UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D. C. 20549



	FORM 10-Q

(Mark One)



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

For the quarterly period ended ~~September~~March 3031, ~~2017~~2018



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

For the transition period from to

Commission file number 1-34259



	Willbros Group, Inc.
	(Exact name of registrant as specified in its charter)



Delaware		30-0513080
(Jurisdiction of incorporation)		(I.R.S. Employer Identification Number)

4400 Post Oak Parkway

Suite 1000

Houston, TX 77027

Telephone No.: 713-403-8000

(Address, including zip code, and telephone number, including area code, of principal executive offices of registrant)



	NOT APPLICABLE
	(Former name, former address and former fiscal year, if changed since last report)

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 ý 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 ý No ¨

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



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

Table of Contents

If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended 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 ý

The number of shares of the registrant’s Common Stock, $.05 par value, outstanding as of ~~November~~May 67, ~~2017~~2018 was 63,~~229~~219,~~036~~047.

Table of Contents

WILLBROS GROUP, INC.

FORM 10-Q

FOR QUARTER ENDED ~~SEPTEMBER~~MARCH 3031, ~~2017~~2018

	Page
PART I – FINANCIAL INFORMATION
Item 1. Financial Statements
Condensed Consolidated Balance Sheets (Unaudited) as of September 30, 2017 and December 31, 2016	4
Condensed Consolidated Balance Sheets (Unaudited) as of March 31, 2018 and December 31, 2017	4
Condensed Consolidated Statements of Operations (Unaudited) for the three months and nine months ended September 30, 2017 and 2016	5
Condensed Consolidated Statements of Operations (Unaudited) for the three months ended March 31, 2018 and 2017	5
Condensed Consolidated Statements of Comprehensive Loss (Unaudited) for the three months and nine months ended September 30, 2017 and 2016	6
Condensed Consolidated Statements of Comprehensive Loss (Unaudited) for the three months ended March 31, 2018 and 2017	6
Condensed Consolidated Statements of Cash Flows (Unaudited) for the nine months ended September 30, 2017 and 2016	7
Condensed Consolidated Statements of Cash Flows (Unaudited) for the three months ended March 31, 2018 and 2017	7
Notes to Condensed Consolidated Financial Statements (Unaudited)	8
Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations	3135
Item 3. Quantitative and Qualitative Disclosures About Market Risk	4953
Item 4. Controls and Procedures	5054
PART II – OTHER INFORMATION
Item 1. Legal Proceedings	5155
Item 1A. Risk Factors	5155
Item 2. Unregistered Sales of Equity Securities and Use of Proceeds	5255
Item 3. Defaults Upon Senior Securities	5255
Item 4. Mine Safety Disclosures	5255
Item 5. Other Information	5255
Item 6. Exhibits	5456
SIGNATURE	5557

Table of Contents

PART I—FINANCIAL INFORMATION

ITEM 1. FINANCIAL STATEMENTS

WILLBROS GROUP, INC.

CONDENSED CONSOLIDATED BALANCE SHEETS

(In thousands, except share and per share amounts)

(Unaudited)

	September 30, 2017			December 31, 2016
	March 31, 2018			December 31, 2017
ASSETS
Current assets:
Cash and cash equivalents	$	3121,~~294~~364		$	4133,~~420~~472
Accounts receivable, net	~~156~~134,~~589~~560			~~112~~142,~~037~~192
Contract cost and recognized income not yet billed	2621,~~466~~615			1113,~~938~~992
Prepaid expenses and other current assets	1924,~~031~~405			1820,~~416~~760
Parts and supplies inventories	~~908~~2,432			~~800~~1,152
Assets held for sale	121,~~235~~604			91,~~050~~804
Current assets associated with discontinued operations	69			505
Assets associated with discontinued operations	336			324
Total current assets	~~246~~206,~~592~~316			~~194~~213,~~166~~696
Property, plant and equipment, net	3124,~~915~~776			3830,~~123~~113
Intangible assets, net	6963,~~598~~950			7667,~~848~~181
Restricted cash	40,~~333~~473			40,~~206~~367
Deferred income taxes	409			315
Other long-term assets	13,524			12,520
Other long-term assets	11,706			13,378
Total assets	$	349,039		$	363,877
Total assets	$	400,553		$	363,036
LIABILITIES AND STOCKHOLDERS’ EQUITY
Current liabilities:
Accounts payable and accrued liabilities	$	~~147~~141,~~327~~884		$	83138,~~488~~161
Contract billings in excess of cost and recognized income	139,~~067~~346			417,~~938~~814
Short-term borrowings under revolving credit facility	12,000			—
Current maturities of long-term debt	116,857			105,175
Accrued income taxes	310			311
Short-term borrowings under revolving credit facility	23,045			28,108
Other current liabilities	6,002			6,253
Accrued income taxes	320			310
Liabilities held for sale	9,712			8,275
Other current liabilities	6,200			6,056
Current liabilities associated with discontinued operations	1,554			1,578
Liabilities held for sale	—			865
Total current liabilities	189,972			104,843
Current liabilities associated with discontinued operations	1,028			1,091
Long-term debt obligations	88,927			89,189
Total current liabilities	298,680			297,580
Other long-term liabilities	34,324			32,872
Long-term liabilities for unrecognized tax benefits	612			603
Long-term liabilities associated with discontinued operations	1,035			995
Other long-term liabilities	33,780			33,093
Total liabilities	314,258			227,899
Long-term liabilities associated with discontinued operations	794			893
Total liabilities	333,866			332,169
Contingencies and commitments (Note 13)
Stockholders’ equity:
Preferred stock, par value $.01 per share, 1,000,000 shares authorized, none issued	—			—
Common stock, par value $.05 per share, 105,000,000 shares authorized and 65,531,300 shares issued at September 30, 2017 (64,679,896 at December 31, 2016)	3,268			3,226
Common stock, par value $.05 per share, 105,000,000 shares authorized and 65,613,565 shares issued at March 31, 2018 (65,598,095 at December 31, 2017)	3,272			3,271
Additional paid-in capital	~~751~~752,~~382~~640			~~749~~752,~~303~~117
Accumulated deficit	(~~651~~723,~~095~~081		)	(~~598~~706,~~021~~116		)
Treasury stock at cost, 2,304,670 shares at September 30, 2017 (2,025,208 at December 31, 2016)	(15,679		)	(15,137		)
Treasury stock at cost, 2,406,051 shares at March 31, 2018 (2,361,343 at December 31, 2017)	(15,729		)	(15,702		)
Accumulated other comprehensive loss	(1,~~581~~929		)	(41,~~234~~862		)
Total stockholders’ equity	8615,~~295~~173			~~135~~31,~~137~~708
Total liabilities and stockholders’ equity	$	~~400~~349,~~553~~039		$	363,~~036~~877

See accompanying notes to condensed consolidated financial statements.

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WILLBROS GROUP, INC.

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS

(In thousands, except share and per share amounts)

(Unaudited)

	Three Months Ended September 30,						Nine Months Ended September 30,
	Three Months Ended March 31,
	2017			2016			2017			2016
	2018			2017
Contract revenue	$	~~240~~200,~~773~~980		$	~~174~~163,~~821~~900		$	~~632,120~~		$	~~567,293~~
Contract costs	~~252~~193,~~961~~294			162,~~806~~219			~~625,548~~			~~526,322~~
Contract income (loss)	(12,188		)	12,015			6,572			40,971
Contract income	7,686			1,681
Amortization of intangibles	2,~~416~~399			2,~~438~~417			~~7,250~~			~~7,315~~
General and administrative	13,~~036~~475			1514,~~377~~051			~~40,260~~			~~47,031~~
Other charges	149			519			1,346			5,146
Gain on sale of assets	(6,080		)	(696		)
Operating loss	(27,789		)	(6,319		)	(42,284		)	(18,521		)
Other charges	8,365			762
Interest expense	(3,817		)	(3,564		)	(10,972		)	(10,433		)
Operating loss	(10,473		)	(14,853		)
Interest income	8			12			23			443
Interest expense	(6,528		)	(3,488		)
Debt covenant suspension and extinguishment charges	—			—			—			(63		)
Interest income	8			8
Other, net	2137			2(3		)	2			—
Loss from continuing operations before income taxes	(3116,~~577~~956		)	(918,~~869~~336		)	~~(53,231~~		)	~~(28,574~~		)
Provision (benefit) for income taxes	1,132			792			(1,665		)	1,146
Benefit for income taxes	(221		)	(600		)
Loss from continuing operations	(3216,~~709~~735		)	(1017,~~661~~736		)	~~(51,566~~		)	~~(29,720~~		)
Loss from discontinued operations net of provision for income taxes	(~~1,496~~230		)	(~~1,325~~31		)	~~(1,508~~		)	~~(3,836~~		)
Net loss	$	(3416,~~205~~965	)	$	(1117,~~986~~767	)	$	~~(53,074~~	)	$	~~(33,556~~	)
Basic loss per share attributable to Company shareholders:
Loss from continuing operations	$	(0.5227	)	$	(0.1729	)	$	~~(0.83~~	)	$	~~(0.49~~	)
Loss from discontinued operations	~~(0.02~~—		)	~~(0.02~~—		)	~~(0.02~~		)	~~(0.06~~		)
Net loss	$	(0.5427	)	$	(0.1929	)	$	~~(0.85~~	)	$	~~(0.55~~	)
Diluted loss per share attributable to Company shareholders:
Loss from continuing operations	$	(0.5227	)	$	(0.1729	)	$	~~(0.83~~	)	$	~~(0.49~~	)
Loss from discontinued operations	~~(0.02~~—		)	~~(0.02~~—		)	~~(0.02~~		)	~~(0.06~~		)
Net loss	$	(0.5427	)	$	(0.1929	)	$	~~(0.85~~	)	$	~~(0.55~~	)
Weighted average number of common shares outstanding:
Basic	62,~~310~~404,~~191~~906			61,~~639~~829,~~590~~768			~~62,105,282~~			~~61,257,851~~
Diluted	62,~~310~~404,~~191~~906			61,~~639~~829,~~590~~768			~~62,105,282~~			~~61,257,851~~

See accompanying notes to condensed consolidated financial statements.

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WILLBROS GROUP, INC.

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE LOSS

(In thousands)

(Unaudited)

	Three Months Ended September 30,						Nine Months Ended September 30,
	Three Months Ended March 31,
	2017			2016			2017			2016
	2018			2017
Net loss	$	(3416,~~205~~965	)	$	(1117,~~986~~767	)	$	~~(53,074~~	)	$	~~(33,556~~	)
Other comprehensive income (loss), net of tax
Foreign currency translation adjustments	~~1,054~~(343		)	~~(495~~219		)	~~1,842~~			~~1,273~~
Changes in derivative financial instruments	~~273~~276			~~273~~267			~~811~~			~~949~~
Total other comprehensive income (loss) net of tax	~~1,327~~(67		)	~~(222~~486		)	~~2,653~~			~~2,222~~
Total comprehensive loss	$	(3217,~~878~~032	)	$	(1217,~~208~~281	)	$	~~(50,421~~	)	$	~~(31,334~~	)

See accompanying notes to condensed consolidated financial statements.

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WILLBROS GROUP, INC.

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(In thousands)

(Unaudited)

	Nine Months Ended September 30,
	Three Months Ended March 31,
	2017			2016
	2018			2017
Cash flows from operating activities:
Net loss	$	(5316,~~074~~965	)	$	(3317,~~556~~767	)
Adjustments to reconcile net loss to net cash provided by (used in) operating activities:
Loss from discontinued operations	~~1,508~~230			~~3,836~~31
Depreciation and amortization	144,~~600~~315			165,~~694~~037
Debt covenant suspension and extinguishment charges	—			63
Stock-based compensation	524			906
Stock-based compensation	2,121			3,269
Amortization of debt issuance costs	718			410
Amortization of debt issuance costs	1,503			704
Non-cash interest expense	1,316			517
Non-cash interest expense	1,582			1,665
Provision (benefit) for deferred income taxes	—			(31		)
Provision (benefit) for deferred income taxes	(67		)	487
Gain on sale of assets	(6,080		)	(696		)
Gain on disposal of property and equipment	(2,545		)	(2,851		)
Provision for bad debt	16			44
Provision for bad debt	178			106
Changes in operating assets and liabilities:
Accounts receivable, net	~~(43~~7,~~969~~115		)	~~16,466~~92
Contract cost and recognized income not yet billed	(147,~~416~~655		)	3(5,~~648~~162		)
Prepaid expenses and other current assets	(~~492~~3,694		)	~~177~~(206		)
Accounts payable and accrued liabilities	623,~~502~~593			~~(14~~9,~~105~~972		)
Accrued income taxes	(110		)	~~(665~~80		)
Contract billings in excess of cost and recognized income	(8,~~108~~474		)	(32,~~438~~724		)
Assets held for sale	~~(3,185~~—		)	—(8,670		)
Liabilities held for sale	~~1,437~~—			—9,748
Other assets and liabilities, net	~~2,653~~(908		)	(~~732~~714		)
Cash used in operating activities from continuing operations	(2125,~~557~~939		)	(83,~~232~~685		)
Cash used in operating activities from discontinued operations	(~~1,056~~404		)	(~~7,030~~240		)
Cash used in operating activities	(2226,~~613~~343		)	(153,~~262~~925		)
Cash flows from investing activities:
Proceeds from sales of property, plant and equipment	3,589			5,311
Proceeds from sale of property, plant and equipment	7,848			1,094
Proceeds from sale of subsidiaries	950			9,963
Proceeds from sale of subsidiary	2,500			950
Purchases of property, plant and equipment	(~~2,132~~385		)	(~~2,528~~493		)
Changes in restricted cash	(127		)	(6,107		)
Cash provided by investing activities from continuing operations	9,963			1,551
Cash provided by investing activities from continuing operations	2,280			6,639
Cash provided by (used in) investing activities from discontinued operations	—			—
Cash provided by investing activities	29,~~280~~963			61,~~639~~551
Cash flows from financing activities:
Proceeds from revolving credit facility	~~12,000~~72			—
Payments on capital leases	—			(469		)
Proceeds from Initial First-Out Loan	10,000			—
Payments on term loan facility	—			(3,128		)
Payments on revolving credit facility	(5,000		)	—
Cost of debt issuance	(~~2,306~~528		)	(42,~~612~~306		)
Payments to reacquire common stock	(~~542~~27		)	(~~361~~148		)
Cash provided by (used in) financing activities from continuing operations	94,~~152~~517			(82,~~570~~454		)
Cash provided by (used in) financing activities from discontinued operations	—			—
Cash provided by (used in) financing activities	94,~~152~~517			(82,~~570~~454		)
Effect of exchange rate changes on cash and cash equivalents	1,055			620
Effect of exchange rate changes on cash, cash equivalents and restricted cash	(139		)	86
Net decrease in cash and cash equivalents	(10,126		)	(16,573		)
Net decrease in cash, cash equivalents and restricted cash	(12,002		)	(4,742		)
Cash and cash equivalents at beginning of period	41,420			58,832
Cash, cash equivalents and restricted cash at beginning of period	73,839			81,626
Cash and cash equivalents at end of period	$	31,294		$	42,259
Cash, cash equivalents and restricted cash at end of period	$	61,837		$	76,884
Supplemental disclosures of cash flow information:
Cash paid for interest (including discontinued operations)	$	73,~~780~~786		$	62,~~320~~629
Cash paid for income taxes (including discontinued operations)	$	~~446~~7		$	~~1,501~~10

See accompanying notes to condensed consolidated financial statements.

