impairments were $50.0 million for the Vølund & Other Renewable segment as 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$74.4 million and $36.9 million for the SPIG segment as of December 31, 2016,2018 and December 31, 2017, 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 |
|
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,December 31, 2016, we had not recorded any goodwill impairment charges.
Our annualIn January 2017, the FASB issued ASU 2017-04, Intangibles—Goodwill and Other (Topic 350), Simplifying the Test for Goodwill Impairment (ASU 2017-04). The standard simplifies the subsequent measurement of goodwill by removing the requirement to perform a hypothetical purchase price allocation to compute the implied fair value of goodwill to measure impairment. Instead, goodwill impairment assessment is performedmeasured as the difference between the fair value of the reporting unit and the carrying value of the reporting unit. The standard also clarifies the treatment of the income tax effect of tax-deductible goodwill when measuring goodwill impairment loss. We early adopted ASU 2017-04 on OctoberApril 1, of each year (the "annual assessment" date); however, events during 2017 have required two interim assessments of all six2018, effective the first day of our 2018 second quarter.
Goodwill is tested for impairment annually and when impairment indicators exist. Interim impairment testing as of June 30, 2018 was performed for the SPIG reporting units. Inunit due to lower bookings in the second quarter of 2017, significant charges2018 than previously forecasted, which resulted in a reduction in the forecast for the reporting unit. In this test, we compared the fair value of the reporting unit to its carrying value to measure goodwill impairment loss as required by ASU 2017-04. Fair value was determined using the combination of a discounted cash flow method (income approach) and the guideline public company method (market comparable approach), weighted equally in determining the fair value. The market comparable approach estimates fair value using market multiples of various financial measures compared to a set of comparable public companies. Key Level 3 unobservable inputs in our Renewable segment were considered to bevaluation included cash flows and long-term growth rates reflective of management's forecasted outlook, and discount rates inclusive of risk adjustments consistent with current market conditions. A discount rate of 14.5% was used, which is based on the weighted average cost of capital using guideline public company data, factoring in current market data and company-specific risk factors. As a triggering event forresult of the interim assessment asimpairment test, we recognized a $37.5 million impairment of goodwill in the SPIG reporting unit at June 30, 2017, which2018. After the impairment, the SPIG reporting unit did not indicate impairment. have any remaining goodwill.
During the third quarter of 2017,2018, we established a full valuation allowance on the majority of its U.S. deferred tax assets. Substantially all of those U.S. deferred tax assets related to the Babcock & Wilcox reporting unit such that the establishment of the valuation allowance reduced the carrying value of the Babcock & Wilcox reporting unit to a negative amount. Within the Babcock & Wilcox segment, $38.3 million of goodwill was allocated to the Babcock & Wilcox reporting unit that had a negative carrying value as of September 30, 2018. An analysis was performed as of September 30, 2018 noting no indicators of impairment for this reporting unit.
During the annual impairment analysis as of October 1, 2018, which was performed in a manner consistent with the methodology described above, the fair value of the Babcock & Wilcox and Construction reporting units exceeded their carrying value and no impairment of goodwill was recognized. The discount rates used in this analysis were 14.5% and 14.0% for the Babcock & Wilcox and Construction reporting units, respectively, which were the only reporting units with goodwill balances remaining as of the analysis date. Reasonable changes in assumptions for our Babcock & Wilcox and Construction reporting units also would not indicate impairment because of the positive fair value of the Babcock & Wilcox reporting unit compared with its negative carrying value and the 118% headroom indicated by the test for the Construction reporting unit.
Interim impairment testing as of December 31, 2018 was performed for all reporting units due to significant decrease in the Company's market capitalization significantly decreased to below our equityduring the quarter. This analysis was performed in a manner consistent with the methodology described above and the results demonstrated that the fair value of the Babcock & Wilcox and Construction reporting units exceeded their carrying value and no impairment of goodwill was recognized. The discount rates used in this analysis were 12.5% and 13.0% for the Babcock & Wilcox and Construction reporting units, respectively, which was considered to be a trigger for a second interim assessment. Additionally,were the forecast was reducedonly reporting units with goodwill balances remaining as of the analysis date. Reasonable changes in assumptions for our SPIGBabcock & Wilcox and Construction reporting unit based on a change inalso would not indicate impairment because of the market strategy implementedpositive fair value of the Babcock & Wilcox reporting unit compared with its negative carrying value and the 98% headroom indicated by the new segment management to focus on core geographies and products, which we considered to be another triggering eventtest for an interim assessment duringthe Construction reporting unit.
In the third quarter of 2017. The second2017, we completed an 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 asthat was performed in a manner consistent with the methodology described above and recorded $50.0 million of October 1, 2017 did not indicate additional impairment.
Assessing goodwill for impairment involves a two step test. Step 1 ofcharges in the test compares the fair value of aVølund & Other Renewable reporting unit with its carrying amount, including goodwill. If the carrying amount ofdue to significant charges incurred that attributed to 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. AsAlso, as a result of the increaseour analysis in the discount rate and an increase in the carrying valuethird quarter 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 indicatedrecorded a $36.9 million 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 approachescharge due to a short-term decrease in profitability attributable to specific, currentthen-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 eachquarter 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.2017.
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:110
|
| | | | | |
| | 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 15– WARRANTY EXPENSEINTANGIBLE ASSETS
ChangesOur intangible assets are as follows: |
| | | | | | |
| | Year Ended December 31, |
| (in thousands) | 2018 | 2017 |
Definite-lived intangible assets(1) | | |
| Customer relationships | $ | 24,764 |
| $ | 25,494 |
|
| Unpatented technology | 15,098 |
| 12,910 |
|
| Patented technology | 2,616 |
| 6,542 |
|
| Tradename | 12,566 |
| 13,951 |
|
| Backlog | 17,760 |
| 18,060 |
|
| All other | 9,728 |
| 7,611 |
|
| Gross value of definite-lived intangible assets | 82,532 |
| 84,568 |
|
| Customer relationships amortization | (17,219 | ) | (12,455 | ) |
| Unpatented technology amortization | (3,760 | ) | (2,184 | ) |
| Patented technology amortization | (2,348 | ) | (2,213 | ) |
| Tradename amortization | (3,672 | ) | (3,042 | ) |
| Acquired backlog amortization | (17,760 | ) | (16,622 | ) |
| All other amortization | (8,285 | ) | (7,292 | ) |
| Accumulated amortization | (53,044 | ) | (43,808 | ) |
| Net definite-lived intangible assets | $ | 29,488 |
| $ | 40,760 |
|
| Indefinite-lived intangible assets | | |
| Trademarks and trade names | $ | 1,305 |
| $ | 1,305 |
|
| Total intangible assets, net | $ | 30,793 |
| $ | 42,065 |
|
(1) Intangible assets for MEGTEC and Universal are included in noncurrent assets of discontinued operations. See Note 4.
The following summarizes the changes in the carrying amount of our accrued warranty expense are as follows:intangible assets:
|
| | | | | | | | | |
| | 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 |
|
|
| | | | | | | | | |
| | Year Ended December 31, |
| (in thousands) | 2018 | 2017 | 2016 |
| Balance at beginning of period | $ | 42,065 |
| $ | 48,622 |
| $ | 11,293 |
|
| Business acquisitions & adjustments | — |
| — |
| 55,438 |
|
| Amortization expense | (6,715 | ) | (11,049 | ) | (15,789 | ) |
| Impairment expense | (2,521 | ) | — |
| — |
|
| Currency translation adjustments and other | (2,036 | ) | 4,492 |
| (2,320 | ) |
| Balance at end of the period | $ | 30,793 |
| $ | 42,065 |
| $ | 48,622 |
|
Amortization of intangible assets is included in cost of operations and SG&A in our Consolidated Statement of Operations, but it is not allocated to segment results.
Long-lived assets, including intangible assets, are reviewed for impairment annually, or whenever circumstances indicate that the carrying amount might not be recoverable. The circumstances leading to the goodwill impairments as of June 30, 2018 and September 30, 2017 also triggered evaluations for the SPIG reporting unit. In our tests as of June 30, 2018 and September 30, 2017, as well as our annual test as of October 1, 2018, the sum of the undiscounted cash flows and the residual value of the primary assets exceeded the carrying value of the SPIG asset group and no impairment was indicated. In the fourth quarter of 2018, a strategic decision was made to exit certain geographies of the SPIG segment, and as a result, $2.5 million of the customer relationship and other intangible assets related to these geographies were impaired. As of December 31, 2018, and December 31, 2017, the SPIG reporting unit had $25.0 million and $32.7 million of identifiable intangible assets, net of accumulated amortization, respectively.
During the years endedAs of December 31, 20172018, the Vølund asset group unit had $2.0 million of identifiable intangible assets, net of accumulated amortization. In our annual impairment test as of October 1, 2018 and 2016, our Power segment reduced its accrued warranty expense by $9.1 million and $4.4 million, respectively, to reflect the expirationinterim test as 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, 20172018, the sum of the undiscounted cash flows and 2016, respectively.the residual value of the primary assets exceeded the carrying value of the Vølund asset group and no impairment was indicated.
Estimated future intangible asset amortization expense is as follows (in thousands):
|
| | |
| Year ending | Amortization expense |
| December 31, 2019 | 4,226 |
|
| December 31, 2020 | 3,523 |
|
| December 31, 2021 | 3,303 |
|
| December 31, 2022 | 3,225 |
|
| December 31, 2023 | 3,216 |
|
| Thereafter | 11,995 |
|
NOTE 16 – PROPERTY, PLANT & EQUIPMENT
Property, plant and equipment less accumulated depreciation is as follows:
|
| | | | | | |
| | Year Ended December 31, |
| (in thousands) | 2018 | 2017 |
| Land | $ | 3,575 |
| $ | 3,631 |
|
| Buildings | 106,238 |
| 107,944 |
|
| Machinery and equipment | 181,825 |
| 205,331 |
|
| Property under construction | 2,290 |
| 5,979 |
|
| | 293,928 |
| 322,885 |
|
| Less accumulated depreciation | 203,036 |
| 208,178 |
|
| Net property, plant and equipment | $ | 90,892 |
| $ | 114,707 |
|
In September 2018, we relocated our corporate headquarters to Barberton, Ohio from Charlotte, North Carolina. At the same time, we announced that we would consolidate most of our Barberton and Copley, Ohio operations into new, leased office space in Akron, Ohio in approximately the third quarter of 2019. We do not expect to incur significant relocation costs; however, we expect $7.0 million of accelerated depreciation to be recognized through mid-2019, of which $2.9 million was recognized in the year ended December 31, 2018.
NOTE 17 – WARRANTY EXPENSE
We may offer assurance type warranties on products and services we sell. Changes in the carrying amount of our accrued warranty expense are as follows:
|
| | | | | | | | | |
| | Year Ended December 31, |
| (in thousands) | 2018 | 2017 | 2016 |
| Balance at beginning of period | $ | 33,514 |
| $ | 36,520 |
| $ | 35,819 |
|
| Additions | 33,095 |
| 22,373 |
| 22,117 |
|
| Expirations and other changes | (5,963 | ) | (13,805 | ) | (10,531 | ) |
| Increases attributable to business combinations | — |
| — |
| 918 |
|
| Payments | (14,151 | ) | (13,622 | ) | (11,089 | ) |
| Translation and other | (1,378 | ) | 2,048 |
| (714 | ) |
| Balance at end of period | $ | 45,117 |
| $ | 33,514 |
| $ | 36,520 |
|
We accrue estimated expense included in cost of operations to satisfy contractual warranty requirements when we recognize the associated revenues on the related contracts, or in the case of a loss contract, the full amount of the estimated warranty costs is accrued when the contract becomes a loss contract. 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.
Warranty expense in the year ended December 31, 2018 includes a $14.2 million increase in expected warranty costs for the six European Vølund loss contracts based on experience from the startup and commissioning activities in the second quarter of 2018. The Babcock & Wilcox segment recorded additions to the warranty accrual to include specific provisions on industrial steam contracts totaling $4.3 million, $7.9 million and $2.1 million during the years ended December 31, 2018, 2017 and 2016, respectively. During the years ended December 31, 2018, 2017 and 2016, our Babcock & Wilcox segment reduced its accrued warranty expense by $4.5 million, $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 contractual warranty obligations.
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"U.S. Plan"), a noncontributory plan. As of 2006, the CompanyU.S. 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 CompanyU.S. Plan will cease. Furthermore, beginning on January 1, 2016, we began making service-based, cash contributionsceased. As of December 31, 2018, and 2017, only approximately 100 hourly union employees continue to a defined contribution plan for those employees impacted byaccrue benefits under the plan freeze.U.S. Plan.
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,BWXT, 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 also sponsor the Diamond Power Specialty Limited Retirement Benefits Plan (the "U.K. Plan") through our subsidiary. Benefit accruals under this plan ceased effective November 30, 2015. We have accounted for the GMP equalization following the U.K. High Court ruling during the fourth quarter of 2018 by recording prior service cost in accumulated other comprehensive income that will be amortized through net periodic pension cost over 15 years.
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, | Pension Benefits Year Ended December 31, | | Other Postretirement Benefits Year Ended December 31, |
| (in thousands) | 2017 | 2016 | | 2017 | 2016 | 2018 | 2017 | | 2018 | 2017 |
| Change in benefit obligation: | | | | | | |
| Benefit obligation at beginning of period | $ | 1,211,720 |
| $ | 1,205,163 |
| | $ | 11,907 |
| $ | 31,889 |
| $ | 1,248,529 |
| $ | 1,206,320 |
| | $ | 11,029 |
| $ | 11,907 |
|
| Service cost | 789 |
| 1,680 |
| | 15 |
| 23 |
| 729 |
| 687 |
| | 16 |
| 15 |
|
| Interest cost | 41,113 |
| 40,875 |
| | 319 |
| 897 |
| 40,411 |
| 41,014 |
| | 427 |
| 319 |
|
| Plan participants’ contributions | — |
| — |
| | 219 |
| 574 |
| — |
| — |
| | 210 |
| 219 |
|
| Curtailments | — |
| 266 |
| | — |
| — |
| 3,517 |
| — |
| | — |
| — |
|
| Settlements | 509 |
| 1,453 |
| | — |
| — |
| 57 |
| 509 |
| | — |
| — |
|
| Amendments | — |
| 231 |
| | — |
| (10,801 | ) | 743 |
| — |
| | 5,248 |
| — |
|
| Actuarial loss (gain) | 73,403 |
| 41,957 |
| | (141 | ) | (7,162 | ) | (66,326 | ) | 73,405 |
| | (1,296 | ) | (141 | ) |
| Loss (gain) due to transfer | — |
| 3,641 |
| | — |
| — |
| (1,142 | ) | — |
| | — |
| — |
|
| Foreign currency exchange rate changes | 6,222 |
| (5,099 | ) | | 126 |
| 50 |
| (4,689 | ) | 5,475 |
| | (142 | ) | 126 |
|
| Benefits paid | (78,954 | ) | (78,447 | ) | | (1,416 | ) | (3,563 | ) | (81,702 | ) | (78,881 | ) | | (1,473 | ) | (1,416 | ) |
| Benefit obligation at end of period | $ | 1,254,802 |
| $ | 1,211,720 |
| | $ | 11,029 |
| $ | 11,907 |
| $ | 1,140,127 |
| $ | 1,248,529 |
| | $ | 14,019 |
| $ | 11,029 |
|
| Change in plan assets: | | | | | | |
| Fair value of plan assets at beginning of period | $ | 922,868 |
| $ | 923,030 |
| | $ | — |
| $ | — |
| $ | 1,007,002 |
| $ | 922,868 |
| | $ | — |
| $ | — |
|
| Actual return on plan assets | 149,449 |
| 76,570 |
| | — |
| — |
| (67,691 | ) | 149,449 |
| | — |
| — |
|
| Employer contribution | 17,307 |
| 3,986 |
| | 1,197 |
| 2,989 |
| 20,059 |
| 17,234 |
| | 1,263 |
| 1,197 |
|
| Plan participants' contributions | — |
| — |
| | 219 |
| 574 |
| — |
| — |
| | 210 |
| 219 |
|
| Transfers | — |
| 2,744 |
| | — |
| — |
| (1,121 | ) | — |
| | — |
| — |
|
| Foreign currency exchange rate changes | (3,668 | ) | (5,015 | ) | | — |
| — |
| (4,622 | ) | (3,668 | ) | | — |
| — |
|
| Benefits paid | (78,954 | ) | (78,447 | ) | | (1,416 | ) | (3,563 | ) | (81,702 | ) | (78,881 | ) | | (1,473 | ) | (1,416 | ) |
| Fair value of plan assets at the end of period | 1,007,002 |
| 922,868 |
| | — |
| — |
| 871,925 |
| 1,007,002 |
| | — |
| — |
|
| Funded status | $ | (247,800 | ) | $ | (288,852 | ) | | $ | (11,029 | ) | $ | (11,907 | ) | $ | (268,202 | ) | $ | (241,527 | ) | | $ | (14,019 | ) | $ | (11,029 | ) |
| Amounts recognized in the balance sheet consist of: | | | | | | |
| Accrued employee benefits | $ | (1,930 | ) | $ | (1,099 | ) | | $ | (1,615 | ) | $ | (1,722 | ) | $ | (1,165 | ) | $ | (1,853 | ) | | $ | (1,985 | ) | $ | (1,615 | ) |
| Accumulated postretirement benefit obligation | — |
| — |
| | (9,414 | ) | (10,185 | ) | — |
| — |
| | (12,034 | ) | (9,414 | ) |
| Pension liability | (245,870 | ) | (287,753 | ) | | — |
| — |
| (269,613 | ) | (239,674 | ) | | — |
| — |
|
| Prepaid pension | — |
| — |
| | — |
| — |
| 2,576 |
| — |
| | — |
| — |
|
| Accrued benefit liability, net | $ | (247,800 | ) | $ | (288,852 | ) | | $ | (11,029 | ) | $ | (11,907 | ) | $ | (268,202 | ) | $ | (241,527 | ) | | $ | (14,019 | ) | $ | (11,029 | ) |
| Amount recognized in accumulated comprehensive income (before taxes): | Amount recognized in accumulated comprehensive income (before taxes): | | | Amount recognized in accumulated comprehensive income (before taxes): | | |
| Prior service cost (credit) | $ | 324 |
| $ | 432 |
| | $ | (7,792 | ) | $ | (10,801 | ) | $ | 943 |
| $ | 324 |
| | $ | (195 | ) | $ | (7,792 | ) |
| Supplemental information: | | | | | | |
| Plans with accumulated benefit obligation in excess of plan assets | Plans with accumulated benefit obligation in excess of plan assets | | | Plans with accumulated benefit obligation in excess of plan assets | | |
| Projected benefit obligation | $ | 1,254,802 |
| $ | 1,183,345 |
| | $ | — |
| $ | — |
| $ | 1,083,965 |
| $ | 1,248,529 |
| | $ | — |
| $ | — |
|
| Accumulated benefit obligation | $ | 1,272,010 |
| $ | 1,206,056 |
| | $ | 11,029 |
| $ | 11,907 |
| $ | 1,083,965 |
| $ | 1,266,902 |
| | $ | 14,019 |
| $ | 11,029 |
|
| Fair value of plan assets | $ | 1,007,002 |
| $ | 894,105 |
| | $ | — |
| $ | — |
| $ | 813,187 |
| $ | 1,007,002 |
| | $ | — |
| $ | — |
|
| Plans with plan assets in excess of accumulated benefit obligation | Plans with plan assets in excess of accumulated benefit obligation | | | Plans with plan assets in excess of accumulated benefit obligation | | |
| Projected benefit obligation | $ | — |
| $ | 28,375 |
| | $ | — |
| $ | — |
| $ | 56,162 |
| $ | — |
| | $ | — |
| $ | — |
|
| Accumulated benefit obligation | $ | — |
| $ | 28,375 |
| | $ | — |
| $ | — |
| $ | 56,162 |
| $ | — |
| | $ | — |
| $ | — |
|
| Fair value of plan assets | $ | — |
| $ | 28,763 |
| | $ | — |
| $ | — |
| $ | 58,738 |
| $ | — |
| | $ | — |
| $ | — |
|
Components of net periodic benefit cost (benefit) included in net income (loss) are as follows:
| | | | | | | | | | | | | | | Pension Benefits | | Other Benefits |
| | Pension Benefits | | Other Benefits | Year Ended December 31, | | Year Ended December 31, |
| (in thousands) | 2017 | 2016 | 2015 | | 2017 | 2016 | 2015 | 2018 | 2017 | 2016 | | 2018 | 2017 | 2016 |
| Service cost | $ | 789 |
| $ | 1,680 |
| $ | 13,677 |
| | $ | 15 |
| $ | 23 |
| $ | 24 |
| |
| Interest cost | 41,113 |
| 40,875 |
| 49,501 |
| | 319 |
| 897 |
| 1,143 |
| $ | 40,411 |
| $ | 41,014 |
| $ | 40,784 |
| | $ | 427 |
| $ | 319 |
| $ | 897 |
|
| Expected return on plan assets | (59,409 | ) | (61,939 | ) | (68,709 | ) | | — |
| — |
| — |
| (63,964 | ) | (59,409 | ) | (61,940 | ) | | — |
| — |
| — |
|
| Amortization of prior service cost | 103 |
| 250 |
| 307 |
| | (3,009 | ) | — |
| — |
| 124 |
| 103 |
| 250 |
| | (2,349 | ) | (3,009 | ) | — |
|
| Recognized net actuarial loss (gain) | (8,191 | ) | 31,932 |
| 41,574 |
| | (505 | ) | (7,822 | ) | (1,364 | ) | 68,771 |
| (8,201 | ) | 31,982 |
| | (1,297 | ) | (505 | ) | (7,822 | ) |
| Benefit plans, net | | 45,342 |
| (26,493 | ) | 11,076 |
| | (3,219 | ) | (3,195 | ) | (6,925 | ) |
| Service cost included in COS | | 729 |
| 687 |
| 1,595 |
| | 16 |
| 15 |
| 23 |
|
| Net periodic benefit cost (benefit) | $ | (25,595 | ) | $ | 12,798 |
| $ | 36,350 |
| | $ | (3,180 | ) | $ | (6,902 | ) | $ | (197 | ) | $ | 46,071 |
| $ | (25,806 | ) | $ | 12,671 |
| | $ | (3,203 | ) | $ | (3,180 | ) | $ | (6,902 | ) |
95Recognized net actuarial loss (gain) consists primarily of our reported actuarial loss (gain), curtailments, settlements, and the difference between the actual return on plan assets and the expected return on plan assets. Total net MTM adjustments for our pension and other postretirement benefit plans were losses (gains) of $67.5 million, $(8.7) million and $24.2 million in the years ended, December 31, 2018, 2017 and 2016, respectively. We have excluded the recognized net actuarial loss from our reportable segments and such amount has been reflected in Note 6 as the MTM adjustment in the reconciliation of reportable segment income (loss) to consolidated operating losses. The recognized net actuarial loss (gain) was recorded in "Benefit plans, net" in our Consolidated Statements of Operations.