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WILLBROS GROUP, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

1. Company Description and ~~Organization~~Financial Condition

Company ~~Information~~Description

Willbros Group, Inc., a Delaware corporation, and its subsidiaries (the “Company,” “Willbros” or “WGI”), is a specialty energy infrastructure contractor serving the oil and gas and power industries with offerings that primarily include construction, maintenance and facilities development services. The Company’s principal markets for continuing operations are the United States and Canada. The Company obtains its work through competitive bidding and negotiations with prospective clients. Contract values range from several thousand dollars to several hundred million dollars, and contract durations range from a few weeks to more than two years. ~~The Company has three reportable segments: Oil & Gas, Utility T&D and Canada.~~

~~The~~Business ~~Company's~~Segments Oil & Gas segment provides construction, maintenance and lifecycle extension services to the midstream markets. These services include pipeline construction to support the transportation and storage of hydrocarbons, including gathering, lateral and main-line pipeline systems, as well as, facilities construction such as pump stations, flow stations, gas compressor stations and metering stations. In addition, the Oil & Gas segment provides integrity construction and pipeline systems maintenance to a number of different customers. See Additional Sources and Uses of Capital below for more information related to the Company's future plans regarding the Oil & Gas segment.

The ~~Oil~~Company &has ~~Gas~~three ~~segment's~~reportable ~~tank~~segments: ~~services~~Utility ~~business is classified as held for sale at September 30~~T&D, ~~2017.~~Canada ~~See~~and ~~Note~~Oil 5& ~~- Assets Held for Sale for more information~~Gas.

The ~~Company's~~ Utility T&D segment provides a wide range of services in electric and natural gas transmission and distribution, including comprehensive engineering, procurement, maintenance and construction, repair and restoration of utility infrastructure. These services include engineering, design, installation, maintenance, procurement and repair of electrical transmission, distribution, substation, wireless and gas distribution systems. The Company'’s Utility T&D segment conducts projects ranging from small engineering and consulting projects to multi-million dollar turnkey distribution, substation and transmission line projects, including those required for renewable energy facilities.

~~The~~On ~~Company's~~March ~~Canada~~5, ~~segment~~2018, ~~provides construction~~Oncor, ~~maintenance~~the ~~and~~Company’s ~~fabrication~~largest ~~services,~~customer ~~including~~in ~~integrity~~the ~~and~~Utility ~~supporting~~T&D ~~civil work~~segment, ~~pipeline~~notified ~~construction,~~the ~~general~~Company ~~mechanical~~of ~~and~~its ~~facility~~election ~~construction,~~to ~~API~~extend ~~storage~~its ~~tanks,~~alliance ~~general~~agreement ~~and~~under ~~modular~~the ~~fabrication,~~terms ~~along with electrical~~ and ~~instrumentation~~conditions ~~projects~~currently ~~serving~~in ~~the~~effect, ~~Canadian~~through ~~energy~~December ~~and~~31, ~~water industries~~2019.

~~Additional~~The ~~Sources~~Company’s Canada segment provides construction, maintenance and ~~Uses~~fabrication ofservices, ~~Capital~~including integrity and supporting civil work, pipeline construction, general mechanical and facility construction, American Petroleum Institute (“API”) storage tanks, general and modular fabrication, along with electrical and instrumentation projects serving the Canadian energy and water industries.

~~Due~~The toCompany’s ~~significant operating losses during the third quarter of 2017 primarily driven by losses on two mainline pipeline construction projects and a small-diameter pipeline construction project in its~~ Oil & Gas segment, anprovides ~~increased~~construction, ~~volume~~maintenance ~~discount associated with its alliance agreement with a major customer~~ and ~~losses~~lifecycle onextension ~~two~~services ~~discrete~~to ~~projects in its Utility T&D segment,~~ the ~~Company~~midstream ~~was~~markets. ~~not~~These inservices ~~compliance~~include ~~with~~facilities ~~the~~construction ~~Maximum~~such ~~Total~~as ~~Leverage~~tank ~~Ratio and Minimum Interest Coverage Ratio for the quarterly period ended September 30~~terminals, ~~2017.~~pump ~~In addition~~stations, inflow ~~combination with its current forecast~~stations, ~~the~~gas ~~Company~~compressor ~~did~~stations ~~not expect to be in compliance with the Maximum Total Leverage Ratio~~ and ~~Minimum~~metering ~~Interest~~stations, ~~Coverage~~as ~~Ratio~~well ~~for~~as ~~the~~small-diameter ~~period~~midstream ~~from~~pipeline ~~December 31~~construction, ~~2017~~integrity ~~through~~construction ~~December~~and ~~31,~~system ~~2018~~maintenance. ~~The Company also generated negative operating cash flow of approximately $22.6 million in the third quarter of 2017.~~

InOn ~~response~~January to2, ~~the above~~2018, the Company ~~performed~~sold ~~the~~its ~~following~~tank ~~mitigating~~services ~~actions~~business, towhich ~~ensure~~was ithistorically ~~has~~included ~~sufficient~~in ~~liquidity~~its ~~and~~Oil ~~capital~~& ~~resources~~Gas segment, to ~~meet~~ATS ~~its~~Group, ~~obligations~~Inc. (“ATS”) for a $3.0 million purchase price subject to working capital and other adjustments. In connection with this transaction, the ~~next~~Company ~~twelve~~received cash proceeds of $2.5 million and recorded a net gain on sale of $1.0 million, which is included in the line item “Gain on sale of assets” in the Company’s Condensed Consolidated Statement of Operations for the three months: ended March 31, 2018. See Note 5 – Assets Held for Sale for more information.

•On ~~Announced~~January ~~plans~~9, to2018, ~~de-risk~~ the Company byentered ~~exiting~~into ~~the~~an ~~U.S.~~Asset Purchase Agreement to sell assets comprising its mainline pipeline construction business (the “Asset Purchase Agreement”), which was historically included in ~~the~~its Oil & Gas segment., ~~The~~to ~~Company~~WB ~~plans~~Pipeline, toLLC, ~~continue~~an toaffiliate ~~perform~~of ~~facilities~~Meridien ~~and~~Energy, ~~integrity~~LLC. ~~construction~~(“Meridien”). ~~services~~For asmore ~~well~~information, assee ~~small-diameter~~the ~~pipeline~~subsection ~~construction~~“Sale ~~services~~of inMainline ~~the~~Pipeline ~~Northeast;~~Construction Business” below.

•Merger Obtained additional liquidity of $15.0 million in the form of a commitment for an additional term loan pursuant to a Sixth Amendment to the Company's 2014 Term Loan Facility (the “Sixth Amendment”);Agreement

•On ~~Borrowed~~March 27, 2018, the Company entered into an ~~additional~~Agreement ~~$17~~and Plan of Merger (the “Merger Agreement”) with Primoris Services Corporation (“Primoris”) and Waco Acquisition Vehicle, Inc., a wholly-owned subsidiary of Primoris (“Merger Sub”). Pursuant to the Merger Agreement, Merger Sub will be merged into the Company, and the Company will become a wholly owned subsidiary of Primoris. The Merger Agreement includes customary representations, warranties and covenants. Primoris will pay $0.60 ~~million~~per ~~under~~share for all of the ~~2013~~Company’s ~~ABL~~outstanding ~~Credit~~common ~~Facility;~~stock. The Merger Agreement is expected to close in the second quarter of 2018, subject to satisfaction of customary closing conditions, including approval of the Merger Agreement by the requisite vote of the Company’s stockholders. Upon termination of the Merger Agreement in certain circumstances, the Company is obligated to pay Primoris a termination fee of $4.3 million and, in certain other circumstances, a termination fee of $8.0 million.

• Obtained covenant relief pursuant to the Sixth Amendment as follows.

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WILLBROS GROUP, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

1. Company Description and ~~Organization~~Financial Condition (continued)

~~2018~~Term ~~and~~Forbearance increase to 2.75 to 1.00 as of March 31, 2019, and thereafter. The Sixth Amendment also provides that, for the four-quarter period ending March 31, 2018, Consolidated EBITDA shall be equal to the sum of Consolidated EBITDA for the quarterly periods ending December 31, 2017 and March 31, 2018 multiplied by two, and, for the four-quarter period ending June 30, 2018, Consolidated EBITDA shall be equal to the annualized sum of Consolidated EBITDA for the quarterly periods ending December 31, 2017, March 31, 2018 and June 30, 2018.Agreement

InOn ~~addition~~March to27, 2018, the ~~decision~~Company toentered ~~exit~~into a Forbearance Agreement (the U“Term Forbearance Agreement”) with the lenders under the 2014 Term Credit Agreement (the “Term Lenders”).S. ~~mainline~~Under ~~pipeline~~the ~~construction~~Term ~~business~~Forbearance inAgreement, the ~~Oil~~Term &Lenders ~~Gas~~agreed ~~segment~~to, ~~obtain~~among ~~additional~~other ~~liquidity~~things, ~~pursuant~~forbear from taking any action to enforce certain of their rights or remedies under the ~~Sixth~~2014 ~~Amendment~~Term Credit Agreement with respect to certain defaults and ~~increase~~events ~~its~~of ~~revolver~~default ~~borrowings~~(the “Term Specified Defaults”). The Term Forbearance Agreement is effective until the earliest of (i) August 15, 2018 or the ~~Company~~closing isof ~~evaluating~~the ~~options~~Merger toAgreement ~~extend~~or (ii) the occurrence of any one of several specified termination events including, ~~modify~~among other things, the termination of the Merger Agreement (the “Term Forbearance Period”). Upon expiration of the Term Forbearance Agreement or ~~refinance~~if the ~~2013~~Company ~~ABL~~were to default under the Term Forbearance Agreement or the 2014 Term Credit ~~Facility~~Agreement, other than Term Specified Defaults, the Term Lenders would be free to exercise any rights and remedies with respect to such defaults and events of defaults pursuant to the terms of the 2014 Term Credit Agreement.

Concurrent with the effectiveness of the Sixth Amendment, the decision to exit the U.S. mainline pipeline construction business in the Oil & Gas segment and the expected ability to extend, modify or refinance the 2013 ABL ~~Credit~~Forbearance Facility, coupled with its cash on hand, including recent and additional anticipated borrowings under the 2013 ABL Credit Facility and the 2014 Term Loan Facility, its current forecasts and its projected cash flow from operations, the Company expects to meet its required financial covenants and have sufficient liquidity and capital resources to meet its obligations for at least the next twelve months. However, the Company's results of operations must improve in the fourth quarter of 2017 and into 2018 in order to meet its forecasts and required financial covenants. In addition, while the Company expects to extend, modify or refinance the 2013 ABL Credit Facility, there can be no assurance that the Company will be able to extend, modify or negotiate agreeable refinancing terms prior to the expiration of the 2013 ABL Credit Facility.Agreement

~~See~~On ~~Note~~March 827, -2018, ~~Debt~~the ~~Obligations~~Company ~~for~~entered ~~more~~into ~~information~~a onLimited Forbearance Agreement (the ~~Sixth~~“ABL ~~Amendment~~Forbearance Agreement”) with the lenders under the 2013 ABL Credit Facility (the “ABL Lenders”). Under the ABL Forbearance Agreement, the ABL Lenders agreed to, among other things, forbear from taking any action to enforce certain of their rights or remedies under the 2013 ABL Credit Facility with respect to certain defaults and events of default (the “ABL Specified Defaults”). The ABL Forbearance Agreement is effective until the earliest of (i) July 31, 2018 or the closing of the Merger Agreement or (ii) the occurrence of any one of several specified termination events including, among other things, the termination of the Merger Agreement (the “ABL Forbearance Period”). Upon expiration of the ABL Forbearance Agreement or if the Company were to default under the ABL Forbearance Agreement or the 2013 ABL Credit Facility, other than ABL Specified Defaults, the ABL Lenders would be free to exercise any rights and remedies with respect to such defaults and events of defaults pursuant to the terms of the 2013 ABL Credit Facility.

Seventh Amendment to the 2014 Term Credit Agreement

On March 27, 2018, the Company amended the 2014 Term Credit Agreement pursuant to a Seventh Amendment among the Company, as borrower, the guarantors from time to time party thereto, Primoris as initial first-out lender, the lenders from time to time party thereto and Cortland Capital Market Services LLC, as administrative agent (the “Seventh Amendment”). Under the terms of the Seventh Amendment, Primoris provided the Company with an additional term loan in an amount equal to $10.0 million (the “Initial First-Out Loan”) that was drawn in full on March 30, 2018 and bears the same maturity date as the aggregate outstanding principal balance of the Company’s 2014 Term Loan Facility.

In addition, under the terms of the Seventh Amendment, Primoris may provide the Company with additional term loans in an aggregate amount not to exceed $10.0 million (the “Additional First-Out Loans”). Interest payable with respect to the Initial First-Out Loan and any Additional First-Out Loans will be paid in-kind through additions to the principal amount of such loans.

The Seventh Amendment further provides that, until the termination of the Term Forbearance Period, the due date of any payments due and owing to the lenders (other than Primoris) under the 2014 Term Credit Agreement will be deferred until the fifth business day after the date of the termination of the Term Forbearance Period. In addition, the Seventh Amendment provides that the payment by the borrower of an amount equal to $100.0 million plus the expenses of the administrative agent in an amount not to exceed $1.1 million shall constitute payment in full and satisfaction and discharge of all obligations of the borrower and the other loan parties under the 2014 Term Credit Agreement, but solely if such payment is made in connection with the consummation of the merger.

Going Concern

In 2017, the Company incurred significant operating losses, cash outflows from operating activities and a net working capital deficiency. These significant operating losses continued to generate negative cash outflows in the first quarter of 2018. The Company is not in compliance with the Maximum Total Leverage Ratio and Minimum Interest Coverage Ratio for the quarterly period ended March 31, 2018 and does not expect to be in compliance with the Maximum Total Leverage Ratio and Minimum Interest Coverage Ratio under the 2014 Term Credit Agreement for the next twelve months, primarily due to these significant operating losses. In addition, the Company is currently not in compliance with certain other provisions under the 2014 Term Credit Agreement and the 2013 ABL Credit Facility, which expires on August 7, 2018. Absent the temporary forbearance provided under the Term Forbearance Agreement and the ABL Forbearance Agreement, all of the Company’s debt obligations would become due under the default provisions in the 2014 Term Credit Agreement and the 2013 ABL Credit

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WILLBROS GROUP, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

1. Company Description and Financial Condition (continued)

Facility. In addition, these significant operating losses and cash outflows have put a considerable strain on the Company’s overall liquidity. Although the Seventh Amendment provides the Company with additional short-term liquidity for the period between the signing of the Merger Agreement and the completion of the merger, the Company can provide no assurance that the merger will be completed. If the Company is unable to complete the merger, it will likely need to explore other strategic alternatives, which could include seeking protection under the U.S. Bankruptcy laws.

The Company’s continuing failure to comply with financial covenants and other covenants, its inability to extend or refinance the 2013 ABL Credit Facility and its continuing liquidity issues raise substantial doubt about its ability to continue as a going concern, notwithstanding the temporary forbearance provided under the Term Forbearance Agreement and the ABL Forbearance Agreement and the short-term liquidity provided by the Seventh Amendment.

In consideration of the above facts and circumstances, at March 31, 2018, the Company has classified all of its debt obligations as current, which has caused its current liabilities to far exceed its current assets since such date. These debt obligations, net of unamortized discount and debt issuance costs, approximate $139.9 million at March 31, 2018.