PBRRC after the September 2018 sale of this business, the status change of these participants in the U.S. Plan resulted in a $3.5 million curtailment loss in the three months ended September 30, 2018, which also triggered an interim MTM of the U.S. Plan assets and liabilities that was a gain of $7.7 million in the three months ended September 30, 2018. Both the curtailment and the MTM are reflected in the "Recognized net actuarial loss (gain)" in the table above and are included in our Consolidated Statements of Operations in the "Benefit plans, net" line item.
During the first quarter ofthree months ended June 30, 2018 and March 31, 2017, lump sum payments from our Canadian pension planPlans resulted in a plan settlement gain of $0.1 million and a plan settlement loss of $0.4 million, whichrespectively. Both settlements also resulted intriggered an interim mark to market accounting forMTM of the pension plan. The mark to market adjustmentCanadian Plans assets and liabilities that was a gain of $0.4 million and a loss of $0.7 million in the first quarter ofthree months ended June 30, 2018 and March 31, 2017, was $0.7 million. The effect of these chargesrespectively. Both the settlement and mark to market adjustmentsthe MTM gains/losses are reflected in the "Recognized"Recognized net actuarial loss (gain)" in the table above. There were no significant plan settlements or interim mark to market adjustments afterabove and are included in our Consolidated Statements of Operations in the first quarter of 2017."Benefit plans, net" line item.
We terminated the Babcock & Wilcox Retiree Medical Plan (the "Retiree OPEB plan"Medical Plan") effective December 31, 2016. The Retiree OPEB planMedical 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,Medical Plan, the participants had the option to enroll in a third-party health care exchange, to which B&Wthe Company agreed to contribute up to $750 a year for each of the next three years (beginning in 2017) to a health reimbursement account ("HRA"), provided the plan participant had not yet reached their lifetime maximum under the terminated Retiree OPEB plan.Medical 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 enrollenrolled 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 planMedical 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 $3.0was being recognized as income through 2020. Participants in the Retiree Medical Plan filed a class action lawsuit against the Company in 2017 asserting that the change in health care coverage breached the Company's obligations under collective bargaining agreements. In April 2018, the court approved a settlement whereby the Company will contribute $1,000 a year for 2018 and 2019, and $1,100 a year thereafter for the life of a participant to an HRA. As a result of the settlement, the revised Retiree Medical Plan was actuarially remeasured as of April 1, 2018. The unamortized balance of the curtailment gain of $5.2 million and the related deferred tax of $1.3 million was recognized in 2017,reversed from AOCI 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$5.2 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 million in 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 lossother accumulated postretirement benefit liabilities for the annual MTM adjustmentactuarial value 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% | | —% | —% |
|
| | | | | |
| | Pension Benefits | | Other Benefits |
| | Year Ended December 31, | | Year Ended December 31, |
| | 2018 | 2017 | | 2018 | 2017 |
| Weighted average assumptions used to determine net periodic benefit obligations: | | | | | |
| Comparative single equivalent discount rate | 4.26% | 3.65% | | 4.02% | 3.33% |
| Rate of compensation increase | 0.07% | 0.10% | | — | — |
| Weighted average assumptions used to determine net periodic benefit cost: | | | | | |
| Comparative single equivalent discount rate | 3.65% | 4.11% | | 4.02% | 3.33% |
| Expected return on plan assets | 6.66% | 6.64% | | —% | —% |
| Rate of compensation increase | 0.07% | 0.10% | | —% | —% |
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)2018).
|
| | |
| 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 CompanyU.S. 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
2018 and 2016,2017, the investment return on domestic plan assets of the Master Trust (net of deductions for management fees) was approximately 17%(7)% and 9%17%, respectively.
The following is a summary of the asset allocations for the Master Trust at December 31, 2017 and 2016 by asset category:
| | | | | | Year Ended December 31, |
| | 2017 | 2016 | 2018 | 2017 |
| Asset Category: | | |
| Fixed Income (excluding United States Government Securities) | 33 | % | 32 | % | 33 | % | 33 | % |
| Commingled and Mutual Funds | 41 | % | 38 | % | 41 | % | 41 | % |
| United States Government Securities | 21 | % | 20 | % | 25 | % | 21 | % |
| Equity Securities | 3 | % | 7 | % | — | % | 3 | % |
| Derivatives | 1 | % | 1 | % | — | % | 1 | % |
| Other | 1 | % | 2 | % | 1 | % | 1 | % |
The target asset allocation for the domestic defined benefit planMaster Trust is 55% fixed income and 45% equities. We routinely reassess the target asset allocation with a goal of better aligning the timing of expected cash flows from those assets to the anticipated timing of benefit payments.
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").
U.K. Plan. The combined weighted average asset allocations of these plans at December 31, 2017 and 2016 by asset category were as follows:
| | | | | | Year Ended December 31, |
| | 2017 | | 2016 | 2018 | | 2017 |
| Asset Category: | | | | | | |
| Equity Securities and Commingled Mutual Funds | 41 | % | | 44 | % | 41 | % | | 41 | % |
| Fixed Income | 58 | % | | 55 | % | 58 | % | | 58 | % |
| Other | 1 | % | | 1 | % | 1 | % | | 1 | % |
The target allocation for 20172018 for the foreign plans, by asset class, is as follows:
| | | | Canadian Plans | | Diamond UK Plan | Canadian Plans | | U.K. Plan |
| Asset Class: | | | | | | |
| United States Equity | 27 | % | | 10 | % | 27 | % | | 10 | % |
| Global Equity | 23 | % | | 12 | % | 23 | % | | 12 | % |
| Fixed Income | 50 | % | | 78 | % | 50 | % | | 78 | % |
Fair value of plan assets
See Note 2325 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:value: | | | | | | | | | Year Ended December 31, | |
| (in thousands) | 12/31/2017 | Level 1 | Level 2 | 2018 | Level 1 | Level 2 |
| Fixed income | $ | 352,484 |
| $ | — |
| $ | 352,484 |
| $ | 304,961 |
| $ | — |
| $ | 304,961 |
|
| Equities | 33,525 |
| 33,525 |
| — |
| — |
| — |
| — |
|
| Commingled and mutual funds | 413,166 |
| — |
| 413,166 |
| 359,126 |
| — |
| 359,126 |
|
| United States government securities | 193,249 |
| 193,249 |
| — |
| 198,017 |
| 198,017 |
| — |
|
| Cash and accrued items | 14,578 |
| 12,585 |
| 1,993 |
| 9,821 |
| 9,816 |
| 5 |
|
| Total pension and other postretirement benefit assets | $ | 1,007,002 |
| $ | 239,359 |
| $ | 767,643 |
| $ | 871,925 |
| $ | 207,833 |
| $ | 664,092 |
|
The following is a summary of total investments for our plans measured at fair value at December 31, 2016:
| | | | | | | | | Year Ended December 31, | |
| (in thousands) | 12/31/2016 | Level 1 | Level 2 | 2017 | Level 1 | Level 2 |
| Fixed income | $ | 321,847 |
| $ | — |
| $ | 321,847 |
| $ | 352,484 |
| $ | — |
| $ | 352,484 |
|
| Equities | 83,441 |
| 78,268 |
| 5,173 |
| 33,525 |
| 33,525 |
| — |
|
| Commingled and mutual funds | 349,348 |
| 4,609 |
| 344,739 |
| 413,166 |
| — |
| 413,166 |
|
| United States government securities | 156,599 |
| 156,599 |
| — |
| 193,249 |
| 193,249 |
| — |
|
| Cash and accrued items | 11,633 |
| 9,394 |
| 2,239 |
| 14,578 |
| 12,585 |
| 1,993 |
|
| Total pension and other postretirement benefit assets | $ | 922,868 |
| $ | 248,870 |
| $ | 673,998 |
| $ | 1,007,002 |
| $ | 239,359 |
| $ | 767,643 |
|
Expected cash flows
| | | | Domestic Plans | | Foreign Plans | Domestic Plans | | Foreign Plans |
| (in thousands) | Pension Benefits 1 | Other Benefits | | Pension Benefits 1 | Other Benefits | Pension Benefits | 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(1) | | $ | 2,201 |
| $ | 1,900 |
| | $ | 1,768 |
| $ | 157 |
|
Expected benefit payments(2): | | | | |
| 2019 | 72,537 |
| 1,342 |
| | 3,095 |
| 167 |
| $ | 75,753 |
| $ | 1,857 |
| | $ | 2,641 |
| $ | 157 |
|
| 2020 | 73,104 |
| 854 |
| | 3,175 |
| 169 |
| 75,756 |
| 1,554 |
| | 2,712 |
| 159 |
|
| 2021 | 73,331 |
| 802 |
| | 3,252 |
| 163 |
| 75,412 |
| 1,434 |
| | 3,008 |
| 153 |
|
| 2022 | 73,434 |
| 746 |
| | 3,318 |
| 146 |
| 75,045 |
| 1,318 |
| | 2,792 |
| 137 |
|
| 2023-2027 | 359,308 |
| 2,975 |
| | 18,576 |
| 611 |
| |
| 2023 | | 74,631 |
| 1,206 |
| | 2,802 |
| 131 |
|
| 2024-2028 | | 357,776 |
| 4,510 |
| | 15,687 |
| 533 |
|
1 Pension benefit payments are made from their respective plan's trust. | |
(1) | Expected employer contributions to the U.S. Plan assume that relief under pension contribution waivers that were filed with the IRS in January 2019, which would defer minimum pension contributions for approximately one year to then be repaid over a five-year period. If the temporary hardship waivers are not fully granted, required employer contributions in 2019 could increase up to approximately $15 million in 2019. |
| |
(2) | 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%the first 8% of the participants 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 $9.5 million, $14.4 million $13.4 million and $8.9$13.4 million in the years ended December 31, 2018, 2017 and 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 statementsConsolidated 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$0.3 million and $0.1$0.4 million in the years ended December 31, 2018, 2017 and 2016, and 2015, respectively.
Multi-employer plans
One of our subsidiaries in the PowerBabcock & Wilcox 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 | | EIN/PIN | | Pension Protection Act Zone Status | | FIP/RP Status Pending/ Implemented | | Contributions | | Surcharge Imposed | | Expiration Date Of Collective Bargaining Agreement |
| | 2017 | | 2016 | | 2015 | | | 2018 | | 2017 | | 2016 | | |
| 2017 | | 2016 | | (in millions) | | 2018 | | 2017 | | (in millions) | |
| Boilermaker-Blacksmith National Pension Trust | | 48-6168020/ 001 | | Yellow | | Yellow | | Yes | | $ | 7.9 |
| | $ | 17.8 |
| | $ | 20.3 |
| | No | | Described
Below | | 48-6168020/ 001 | | Yellow | | Yellow | | Yes | | $ | 9.5 |
| | $ | 7.9 |
| | $ | 17.8 |
| | No | | Described
Below |
| All Other | | 2.0 |
| | 3.2 |
| | 4.6 |
| | | 4.9 |
| | 2.0 |
| | 3.2 |
| |
| | | $ | 9.9 |
| | $ | 21.0 |
| | $ | 24.9 |
| | | $ | 14.4 |
| | $ | 9.9 |
| | $ | 21.0 |
| |
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:
| | | | | | | Year Ended December 31, |
| (in thousands) | December 31, 2017 | December 31, 2016 | 2018 | 2017 |
| United States | $ | 94,300 |
| $ | 9,800 |
| $ | 144,900 |
| $ | 94,300 |
|
| Foreign | 9,173 |
| 14,241 |
| 606 |
| 9,173 |
|
| Total revolving debt | $ | 103,473 |
| $ | 24,041 |
| $ | 145,506 |
| $ | 103,473 |
|
United States revolving credit facilityU.S. Revolving Credit Facility
On May 11, 2015, we entered into a credit agreement with a syndicate of lenders ("(as amended, the "Amended Credit Agreement") in connection with our spin-off from The Babcock & Wilcox Company. TheCompany (now BWX Technologies, Inc.) which governs the U.S. Revolving Credit Facility and the Last Out Term Loans. Since June 2016, we have entered into a number of waivers and amendments ("the Amendments") to the Amended Credit Agreement, which isincluding those to avoid default. The U.S. Revolving Credit Facility as in effect at December 31, 2018 was scheduled to mature on June 30, 2020 providesand provided for a senior secured revolving credit facility initially in an aggregate amount of up to $600.0 million.$347.0 million, as amended and adjusted for completed asset sales. The proceeds from loans under the U.S. Revolving Credit AgreementFacility 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, includinglimits specified in 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.amendment described below.
The Amended Credit Agreement and our obligations under certain hedging agreements and cash management agreements with our lenders and their affiliates arecontinue to be (1) guaranteed by substantially all of our wholly owned domestic subsidiaries and certain of our foreign subsidiaries, but excluding our captive insurance subsidiary, and (2) secured by first-priority liens on certain assets owned by us and the guarantors. The AmendedU.S. Revolving Credit AgreementFacility 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 AmendedU.S. Revolving Credit AgreementFacility 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, suchexceptions. Such prepayments may require us to reduce the commitments under the AmendedU.S. Revolving Credit AgreementFacility 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 through December 31, 2018, revolving loans outstanding under the AmendedU.S. Revolving Credit AgreementFacility 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.are detailed in Note 26. A commitment fee of 1.0% per annum is charged on the unused portions of the revolving credit facility.U.S. Revolving Credit Facility. 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. A deferred fee of 2.5% was charged until October 9, 2018 and decreased to 1.5% effective October 10, 2018 due to achieving certain asset sales. A letter of credit fee of 2.50%2.5% 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%1.5% 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, theThese include a maximum permitted senior debt leverage ratio and a minimum consolidated interest coverage ratio, each as defined in the Amended Credit Agreement is:
8.50:1.0 for the quarter endedAgreement. Compliance with these ratios were waived as of 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 fornew ratios were established in the quarter endingsubsequent amendments described in Note 31, as we would not have otherwise been in compliance at 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.2018.
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, 2017,2018, borrowings under the AmendedU.S. Revolving Credit Agreement and foreign facilitiesFacility consisted of $103.5$144.9 million at an effectivea weighted average interest rate of 6.89%7.82%. Usage under the AmendedU.S. Revolving Credit AgreementFacility consisted of $94.3$144.9 million of borrowings, $7.4$29.1 million of financial letters of credit and $123.7$146.8 million of performance letters of credit. After giving effect to the March 1, 2018 amendment, atAt December 31, 2017,2018, we had approximately $221.4$25.0 million available for borrowings or to meet letter of credit requirements primarily based on trailing 12 month EBITDA (as definedour overall facility size, our borrowing sublimit and giving effect to the limited waivers described in Note 31. Since March 20, 2019, we have been nearly fully drawn on the U.S. Revolving Credit Facility, minimal additional amounts were available for borrowings or letters of credit, and we were in compliance with the terms of 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 closestAgreement subject to the minimum financial covenant thresholds at September 30, 2018.limited waivers that cumulatively extend through April 5, 2019. As a result, the U.S. Revolving Credit Facility balance as of December 31, 2018 is presented as a current liability in our Consolidated Balance Sheets.
Foreign revolving credit facilitiesRevolving Credit Facilities
Outside of the United States, we have revolving credit facilities in Turkey and, until the first quarter of 2018, in 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 aggregatelocal operations. At December 31, 2018 and each have a one year term. At December 31, 2017, we had aggregate borrowings under these facilities of $0.6 million and $9.2 million respectively. Our weighted average interest rate on these facilities was 40.00% and 6.07% at December 31, 2018 and December 31, 2017, respectively. In 2018, our banking counterparties in borrowings outstanding underTurkey began to require the conversion of these revolving credit facilities to Turkish lira denomination from euro denomination, resulting in correspondingly higher market interest rates. As of January 4, 2019, the foreign revolving credit facilities at an effective weighted-average interest rate of 6.07%. Subsequent to December 31, 2017, the foreign facilities were repaidpaid in full and extinguished.closed.
Letters of credit, bank guaranteesCredit, Bank Guarantees and surety bondsSurety 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 byopened outside of the United States revolving credit facilityU.S. Revolving Credit Facility as of December 31, 2018 and December 31, 2017 and 2016 was $269.1$175.9 million and $255.2$269.1 million, respectively. The aggregate value of all such letters of credit and bank guarantees that are partially secured by the United States revolving credit facilityU.S. Revolving Credit Facility as of December 31, 2017
2018 was $114.2$80.2 million. The aggregate value of the letters of credit provided by the Company's United States revolving credit facilityU.S. Revolving Credit Facility in support of letters of credit outside of the United States was $40.4$47.6 million as of December 31, 2017.2018.
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, theseThese 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, 2017,2018, bonds issued and outstanding under these arrangements in support of contracts totaled approximately $378.8$202.7 million. The aggregate value of the letters of credit provided by the U.S. Revolving Credit facility in support of surety bonds was $22.6 million.
Our ability to obtain and maintain sufficient capacity under our U.S. Revolving Credit Facility is essential to allow us to support the issuance of letters of credit, bank guarantees and surety bonds. Without sufficient capacity, our ability to support contract security requirements in the future will be diminished.
NOTE 20– LAST OUT TERM LOANS
The Last Out Term Loan components are as follows:
|
| | | |
| (in thousands) | December 31, 2018 |
| Proceeds | $ | 30,000 |
|
| Discount and fees | 5,111 |
|
| Paid-in-kind interest | 132 |
|
| Principal | 35,243 |
|
| Unamortized discount and fees | (4,594 | ) |
| Net debt balance | $ | 30,649 |
|
Tranche A-1
As referenced above, our Amended Credit Agreement required us to draw $30.0 million of net proceeds under Tranche A-1 of the Last Out Term Loans ("Tranche A-1"), which were borrowed from B. Riley FBR, Inc., a related party, in September and October 2018. On November 19, 2018, Tranche A-1 was assigned from B. Riley FBR, Inc., a related party, to Vintage Capital Management LLC, also a related party. The face principal amount of Tranche A-1 is $30.0 million, which excludes a $2.0 million up-front fee that was added to the principal balance on the first funding date, transaction expenses, paid-in-kind interest, and original issue discounts of 10.00% for each draw under Tranche A-1. Tranche A-1 is incurred under our Amended Credit Agreement and shares on a pari passu basis with the U.S. Revolving Credit Facility. Tranche A-1 matures and is payable in full on July 1, 2020, the day after the maturity date of the U.S. Revolving Credit Facility. Tranche A-1 may be prepaid, subject to the subordination provisions, but not re-borrowed.
Tranche A-1 bears interest at a rate per annum equal to (i) if designated a eurocurrency rate loan, the then-applicable U.S. LIBOR rate plus 14.00%, with 5.50% of such interest rate to be paid in cash and the remaining 8.50% payable in kind by adding such accrued interest to the principal amount of Tranche A-1 and (ii) if designated a base rate loan, the then applicable prime rate set by the Administrative Agent plus 13.00%, with 4.50% of such interest rate to be paid in cash and the remaining 8.50% payable in kind by adding such accrued interest to the principal amount of Tranche A-1. Subject to the subordination provisions, Tranche A-1 shall be subject to all of the other same representations and warranties, covenants and events of default under the Amended Credit Agreement. The total effective interest rate of Tranche A-1 was 25.38% on December 31, 2018. The effective rate of the Tranche A-1 may fluctuate over the life of the loan due to changes in LIBOR, the prime rates or any repayments. Interest expense associated with Tranche A-1 is detailed in Note 26.
As of December 31, 2018, the Tranche A-1 net carrying value of $30.6 million is presented as a current liability in our Consolidated Balance Sheets as a result of the limited waivers that extend through April 5, 2019. See Note 31 for additional Last Out Term Loan transactions and modifications subsequent to December 31, 2018.
NOTE 2021 – SECOND LIEN TERM LOAN FACILITY
Extinguishment of the Second Lien Term Loan Facility
Using $212.6 million of the proceeds from the 2018 Rights Offering, we fully repaid the Second Lien Term Loan Facility (described below) on May 4, 2018, plus accrued interest of $2.3 million. A loss on extinguishment of this debt of approximately $49.2 million was recognized in the second quarter of 2018 as a result of the remaining $32.5 million unamortized debt discount on the date of the repayment, $16.2 million of make-whole interest, and $0.5 million of fees associated with the extinguishment.
Terms of the 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"),AIP, governing a second lien term loan facility.the Second Lien Term Loan Facility. The second lien term loan facility consistsSecond Lien Term Loan Facility consisted 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, havehad a coupon interest rate of 10% per annum, and borrowings under the delayed draw term loan havehad a coupon interest rate of 12% per annum, in each case payable quarterly. As of March 7, 2018, the interest rates increased to 12% and 14% per annum, respectively, due to the covenant default. Undrawn amounts under the delayed draw term loan accrueaccrued 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 havehad a scheduled maturity of December 30, 2020. Interest expense associated with our Second Lien Credit Agreement is detailed in Note 26.
In connection with our entry into the second lien term loan facility,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.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 facilitySecond Lien Term Loan Facility borrowing. Non-cash amortization of the debt discount and direct financing costs will bewere being 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%20.08%.
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
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 containscontained 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 March 31, 2018 and December 31, 2017, we were in default of several financial covenants associated inwith 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.Consolidated Balance Sheet. Under the terms of the intercreditor agreement among the lenders under the United States RevolvingAmended Credit Agreement and the Second Lien Credit Agreement, we have a 180 day standstill period after March 1, 2018 to remedy the event of defaultlenders under the Second Lien Credit Agreement. See Note 1 for our remediation plan.
Agreement cannot enforce remedies against the collateral until after they provide notice of enforcement and after the expiration of a 180-day standstill period. The lenders under the Second Lien Credit Agreement did not provide such notice. The March 1, 2018 United Statesand April 10, 2018 amendments to the U.S. 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.provisions.
NOTE 2122 – RIGHTS OFFERING
On March 19, 2018, we distributed to holders of our common stock one nontransferable subscription right to purchase 1.4 common shares for each common share held as of 5:00 p.m., New York City time, on March 15, 2018 at a price of $3.00 per common share. On April 10, 2018, we extended the expiration date and amended certain other terms regarding the 2018 Rights Offering. As amended, each right entitled holders to purchase 2.8 common shares at a price of $2.00 per share. The 2018 Rights Offering expired at 5:00 p.m., New York City time, on April 30, 2018. The Company did not issue fractional rights or pay cash in lieu of fractional rights. The 2018 Rights Offering did not include an oversubscription privilege.