Sale of Mainline Pipeline Construction Business

In connection with the Asset Purchase Agreement, the Company recorded a gain on sale of $4.4 million, which is included in the line item “Gain on sale of assets” in the Company’s Condensed Consolidated Statement of Operations for the three months ended March 31, 2018. The remaining assets associated with the Asset Purchase Agreement are classified as “Assets held for sale” in the Company’s Condensed Consolidated Balance Sheet at March 31, 2018. See Note 5 – Assets Held for Sale for more information.

In addition, as part of the Asset Purchase Agreement, the Company retained the three mainline pipeline construction projects associated with its mainline pipeline construction business through completion. Two of these projects have reached mechanical completion with an existing letter of credit returned in the first quarter of 2018. The remaining right-of-way restoration and other clean-up activities associated with these projects are expected to be completed by the end of the third quarter of 2018.

With respect to the remaining mainline pipeline construction project, in the first quarter of 2018, the Company reached an agreement with the customer to mutually conclude the remaining work. In addition, the agreement releases the Company from further liability at the completion of the project. As such, the Company has withdrawn and released any outstanding change orders or claims associated with the project.

2. Basis of Presentation

Condensed Consolidated Financial Information

The accompanying Condensed Consolidated Balance Sheet as of ~~December~~March 31, ~~2016~~2018, which has been derived from audited Consolidated Financial Statements, and the unaudited Condensed Consolidated Financial Statements as of ~~September~~March 3031, ~~2017~~2018 and ~~2016~~2017, have been prepared pursuant to the rules and regulations of the Securities and Exchange Commission (“SEC”). Accordingly, certain information and note disclosures normally included in annual financial statements prepared in accordance with U.S. generally accepted accounting principles (“GAAP”) have been condensed or omitted pursuant to those rules and regulations. However, the Company believes the presentations and disclosures herein are adequate to make the information not misleading. These unaudited Condensed Consolidated Financial Statements should be read in conjunction with the Company’s December 31, ~~2016~~2017 audited Consolidated Financial Statements and notes thereto contained in the Company’s Annual Report on Form 10-K for the year ended December 31, ~~2016~~2017.

In the opinion of management, the unaudited Condensed Consolidated Financial Statements reflect all recurring adjustments necessary to fairly state the financial position as of ~~September~~March 3031, ~~2017~~2018, and the results of operations and cash flows of the Company for all interim periods presented. The results of operations and cash flows for the ~~nine~~three months ended ~~September~~March 3031, ~~2017~~2018 are not necessarily indicative of the operating results and cash flows to be achieved for the full year.

~~Use of Estimates and Assumptions~~10

The Condensed Consolidated Financial Statements include certain estimates and assumptions made by management. These estimates and assumptions relate to the reported amounts of assets and liabilities at the dates of the Condensed Consolidated Financial Statements and the reported amounts of revenue and expense during those periods. Significant items subject to such estimates and assumptions include revenue recognition under the percentage-of-completion method of accounting, including estimates of progress towards completion and estimates of gross profit or loss accrual on contracts in progress; tax accruals and certain other accrued liabilities; quantification of amounts recorded for contingencies; valuation allowances for accounts receivable and deferred income tax assets; and the carrying amount of property, plant and equipment, goodwill and intangible assets. The Company bases its estimates on historical experience and other assumptions it believes to be relevant under the circumstances. Actual results could differ from those estimates.

The Company's contract income (loss) was negatively impacted by $0.1 million for the three months ended September 30, 2017, and positively impacted by $1.6 million for the nine months ended September 30, 2017, as a result of changes in contract estimates related to projects that were in progress at December 31, 2016. Included in these changes in contract estimates for the nine months ended September 30, 2017 is a $2.0 million income recovery associated with a claim on a cross-country pipeline project in the Canada segment. The remainder of these changes in contract estimates are primarily attributed to, among other things, changes in estimated costs for certain individually immaterial projects as they progress to completion;

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WILLBROS GROUP, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

2. Basis of Presentation (continued)

~~the~~Use ~~realization~~ of ~~change~~Estimates ~~orders related to work previously performed;~~ and ~~other changes in events, facts and circumstances during the period in which the estimate was revised.~~Assumptions

The ~~Company's~~Condensed ~~contract~~Consolidated ~~income~~Financial ~~was~~Statements ~~positively~~include ~~impacted~~certain estimates and assumptions made by $3management.3 ~~million~~These estimates and ~~$7.1~~assumptions ~~million~~relate ~~for~~to the ~~three~~reported amounts of assets and ~~nine~~liabilities ~~months~~at ~~ended~~the ~~September 30,~~dates ~~2016,~~of ~~respectively,~~the asCondensed aConsolidated ~~result~~Financial Statements and the reported amounts of ~~changes~~revenue inand ~~contract~~expense ~~estimates~~during ~~related~~those periods. Significant items subject to ~~projects~~such ~~that~~estimates ~~were~~and inassumptions ~~progress~~include atrevenue ~~December 31~~recognition over time, ~~2015.~~including ~~These~~estimates ~~changes~~of inprogress ~~contract~~towards completion and estimates ~~are~~of ~~primarily~~gross ~~attributed~~profit ~~to,~~or ~~among~~loss ~~other~~accrual ~~things,~~on ~~changes~~contracts in ~~estimated~~progress; ~~costs~~tax ~~for~~accruals and certain ~~individually~~other ~~immaterial~~accrued ~~projects~~liabilities; asquantification ~~they~~of ~~progress~~amounts torecorded ~~completion~~for contingencies; ~~the~~valuation ~~realization~~allowances offor ~~change~~accounts ~~orders~~receivable ~~related~~and todeferred ~~work~~income ~~previously~~tax ~~performed~~assets; and ~~other~~the ~~changes~~carrying inamount ~~events~~of property, ~~facts~~plant and ~~circumstances~~equipment, ~~during~~goodwill ~~the~~and ~~period~~intangible inassets. ~~which~~The Company bases its estimates on historical experience and other assumptions it believes to be relevant under the ~~estimate~~circumstances. ~~was~~Actual ~~revised~~results could differ from those estimates.

The Company’s contract income was negatively impacted by $2.7 million for the three months ended March 31, 2018 as a result of changes in contract estimates related to projects that were in progress at December 31, 2017. The Company’s contract income was negatively impacted by $0.6 million for the three months ended March 31, 2017 as a result of changes in contract estimates related to projects that were in progress at December 31, 2016. These changes in contract estimates are primarily attributed to, among other things, changes in estimated costs for certain individually immaterial projects as they progress to completion; the realization of change orders related to work previously performed; and other changes in events, facts and circumstances during the period in which the estimate was revised.

Reclassifications

Certain reclassifications have been made to prior period amounts to conform to the current period financial statement presentation. These reclassifications relate to the breakout of the line item “Gain on sale of assets” in the Company’s Condensed Consolidated Statements of Operations.

Change in Presentation

In the second quarter of 2017, the Company adopted a change in presentation on its Condensed Consolidated Statements of Operations in order to present a “Contract income ~~(loss)~~” line item that is consistent with its peers. “Contract income ~~(loss)~~” is defined as contract revenue less contract costs (which is inclusive of both direct and indirect costs). Previously reported information has been modified to conform to this new presentation.

3. New Accounting Standards

Recently Adopted Accounting Standards

In ~~March~~May ~~2016~~2017, the FASB issued Accounting Standards Update (“ASU”) ~~2016~~2017-09, which ~~changes~~clarifies ~~how~~when ~~companies~~a ~~account~~change ~~for~~to ~~certain~~the ~~aspects~~terms or conditions of a share-based payment ~~awards~~award toshould ~~employees,~~be ~~including~~accounted ~~the accounting~~ for ~~income taxes, forfeitures, and statutory tax withholding requirements,~~ as ~~well~~a ~~as classification in the statement of cash flows~~modification. ~~The~~An ~~standard~~entity isshould ~~effective~~account for ~~annual periods beginning after December 15, 2016 and interim periods within those annual periods with early adoption permitted. The Company adopted ASU 2016-09 in~~ the ~~first~~effects ~~quarter with an effective date~~ of ~~January~~a 1,modification ~~2017.~~unless ~~The recognition of previously unrecognized windfall tax benefits increased~~ the ~~Company's~~fair ~~deferred~~value, ~~tax~~vesting ~~assets~~conditions byand ~~$1.8~~classification, ~~million~~as ~~offset~~an byequity ainstrument ~~related~~or ~~valuation allowance which resulted in~~ a $0liability ~~cumulative-effect adjustment~~instrument, ~~net~~ of ~~tax, on~~ the ~~Company's~~modified ~~Condensed~~award ~~Consolidated~~are ~~Balance Sheet as of~~ the ~~beginning~~same ofbefore ~~2017.~~and ~~The~~after ~~amendments~~a ~~within~~change ~~ASU 2016-09 related~~ to the ~~recognition~~terms ofor ~~excess~~conditions ~~tax benefits and tax shortfalls in the Condensed Consolidated Statement~~ of ~~Operations and presentation within~~ the ~~operating~~share-based ~~section~~payment ofaward. ~~the~~The ~~Condensed~~standard ~~Consolidated~~is ~~Statement~~effective offor ~~Cash~~annual ~~Flows~~reporting ~~were~~periods ~~adopted~~beginning ~~prospectively~~after ~~with~~December no15, ~~adjustments~~2017, toincluding ~~prior~~interim periods. ~~The~~within ~~Company~~those ~~has~~annual ~~elected~~reporting ~~to account for forfeitures as they occur~~periods. ~~The~~This ~~remaining~~standard ~~provisions of ASU 2016-09~~ did not ~~have~~impact ~~a material effect on~~ the Company'’s Condensed Consolidated Financial Statements.

~~Accounting~~In ~~Standards~~November ~~Not~~2016, ~~Yet~~the ~~Adopted~~FASB issued ASU 2016-18, which requires a reporting entity to include restricted cash and restricted cash equivalents in its cash and cash-equivalent balances presented in the entity’s statement of cash flows. A reconciliation between the statement of financial position and the statement of cash flows must be disclosed when the balance sheet includes more than one line item for cash, cash equivalents, restricted cash and restricted cash equivalents. Transfers between non-restricted and restricted cash should not be presented as cash flow activities in the statement of cash flows. Furthermore, an entity with a material restricted cash balance must disclose information regarding the nature of the restrictions. The standard is effective for annual periods beginning after December 15, 2017, including interim periods within those annual reporting periods. The Company adopted this standard in the first quarter of 2018. See the Company’s Condensed Consolidated Statements of Cash Flows for more information.

In ~~May~~October ~~2017~~2016, the FASB issued ASU ~~2017~~2016-0916, which ~~clarifies~~requires ~~when~~ a ~~change~~reporting ~~to the terms or conditions of a share-based payment award should be accounted for as a modification. An~~ entity ~~should~~to ~~account~~recognize ~~for~~ the ~~effects~~tax ofexpense afrom ~~modification unless~~ the ~~fair~~sale ~~value,~~of ~~vesting conditions and classification, as~~ an ~~equity~~asset ~~instrument~~in ~~or a liability instrument, of~~ the ~~modified~~seller’s ~~award~~tax ~~are~~jurisdiction ~~the~~when ~~same before and after a change to~~ the ~~terms~~transfer oroccurs, ~~conditions~~even ofthough the ~~share~~pre-~~based~~tax ~~payment~~effects ~~award.~~of ~~The~~that ~~standard~~transaction isare ~~effective~~eliminated ~~for~~in ~~annual reporting periods beginning after December 15, 2017, including interim periods within those annual reporting periods~~consolidation. The ~~Company~~new guidance does not ~~expect~~apply ~~the new standard~~ to ~~have~~intra-entity atransfers ~~material~~of ~~impact~~inventory, onand ~~its~~the ~~Condensed~~income ~~Consolidated~~tax ~~Financial Statements.~~

In November 2016, the FASB issued ASU 2016-18, which requires a reporting entity to include restricted cash and restricted cash equivalents in its cash and cash-equivalent balances presented in the entity's statement of cash flows. A reconciliation between the statement of financial position and the statement of cash flows must be disclosed when the balance sheet includes more than one line item for cash, cash equivalents, restricted cash and restricted cash equivalents. Transfers between non-restricted and restricted cash should not be presented as cash flow activities in the statement of cash flows. Furthermore, an entity with a material restricted cash balance must disclose information regarding the nature of the restrictions. The standard is effective for annual periods beginning after December 15, 2017, including interim periods within those annual reporting periods. At September 30, 2017 and December 31, 2016, approximately $40.3 million and $40.2 million, respectively, is recorded as “Restricted cash” on the Company's Condensed Consolidated Balance Sheets. These amounts are primarily composed of eligible pledged cash in the Company's September 30, 2017 and December 31, 2016 borrowing base calculation. The Company will adopt this standard in the first quarter of 2018.11

In October 2016, the FASB issued ASU 2016-16, which requires a reporting entity to recognize the tax expense from the sale of an asset in the seller's tax jurisdiction when the transfer occurs, even though the pre-tax effects of that transaction are eliminated in consolidation. The new guidance does not apply to intra-entity transfers of inventory, and the income tax

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WILLBROS GROUP, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

3. New Accounting Standards (continued)

consequences from the sale of inventory from one member of a consolidated entity to another will continue to be deferred until the inventory is sold to a third party. The standard is effective for annual reporting periods beginning after December 15, 2017, including interim periods within those annual reporting periods. ~~The~~This ~~Company~~standard isdid ~~currently~~not ~~evaluating the~~ impact of the ~~standard~~Company’s ~~on its~~ Condensed Consolidated Financial Statements.

In August 2016, the FASB issued ASU 2016-15, which provides specific guidance for cash flow classifications of cash payments and receipts to reduce the diversity of treatment of such items. The standard is effective for annual periods beginning after December 15, 2017 and interim periods within those annual periods with early adoption permitted. ~~The~~This ~~Company~~standard ~~does~~did not ~~expect~~impact the ~~new~~Company’s ~~standard to have a material impact on its~~ Condensed Consolidated Financial Statements.

In May 2014, the FASB issued ASU 2014-09, “Revenue from Contracts with Customers (ASC 606)” as modified by subsequently issued ASUs 2015-14, 2016-08, 2016-10, 2016-12 and 2016-20, 2017-13 and 2017-14. ASC 606 supersedes the revenue recognition requirements in “Revenue Recognition (ASC 605)” and requires entities to recognize revenue when control of the promised goods or services are transferred to customers at an amount that reflects the consideration to which the entity expects to be entitled to in exchange for those goods and services. The Company adopted ASC 606 as of January 1, 2018 using the modified retrospective transition method. See Note 4 – Revenue for more information.

Accounting Standards Not Yet Adopted

In February 2018, the FASB issued ASU 2018-02, which provides that the stranded tax effects from the Tax Cuts and Jobs Act on the balance of other comprehensive earnings may be reclassified to retained earnings. The ASU is effective for fiscal years beginning after December 15, 2018, and interim periods within those fiscal years, with an option to adopt early. The Company does not expect this standard to have a material impact on its Condensed Consolidated Financial Statements.

In February 2016, the FASB issued ASU 2016-02, which requires companies that lease assets to recognize on the balance sheet the assets and liabilities for the rights and obligations created by those assets. The standard is effective for interim and annual periods beginning after December 15, 2018. Early adoption is permitted for financial statements of fiscal years or interim periods that have not been previously issued. The Company is currently evaluating the impact of the standard on its Condensed Consolidated Financial Statements. Based on initial evaluation, the Company expects to include operating leases with durations greater than twelve months on its Condensed Consolidated Balance Sheets. The Company will provide additional information about the expected financial impact as it progresses through the evaluation and implementation of the standard.

In May 2014, the FASB issued ASU 2014-09 governing the recognition of revenue from contracts with customers. Under the new standard, a company will recognize revenue when it satisfies a performance obligation by transferring a promised good or service to a customer at an amount that reflects the consideration it expects to receive in exchange for those goods and services. The standard also requires additional disclosure about the nature, amount, timing and uncertainty of revenue and cash flows arising from customer contracts, including significant judgments and changes in judgments and assets recognized from costs incurred to obtain or fulfill a contract. In August 2015, the FASB deferred the effective date of the standard to December 15, 2017 with early adoption permitted. The standard can be applied on a full retrospective or modified retrospective basis whereby the entity records a cumulative effect of initially applying this update at the date of initial application. Furthermore, in March, April, and May of 2016, the FASB issued ASUs 2016-08, 2016-10, and 2016-12, respectively, which provide practical expedients and clarification in regards to ASU 2014-09. ASU 2016-08 amends and clarifies the principal versus agent considerations under the new revenue recognition standard, which requires determination of whether the nature of a promise is to provide the specified good or service to the customer (that is, the entity is a principal) or to arrange for the good or service to be provided to the customer by another party (that is, the entity is an agent); this determination affects the timing and amount of revenue recognition. ASU 2016-10 clarifies issues related to identifying performance obligations. ASU 2016-12 provides practical expedients and clarification pertaining to the exclusion of sales tax from the measurement of a transaction price, the measurement of non-cash consideration, allocation of a transaction price on the basis of all satisfied and unsatisfied performance obligations in a modified contract at transition, and the definition of a completed contract. The effective date of ASUs 2016-08, 2016-10, and 2016-12 is December 15, 2017 with early adoption permitted. The Company will adopt the standards using a modified retrospective approach with the cumulative effect recognized in retained earnings at the date of initial application. As part of its ongoing evaluation of the impact of the standards, the Company is holding regular meetings with key stakeholders from across the organization to discuss the impact of the standards on its existing contracts. The Company is analyzing the impact of the standards on its portfolio of contracts by reviewing its current accounting policies and practices to identify potential differences that would result from applying the requirements of the new standards to its existing revenue contracts. In addition, the Company is currently evaluating the related quantitative and qualitative disclosures arising from the standards. The Company will adopt the standards effective January 1, 2018.

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WILLBROS GROUP, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

4. ~~Contracts in Progress~~Revenue

~~Contract~~Adoption ~~cost and recognized income not yet billed on uncompleted contracts arise when recorded revenues for a contract exceed the amounts billed under the terms~~ of ~~the~~ASC ~~contracts. Contract billings in excess of cost and recognized income arise when billed amounts exceed revenues recorded. Amounts are billable to customers upon various measures of performance~~606, ~~including~~“Revenue ~~achievement~~from ofContracts ~~certain~~with ~~milestones, completion of specified units or completion of the contract.~~Customers”

~~Contract~~On ~~cost~~January ~~and~~1, ~~recognized~~2018, ~~income~~the ~~not~~Company ~~yet~~adopted ~~billed~~ASC ~~and~~606 ~~related~~using ~~amounts~~the ~~billed~~modified retrospective method applied to those contracts which were not completed as of ~~September 30~~January 1, ~~2017~~2018. ~~and~~No ~~December 31,~~adjustment ~~2016~~to beginning 2018 retained earnings was recorded as ~~follows~~a ~~(in~~result ~~thousands):~~of the Company’s adoption.

	September 30, 2017			December 31, 2016
Cost incurred on contracts in progress	$	309,315		$	234,544
Recognized income	20,052			28,702
	329,367			263,246
Progress billings and advance payments	(315,968		)	(256,246		)
	$	13,399		$	7,000
Contract cost and recognized income not yet billed	$	26,466		$	11,938
Contract billings in excess of cost and recognized income	(13,067		)	(4,938		)
	$	13,399		$	7,000

Results for reporting periods beginning after January 1, 2018 are presented under ASC 606, while prior period amounts are not adjusted and continue to be reported in accordance with ASC 605.

~~Contract~~For ~~cost~~the ~~and~~first ~~recognized~~quarter ~~income~~of ~~not~~2018, ~~yet~~the ~~billed~~difference ~~includes~~between ~~$0.9~~the ~~million~~Company’s ~~and~~financial ~~$0.5~~results ~~million~~due atto ~~September 30,~~the ~~2017~~application of ASC 606 on the Company’s contracts and ~~December 31,~~the ~~2016,~~financial ~~respectively,~~results onif ~~completed~~such contracts had been reported under ASC 605 was not material.

~~The~~Performance ~~balances~~Obligations billed but not paid by customers pursuant to retainage provisions in certain contracts are generally due upon completion of the contracts and acceptance by the customer. Based on the Company’s contract terms in recent years, the majority of the retainage balances at each balance sheet date are expected to be collected within the next 12 months. Current retainage balances at September 30, 2017 and December 31, 2016, were approximately $18.9 million and $12.2 million, respectively, and are included in “Accounts receivable, net” in the Condensed Consolidated Balance Sheets. There were no retainage balances with settlement dates beyond the next 12 months at September 30, 2017 and December 31, 2016.

5A performance obligation is a promise in a contract to transfer a distinct good or service to the customer and is the unit of account in ASC 606. ~~Assets~~A ~~Held~~contract’s transaction price is allocated to each distinct performance obligation and recognized as revenue when, or as, the performance obligation is satisfied. The Company elected to present amounts collected from customers for ~~Sale~~sales and other taxes net of the related amounts remitted. Therefore, such amounts are excluded from the determination of the transaction price.

~~Components~~The majority of ~~assets~~the ~~held~~Company’s ~~for~~revenue ~~sale~~is asderived from long-term contracts and programs that can range from a few weeks to more than two years. The majority of ~~September 30,~~these ~~2017~~contracts have a single performance obligation as the promise to transfer the individual goods or services is not separately identifiable from other promises in the contracts and, ~~December 31~~therefore, ~~2016~~not ~~were~~distinct. asFor ~~follows~~contracts (with multiple performance obligations, the Company allocates the transaction price to each performance obligation using its best estimate of the standalone selling price of each distinct good or service in ~~thousands):~~the contract.

	September 30, 2017		December 31, 2016
Accounts receivable, net	$	10,534	$	7,806
Contract cost and recognized income not yet billed	575		136
Prepaid expenses and other assets	36		61
Parts and supplies inventories	455		468
Property, plant and equipment, net	375		318
Intangible assets, net	260		260
Other long-term assets	—		1
Total assets held for sale	$	12,235	$	9,050
Accounts payable and accrued liabilities	$	5,794	$	3,789
Contract billings in excess of cost and recognized income	3,918		4,480
Other current liabilities	—		3
Other long-term liabilities	—		3
Total liabilities held for sale	$	9,712	$	8,275

The primary method used to estimate standalone selling price is the expected cost plus a margin approach. Under this method, the Company forecasts its expected costs of satisfying a performance obligation and then adds an appropriate margin for that distinct good or service. The Company’s performance obligations are satisfied over time as work progresses; therefore, substantially all its revenue in all of its segments is recognized over time. Customer contracts include a standard assurance warranty clause.

~~The~~A ~~above~~portion ~~balances~~of ~~are~~the ~~comprised~~Company’s revenue from goods and services transferred to customers is recognized over time using an input method (i.e. costs incurred to date relative to total estimated costs at completion) to measure progress to completion due to Company performance creating or enhancing an asset that the customer controls. Contract costs include labor, material and overhead. The remainder of the Company'’s ~~tank~~revenue from goods and services ~~business,~~transferred ~~which~~to customers is ~~included~~recognized inover time using an output method (i.e. units delivered or time units elapsed or a combination thereof). This method faithfully depicts the Company'’s ~~Oil~~performance &since ~~Gas~~it ~~segment.~~directly ~~The~~measures ~~tank~~the ~~services~~value ~~business~~of isthe ~~currently~~goods ~~being~~and ~~actively~~services ~~marketed~~transferred to ~~outside~~the ~~parties~~customer and although not common, revenue is ~~expected~~adjusted for any material unrecognized performed service. The Company incurs contract costs to ~~sell~~fulfill ~~within~~performance ~~the~~obligations as an expense when recognizing revenue for services transferred to customers.

12Additionally, as a practical expedient, the Company does not adjust the promised amount of consideration for the effects of a significant financing component if the Company expects, at contract inception, that the period between when the entity transfers a promised good or service to a customer and when the customer pays for that good or service will be one year or less.

At March 31, 2018, the Company had remaining performance obligations (“RPOs”) of $340.7 million. The Company expects to recognize approximately 69.8 percent of its RPOs at March 31, 2018 as revenue within the next twelve months with the remainder expected to be recognized by December 31, 2019.

Contract Estimates

A number of factors relating to the Company’s business affect the recognition of contract revenue. The Company typically structures contracts as unit-price, time and materials, fixed-price, cost plus fixed fee or a combination of fixed price and unit rates. The Company believes that its operating results should be evaluated over a time period during which major contracts in progress are completed and change orders, cost recoveries and other claims are negotiated and realized. Revenue from unit-price and time and materials contracts is recognized as delivered and earned.

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WILLBROS GROUP, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

54. ~~Assets~~Revenue ~~Held for Sale~~ (continued)

~~year~~Revenue for fixed-price and cost plus fixed fee contracts is ~~measured~~recognized atusing the ~~lower~~cost ofto ~~its~~cost ~~carrying~~input ~~value~~method. orUnder ~~fair~~this ~~value~~method, ~~less~~estimated contract income and resulting revenue is generally accrued based on costs incurred to ~~sell~~date as a percentage of total estimated costs, taking into consideration physical completion. ~~Depreciation~~Total estimated costs, and ~~amortization~~thus ~~related~~contract toincome, ~~property~~are impacted by changes in productivity, ~~plant~~scheduling, unit cost of labor, subcontracts, materials and equipment. Additionally, external factors such as weather, client needs, client delays in providing permits and ~~intangible~~approvals, ~~assets~~labor ~~ceased~~availability, ~~upon~~governmental ~~held~~regulation ~~for~~and ~~sale~~politics ~~classification~~may affect the progress of a project’s completion and thus the estimated amount and timing of revenue recognition.

Shipping, handling & fulfillment activities are costs to fulfill the promise to transfer goods and services to the Company’s customers. The Company generally does not recognize income on a fixed-price contract until the contract is approximately five to ten percent complete, depending upon the nature of the contract. If a current estimate of total contract cost indicates a loss on a contract, the projected loss is recognized in full when determined.

Contract modifications are routine in the performance of the Company’s contracts. Contracts are often modified to account for changes in the contract specifications or requirements. In most instances, contract modifications are for goods and services that are not distinct, and therefore, are accounted for as part of the existing contract.

The Company considers unapproved change orders to be contract variations on which the Company has customer approval for scope change but not for price associated with that scope change. Costs associated with unapproved change orders are included in the estimated cost to complete the contracts and are expensed as incurred. The Company recognizes revenue equal to cost incurred on unapproved change orders when realization of price approval is probable and the amount is estimable. Revenue recognized on unapproved change orders is included in “Contract cost and recognized income not yet billed” on the Condensed Consolidated Balance Sheets. Revenue recognized on unapproved change orders is subject to adjustment in subsequent periods to reflect the changes in estimates or final agreements with customers.

The nature of the Company’s contracts gives rise to several types of variable consideration, including claims, incentives and volume discounts. The Company considers claims to be amounts that the Company seeks or will seek to collect from customers or others for customer-caused changes in contract specifications or design, or other customer-related causes of unanticipated additional contract costs on which there is no agreement with customers on both scope and price changes. Revenue from claims is recognized when agreement is reached with customers as to the value of the claims, which in some instances may not occur until after completion of work under the contract. Costs associated with claims are included in the estimated costs to complete the contracts and are expensed when incurred. Certain fixed-price and cost plus fixed fee contracts include, or are amended to include, incentive bonus amounts, contingent on accomplishing a stated milestone. Revenue attributable to incentives is recognized when the risk and uncertainty surrounding the achievement of the milestone have been removed.

To the extent variable consideration is material, it can be estimated by either using an expected value method using probability weighting or using the most likely amount based on the single most likely amount that best predicts the amount of considerations to which the Company will be entitled based on the terms of the contract.

As a significant change in one or more of these estimates could affect the profitability of its contracts, the Company reviews and updates the contract-related estimates regularly. The Company recognizes adjustments in estimated profit on contracts under the cumulative catch-up method. Under this method, the impact of the adjustment on profit recorded to date on a contract is recognized in the period the adjustment is identified. Revenue and profit in future periods of contract performance are recognized using the adjusted estimate.

Contract Balances and Accounts Receivable

The timing of revenue recognition, billings and cash collections results in unbilled accounts receivables, contract assets and contract liabilities on the Company’s Condensed Consolidated Balance Sheets and are recorded on a contract-by-contract basis. Contract cost and recognized income not yet billed on uncompleted contracts (“contract assets”) arise when recorded revenues for a contract exceed the amounts billed under the terms of the contracts. These contract assets are recorded as receivables when the rights become unconditional. Contract billings in excess of cost and recognized income (“contract liabilities”) arise when billed amounts exceed revenues recorded. These contract liabilities primarily relate to the advance consideration received for customer contracts.

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WILLBROS GROUP, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

4. Revenue (continued)

Contract assets and liabilities as of March 31, 2018 and December 31, 2017 were as follows (in thousands):



	March 31, 2018			December 31, 2017
Cost incurred on contracts in progress	$	472,232		$	445,029
Recognized income	(20,699		)	(14,536		)
	451,533			430,493
Progress billings and advance payments	(439,264		)	(434,315		)
	$	12,269		$	(3,822	)
Contract cost and recognized income not yet billed (contract assets)	$	21,615		$	13,992
Contract billings in excess of cost and recognized income (contract liabilities)	(9,346		)	(17,814		)
Net contract assets (liabilities)	$	12,269		$	(3,822	)

The increase from a net contract liability to a net contract asset at March 31, 2018, is primarily driven by revenue recognized upon satisfaction of performance obligations, partially offset by cash payments received or due in advance of satisfying performance obligations. Changes in the contract asset and liability balances during the three-month period ended March 31, 2018, were not materially impacted by any other factors, other than revenue recognition and billings.

Contract cost and recognized income not yet billed includes $1.6 million and $0.5 million at March 31, 2018 and December 31, 2017, respectively, on completed contracts.

For the three months ended March 31, 2018, $16.4 million of revenue was recognized during the period that was included in the contract liability balance at January 1, 2018.

The Company’s payment terms vary by the type and location of its customer and the type of services offered. The term between invoicing and when payment is due is not significant. Although uncommon, to the extent material, the Company includes a significant financing component in the transaction price at contract inception when it expects the period between customer payment and transfer of control of the promised goods or services to exceed one year.

The balances billed but not paid by customers pursuant to retainage provisions in certain contracts are generally due upon completion of the contracts and acceptance by the customer. Based on the Company’s contract terms in recent years, the majority of the retainage balances at each balance sheet date are expected to be collected within the next 12 months. Current retainage balances at March 31, 2018 and December 31, 2017, were approximately $22.8 million and $26.1 million, respectively, and are included in “Accounts receivable, net” in the Condensed Consolidated Balance Sheets. There were $0.3 million and no retainage balances with settlement dates beyond the next 12 months at March 31, 2018 and December 31, 2017, respectively.