The 2018 Rights Offering concluded on April 30, 2018, resulting in the issuance of 124.3 million common shares on April 30, 2018. Gross proceeds from the 2018 Rights Offering were $248.4 million. Of the proceeds received, $214.9 million was used to fully repay the Second Lien Credit Agreement, including $2.3 million of accrued interest, and the remainder was used for working capital purposes. Direct costs of the 2018 Rights Offering totaled $3.3 million.
NOTE 23 – 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 litigationLitigation
On March 3, 2017 and March 13, 2017, the Company and certain of its former officers were named as defendants in two separate but largely identical complaints alleging violations of the federal securities laws. The two 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. DuringThrough subsequent amendments, the third quarter of 2017, the plaintiff further amended its complaint. As amended, the complaint now purportsputative class period was expanded to coverinclude investors who purchased shares between June 17, 2015 and August 9, 2017. We filed a motion to dismiss in late 2017; the2017. The court denied the motion in early 2018.2018 and the case is presently in discovery.
The plaintiff in the Stockholder Litigation alleges fraud, misrepresentation and a course of conduct relating to the facts surrounding certain projects underway inundertaken by the Company'sVølund & Other 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 present and former 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”"Federal Court Derivative Litigation"). The allegationsOn April 23, 2018, the United States District Court for the District of Delaware entered an order consolidating the related derivative actions and claims against defendants are largely the same.designating co-lead and co-liaison counsel. On June 1, 2018, plaintiffs filed a consolidated derivative complaint. 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 an unspecified amount of damages, and force implementation of corporate governance changes.
On June 28, 2018, the Federal Court Derivative Litigation was transferred to the United States District Court for the Western District of North Carolina, where the Stockholder Litigation is pending. The parties filed a motion to stay the Federal Court Derivative Litigation, which was granted by the Court on August 13, 2018.
On November 14, 2018, the Company and certain of its present and former officers and directors were named as defendants in an additional shareholder derivative lawsuit filed in the North Carolina Superior Court (the "State Court Derivative Litigation"). The complaint in that action covers the same period and contains allegations substantially similar to those asserted in the pending Federal Court Derivative Litigation and Stockholder Litigation.
We believe the allegations in the Stockholder Litigation, Federal Court Derivative Litigation, and theState Court 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 2224 – 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, 20172018 and 2016,2017, we had deferred approximately $1.8$1.4 million and $0.8$1.8 million, respectively, of net gains (losses) on these derivative financial instruments in accumulated other comprehensive income ("AOCI").AOCI.
At December 31, 2017,2018, our derivative financial instruments consisted solely of FX forward contracts. The notional value of our FX forward contracts totaled $63.0$16.5 million at December 31, 20172018 with maturities extending to November 2019. These instruments consist primarily of contracts to purchase or sell eurosDanish krone, Swedish króna, and British pounds sterling.Euros. 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.U.S. 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.U.S. 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 | As of December 31, |
| (in thousands) | December 31, 2017 | December 31, 2016 | 2018 | 2017 |
| Derivatives designated as hedges: | | |
| Foreign exchange contracts: | | |
| Location of FX forward contracts designated as hedges: | | |
| Accounts receivable-other | $ | 1,088 |
| $ | 3,805 |
| $ | 532 |
| $ | 1,088 |
|
| Other assets | 312 |
| 665 |
| — |
| 312 |
|
| Accounts payable | 105 |
| 1,012 |
| — |
| 105 |
|
| 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 |
| $ | 14 |
| $ | 7 |
|
| Accounts payable | 1,722 |
| 403 |
| — |
| 1,722 |
|
| Other liabilities | 12 |
| 7 |
| — |
| 12 |
|
The effects of derivatives on our financial statements are outlined below:
| | | | Year Ended December 31, | Year Ended December 31, |
| (in thousands) | 2017 | 2016 | 2018 | 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 |
| $ | 1,074 |
| $ | 3,346 |
| $ | 2,208 |
|
| Effective portion of gain (loss) reclassified from AOCI into earnings by location: | | |
| Revenues | 10,059 |
| 4,624 |
| 1,638 |
| 10,059 |
| 4,624 |
|
| Cost of operations | (118 | ) | 195 |
| (15 | ) | (118 | ) | 195 |
|
| Other-net | (7,438 | ) | (1,221 | ) | — |
| (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 |
| (771 | ) | (5,277 | ) | 4,518 |
|
| | | |
| Derivatives not designated as hedges: | | |
| Forward contracts | | |
| Loss recognized in income by location: | | |
| Other-net | $ | (3,436 | ) | $ | (872 | ) | $ | (8 | ) | $ | (3,436 | ) | $ | (872 | ) |
NOTE 2325 – 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 FASBFinancial Accounting Standards Board ("FASB") Topic, Fair Value Measurements and Disclosures).
| | | (in thousands) | | |
| Available-for-sale securities | December 31, 2017 | Level 1 | Level 2 | Level 3 | December 31, 2018 | 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 |
| — |
| $ | 1,283 |
| $ | — |
| $ | 1,283 |
| $ | — |
|
| Corporate notes and bonds | 4,447 |
| 4,447 |
| — |
| — |
| 13,028 |
| 13,028 |
| — |
| — |
|
| United States Government and agency securities | 5,738 |
| 5,738 |
| — |
| — |
| 1,437 |
| 1,437 |
| — |
| — |
|
| Total fair value of available-for-sale securities | $ | 15,809 |
| $ | 10,185 |
| $ | 5,624 |
| $ | — |
| $ | 15,748 |
| $ | 14,465 |
| $ | 1,283 |
| $ | — |
|
| | | (in thousands) | | |
| Available-for-sale securities | December 31, 2016 | Level 1 | Level 2 | Level 3 | December 31, 2017 | Level 1 | Level 2 | Level 3 |
| Commercial paper | $ | 6,734 |
| $ | — |
| $ | 6,734 |
| $ | — |
| $ | 1,895 |
| $ | — |
| $ | 1,895 |
| $ | — |
|
| Certificates of deposit | 2,251 |
| — |
| 2,251 |
| — |
| 2,398 |
| — |
| 2,398 |
| — |
|
| Mutual funds | 1,152 |
| — |
| 1,152 |
| — |
| 1,331 |
| — |
| 1,331 |
| — |
|
| Corporate notes and bonds | 750 |
| 750 |
| — |
| — |
| 4,447 |
| 4,447 |
| — |
| — |
|
| United States Government and agency securities | 7,104 |
| 7,104 |
| — |
| — |
| 5,738 |
| 5,738 |
| — |
| — |
|
| Total fair value of available-for-sale securities | $ | 17,991 |
| $ | 7,854 |
| $ | 10,137 |
| $ | — |
| $ | 15,809 |
| $ | 10,185 |
| $ | 5,624 |
| $ | — |
|
| | | (in thousands) | | |
| Derivatives | December 31, 2017 | December 31, 2016 | December 31, 2018 | December 31, 2017 |
| Forward contracts to purchase/sell foreign currencies | $ | (432 | ) | $ | 2,940 | | $ | 546 | | $ | (432 | ) |
Available-for-sale securitiesAvailable-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.Consolidated Balance Sheets with contractual maturities ranging from 0-6 years.
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 instrumentsFinancial 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 sheetsConsolidated 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 and Last Out Term Loans. We base the fair values of debt instruments on quoted market prices. Where quoted prices are not available, we base the fair values on Level 2 inputs such as 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, 20172018 and December 31, 2016.2017.
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 Non-Recurring 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 repurchaseOur annual and interim goodwill impairment tests and second quarter 2018 impairment charges required significant fair value measurements using unobservable inputs (see Note 20)14). We utilizedThe fair values of the reporting units were based on an income approach using a discounted cash flow modelanalysis, a market approach using multiples of revenue and estimatesEBITDA of our weighted average costguideline companies, and a market approach using multiples of capital on the transaction daterevenue and EBITDA from recent, similar business combinations.
Our second quarter 2018 impairment charges to derive the estimatedassets held for sale of discontinued operations required significant fair value measurements using unobservable inputs (see Note 4). The fair value of the share repurchase.net assets held for sale was based on the expected net proceeds for the sale of MEGTEC and Universal.
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 based on an income approach using a discounted cash flow analysis or based on the price that the Company expects to receive upon the sale of these assets. Both of those approaches utilize unobservable inputs (See Note 8 and Note 16).
NOTE 2426 – SUPPLEMENTAL CASH FLOW AND INTEREST INFORMATION
DuringIn addition to non-cash items described in the twelve months ended December 31, 2017, 2016 and 2015,Consolidated Statements of Cash Flows, we also recognized the following non-cash activitychanges in our consolidated financial statements:Consolidated Balance Sheets related to interest expense as described below:
| | | | | | | | | Year Ended December 31, |
| (in thousands) | 2017 | 2016 | 2015 | 2018 | 2017 | 2016 |
| Accrued capital expenditures in accounts payable | $ | 1,383 |
| $ | 2,751 |
| $ | 568 |
| $ | 139 |
| $ | 1,383 |
| $ | 2,751 |
|
| Accreted interest expense on our second lien term loan facility | $ | 3,226 |
| $ | — |
| $ | — |
| |
During the years ended December 31, 2017, 2016 and 2015 weWe recognized the following cash activity in our consolidated financial statements:Consolidated Financial Statements:
| | | | | | | | | Year Ended December 31, |
| (in thousands) | 2017 | 2016 | 2015 | 2018 | 2017 | 2016 |
| Income tax payments (refunds), net | $ | (10,889 | ) | $ | 10,781 |
| $ | 15,008 |
| $ | 3,690 |
| $ | (10,889 | ) | $ | 10,781 |
|
| Interest payments on our United States revolving credit facility | $ | 4,909 |
| $ | 425 |
| $ | — |
| |
| Interest payments on our U.S. revolving credit facility | | $ | 10,784 |
| $ | 4,909 |
| $ | 425 |
|
| Interest payments on our second lien term loan facility | $ | 7,044 |
| $ | — |
| $ | — |
| $ | 7,627 |
| $ | 7,044 |
| $ | — |
|
During the years ended December 31, 2017, 2016 and 2015, interest
Interest expense in our consolidated financial statementsConsolidated Financial Statements consisted of the following components:
|
| | | | | | | | | |
| | Year Ended December 31, |
| (in thousands) | 2018 | 2017 | 2016 |
| Components associated with borrowings from: | | | |
| U.S. Revolving Credit Facility | $ | 12,284 |
| $ | 5,051 |
| $ | 1,669 |
|
| Second Lien Term Loan Facility | 7,460 |
| 7,211 |
| — |
|
| Last Out Term Loan - cash interest | 513 |
| — |
| — |
|
| Last Out Term Loan - interest paid-in-kind | 1,079 |
| — |
| — |
|
| Foreign revolving credit facilities | 716 |
| 1,021 |
| 753 |
|
| | 22,052 |
| 13,283 |
| 2,422 |
|
| Components associated with amortization or accretion of: | | | |
| U.S. Revolving Credit Facility deferred financing fees and commitment fees | 22,943 |
| 6,270 |
| 1,244 |
|
| Second Lien Term Loan Facility discount and financing fees | 3,202 |
| 3,226 |
| — |
|
| Last Out Term Loan discount and financing fees | 552 |
| — |
| — |
|
| | 26,697 |
| 9,496 |
| 1,244 |
|
| | | | |
| Other interest expense | 864 |
| 3,154 |
| 36 |
|
| | | | |
| Total interest expense | $ | 49,613 |
| $ | 25,933 |
| $ | 3,702 |
|
The following table provides a reconciliation of cash, cash equivalents and restricted cash reporting within the Consolidated Balance Sheets that sum to the total of the same amounts in the Consolidated Statements of Cash Flows:
|
| | | | | | | | | |
| | Year Ended December 31, |
| (in thousands) | 2018 | 2017 | 2016 |
| Held by foreign entities | $ | 35,522 |
| $ | 42,490 |
| $ | 89,042 |
|
Held by United States entities (1) | 7,692 |
| 1,227 |
| (1,616 | ) |
| Cash and cash equivalents of continuing operations | 43,214 |
| 43,717 |
| 87,426 |
|
| | | | |
| Reinsurance reserve requirements | 11,768 |
| 21,061 |
| 21,189 |
|
| Restricted foreign accounts | 5,297 |
| 4,919 |
| 6,581 |
|
| Restricted cash and cash equivalents | 17,065 |
| 25,980 |
| 27,770 |
|
| | | | |
| Total cash, cash equivalents and restricted cash of continuing operations shown in the Consolidated Statements of Cash Flows | $ | 60,279 |
| $ | 69,697 |
| $ | 115,196 |
|
| | | | |
Total cash and cash equivalents of discontinued operations (2) | $ | — |
| $ | 12,950 |
| $ | 8,461 |
|
(1) Cash and cash equivalents held by United States entities is negative at December 31, 2016 due to outstanding checks at continuing operations, for which we had the right to offset against cash held by U.S. entities of discontinued operations at that date.