As of March 31, 2018 and December 31, 2017, accounts receivables related to products and services were $133.9 million and $141.3 million, respectively. For the three months ended March 31, 2018, the Company had an immaterial amount of bad debt expense.

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WILLBROS GROUP, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

4. Revenue (continued)

Disaggregation of Revenue

The following table presents the Company’s disaggregated revenue for the three months ended March 31, 2018 and 2017 (in thousands):



	Three Months Ended March 31,
	2018			2017 (1)
Utility T&D
Transmission and substation services	$	42,426		$	48,593
West distribution services	27,603			29,438
East distribution services	18,752			24,101
Southeast distribution services	15,181			6,735
Engineering services	4,428			3,591
Other	4,222			3,050
Total Utility T&D	$	112,612		$	115,508

Canada
Construction and maintenance services	$	17,289		$	18,138
Facilities and tank services	5,053			1,983
Project and specialty services	2,969			5,874
Other	492			(35		)
Total Canada	$	25,803		$	25,960

Oil & Gas
Facilities construction services	$	42,015		$	3,595
Small-diameter midstream pipeline construction services	3,281			2,478
Mainline pipeline construction services	11,723			5,340
Tank services	5,620			10,626
Integrity construction services	—			393
Total Oil & Gas	$	62,639		$	22,432

Eliminations	$	(74	)	$	—

Contract revenue (2)	$	200,980		$	163,900

(1) Prior period amounts have not been adjusted under the modified retrospective method.

(2) See Note 12 – Segment Information for additional information.

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WILLBROS GROUP, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

5. Assets Held for Sale

Components of assets held for sale as of March 31, 2018 and December 31, 2017 were as follows (in thousands):



	March 31, 2018		December 31, 2017
Accounts receivable, net	$	—	$	490
Contract cost and recognized income not yet billed	—		234
Prepaid expenses and other assets	—		36
Parts and supplies inventories	—		409
Property, plant and equipment, net	1,604		375
Intangible assets, net	—		260
Total assets held for sale	$	1,604	$	1,804

Accounts payable and accrued liabilities	$	—	$	100
Contract billings in excess of cost and recognized income	—		765
Total liabilities held for sale	$	—	$	865

The Company, as part of its ongoing strategic evaluation, made the decision to offer the sale of its tank services business, which is included in the Company’s Oil & Gas segment, to an outside party. At December 31, 2017, the tank services business was classified as held for sale, as it was being actively marketed, expected to sell within one year and measured at the lower of carrying value or fair value less costs to sell.

On January 2, 2018, the Company sold its tank services business to ATS for a $3.0 million purchase price subject to working capital and other adjustments. Certain contracts and other working capital associated with the tank services business were retained by the Company and not included in the sale to ATS. In connection with this transaction, the Company recorded a gain on sale of $1.0 million, which is included in the line item “Gain on sale of assets” in the Company’s Condensed Consolidated Statement of Operations for the three months ended March 31, 2018.

On January 9, 2018, the Company entered into an Asset Purchase Agreement to sell assets comprising its mainline pipeline construction business to Meridien. The Asset Purchase Agreement, among other things, states that funding will occur in various stages in 2018 and in conjunction with the completed valuation of the assets and final approval by Meridien. In connection with the Asset Purchase Agreement, the Company recorded a gain on sale of $4.4 million, which is included in the line item “Gain on sale of assets” in the Company’s Condensed Consolidated Statement of Operations for the three months ended March 31, 2018. The remaining assets associated with the Asset Purchase Agreement are expected to be sold to Meridien in the second quarter of 2018 and are measured at the lower of carrying value or fair value less costs to sell. These assets are classified as “Assets held for sale” in the Company’s Condensed Consolidated Balance Sheet at March 31, 2018.

6. Intangible Assets

~~The~~At March 31, 2018, the Company'’s intangible assets with finite lives include customer relationships and trade names ~~and are predominantly~~ within the Utility T&D segment. The changes in the carrying amounts of intangible assets for the ~~nine~~three months ended ~~September~~March 3031, ~~2017~~2018 are detailed below (in thousands):

	CustomerRelationships			Trademark /Tradename			Total
Balance as of December 31, 2016	$	73,100		$	3,748		$	76,848
Balance as of December 31, 2017	$	64,503		$	2,678		$	67,181
Amortization	(62,~~447~~131		)	(~~803~~268		)	(72,~~250~~399		)
Balance as of September 30, 2017	$	66,653		$	2,945		$	69,598
Disposal	(832		)	—			(832		)
Weighted average remaining amortization period	7.8 years			2.8 years
Balance as of March 31, 2018	$	61,540		$	2,410		$	63,950
Weighted average remaining amortization period	7.3 years			2.3 years

Intangible assets are amortized on a straight-line basis over their estimated useful lives, which range from 5 to 15 years.

~~Estimated amortization expense for the remainder of 2017 and each of the subsequent five years and thereafter is as follows (in thousands):~~17

Fiscal year:
Remainder of 2017	$	2,418
2018	9,667
2019	9,667
2020	9,135
2021	8,597
2022	8,597
Thereafter	21,517
Total amortization	$	69,598

7. Accounts Payable and Accrued Liabilities

Accounts payable and accrued liabilities as of September 30, 2017 and December 31, 2016 were as follows (in thousands):

	September 30, 2017		December 31, 2016
Trade accounts payable	$	64,243	$	34,770
Payroll and payroll liabilities	17,424		10,377
Accrued contract costs	42,656		15,840
Self-insurance accrual	6,903		11,210
Other accrued liabilities	16,101		11,291
Total accounts payable and accrued liabilities	$	147,327	$	83,488

Accrued contract costs includes $4.2 million and $3.7 million at September 30, 2017 and December 31, 2016, respectively, related to provisions on loss projects.

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WILLBROS GROUP, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

6. Intangible Assets (continued)

Estimated amortization expense for the remainder of 2018 and each of the subsequent five years and thereafter is as follows (in thousands):



Fiscal year:
Remainder of 2018	$	7,169
2019	9,559
2020	9,027
2021	8,489
2022	8,489
2023	8,489
Thereafter	12,728
Total amortization	$	63,950

7. Accounts Payable and Accrued Liabilities

Accounts payable and accrued liabilities as of March 31, 2018 and December 31, 2017 were as follows (in thousands):



	March 31, 2018		December 31, 2017
Trade accounts payable	$	71,102	$	54,414
Payroll and payroll liabilities	13,027		12,185
Accrued contract costs	39,555		52,847
Self-insurance accrual	6,850		6,601
Other accrued liabilities	11,350		12,114
Total accounts payable and accrued liabilities	$	141,884	$	138,161

Accrued contract costs includes $5.0 million and $12.2 million at March 31, 2018 and December 31, 2017, respectively, related to provisions on loss projects.

The self-insurance accrual includes $6.9 million and $6.6 million of short-term liabilities at March 31, 2018 and December 31, 2017, respectively. The remaining $17.9 million and $17.2 million of the self-insurance accrual is included within “Other long-term liabilities” on the Condensed Consolidated Balance Sheet at March 31, 2018 and the Consolidated Balance Sheet at December 31, 2017, respectively.

8. Debt Obligations

The Company'’s debt obligations as of ~~September~~March 3031, ~~2017~~2018 and December 31, ~~2016~~2017 were as follows (in thousands):

	September 30, 2017			December 31, 2016
	March 31, 2018			December 31, 2017
Aggregate outstanding principal balance, 2014 Term Loan Facility	$	92107,224		$	92107,224
Repayment fee, 2014 Term Loan Facility	4,611			4,611
Aggregate outstanding principal balance, Initial First-Out Loan	10,000			—
Unamortized discount - repayment fee, 2014 Term Loan Facility	(2,821		)	(3,592		)
Repayment fee, 2014 Term Loan Facility	9,650			9,650
Unamortized debt issuance costs, 2014 Term Loan Facility	(5,087		)	(4,054		)
Unamortized discount – repayment fee, 2014 Term Loan Facility	(6,195		)	(7,235		)
Revolver borrowings, 2013 ABL Credit Facility	12,000			—
Unamortized debt issuance costs, 2014 Term Loan Facility	(3,822		)	(4,464		)
Total debt obligations, net of unamortized discount and debt issuance costs	100,927			89,189
Revolver borrowings, 2013 ABL Credit Facility	23,045			28,108
Less: short-term borrowings	(12,000		)	—
Total debt obligations, net of unamortized discount and debt issuance costs	$	139,902		$	133,283
Long-term debt obligations, net	$	88,927		$	89,189
Current maturities of long-term debt	$	116,857		$	105,175
Short-term borrowings under revolving credit facility	23,045			28,108
Total debt obligations, net of unamortized discount and debt issuance costs	$	139,902		$	133,283

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WILLBROS GROUP, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

8. Debt Obligations (continued)

2014 Term Loan Facility

On December 15, 2014, the Company entered into ~~a credit agreement (~~the “2014 Term Credit Agreement”) among the Company, certain of its subsidiaries, as guarantors, the lenders from time to time party thereto, and JPMorgan Chase Bank, N.A., as administrative agent. Cortland Capital Market Services LLC currently serves as administrative agent under the 2014 Term Credit Agreement.

Principal, Interest and Maturity

The 2014 Term Credit Agreement initially provided for a five-year $270.0 million term loan facility (the “2014 Term Loan Facility”), which the Company drew in full on the effective date of the 2014 Term Credit Agreement. ~~At September 30, 2017, the aggregate outstanding principal balance of the 2014 Term Loan Facility was $92.2 million.~~ Effective November 6, 2017, the Company amended the 2014 Term Credit Agreement pursuant to a Sixth Amendment (the “Sixth Amendment”). The Sixth Amendment, among other things, provides for an additional term loan in an amount equal to $15.0 million, which ~~will~~is be pari passu in right of payment with, and secured on a pari passu basis with the aggregate outstanding principal balance of the Company'’s 2014 Term Loan Facility. The additional term loan iswas ~~expected to be~~ drawn in full ~~during~~on November 17, 2017 ~~and~~(the ~~will~~“Sixth ~~bear~~Amendment Funding Date”) and bears the same maturity date as the aggregate outstanding principal balance of the Company'’s 2014 Term Loan Facility. At March 31, 2018, the aggregate outstanding principal balance of the 2014 Term Loan Facility was approximately $107.2 million.

The 2014 Term Loan Facility initially bore interest at the “Adjusted Base Rate” plus an applicable margin of 8.75 percent, or the “Eurodollar Rate” plus an applicable margin of 9.75 percent. ~~The~~On ~~interest~~the ~~rate~~Sixth inAmendment ~~effect~~Funding ~~at September 30~~Date, ~~2017~~the ~~and~~interest ~~December 31,~~rate ~~2016~~increased ~~was~~to 1113 percent, ~~which~~consisting ~~consisted~~ of an applicable margin of 911.75 percent for Eurodollar Rate loans plus a LIBOR floor of 1.25 percent. ~~Beginning~~The ~~with~~interest ~~the~~rate ~~date~~in oneffect ~~which~~at ~~the additional term loan is funded~~March 31, ~~(the~~2018 ~~“Sixth~~and ~~Amendment Funding Date”)~~December 31, ~~the~~2017 ~~interest~~was ~~rate will increase to~~ 13 percent~~, consisting of an applicable margin of 11~~.75 ~~percent for Eurodollar Rate loans plus a LIBOR floor of 1.25 percent.~~ Beginning September 30, 2018, the applicable margin will increase an additional 100 basis points each quarterly period until maturity.

On March 27, 2018, the Company amended the 2014 Term Credit Agreement pursuant to the Seventh Amendment. Under the terms of the Seventh Amendment, Primoris provided the Company with an Initial First-Out Loan in an amount equal to $10.0 million that was drawn in full on March 30, 2018 and bears the same maturity date as the aggregate outstanding principal balance of the Company’s 2014 Term Loan Facility. In addition, Primoris may provide the Company with Additional First-Out Loans up to $10.0 million. See Note 1 – Company Description and Financial Condition for more information.

Makewhole

Under the 2014 Term Credit Agreement, with respect to prepayments made from inception of the Term Loan through ~~September~~March 3031, ~~2017~~2018, the Company has not been required to pay prepayment premiums in respect of the “makewhole amount.” However, future prepayments or refinancing of the balance of the 2014 Term Loan Facility ~~will~~may require the Company to pay a prepayment premium equal to the makewhole amount and the repayment fee described below. Pursuant to the Sixth Amendment and beginning with the Sixth Amendment Funding Date, if a prepayment is made on or before September 30, 2018, the makewhole amount will be calculated as the present value of all interest payments that would have been made on the amount prepaid from the date of the prepayment to June 15, 2019 at a rate per annum equal to the sum of the applicable margin on the date of the prepayment plus the greater of 1.25 percent and the Eurodollar rate in effect on the date of the repayment. If a prepayment is made after September 30, 2018, the makewhole amount will be calculated as the present value of all interest payments that would have been made on the amount prepaid from the date of the prepayment to December 15, 2019 at a rate per annum equal to the sum of the applicable margin on the date of the prepayment plus the greater of 1.25 percent and the Eurodollar rate in effect on the date of the repayment.

14Should a prepayment in full occur under the Sixth Amendment, the estimated makewhole amount due at future prepayment dates would be as follows (in thousands):



	June 30, 2018		September 30, 2018		December 31, 2018		March 31, 2019		June 30, 2019		September 30, 2019
Makewhole	$	13,358	$	9,874	$	16,888	$	12,331	$	7,595	$	3,350

Repayment Fee

Prior to the Sixth Amendment, the Company was also required to pay a repayment fee on the date of any prepayment and on the maturity date of the 2014 Term Loan Facility equal to a total of $4.6 million, which was 5.0 percent of the amount prepaid or 5.0 percent of the aggregate remaining outstanding principal balance on the maturity date. Pursuant to the Sixth Amendment and beginning with the Sixth Amendment Funding Date, the repayment fee increased to a total of $9.7 million,

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WILLBROS GROUP, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

8. Debt Obligations (continued)

~~Should~~which is 9.0 percent of the amount prepaid or 9.0 percent of the aggregate remaining outstanding principal balance on the maturity date. The Company is amortizing the repayment fee as a ~~prepayment~~discount, ~~occur~~from inthat ~~full~~date ~~under~~through the ~~Sixth~~maturity ~~Amendment~~date of the 2014 Term Loan Facility, using the ~~estimated~~effective ~~makewhole~~interest method. The unamortized amount ~~due~~of the repayment fee was $6.2 million and $7.2 million at ~~future~~March 31, ~~prepayment~~2018 ~~dates~~and ~~would~~December 31, be2017, asrespectively, ~~follows~~based (on the 9.0 percent repayment fee in ~~thousands):~~effect as of those dates.