(2) Cash and cash equivalents of discontinued operations is included in current assets of discontinued operations in the Consolidated Balance Sheet. See Note 4 for further information.
Our U.S. 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.
|
| | | | | | | | | |
| (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 27– 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 entered into on August 9, 2017 and related repurchase of shares of our common stock as described in Note 21 were related party transactions.
Transactions with B. Riley and its Affiliates
B. Riley Financial, Inc. and its affiliates (collectively, "B. Riley") became the beneficial owner of greater than five percent of our common stock in May 2018, upon completion of the 2018 Rights Offering described in Note 22. As of December 31, 2018, B. Riley Capital Management, LLC owns approximately 6.43% of our outstanding common stock.
Tranche A-1 of the Last Out Term Loans described in Note 20 was a related party transaction.transaction with B. Riley FBR, Inc. until November 19, 2018, when it was assigned to Vintage Capital Management LLC, also a related party.
Tranche A-2 of the Last Out Term Loans provided proceeds of $10 million on March 20, 2019, described in Note 31, was also a related party transaction with B. Riley FBR, Inc.
The Company also entered an agreement with BPRI Executive Consulting, LLC on November 19, 2018 for the services of Mr. Kenny Young, to serve as our Chief Executive Officer until November 30, 2020, unless terminated by either party with thirty days written notice. The amount paid in 2018 related to this agreement was $0.1 million. This agreement also granted stock appreciation rights to BRPI Executive Consulting, LLC as described in Note 9.
See also Note 31.
Transactions with Vintage Capital Management, LLC
As of December 31, 2018, Vintage Capital Management, LLC ("Vintage") owned approximately 14.86% of our outstanding common stock.
On April 10, 2018, the Company and Vintage entered into an equity commitment agreement (the "Equity Commitment Agreement"), which Equity Commitment Agreement amended and restated in its entirety the prior letter agreement, dated as of March 1, 2018, between the Company and Vintage, pursuant to which Vintage agreed to backstop the 2018 Rights Offering for the purpose of providing at least $245 million of new capital.
The Last Out Term Loan described in Note 20 also became a related party transaction with Vintage beginning November 19, 2018, after it was assigned to Vintage from B. Riley FBR, Inc., also a related party.
See also Note 31.
NOTE 26 28– DISCONTINUED OPERATIONSFUTURE MINIMUM PAYMENTS
We received corporate allocations from our former Parent as describedOperating leases
Future minimum payments required under operating leases that have initial or remaining noncancelable lease terms in Note 1, which totaled $2.7 million for theexcess of one year endedat December 31, 2015. Though these allocations relate to our discontinued NE segment, they2018 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:follows (in thousands):
|
| | | |
| | 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 |
|
|
| | | |
| (in thousands) | |
| 2019 | $ | 6,748 |
|
| 2020 | $ | 5,035 |
|
| 2021 | $ | 3,545 |
|
| 2022 | $ | 2,025 |
|
| 2023 | $ | 1,236 |
|
| Thereafter | $ | 792 |
|
Total rental expense for the years ended December 31, 2018, 2017 and 2016, was $8.3 million, $8.8 million and $7.0 million, respectively.
In September 2018, we announced that we would consolidate most of our Barberton and Copley, Ohio operations into new, leased office space in Akron, Ohio in approximately the third quarter of 2019. As of December 31, 2018, the operating lease agreement for the office space in Akron had not yet commenced; it will commence when it is ready for occupation. The lease has an initial term of fifteen years, with an option to extend up to two additional ten year terms. Base rent will increase two percent annually, making the total future minimum payments during the initial term of the lease approximately $55 million. This amount is not included in the table above.
Long-term borrowings
Maturities of our long-term borrowings in the five years succeeding December 31, 2018 are as follows (in thousands):
|
| | | |
| (in thousands) | |
2019 (1) (2) | $ | 176,155 |
|
| 2020 | $ | — |
|
| 2021 | $ | — |
|
| 2022 | $ | — |
|
| 2023 | $ | — |
|
| Thereafter | $ | — |
|
| |
(1) | As of January 4, 2019, the foreign revolving credit facilities were paid in full and closed. |
| |
(2) | The maturity date of the U.S. Revolving Credit Facility and the Last Out Term Loans are in 2020. However, as of December 31, 2018, the U.S. Revolving Credit Facility and the Last Out Term Loan amounts are presented as a current liability in our Consolidated Balance Sheets as a result of the limited waivers that extend through April 5, 2019. |
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 29– QUARTERLY FINANCIAL DATA
The following tables set forth selected unaudited quarterly financial information for the years ended December 31, 20172018 and 2016:2017:
|
| | | | | | | | | | | | | | | |
| (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 | ) |
|
| | | | | | | | | | | | | | | |
| (in thousands, except per share amounts) | Quarter ended |
| | March 31, 2018 | | June 30, 2018 | | Sept. 30, 2018 | | Dec. 31, 2018 |
| Revenues | $ | 253,176 |
| | $ | 291,337 |
| | $ | 294,963 |
| | $ | 222,912 |
|
| Gross profit | $ | (24,169 | ) | | $ | (41,066 | ) | | $ | 10,462 |
| | $ | (74,871 | ) |
Operating loss (1) | $ | (106,428 | ) | | $ | (137,351 | ) | | $ | (45,147 | ) | | $ | (137,674 | ) |
| Equity in (loss) income of investees | $ | (11,757 | ) | | $ | — |
| | $ | — |
| | $ | 154 |
|
| Net loss attributable to shareholders | $ | (120,433 | ) | | $ | (265,768 | ) | | $ | (105,688 | ) | | $ | (233,403 | ) |
| Loss per common share | | | | | | | |
| Basic and diluted - Continuing | $ | (2.65 | ) | | $ | (1.68 | ) | | $ | (0.62 | ) | | $ | (1.35 | ) |
| Basic and diluted - Discontinued | $ | (0.08 | ) | | $ | (0.44 | ) | | $ | (0.01 | ) | | $ | (0.04 | ) |
| |
(1)(1) Includes equity in income of investees. | 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 | ) |
|
| | | | | | | | | | | | | | | |
| (in thousands, except per share amounts) | Quarter ended |
| | March 31, 2017 | | June 30, 2017 | | Sept. 30, 2017 | | Dec. 31, 2017 |
| Revenues | $ | 348,072 |
| | $ | 306,231 |
| | $ | 356,870 |
| | $ | 330,256 |
|
| Gross profit | $ | 49,614 |
| | $ | (69,593 | ) | | $ | 30,753 |
| | $ | 13,444 |
|
Operating loss (1) | $ | (11,279 | ) | | $ | (146,586 | ) | | $ | (110,888 | ) | | $ | (47,610 | ) |
| Equity in income (loss) of investees | $ | 618 |
| | $ | (15,232 | ) | | $ | 1,234 |
| | $ | 3,513 |
|
| Net loss attributable to shareholders | $ | (7,045 | ) | | $ | (150,999 | ) | | $ | (114,302 | ) | | $ | (107,478 | ) |
| (Loss) earnings per common share | | | | | | | |
| Basic and diluted - Continuing | $ | (0.12 | ) | | $ | (3.05 | ) | | $ | (2.49 | ) | | $ | (2.56 | ) |
| Basic and diluted - Discontinued | $ | (0.03 | ) | | $ | (0.04 | ) | | $ | 0.01 |
| | $ | 0.12 |
|
| |
(1)(1) Includes equity in income of investees. | Includes equity in income of investees. |
Our quarterly results include the following items that significantsignificantly 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 marketMTM adjustments resulted in (charges) gains of: $(72.2) million in the fourth quarter of 2018, $4.2 million in the third quarter of 2018, $0.5 million in the second quarter of 2018, $9.8 million in the fourth quarter of 2017, and $(1.1) million in the first quarter of 2017.
$39.8 million pre-tax gain in the third quarter of 2018 for the sale of PBRRC, a subsidiary that held two operations and maintenance contracts for waste-to-energy facilities in West Palm Beach, Florida as described in Note 5.
$18.4 million and $18.2 million of other-than-temporary impairment of our interest in TBWES, an equity method investment in India, in the first quarter of 2018 and the second quarter of 2017, $6.4respectively. These are described in Note 13.
Goodwill impairment charges totaled $37.5 million in the second quarter of 2018 and $86.9 million in the third quarter of 2017 as described in Note 14.
Restructuring and spin-off transaction costs totaled $6.9 million in the first quarter of 2018 and $6.3 million in the fourth quarter of 2017.
Financial advisory fees totaled $7.2 million in the third quarter of 2018 and $2.3 million in the fourth quarter of 2016, $(0.5)2017.
Intangible asset impairment of $2.5 million was recorded in the thirdfourth quarter of 2016, and $(30.0)2018 for the SPIG segment as described in Note 6.
An allowance for doubtful accounts of $5.8 million was recorded in the secondfourth quarter of 2016.2018 for our China operation as described in Note 6.
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 changesChanges in the estimates of the forecasted revenues and costs to complete six renewable energyEuropean Vølund loss contracts (seesignificantly affected the quarterly earnings throughout 2018 and 2017. These contracts and their status as of December 31, 2018 are described in Note 6).7.
In the third quarter of 2018, we recognized $99.6 million of non-cash income tax charges to increase the valuation allowance against our remaining net deferred tax assets. In the fourth quarter of 2017, we recognized $62.4 million of additional income tax expense resulting from the enactment of new tax legislation in the United States on December 22, 2017 (see2017. These are described in Note 10).10.
NOTE 30 – NEW ACCOUNTING STANDARDS
New accounting standards that could affect our Consolidated Financial Statements in the future are summarized as follows:
In February 2016, the FASB issued ASU 2016-02, Leases (Topic 842). With adoption of this standard, lessees will have to recognize long-term 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. We adopted the new standard on January 1, 2019 and use the effective date as our date of initial application. In July 2018, the FASB issued an update that provided an additional transition option that allows companies to continue applying the guidance under the lease standard in effect at that time in the comparative periods presented in the Consolidated Financial Statements. Companies that elect this option would record a cumulative-effect adjustment to the opening balance of retained earnings on the date of
adoption. We elected this optional transition method. We also elected the “package of practical expedients”, which permits us not to reassess under the new standard our prior conclusions about lease identification, lease classification and initial direct costs. However, we are not electing to adopt the hindsight practical expedient and are therefore maintaining the lease terms we previously determined under ASC 840.
We have substantially completed our assessment of the standard as well as implementation of our leasing software, including data upload and test procedures. We continue to finalize our calculations, including our discount rate assumptions, related to the new standard. We are also continuing to establish new processes and internal controls that may be required to comply with the new lease accounting and disclosure requirements set by the new standard. We expect the impact of the standard adoption to increase our assets and liabilities within our Consolidated Balance Sheet by approximately $14 million to $19 million, but do not expect a material impact on our results of operations or cash flows.
In February 2018, the FASB issued ASU 2018-02, Income Statement - Reporting Comprehensive Income (Topic 220): Reclassification of Certain Tax Effects from Accumulated Other Comprehensive Income. The new guidance provides companies with the election to reclassify stranded tax effects resulting from the Tax Act from accumulated other comprehensive income to retained earnings. Existing guidance requiring the effect of a change in tax law or rates to be recorded in continuing operations is not affected. This standard is effective for all public business entities for fiscal years beginning after December 15, 2018, and any interim periods within those fiscal years. Early adoption is permitted in any interim period. We expect the impact of this standard on our financial statements will be immaterial.
In August 2018, the FASB issued ASU 2018-15, Intangibles - Goodwill and Other - Internal-Use Software (Subtopic 350-40): Customer’s Accounting for Implementation Costs Incurred in a Cloud Computing Arrangement That Is a Service Contract. The new guidance requires companies acting as the customer in a cloud hosting service arrangement to follow the requirements of ASC 350-40 for capitalizing implementation costs for internal-use software and requires the amortization of these costs over the life of the related service contract. This standard is effective for all public business entities for fiscal years beginning after December 15, 2019, and any interim periods within those fiscal years. Early adoption is permitted in any interim period. We are currently evaluating the impact of this standard on our financial statements and whether we will elect to adopt this standard early.
NOTE 31 – SUBSEQUENT EVENTS
Subsequent to December 31, 2018, we have entered into a series of limited waivers (described below) to avoid default under our U.S. Revolving Credit Facility and Last Out Term Loans while we negotiated the settlement of the final two European Vølund loss contracts described in Note 7 and negotiated terms for financing and the related further amendment to our Amended Credit Agreement to allow for that financing. On March 20, 2019, we borrowed $10.0 million of additional funding in the form of a Tranche A-2 Last Out Term Loan (described below) to support working capital needs. Since March 20, 2019, we have been nearly fully drawn on the U.S. Revolving Credit Facility, minimal additional amounts were available for borrowings or letters of credit, and we were in compliance with the terms of the Amended Credit Agreement subject to the limited waivers that cumulatively extend through April 5, 2019.
As of April 2, 2019, the settlement of the final two European Vølund loss contracts has been completed pending payment of amounts due under the settlement. Binding agreement of this settlement, subject to payment, was a requirement of the lending group of the Amended Credit Agreement for further amendment. The additional financing required to make those settlement payments and to provide additional funding of working capital has not been yet been committed. Our financing plans and the status of those negotiations as of April 2, 2019 are described more fully in Note 1.
March 15, 2019 Limited Waiver to the Amended Credit Agreement
On March 15, 2019, we entered into a limited waiver to our Amended Credit Agreement ("First Limited Waiver"), which waived our compliance with covenants in the Amended Credit Agreement and certain events of default through March 25, 2019.
March 19, 2019 Amendment and Limited Waiver to the Amended Credit Agreement
On March 19, 2019, we entered into an amendment and limited waiver (the "15th Amendment") to our Amended Credit Agreement, which replaced in full the First Limited Waiver, and extended the waivers of our compliance with covenants in the Amended Credit Agreement and certain events of default through March 29, 2019. The 15th Amendment also made
certain other modifications to the Amended Credit Agreement. Specifically, the 15th Amendment provided $10.0 million in additional commitments from B. Riley Financial, Inc. under a Tranche A-2 of Last Out Term Loans, which were fully borrowed on March 20, 2019. This borrowing under Tranche A-2 of Last Out Term Loans was generally made on terms, including interest rate, maturity and prepayment, that are the same as our Tranche A-1 of the Last Out Term Loans.
Certain of the lenders, as well as certain of their respective affiliates, have performed and may in the future perform for us and our subsidiaries, various commercial banking, investment banking, lending, underwriting, trust services, financial advisory and other financial services, for which they have received and may in the future receive customary fees and expenses. B. Riley is a significant stockholder, owning approximately 6.43% of our outstanding common stock. See also Note 27.
March 29, 2019 Limited Waiver to the Amended Credit Agreement
On March 29, 2019, we entered into a limited waiver (the “Third Limited Waiver”) to our Amended Credit Agreement, which waives our compliance with certain covenants in the Amended Credit Agreement, including but not limited to covenants (1) requiring that we maintain a minimum liquidity amount of $40.0 million as a condition to borrowing both at the time of any credit extension request and on the proposed date of the credit extension (as defined in the Amended Credit Agreement), provided that we must maintain a minimum liquidity amount of $35.0 million as a condition to borrowing both at the time of any credit extension request and on the proposed date of the credit extension, (2) requiring that we maintain the specified consolidated interest coverage and senior leverage coverage ratios contained in the Amended Credit Agreement, (3) requiring that we maintain a minimum liquidity amount of $40.0 million as of the last business day of any calendar month, (4) specifying certain contract completion milestones that we are required to meet in connection with one renewable energy project, (5) limiting the amount of certain net losses permitted in connection with renewable energy projects, and (6) requiring our independent registered public accounting firm certify our consolidated financial statements without a going concern qualification. The Third Limited Waiver also waives certain events of default related to projects in our Vølund & Other Renewables segment. The Third Limited Waiver will terminate at 5:00 p.m., New York City time, on April 5, 2019 unless earlier terminated upon the occurrence of, among other things, an event of default under the Amended Credit Agreement, our payment of certain fees in connection with certain renewable energy projects or our failure to maintain a minimum liquidity amount of $35.0 million as a condition to borrowing both at the time of any credit extension request and on the proposed date of the credit extension.
NOTE 29 – NEWItem 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING STANDARDSAND FINANCIAL DISCLOSURE
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
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:
|
| | | | | | | | | | | |
| 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 controlsControls and proceduresProcedures
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, has evaluated the effectiveness of the design and operation of our disclosure controls and procedures as(as that term is defined in Rules 13a-15(e) and 15d-15(e) ofadopted by the Securities and Exchange Commission under 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. TheYou should note that the design of any system of disclosure controls and procedures is based in part upon various assumptions about the likelihood of future events, and we cannot provide absolute assuranceassure you that any design will succeed in achieving its stated goals under all potential future conditions, regardless of how remote.
Based on the evaluation referred to above, management of B&Wour Chief Executive Officer and Chief Financial Officer concluded that as of December 31, 2017 the design and operation of our disclosure controls and procedures are effective as of December 31, 2018 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 SECSecurities and Exchange Commission, 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
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.
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 statementsConsolidated 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, 2017.2018. 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, 2017.2018.
The effectiveness of our internal control over financial reporting as of December 31, 20172018 has been audited by Deloitte & Touche LLP, the independent registered public accounting firm who also audited our consolidated financial statementsConsolidated 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.
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, 2017,2018, 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, 2017,2018, 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, 20172018 of the Company and our report dated March 1, 2018April 2, 2019 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 CarolinaCleveland, Ohio
March 1, 2018April 2, 2019
Changes in internal control over financial reportingInternal Control Over Financial Reporting
There were no changes in our internal control over financial reporting during the quarter ended December 31, 20172018 that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.
Item 9B. OTHER INFORMATION
Amended credit agreementNot applicable.
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.
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 20182019 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 20182019 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 20182019 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, 2018,2019, are as follows:
|
| | |
| Name | Age | Position |
Jenny L. ApkerHenry E. Bartoli | 6072 | Senior Vice President and Chief FinancialStrategy Officer |
Mark A. CaranoRobert M. Caruso | 4856 | Senior Vice President, Industrial and Corporate DevelopmentChief Implementation Officer |
| J. André Hall | 5253 | Senior Vice President, General Counsel and Corporate Secretary |
| Daniel W. Hoehn | 3940 | Vice President, Controller and Chief Accounting Officer |
Mark S. LowJimmy B. Morgan | 6150 | Senior Vice President, Power |
Jimmy B. Morgan | 49 | Senior Vice President, Renewable |
Leslie C. Kass | 47 | President and Chief Executive OfficerBabcock & Wilcox |
| James J. Muckley | 5960 | Senior Vice President, Operations |
| Louis Salamone | 72 | Chief Financial Officer |
| Kenneth Young | 55 | Chief Executive Officer |
Jenny L. Apker servesHenry E. Bartoli has served as our Chief Strategy Officer since November 2018, in addition to serving as a member of our Board of Directors since January 2018. Prior to joining the Company, Mr. Bartoli served as President and Chief Executive Officer of Hitachi Power Systems America LTD from 2004 until his retirement in 2014. From 2002 to 2004, he was Executive Vice President of The Shaw Group, after serving in a number of senior leadership roles at Foster Wheeler Ltd. from 1992 to 2002, including Group Executive and Corporate Senior Vice President, Energy Equipment Group, and Chief Financial Officer. Prior to the spin-off, Ms. Apker served as Vice President, TreasurerGroup Executive and Investor Relations of BWC since August 2012 and, prior to that time, served asCorporate Vice President and Treasurer since joining BWCGroup Executive, Foster Wheeler Power Systems Group. Previously, from 1971 to 1992, he served in June 2010. Previously, Ms. Apkera number of positions of increasing importance at Burns and Roe Enterprises, Inc.
Robert M. Caruso has served as Vice Presidentour Chief Implementation Officersince April 2018. He works closely with the Company’s executive leadership team to review financial and Treasurer with Dex One Corporation (formerly R.H. Donnelley Corporation), a marketing services company, from May 2003 until June 2010.operational strategies, and revenue and profitability enhancement
opportunities. Mr. Caruso also 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 inof Alvarez & Marsal's North American Commercial Restructuring practice ("NACR") since September 2006. He is a member of the Investment Banking Group of Bank of America Merrill Lynch since 2006. Mr. Carano also previously held positions withNACR Executive Committee and co-leads the Investment Banking Group of Deutsche Bank.NACR Midwest Region.
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 BWCour former parent, now known as BWX Technologies, Inc. ("BWXT"), since August 2013. Prior to joining BWC,BWXT, 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 BWCBWXT in March 2015. From 2013 to 2015, Mr. Hoehn was Vice President and Controller at Chiquita Brands International, Inc., a producer
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 servesJimmy B. Morgan has served as our Senior Vice President, Power. From July 2015 to June 2016, heBabcock & Wilcox since January 2019. Previously, Mr. Morgan 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 ofRenewable, including 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 VolundVølund subsidiary, and Babcock & Wilcox's operations and maintenance services businesses.businesses, from December 2016 to January 2019. 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.James BeforeJ 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.