		December 31, 2017				March 31, 2018				June 30, 2018				September 30, 2018				December 31, 2018				March 31, 2019				June 30, 2019				September 30, 2019
Makewhole		$	20,328			$	16,843			$	13,358			$	9,874			$	16,888			$	12,331			$	7,595			$	3,350

Term Loan Discounted Payoff

~~Prior~~The toSeventh ~~the~~Amendment ~~Sixth~~provides ~~Amendment~~that ~~Funding~~the ~~Date,~~payment by the ~~makewhole~~borrower of an amount ~~was~~equal ~~calculated~~to as$100.0 ~~the~~million ~~present~~plus ~~value~~the expenses of ~~all~~the ~~interest~~administrative ~~payments~~agent ~~that~~in ~~would~~an ~~have~~amount ~~been~~not ~~made~~to onexceed ~~the~~$1.1 ~~amount~~million ~~prepaid~~shall ~~from~~constitute ~~the~~payment ~~date~~in full and satisfaction and discharge of all obligations of the ~~prepayment~~borrower toand ~~December~~the ~~15,~~other ~~2019~~loan ~~(or~~parties ~~June~~under 15the 2014 Term Credit Agreement, ~~2019~~but solely if ~~the~~such ~~prepayment~~payment is made onin orconnection ~~after~~with ~~June~~the 15consummation of the merger. Accordingly, ~~2018)~~if atthe a2014 ~~rate~~Term ~~per~~Loan ~~annum~~Facility ~~equal~~is topaid off in connection with the ~~sum~~closing of 9the merger, no amounts will be owed in respect of the makewhole amount and the repayment fee.75 ~~percent~~Based ~~plus~~on the ~~greater~~above information, the settlement of 1the debt at the discounted amount is considered a troubled debt restructuring transaction.25 ~~percent~~However, ~~and~~given the ~~Eurodollar~~settlement ~~rate~~of inthe ~~effect~~debt onat the ~~date~~discounted amount is contingent upon the consummation of the ~~repayment~~merger, the Company has not recorded an adjustment to its Condensed Consolidated Financial Statements.

~~Repayment~~Debt ~~Fee~~Covenants

~~The~~On ~~Company~~March ~~was~~31, ~~also~~2015 ~~required~~(the to“First ~~pay~~Amendment aClosing ~~repayment~~Date”), ~~fee~~March on1, ~~the~~2016, ~~date~~July of26, ~~any~~2016 ~~prepayment~~ and onMarch ~~the~~3, ~~maturity~~2017, ~~date~~the ofCompany amended the 2014 Term ~~Loan~~Credit ~~Facility~~Agreement ~~equal~~pursuant to a ~~total~~First ofAmendment ~~$4.6~~(the ~~million~~“First Amendment”), ~~which~~a ~~was~~Third ~~5.0~~Amendment, ~~percent~~a ofFourth ~~the~~Amendment ~~amount~~and ~~prepaid~~a orFifth 5Amendment (the “Fifth Amendment”).0 ~~percent~~These ofamendments, ~~the~~among ~~aggregate~~other ~~remaining~~things, ~~outstanding~~suspended ~~principal~~the ~~balance~~calculation onof the ~~maturity~~Maximum ~~date.~~Total ~~The~~Leverage ~~Company~~Ratio isand ~~amortizing~~Minimum ~~the~~Interest ~~repayment~~Coverage ~~fee~~Ratio asfor athe ~~discount,~~period from ~~that~~December ~~date~~31, 2014 through ~~the~~June ~~maturity~~30, ~~date~~2017 of (the ~~2014~~“Covenant ~~Term~~Suspension ~~Loan~~Periods”) ~~Facility,~~so ~~using~~that ~~the~~any ~~effective~~failure ~~interest~~by ~~method.~~the ~~The~~Company ~~unamortized~~to ~~amount~~comply ofwith the ~~repayment~~Maximum ~~fee~~Total ~~was~~Leverage ~~$2.8~~Ratio ~~million~~or ~~and~~Minimum ~~$3.6~~Interest ~~million~~Coverage atRatio ~~September 30,~~during ~~2017~~the ~~and~~Covenant ~~December 31,~~Suspension ~~2016,~~Periods ~~respectively,~~shall ~~based~~not onbe ~~the~~deemed ~~5.0~~to ~~percent~~result ~~repayment~~in ~~fee~~a indefault ~~effect~~or asevent of ~~those dates~~default.

~~Pursuant~~In toconsideration of the ~~Sixth~~initial ~~Amendment~~suspension of the calculation of the Maximum Total Leverage Ratio and ~~beginning~~Minimum ~~with~~Interest Coverage Ratio under the ~~Sixth~~First Amendment, ~~Funding~~the ~~Date~~Company issued 10.1 million shares, which was equivalent to 19.9 percent of the ~~repayment~~then ~~fee~~outstanding ~~will~~shares ~~increase~~of common stock immediately prior to the First Amendment Closing Date, to KKR Lending Partners II L.P. and other entities indirectly advised by KKR Credit Advisers (US) LLC, which made them a ~~total~~related party. In connection with this transaction, the Company recorded debt covenant suspension charges of approximately $933.75 million, which isrepresented 9the fair value of the 10.01 ~~percent~~million outstanding shares of common stock issued, multiplied by the ~~amount~~closing ~~prepaid~~stock orprice 9on the First Amendment Closing Date.0 ~~percent~~In addition, the Company recorded debt extinguishment charges of approximately $0.8 million related to the ~~aggregate~~write-off ~~remaining~~of ~~outstanding~~debt ~~principal~~issuance ~~balance~~costs onassociated with the ~~maturity~~Company’s ~~date~~2014 Term Credit Agreement.

~~Other~~In consideration for the Fifth Amendment, the Company paid a $2.3 million amendment fee during the three months ended March 31, 2017. The amendment fee is recorded as a direct deduction from the carrying amount of the 2014 Term Loan Facility and is being amortized through the maturity date of the 2014 Term Loan Facility using the effective interest method.

The ~~Company~~Sixth isAmendment suspended compliance with the ~~borrower~~Maximum Total Leverage Ratio and the Minimum Interest Coverage Ratio covenants through December 31, 2017. In addition, under the ~~2014~~Sixth ~~Term~~Amendment, ~~Credit~~the ~~Agreement~~Maximum Total Leverage Ratio was 5.50 to 1.00 as of March 31, ~~with~~2018 ~~all~~and will decrease to 4.50 to 1.00 as of ~~its~~June ~~obligations~~30, ~~guaranteed~~2018, by4.25 ~~its~~to ~~material~~1.00 Uas of September 30, 2018 and 3.S00 to 1.00 ~~subsidiaries~~as of March 31, ~~other~~2019, ~~than~~and ~~excluded~~thereafter. ~~subsidiaries~~The Minimum Interest Coverage Ratio was 1.75 ~~Obligations~~to ~~under~~1.00 ~~the~~as ~~2014~~of ~~Term~~March ~~Loan~~31, ~~Facility~~2018, ~~are~~will ~~secured~~increase byto a2.00 ~~first~~to ~~priority~~1.00 ~~security~~as ~~interest~~of inJune 30, ~~among~~2018, ~~other~~decrease ~~things~~to 1.50 to 1.00 as of December 31, ~~the~~2018 ~~borrower’s~~and increase to 2.75 to 1.00 as of March 31, 2019, and thereafter. The Sixth Amendment also provided that, for the ~~guarantors’~~four-quarter ~~equipment~~period ending March 31, ~~subsidiary~~2018, ~~capital~~Consolidated ~~stock~~EBITDA ~~and~~was ~~intellectual~~equal ~~property~~to (the ~~“2014~~sum ~~Term~~of ~~Loan~~Consolidated ~~Priority~~EBITDA ~~Collateral”)~~for the quarterly periods ending December 31, 2017 and aMarch ~~second~~31, ~~priority~~2018 ~~security~~multiplied ~~interest~~by intwo, ~~among~~and, ~~other~~for ~~things~~the four-quarter period ending June 30, 2018, Consolidated EBITDA shall be equal to the ~~borrower’s~~annualized ~~and~~sum of Consolidated EBITDA for the ~~guarantors’~~quarterly ~~inventory,~~periods ~~accounts~~ending ~~receivable~~December 31, ~~deposit~~2017, ~~accounts~~March 31, 2018 and ~~similar~~June ~~assets~~30, 2018.

~~Unamortized~~The ~~debt~~Company ~~issuance~~is ~~costs~~not in compliance with the Maximum Total Leverage Ratio and Minimum Interest Coverage Ratio for the quarterly period ended March 31, ~~primarily~~2018 ~~related~~and does not expect to ~~amendment~~be ~~fees~~in ~~associated~~compliance with the Maximum Total Leverage Ratio and Minimum Interest Coverage Ratio under the 2014 Term ~~Loan~~Credit ~~Facility,~~Agreement ~~were~~for ~~$5.1~~the ~~million~~next ~~and~~twelve $4months.1 ~~million~~In ~~at September 30~~addition, ~~2017~~the ~~and~~Company ~~December 31,~~is ~~2016,~~currently ~~respectively.~~not ~~These~~in ~~costs~~compliance ~~are~~with ~~being~~certain ~~amortized~~other ~~through~~provisions under the ~~maturity~~2014 ~~date~~Term ofCredit Agreement and the ~~2014~~2013 ~~Term~~ABL ~~Loan~~Credit Facility, ~~using~~which ~~the~~expires ~~effective~~on ~~interest~~August ~~method~~7, 2018. Absent the temporary forbearance provided under the Term Forbearance

The Company made no early payments during the nine months ended September 30, 2017 and $3.1 million of early payments during the nine months ended September 30, 2016 against its 2014 Term Loan Facility. As a result of these early payments, the Company recorded no debt extinguishment charges during the nine months ended September 30, 2017 and $0.1 million of debt extinguishment charges, which consisted of the write-off of debt issuance costs, during the nine months ended September 30, 2016.20

On March 31, 2015 (the “First Amendment Closing Date”), March 1, 2016, July 26, 2016 and March 3, 2017, the Company amended the 2014 Term Credit Agreement pursuant to a First Amendment (the “First Amendment”), a Third Amendment (the “Third Amendment”), a Fourth Amendment (the “Fourth Amendment”) and a Fifth Amendment (the “Fifth Amendment”). These amendments, among other things, suspended the calculation of the Maximum Total Leverage Ratio and Minimum Interest Coverage Ratio for the period from December 31, 2014 through June 30, 2017 (the “Covenant Suspension Periods”) so that any failure by the Company to comply with the Maximum Total Leverage Ratio or Minimum Interest Coverage Ratio during the Covenant Suspension Periods shall not be deemed to result in a default or event of default.

In consideration of the initial suspension of the calculation of the Maximum Total Leverage Ratio and Minimum Interest Coverage Ratio under the First Amendment, the Company issued 10.1 million shares, which was equivalent to 19.9 percent of the outstanding shares of common stock immediately prior to the First Amendment Closing Date, to KKR Lending Partners II L.P. and other entities indirectly advised by KKR Credit Advisers (US) LLC, which made them a related party. In connection with this transaction, the Company recorded debt covenant suspension charges of approximately $33.5 million which represented the fair value of the 10.1 million outstanding shares of common stock issued, multiplied by the closing stock price

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WILLBROS GROUP, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

8. Debt Obligations (continued)

onAgreement and the ~~First~~ABL ~~Amendment~~Forbearance ~~Closing Date. In addition~~Agreement, the ~~Company~~lenders ~~recorded~~would ~~debt~~have ~~extinguishment~~the ~~charges~~right ofto ~~approximately~~require ~~$0.8~~immediate ~~million~~repayment ~~related~~of toall of the ~~write-off~~Company’s of debt ~~issuance~~obligations ~~costs~~under ~~associated~~the ~~with~~default ~~the~~provisions ~~Company's~~in the 2014 Term Credit Agreement and the 2013 ABL Credit Facility.

In consideration for the Third Amendment, Fourth Amendment and Fifth Amendment, the Company paid a total of $4.6 million in amendment fees in 2016 and $2.3 million in amendment fees during the nine months ended September 30, 2017. The amendment fees are recorded as direct deductions from the carrying amount of the 2014 Term Loan Facility and are being amortized through the maturity date of the 2014 Term Loan Facility using the effective interest method.Other

The Company is the borrower under the 2014 Term Credit Agreement, with all of its obligations guaranteed by its material U.S. subsidiaries, other than excluded subsidiaries. Obligations under the 2014 Term Loan Facility are secured by a first priority security interest in, among other things, the borrower’s and the guarantors’ equipment, subsidiary capital stock and intellectual property (the “2014 Term Loan Priority Collateral”) and a second priority security interest in, among other things, the borrower’s and the guarantors’ inventory, accounts receivable, deposit accounts and similar assets.

Unamortized debt issuance costs, primarily related to amendment fees associated with the 2014 Term Loan Facility, were $3.8 million and $4.5 million at March 31, 2018 and December 31, 2017, respectively. These costs are being amortized through the maturity date of the 2014 Term Loan Facility using the effective interest method.

2013 ABL Credit Facility

On August 7, 2013, the Company entered into a five-year asset based senior revolving credit facility maturing on August 7, 2018 with Bank of America, N.A. serving as sole administrative agent for the lenders thereunder, collateral agent, issuing bank and swingline lender (as amended, the “2013 ABL Credit Facility”).

The aggregate amount of commitments for the 2013 ABL Credit Facility is $100.0 million, which is comprised of $90.0 million for the U.S. facility (the “U.S. Facility”) and $10.0 million for the Canadian facility (the “Canadian Facility”). InAt ~~the~~March 31, ~~third quarter of 2017~~2018, the Company ~~borrowed~~had approximately $1223.0 million in outstanding borrowings under the 2013 ABL Credit Facility for working capital purposes ~~and to fund revenue growth and operating losses~~. ~~On November 6, 2017, the Company borrowed an additional $17.0 million under the 2013 ABL Credit Facility.~~

The 2013 ABL Credit Facility includes a sublimit of $80.0 million for letters of credit. The borrowers under the U.S. Facility consist of all of the Company’s U.S. operating subsidiaries with assets included in the borrowing base, and the U.S. Facility is guaranteed by Willbros Group, Inc. and its material U.S. subsidiaries, other than excluded subsidiaries. The borrower under the Canadian Facility is Willbros Construction Services (Canada) LP, and the Canadian Facility is guaranteed by Willbros Group, Inc. and all of its material U.S. and Canadian subsidiaries, other than excluded subsidiaries.

Advances under the U.S. and Canadian Facilities are limited to a borrowing base consisting of the sum of the following, less applicable reserves:


•	85 percent of the value of “eligible accounts” (as defined in the 2013 ABL Credit Facility);


•	the lesser of (i) 75 percent of the value of “eligible unbilled accounts” (as defined in the 2013 ABL Credit Facility) and (ii) $33.0 million minus the amount of eligible unbilled accounts then included in the borrowing base; and


•	“eligible pledged cash”.

The Company is also required, as part of its borrowing base calculation, to include a minimum of $25.0 million of the net proceeds of the sale of Bemis, LLC and the balance of the Professional Services segment as eligible pledged cash. The Company has included $40.0 million as eligible pledged cash in its ~~September~~March 3031, ~~2017~~2018 borrowing base calculation, which is included in the “Restricted cash” line item on its Condensed Consolidated Balance Sheets.

The aggregate amount of the borrowing base attributable to eligible accounts and eligible unbilled accounts constituting certain progress or milestone billings, retainage and other performance-based benchmarks may not exceed $23.0 million.

Advances in U.S. dollars bear interest at a rate equal to LIBOR or the U.S. or Canadian base rate plus an additional margin. Advances in Canadian dollars bear interest at the Bankers Acceptance (“BA”) Equivalent Rate or the Canadian prime rate plus an additional margin.