Louis Salamone has served as our Chief Financial Officer since February 2019. Before that, Mr. Salamone served as the Company's Executive Vice President of Finance since November 2018. Mr. Salamone also serves as an advisor to MDx Diagnostics, LLC, a provider of medical devices, since December 2017. From April 2013 until December 2017, Mr. Salamone served as Chief Financial Officer of CityMD, an urgent care provider. Prior to joining CityMD, Mr. Salamone was Vice President and Chief Financial Officer of OpenPeak Inc., a provider of mobile cybersecurity solutions, from April 2009 until March 2013, and Executive Vice President and Chief Financial Officer of LCC, from June 2006 until April 2009.
Kenneth Young has served as our Chief Executive Officer since November 2018. Mr. Young also serves as the President of B. Riley Financial, Inc. ("B. Riley"), a provider of collaborative financial services and solutions, since July 2018, and as Chief Executive Officer of B. Riley’s subsidiary, B. Riley Principal Investments, since October 2016. From August 2008 to March 2016, Mr. Young served as the President and Chief Executive Officer of Lightbridge Communications Corporation (f/k/a LCC International, Inc.), a provider of integrated end-to-end solutions for wireless voice and data communications networks. Mr. Young has served as a member of the boards of directors of Globalstar, Inc. since 2015, Orion Energy Systems, Inc. since 2017, Liberty Tax, Inc. since 2018 and bebe stores, inc. since 2018. Mr. Young previously served as a member of the boards of directors of B. Riley from 2015 to 2016 and Standard Diversified Opportunities Inc. from 2015 to 2017.
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 20182019 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, 2017:2018:
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 |
|
|
| | | |
| Plan Category: | Equity compensation plans approved by security holders |
| Number of securities to be issued upon exercise of outstanding options and rights | 6,249,897 |
|
| Weighted-average exercise price of outstanding options and rights | $ | 11.51 |
|
| Number of securities remaining available for future issuance | 4,191,007 |
|
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 20172019 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 20182019 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"2019" in the Proxy Statement for our 20182019 Annual Meeting of Stockholders.
PART IV
Item 15. Exhibits
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| | 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)) |
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| | 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)) |
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| | 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)) |
| | | |
| | 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)) |
| | | |
| | 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)) |
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| | 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)) |
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| | 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)) |
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| | 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)) |
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| | 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)) |
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| | 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)) |
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| | 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)) |
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| | 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)) |
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| | 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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| | 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)) |
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| | 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)) |
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| | 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)) |
| | | |
| | 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)) |
| | | |
| | 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)) |
| | | |
| | 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)) |
| | | |
| | 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)) |
| | | |
| | 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)) |
| | | |
|
| | |
| | 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)) |
| | | |
| | 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)) |
| | | |
| | 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)) |
| | | |
| | 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)) |
| | | |
| | 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)) |
| | | |
| | 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)) |
| | | |
|
| | |
| | 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)) |
| | | |
| | 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)) |
| | | |
| | 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. |
| | | |
| | 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)) |
| | | |
| | 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)) |
| | | |
| | 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)) |
| | | |
| | 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)) |
| | |
| | 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)) |
| | | |
| | 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)) |
| | | |
| | 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)) |
|
| | |
| | Offer Letter,Equity Commitment Agreement, dated March 1, 2018, by and between Babcock & Wilcox Enterprises, Inc. and Leslie C. Kass dated as of January 31, 2018Vintage Capital Management, LLC (incorporated by reference to Exhibit 10.1 to the Babcock & Wilcox Enterprises, Inc. Current Report on Form 8-K filed February 1,March 5, 2018 (file no.(File No. 001-36876)) |
| | | |
| | SupplementAmendment No. 5 dated March 1, 2018, to EmploymentCredit Agreement, by and betweendated as of May 11, 2015, among Babcock & Wilcox Enterprises, Inc., as the borrower, Bank of America, N.A., as Administrative Agent, and E. James Ferland dated as of January 31, 2018the other lenders party thereto (incorporated by reference to Exhibit 10.2 to the Babcock & Wilcox Enterprises, Inc. Current Report on Form 8-K filed FebruaryMarch 5, 2018 (File No. 001-36876)) |
| | |
| | Amendment No. 6 dated April 10, 2018, to 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 the Babcock & Wilcox Enterprises, Inc. Current Report on Form 8-K filed April 11, 2018 (File No. 001-36876)) |
| | |
| | Equity Commitment Agreement, dated April 10, 2018, by and between Babcock & Wilcox Enterprises, Inc. and Vintage Capital Management, LLC (incorporated by reference to the Babcock & Wilcox Enterprises, Inc. Current Report on Form 8-K filed April 11, 2018 (File No. 001-36876)) |
| | |
| | Stock Purchase Agreement, dated as of June 5, 2018 among B&W Equity Investments, LLC, Babcock & Wilcox MEGTEC Holdings, Inc., Babcock & Wilcox MEGTEC, LLC, The Babcock & Wilcox Company, Babcock & Wilcox Enterprises, Inc., DURR, Inc., and DURR Aktiengesellschaft (incorporated by reference to the Babcock & Wilcox Enterprises, Inc. Quarterly Report on Form 10-Q for the quarter ended June 30, 2018 (File No. 001-36876)) |
| | |
| | Babcock & Wilcox Enterprises, Inc. Amended and Restated 2015 Long-Term Incentive Plan (Amended and Restated as of November 2, 2018) |
| | |
| | Consent and Amendment No. 7 dated May 31, 2018, to 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 the Babcock & Wilcox Enterprises, Inc. Quarterly Report on Form 10-Q for the quarter ended June 30, 2018 (File No. 001-36876)) |
| | |
| | Babcock & Wilcox Enterprises, Inc., Severance Plan, as revised effective June 1, 2018 (file no.(incorporated by reference to the Babcock & Wilcox Enterprises, Inc. Quarterly Report on Form 10-Q for the quarter ended June 30, 2018 (File No. 001-36876)) |
| | |
| | Amendment No. 8 dated August 9, 2018, to 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 the Babcock & Wilcox Enterprises, Inc. Current Report on Form 8-K filed August 13, 2018 (File No. 001-36876)) |
| | Amendment No. 9 dated September 14, 2018, to 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 the Babcock & Wilcox Enterprises, Inc. Quarterly Report on Form 10-Q for the quarter ended September 30, 2018 (File No. 001-36876)) |
| | |
| | Amendment No. 10 dated September 28, 2018, to 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 the Babcock & Wilcox Enterprises, Inc. Quarterly Report on Form 10-Q for the quarter ended September 30, 2018 (File No. 001-36876)) |
| | |
| | Amendment No. 11 dated October 4, 2018, to 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 the Babcock & Wilcox Enterprises, Inc. Quarterly Report on Form 10-Q for the quarter ended September 30, 2018 (File No. 001-36876)) |
| | |
| | Amendment No. 12 dated October 31, 2018, to 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 the Babcock & Wilcox Enterprises, Inc. Quarterly Report on Form 10-Q for the quarter ended September 30, 2018 (File No. 001-36876)) |
| | |
| | Amendment No. 13 dated December 31, 2018, to 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. |
| | |
| | Amendment No. 14 dated January 15, 2019 to 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. |
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|
| | |
| | Consulting Agreement dated November 19, 2018 between Babcock & Wilcox Enterprises, Inc., and BRPI Executive Consulting. |
| | |
| | Executive Employment Agreement dated November 19, 2018 between Babcock & Wilcox Enterprises, Inc. and Louis Salamone. |
| | |
| | Executive Employment Agreement dated November 19, 2018 between Babcock & Wilcox Enterprises, Inc. and Henry Bartoli. |
| | |
| | Form of Stock Appreciation Right Award Grant Agreement. |
| | |
| | Amendment No. 15 and Limited Waiver dated March 19, 2019 to 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. |
| | |
| | | |
| | Significant Subsidiaries of the Registrant |
| | | |
| | Consent of Deloitte & Touche LLP |
| | | |
| | Rule 13a-14(a)/15d-14(a) certification of Chief Executive Officer |
| | |
| | Rule 13a-14(a)/15d-14(a) certification of Chief Financial Officer |
| | |
| | |
| | Section 1350 certification of Chief Executive Officer |
|
| | |
| | |
| | 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.
‡ The Company has omitted certain information contained in this exhibit pursuant to Rule 601(b)(10) of Regulation S-K. The omitted information is not material and, if publicly disclosed, would likely cause competitive harm to the Company.
SCHEDULE II
BABCOCK & WILCOX ENTERPRISES, INC.
SCHEDULE II - VALUATION AND QUALIFYING ACCOUNTS
Allowance for Doubtful Accounts
|
| | | | | | | | | | | | | | | |
| (in thousands) | Beginning
balance | Charges to costs
and expenses | Charged to
other accounts | Deductions | Ending
balance |
| Year Ended December 31, 2018 | $ | 11,591 |
| $ | 8,208 |
| $ | 2,178 |
| $ | 585 |
| $ | 21,392 |
|
| Year Ended December 31, 2017 | $ | 9,526 |
| 1,646 |
| 1,463 |
| 1,044 |
| $ | 11,591 |
|
| Year Ended December 31, 2016 | $ | 4,839 |
| 769 |
| 5,750 |
| 1,832 |
| $ | 9,526 |
|
Deferred Tax Assets Valuation Allowance
|
| | | | | | | | | | | | |
| (in thousands) | Beginning
balance | Charges to costs
and expenses | Charged to
other accounts | Ending
balance |
| Year Ended December 31, 2018 | $ | 108,105 |
| $ | 204,727 |
| $ | 262 |
| $ | 313,094 |
|
| 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 |
|
Inventory Reserves
|
| | | | | | | | | | | | | | | |
| (in thousands) | Beginning
balance | Charges to costs
and expenses | Charged to
other accounts | Deductions | Ending
balance |
| Year Ended December 31, 2018 | $ | 13,328 |
| $ | 1,809 |
| $ | 1,402 |
| $ | 1,010 |
| $ | 15,529 |
|
| Year Ended December 31, 2017 | $ | 13,092 |
| 1,302 |
| 230 |
| 1,296 |
| $ | 13,328 |
|
| Year Ended December 31, 2016 | $ | 13,232 |
| 1,367 |
| 147 |
| 1,654 |
| $ | 13,092 |
|
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.
|
| | | |
| April 2, 2019 | | | BABCOCK & WILCOX ENTERPRISES, INC. |
| | | | |
| | | By: | /s/ Leslie C. Kass |
March 1, 2018 | | By: | Leslie C. KassKenneth M. Young |
| | | | President and Kenneth M. Young |
| | | Chief Executive Officer |
Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report has beento be signed belowon its behalf by the following persons on behalf of the registrant and in the capacities indicated and on the date indicated.undersigned thereunto duly authorized.
|
| | |
| Signature | | Title |
| | |
/s/ Leslie C. KassKenneth M. Young | | President, Chief Executive Officer and Director
(Principal Executive Officer) |
Leslie C. KassKenneth M. Young | |
| | |
/s/ Jenny L. ApkerLouis Salamone | | Senior Vice President and Chief Financial Officer
(Principal Financial Officer and Duly Authorized Representative)Officer) |
Jenny L. ApkerLouis Salamone | |
| | |
| /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. WeyersKenneth Siegel | | Director |
Larry L. WeyersKenneth Siegel | |
March 1, 2018
April 2, 2019