~~The interest rate margins will be adjusted each quarter based on the Company’s fixed charge coverage ratio as of the end of the previous quarter as follows:~~21

Fixed Charge Coverage Ratio	U.S. Base Rate, CanadianBase Rate and CanadianPrime Rate Loans	LIBOR Loans, BA Rate Loans andLetter of Credit Fees
>1.25 to 1	1.25%	2.25%
<1.25 to 1 and >1.15 to 1	1.50%	2.50%
<1.15 to 1	1.75%	2.75%

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WILLBROS GROUP, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

8. Debt Obligations (continued)

The interest rate margins will be adjusted each quarter based on the Company’s fixed charge coverage ratio as of the end of the previous quarter as follows:



Fixed Charge Coverage Ratio	U.S. Base Rate, Canadian Base Rate and Canadian Prime Rate Loans	LIBOR Loans, BA Rate Loans and Letter of Credit Fees
>1.25 to 1	1.25%	2.25%
<1.25 to 1 and >1.15 to 1	1.50%	2.50%
<1.15 to 1	1.75%	2.75%

The Company will also pay an unused line fee on each of the U.S. and Canadian Facilities equal to 50 basis points when usage under the applicable facility during the preceding calendar month is less than 50 percent of the commitments or 37.5 basis points when usage under the applicable facility equals or exceeds 50 percent of the commitments for such period. With respect to the letters of credit, the Company will pay a letter of credit fee equal to the applicable LIBOR margin, shown in the table above, on all letters of credit and a 0.125 percent fronting fee to the issuing bank, in each case, payable monthly in arrears.

Obligations under the 2013 ABL Credit Facility are secured by a first priority security interest in the borrowers’ and guarantors’ accounts receivable, deposit accounts and similar assets (the “ABL Priority Collateral”) and a second priority security interest in the 2014 Term Loan Priority Collateral.

AsIn ~~of September 30, 2017,~~ the ~~Company's~~first ~~unused~~quarter ~~availability was $32.5 million, net~~ of ~~outstanding letters of credit of $55.5 million and outstanding revolver borrowings of $12.0 million. On November 6~~2018, ~~2017,~~ the Company ~~borrowed~~repaid ~~an additional~~ $175.0 million ~~under the 2013 ABL Credit Facility. If the Company’s unused availability under the 2013 ABL Credit Facility is less than the greater~~ of ~~(i) 15.0~~its percent of the revolving commitments or $15.0 million for five consecutive days, or (ii) 12.5 percent of the revolving commitments or $12.5 million at any time, or upon the occurrence of certain events of default under the 2013 ABL Credit Facility, the Company is subject to increased reporting requirements, the administrative agent shall have exclusive control over any deposit account, the Company will not have any right of access to, or withdrawal from, any deposit account, or any right to direct the disposition of funds in any deposit account, and amounts in any deposit account will be applied to reduce the outstanding ~~amounts~~borrowings under the 2013 ABL Credit Facility. Inusing ~~addition,~~available ifcash the Company's unused availability under the 2013 ABL Credit Facility is less than the amounts described above, the Company would be required to comply with a Minimum Fixed Charge Coverage Ratio of 1.15 to 1.00. Based on its current forecasts, the Company does not expect its unused availability under the 2013 ABL Credit Facility to be less than the amounts described above and therefore does not expect the Minimum Fixed Charge Coverage Ratio to be applicable over the next twelve monthshand. If the Minimum Fixed Charge Coverage Ratio were to become applicable, the Company would not expect to be in compliance over the next twelve months and would therefore be in default under its credit agreements.

If the Company’s unused availability under the 2013 ABL Credit Facility is less than the greater of (i) 15.0 percent of the revolving commitments or $15.0 million for five consecutive days, or (ii) 12.5 percent of the revolving commitments or $12.5 million at any time, or upon the occurrence of certain events of default under the 2013 ABL Credit Facility (“Cash Dominion”), the Company is subject to increased reporting requirements, the administrative agent shall have exclusive control over any deposit account, the Company will not have any right of access to, or withdrawal from, any deposit account, or any right to direct the disposition of funds in any deposit account, and amounts in any deposit account will be applied to reduce the outstanding amounts under the 2013 ABL Credit Facility. In addition, if the Company’s unused availability under the 2013 ABL Credit Facility is less than the amounts described above, the Company would be required to comply with a Minimum Fixed Charge Coverage Ratio of 1.15 to 1.00.

Pursuant to the ABL Forbearance Agreement, the aggregate amount of commitments under the 2013 ABL Credit Facility has been reduced from $100.0 million to $90.0 million, which is comprised of $80.0 million for the U.S. Facility and $10.0 million for the Canadian Facility. In addition, during the ABL Forbearance Period, the Company may not request any additional loans or any new or increased letters of credit. The ABL Forbearance Agreement also provides that Cash Dominion will occur if the Company’s unused availability under the 2013 ABL Credit Facility is less than $10.0 million at any time. Under its March 31, 2018 borrowing base certificate, the Company’s unused availability under the 2013 ABL Credit Facility was $12.3 million, which is in accordance with the ABL Forbearance Agreement.

The Company gives no assurance that it will continue to be able to avoid Cash Dominion under the 2013 ABL Credit Facility. If the Minimum Fixed Charge Coverage Ratio were to become applicable, the Company would not expect to be in compliance over the next twelve months and would therefore be in default under its credit agreements.

Events of Default

A default under the 2014 Term ~~Loan~~Credit ~~Facility~~Agreement and the 2013 ABL Credit Facility may be triggered by events such as a failure to comply with financial covenants or other covenants under the 2014 Term ~~Loan~~Credit ~~Facility~~Agreement and the 2013 ABL Credit Facility, a failure to make payments when due under the 2014 Term ~~Loan~~Credit ~~Facility~~Agreement and the 2013 ABL Credit Facility, a failure to make payments when due in respect of, or a failure to perform obligations relating to, debt obligations in excess of $15.0 million, a change of control of the Company and certain insolvency proceedings. A default under the 2013 ABL Credit Facility would permit the lenders to terminate their commitment to make cash advances or issue letters of credit, require the immediate repayment of any outstanding cash advances with interest and require the cash collateralization of outstanding letter of credit obligations. A default under the 2014 Term ~~Loan~~Credit ~~Facility~~Agreement would permit the lenders to require immediate repayment of all principal, interest, fees and other amounts payable thereunder.

The 2014 Term Credit Agreement and the 2013 ABL Credit Facility also include customary representations and warranties and affirmative and negative covenants, including:

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WILLBROS GROUP, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

8. Debt Obligations (continued)


•	the preparation of financial statements in accordance with GAAP;


•	the ability to deliver an audit opinion without a going concern explanation;


•	the identification of any events or circumstances, either individually or in the aggregate, that has had or could reasonably be expected to have a material adverse effect on the business, results of operations, properties or financial condition of the Company;


•	limitations on liens and indebtedness;


•	limitations on dividends and other payments in respect of capital stock;


•	limitations on capital expenditures; and


•	limitations on modifications of the documentation of the 2013 ABL Credit Facility.

17The Company’s inability to deliver its 2017 audited financial statements without a going concern explanation constitutes an event of default under the 2014 Term Credit Agreement and the 2013 ABL Credit Facility. See Note 1 – Company Description and Financial Condition for more information.

~~Table~~On March 27, 2018, the Company entered into a Term Forbearance Agreement with the Term Lenders and an ABL Forbearance Agreement with the ABL Lenders. If the merger with Primoris is not completed, or if these forbearance agreements were to expire or be terminated prior to the completion of ~~Contents~~the merger, the Term Lenders and ABL Lenders would be free to exercise any rights and remedies with respect to such defaults and events of defaults pursuant to the terms of the 2014 Term Credit Agreement and the 2013 ABL Credit Facility, respectively. See Note 1 – Company Description and Financial Condition for more information.

WILLBROS GROUP, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

8. Debt Obligations (continued)

Fair Value of Debt

The estimated fair value of the Company’s debt instruments as of ~~September~~March 3031, ~~2017~~2018 and December 31, ~~2016~~2017 was as follows (in thousands):

	September 30, 2017		December 31, 2016
	March 31, 2018		December 31, 2017
2014 Term Loan Facility	$	98119,~~685~~251	$	95119,~~577~~042
Revolver borrowings, 2013 ABL Credit Facility	12,000		—
Initial First-Out Loan	10,000		—
Total fair value of debt instruments	$	110,685	$	95,577
Revolver borrowings, 2013 ABL Credit Facility	23,045		28,108
Total fair value of debt instruments	$	152,296	$	147,150

The 2014 Term Loan Facility, Initial First-Out Loan and revolver borrowings under the 2013 ABL Credit Facility are classified within Level 2 of the fair value hierarchy. The fair value of the ~~debt~~2014 ~~instruments~~Term ~~have~~Loan Facility (other than the Initial First-Out Loan) has been estimated using discounted cash flow analyses based on the Company’s incremental borrowing rate for similar borrowing arrangements. The fair value of the Initial First-Out Loan and the revolver borrowings approximates its carrying value.

9. Income Taxes

The Company'’s interim tax provision (benefit) has been estimated using the discrete method, which is based on statutory tax rates applied to pre-tax income as adjusted for permanent differences such as transfer pricing differences between generally accepted accounting principles and local country tax. The Company believes this method yields a more reliable income tax calculation for interim periods.

The effective tax rate on continuing operations iswas 3.1.3 percent for the ~~nine~~three months ended ~~September~~March 3031, ~~2017~~2018 and a3.3 ~~negative~~percent 4for the three months ended March 31, 2017.0 ~~percent~~There was no tax benefit or expense for discrete items for the ~~nine~~three months ended ~~September~~March 3031, ~~2016~~2018. The tax benefit for discrete items for the ~~nine~~three months ended ~~September~~March 3031, 2017 iswas $0.15 million. ~~and~~This amount is ~~primarily~~ composed primarily of a ~~refund~~refundable onfederal ~~the~~alternative ~~Company's~~minimum ~~2010~~tax ~~and~~credit ~~2011~~carry-forward. ~~Texas~~The ~~Margins~~tax ~~Tax~~benefit ~~audit~~for ~~and~~the athree ~~refundable~~months ~~alternative~~ended ~~minimum~~March ~~tax~~31, ~~credit~~2018 ~~carry-forward~~was $0.2 million, ~~partially~~primarily ~~offset~~due byto a ~~settlement~~benefit ofon a ~~transfer~~loss ~~pricing~~in ~~audit~~the inCompany’s Canada segment and the Texas Margins Tax. The tax ~~provision~~benefit for ~~discrete items for~~ the ~~nine~~three months ended ~~September~~March 3031, ~~2016~~2017 iswas $0.96 million, ~~and~~primarily isdue ~~primarily~~to ~~composed~~a ofrefundable anfederal alternative minimum tax credit carry-forward and a benefit on a loss in the Company’s Canada segment.

The tax benefit for the nine months ended September 30, 2017 is $1.7 million and is primarily composed of a benefit on a loss in the Company's Canada segment, a refundable alternative minimum tax credit carry-forward and a refund on the Company's 2010 and 2011 Texas Margins Tax audit. The tax benefit is partially offset by a settlement of a transfer pricing audit in Canada. The tax provision for the nine months ended September 30, 2016 is $1.1 million and is primarily composed of an alternative minimum tax credit and Texas Margins Tax.23

The effective tax rate on continuing operations is a negative 3.6 percent for the three months ended September 30, 2017 and a negative 8.0 percent for the three months ended September 30, 2016. The tax provision for the three months ended September 30, 2017 is $1.1 million and is primarily composed of a settlement of a transfer pricing audit in Canada, a reduction of a benefit on a loss in the Company's Canada segment and a reduction in a refundable alternative minimum tax credit carry-forward.

The Company has reserved for the benefit of current year losses in the United States. As of September 30, 2017, U.S. federal and state deferred tax assets continue to be covered by valuation allowances. In evaluating whether deferred tax assets are more likely than not to be realized, the Company considers the impact of reversing taxable temporary differences, future forecasted income and available tax planning strategies.

It is reasonably possible the unrecognized tax benefits may change between $0.0 million and $3.2 million within the next twelve months as a result of settling tax examinations related to 2008-2011.

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WILLBROS GROUP, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

109. ~~Stockholders'~~Income ~~Equity~~Taxes (continued)

The Company has reserved for the benefit of current year losses in the United States. As of March 31, 2018, U.S. federal and state and Canadian deferred tax assets continue to be covered by valuation allowances. In evaluating whether deferred tax assets are more likely than not to be realized, the Company considers the impact of reversing taxable temporary differences, future forecasted income and available tax planning strategies.

It is reasonably possible the unrecognized tax benefits on uncertain tax positions may change between $0.0 million and $2.0 million within the next twelve months as a result of settling tax examinations related to 2008-2011.

On December 31, 2017, the Company recognized the tax effects of the Tax Cuts and Jobs Act of 2017 (the "Tax Act”) and recorded a $0.7 million tax benefit related to the re-measurement of deferred taxes and recognition of the Alternative Minimum Tax Credit. In addition, under the Tax Act, IRC Section 163(j) was revised to limit the deduction on United States business interest expense. As a result, the Company’s ability to fully deduct interest expense may be limited in 2018. The additional information that is needed to be obtained, prepared and analyzed in order to complete the accounting requirements under ASC 740 and IRC section 163(j) will be treated in accordance with the measurement period guidance outlined in Staff Accounting Bulletin No. 118.

10. Stockholders’ Equity

Changes in Accumulated Other Comprehensive Income (Loss) by Component

	Three Months Ended September 30, 2017 (in thousands)
	Three Months Ended March 31, 2018 (in thousands)
	Foreign currencytranslationadjustments			Changes inderivativefinancialinstruments			Totalaccumulatedcomprehensiveincome (loss)
Balance as of June 30, 2017	$	(624	)	$	(2,284	)	$	(2,908	)
Balance as of December 31, 2017	$	(125	)	$	(1,737	)	$	(1,862	)
Other comprehensive income before reclassifications	1,054			—			1,054
Other comprehensive loss before reclassifications	(343		)	—			(343		)
Amounts reclassified from accumulated other comprehensive income (loss)	—			~~273~~276			~~273~~276
Net current-period other comprehensive income	1,054			273			1,327
Net current-period other comprehensive income (loss)	(343		)	276			(67		)
Balance as of September 30, 2017	$	430		$	(2,011	)	$	(1,581	)
Balance as of March 31, 2018	$	(468	)	$	(1,461	)	$	(1,929	)
	Nine Months Ended September 30, 2017 (in thousands)
	Foreign currencytranslationadjustments			Changes inderivativefinancialinstruments			Totalaccumulatedcomprehensiveincome (loss)
Balance as of December 31, 2016	$	(1,412	)	$	(2,822	)	$	(4,234	)
Other comprehensive income before reclassifications	1,842			—			1,842
Amounts reclassified from accumulated other comprehensive income (loss)	—			811			811
Net current-period other comprehensive income	1,842			811			2,653
Balance as of September 30, 2017	$	430		$	(2,011	)	$	(1,581	)

	Three Months Ended September 30, 2016 (in thousands)
	Three Months Ended March 31, 2017 (in thousands)
	Foreign currencytranslationadjustments			Changes inderivativefinancialinstruments			Totalaccumulatedcomprehensiveincome (loss)
Balance as of June 30, 2016	$	(197	)	$	(3,368	)	$	(3,565	)
Balance as of December 31, 2016	$	(1,412	)	$	(2,822	)	$	(4,234	)
Other comprehensive loss before reclassifications	(495		)	—			(495		)
Other comprehensive income before reclassifications	219			—			219
Amounts reclassified from accumulated other comprehensive income (loss)	—			~~273~~267			~~273~~267
Net current-period other comprehensive income (loss)	(495		)	273			(222		)
Net current-period other comprehensive income	219			267			486
Balance as of September 30, 2016	$	(692	)	$	(3,095	)	$	(3,787	)
Balance as of March 31, 2017	$	(1,193	)	$	(2,555	)	$	(3,748	)
	Nine Months Ended September 30, 2016 (in thousands)
	Foreign currencytranslationadjustments			Changes inderivativefinancialinstruments			Totalaccumulatedcomprehensiveincome (loss)
Balance as of December 31, 2015	$	(1,965	)	$	(4,044	)	$	(6,009	)
Other comprehensive income before reclassifications	1,273			—			1,273
Amounts reclassified from accumulated other comprehensive income (loss)	—			949			949
Net current-period other comprehensive income	1,273			949			2,222
Balance as of September 30, 2016	$	(692	)	$	(3,095	)	$	(3,787	)

1924

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WILLBROS GROUP, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

10. Stockholders' Equity (continued)

Reclassifications From Accumulated Other Comprehensive Income (Loss)

Three Months Ended September 30, 2017 (in thousands)
Three Months Ended March 31, 2018 (in thousands)
Details about Accumulated OtherComprehensive Income Components	Amount Reclassified from Accumulated Other Comprehensive Income (Loss)		Details about Accumulated Other Comprehensive Income Components
Interest rate contracts	$	~~273~~276	Interest expense
Total	$	~~273~~276
Nine Months Ended September 30, 2017 (in thousands)
Details about Accumulated OtherComprehensive Income Components	Amount Reclassified from Accumulated Other Comprehensive Income (Loss)		Details about Accumulated Other Comprehensive Income Components
Interest rate contracts	$	811	Interest expense
Total	$	811

Three Months Ended September 30, 2016 (in thousands)
Three Months Ended March 31, 2017 (in thousands)
Details about Accumulated OtherComprehensive Income Components	Amount Reclassified from Accumulated Other Comprehensive Income (Loss)		Details about Accumulated Other Comprehensive Income Components
Interest rate contracts	$	~~273~~267	Interest expense
Total	$	~~273~~267
Nine Months Ended September 30, 2016 (in thousands)
Details about Accumulated OtherComprehensive Income Components	Amount Reclassified from Accumulated Other Comprehensive Income (Loss)		Details about Accumulated Other Comprehensive Income Components
Interest rate contracts	$	949	Interest expense
Total	$	949

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WILLBROS GROUP, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

11. Income (Loss) Per Share

Basic income (loss) per share is computed by dividing net income (loss) by the weighted average number of common shares outstanding for the period. Diluted income (loss) per share is based on the weighted average number of shares outstanding during each period and the assumed exercise of potentially dilutive stock options and vesting of restricted stock units less the number of treasury shares assumed to be purchased from the proceeds using the average market price of the Company’s stock for each of the periods presented.

Basic and diluted income (loss) per common share from continuing operations is computed as follows (in thousands, except share and per share amounts):

	Three Months Ended September 30,						Nine Months Ended September 30,
	Three Months Ended March 31,
	2017			2016			2017			2016
	2018			2017
Net loss from continuing operations applicable to common shares (numerator for basic and diluted calculation)	$	(3216,~~709~~735	)	$	(1017,~~661~~736	)	$	~~(51,566~~	)	$	~~(29,720~~	)
Weighted average number of common shares outstanding for basic loss per share	62,~~310~~404,~~191~~906			61,~~639~~829,~~590~~768			~~62,105,282~~			~~61,257,851~~
Weighted average number of potentially dilutive common shares outstanding	—			—			—			—
Weighted average number of common shares outstanding for diluted loss per share	62,~~310~~404,~~191~~906			61,~~639~~829,~~590~~768			~~62,105,282~~			~~61,257,851~~
Loss per common share from continuing operations:
Basic	$	(0.5227	)	$	(0.1729	)	$	~~(0.83~~	)	$	~~(0.49~~	)
Diluted	$	(0.5227	)	$	(0.1729	)	$	~~(0.83~~	)	$	~~(0.49~~	)

The Company has excluded shares potentially issuable under the terms of use of the securities listed below from the computation of diluted income per share, as the effect would be anti-dilutive:

	Three Months Ended September 30,
	Three Months Ended March 31,
	2017	2016
	2018	2017
Stock options	—	31,522
Restricted stock and restricted stock units	25,184	616,970
Restricted stock and restricted stock units	324,428	52,677
	324,428	84,199

~~12. Segment Information~~25

The Company has three reportable segments: Oil & Gas, Utility T&D and Canada. These segments are comprised of strategic businesses that are defined by the industries or geographic regions they serve. Each segment is managed as an operation with well-established strategic directions and performance requirements. Each segment is led by a separate segment President who reports directly to the Company's Chief Operating Decision Maker (“CODM”). For additional information regarding the Company's reportable segments, see Note 1 - Company and Organization for more information.

The CODM evaluates segment performance using operating income which is defined as contract revenue less contract costs and segment overhead, such as amortization related to intangible assets and general and administrative expenses that are directly attributable to the segment. In 2016, the Company implemented a change to its organizational structure such that corporate overhead costs, such as executive management, public company, accounting, tax and professional services, human resources and treasury, are no longer allocated to each segment. These costs are classified as “Corporate” in the tables below. Previously reported segment information has been modified to conform to this new presentation.

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WILLBROS GROUP, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

12. Segment Information ~~(continued)~~

	Three Months Ended September 30, 2017
	Oil & Gas			Utility T&D			Canada			Corporate			Eliminations		Consolidated
Contract revenue	$	75,284		$	129,906		$	35,583		$	—		$	—	$	240,773
Contract costs	88,114			131,142			33,705			—			—		252,961
Contract income (loss)	(12,830		)	(1,236		)	1,878			—			—		(12,188		)
Amortization of intangibles	27			2,389			—			—			—		2,416
General and administrative	1,962			3,850			1,910			5,314			—		13,036
Other charges (income)	(53		)	—			264			(62		)	—		149
Operating loss	$	(14,766	)	$	(7,475	)	$	(296	)	$	(5,252	)	$	—	(27,789		)
Non-operating expenses															(3,788		)
Provision for income taxes															1,132
Loss from continuing operations															(32,709		)
Loss from discontinued operations net of provision for income taxes															(1,496		)
Net loss															$	(34,205	)

The Company has three reportable segments: Utility T&D, Canada and Oil & Gas. These segments are comprised of strategic businesses that are defined by the industries or geographic regions they serve. The Company’s Chief Operating Decision Maker evaluates segment performance using operating income which is defined as contract revenue less contract costs and segment overhead, such as amortization related to intangible assets and general and administrative expenses that are directly attributable to the segment. For additional information regarding the Company’s reportable segments, see Note 1 – Company Description and Financial Condition for more information.

The following tables reflect the Company’s operations by reportable segment for the three months ended March 31, 2018 and 2017 (in thousands):

	Three Months Ended September 30, 2016
	Three Months Ended March 31, 2018
	Oil & Gas			Utility T&D			Canada			Corporate			Eliminations			Consolidated
	Utility T&D			Canada			Oil & Gas			Corporate			Eliminations			Consolidated
Contract revenue	$	33112,~~100~~612		$	~~106~~25,~~422~~803		$	3562,~~355~~639		$	—		$	(5674	)	$	~~174~~200,~~821~~980
Contract costs	34104,~~192~~305			9524,~~461~~769			3364,~~209~~294			—			(5674		)	~~162~~193,~~806~~294
Contract income (loss)	(18,~~092~~307		)	101,~~961~~034			2(1,~~146~~655		)	—			—			127,~~015~~686
Amortization of intangibles	482,390			~~2,390~~—			—9			—			—			2,~~438~~399
General and administrative	24,~~998~~476			41,~~324~~813			2,~~174~~036			5,~~881~~150			—			1513,~~377~~475
Other charges (income)	245			(15		)	313			(24		)	—			519
Gain on sale of assets	(498		)	(75		)	(5,507		)	—			—			(6,080		)
Operating income (loss)	$	(4,383	)	$	4,262		$	(341	)	$	(5,857	)	$	—		(6,319		)
Other charges	31			146			804			7,384			—			8,365
Non-operating expenses																(3,550		)
Operating income (loss)	$	1,908		$	(850	)	$	1,003		$	(12,534	)	$	—		(10,473		)
Provision for income taxes																792
Non-operating expenses																(6,483		)
Loss from continuing operations																(10,661		)
Benefit for income taxes																(221		)
Loss from discontinued operations net of provision for income taxes																(1,325		)
Loss from continuing operations																(16,735		)
Net loss																$	(11,986	)
Loss from discontinued operations net of provision for income taxes																(230		)
Net loss																$	(16,965	)



	Three Months Ended March 31, 2017
	Utility T&D		Canada			Oil & Gas			Corporate			Eliminations		Consolidated
Contract revenue	$	115,508	$	25,960		$	22,432		$	—		$	—	$	163,900
Contract costs	107,890		26,786			27,543			—			—		162,219
Contract income (loss)	7,618		(826		)	(5,111		)	—			—		1,681
Amortization of intangibles	2,390		—			27			—			—		2,417
General and administrative	4,378		2,324			2,679			4,670			—		14,051
(Gain) loss on sale of assets	66		(269		)	(493		)	—			—		(696		)
Other charges	—		459			12			291			—		762
Operating income (loss)	$	784	$	(3,340	)	$	(7,336	)	$	(4,961	)	$	—	(14,853		)
Non-operating expenses														(3,483		)
Benefit for income taxes														(600		)
Loss from continuing operations														(17,736		)
Loss from discontinued operations net of provision for income taxes														(31		)
Net loss														$	(17,767	)

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WILLBROS GROUP, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

12. Segment Information (continued)

	Nine Months Ended September 30, 2017
	Oil & Gas			Utility T&D		Canada			Corporate			Eliminations		Consolidated
Contract revenue	$	146,748		$	397,097	$	88,275		$	—		$	—	$	632,120
Contract costs	165,297			373,564		86,687			—			—		625,548
Contract income (loss)	(18,549		)	23,533		1,588			—			—		6,572
Amortization of intangibles	81			7,169		—			—			—		7,250
General and administrative	6,872			12,071		5,967			15,350			—		40,260
Other charges	34			—		971			341			—		1,346
Operating income (loss)	$	(25,536	)	$	4,293	$	(5,350	)	$	(15,691	)	$	—	(42,284		)
Non-operating expenses														(10,947		)
Benefit for income taxes														(1,665		)
Loss from continuing operations														(51,566		)
Loss from discontinued operations net of provision for income taxes														(1,508		)
Net loss														$	(53,074	)

Total assets by segment at March 31, 2018 and December 31, 2017 are presented below (in thousands):

	Nine Months Ended September 30, 2016
	March 31, 2018			December 31, 2017
	Oil & Gas			Utility T&D			Canada		Corporate			Eliminations			Consolidated
Utility T&D	$	201,902		$	196,923
Contract revenue	$	147,174		$	313,066		$	107,343	$	—		$	(290	)	$	567,293
Canada	30,753			41,958
Contract costs	147,022			281,025			98,565		—			(290		)	526,322
Oil & Gas	42,512			50,779
Contract income	152			32,041			8,778		—			—			40,971
Corporate	73,536			73,893
Amortization of intangibles	146			7,169			—		—			—			7,315
Total assets, continuing operations	$	348,703		$	363,553
General and administrative	9,450			11,393			6,691		19,497			—			47,031
Other charges (income)	1,575			(3		)	973		2,601			—			5,146
Operating income (loss)	$	(11,019	)	$	13,482		$	1,114	$	(22,098	)	$	—		(18,521		)
Non-operating expenses															(10,053		)
Provision for income taxes															1,146
Loss from continuing operations															(29,720		)
Loss from discontinued operations net of provision for income taxes															(3,836		)
Net loss															$	(33,556	)

~~Total~~13. ~~assets by segment at September 30~~Contingencies, ~~2017~~Commitments and ~~December 31,~~Other ~~2016 are presented below (in thousands):~~Circumstances

	September 30, 2017		December 31, 2016
Oil & Gas	$	78,981	$	42,887
Utility T&D	214,176		201,339
Canada	44,504		47,704
Corporate	62,823		70,601
Total assets, continuing operations	$	400,484	$	362,531

Contingencies

23Litigation and Regulatory Matters Related to the Company’s October 21, 2014 Press Release and December 4, 2014 8-K Announcing the Restatement of Condensed Consolidated Financial Statements for the Quarterly Periods Ended June 30, 2014 and March 31, 2014

After the Company announced it would be restating its Condensed Consolidated Financial Statements for the quarterly period ended June 30, 2014, a complaint was filed in the United States District Court for the Southern District of Texas (“USDC”) on October 28, 2014 seeking class action status on behalf of purchasers of the Company’s stock and alleging damages on their behalf arising from the matters that led to the restatement. The original defendants in the case were the Company, its former Chief Executive Officer, Robert R. Harl, and its former Chief Financial Officer, Van A. Welch. On January 30, 2015, the court named two employee retirement systems as Lead Plaintiffs. Lead Plaintiffs filed their consolidated complaint, captioned In re Willbros Group, Inc. Securities Litigation, on March 31, 2015, adding as a defendant John T. McNabb, II, the former Chief Executive Officer who had succeeded Mr. Harl, and claims regarding the restatement of the Company’s Condensed Consolidated Financial Statements for the quarterly period ended March 31, 2014. On June 15, 2015, Lead Plaintiffs filed a second amended consolidated complaint, seeking unspecified damages and asserting violations of Sections 10(b) and 20(a) of the Securities Exchange Act of 1934, as amended (the “Act”), based on alleged misrepresentations and omissions in the SEC filings and other public disclosures in 2014, primarily regarding internal controls, the performance of the Oil & Gas segment, compliance with debt covenants and liquidity, certain financial results and the circumstances surrounding Mr. Harl’s departure. On July 27, 2015, the Company filed a motion to dismiss the case. At a hearing on May 24, 2016, the court granted the motion to dismiss in part and denied it in part. On July 22, 2016, the Company filed an answer to the suit denying the remaining allegations in the case, which complain of alleged misrepresentations and omissions in violation of the Act regarding internal controls, the performance of the Oil & Gas segment and Mr. Harl’s departure. On June 28, 2017, Lead Plaintiffs filed a motion asking the Court to reconsider its order in 2016 dismissing certain claims and allow Lead Plaintiffs to replead two of the claims the Court has dismissed; the Company opposes the motion. The Court heard oral argument but has not ruled. On February 16, 2018, the Company reached an agreement in principle, which, if approved by the Court, would settle all claims against the defendants and be fully funded by our insurance carriers. On April 17, 2018, the Court signed Order Preliminarily Approving Settlement and Providing Notice, preliminarily approving the settlement and also scheduling, among other dates, a hearing for August 2, 2018 to determine whether the parties’ settlement is fair, reasonable and adequate to the Settlement Class Members.

In addition, two shareholder derivative lawsuits were filed purportedly on behalf of the Company in connection with the restatement. The first, Markovich v. Harl et al, was filed on November 6, 2014 in the District Court of Harris County, Texas. The second, Kumararatne v. McNabb et al, was filed on March 4, 2015 in the USDC, but was voluntarily dismissed by the plaintiff on April 23, 2015. The Markovich lawsuit named certain former officers and current and former members of the Company’s Board of Directors as defendants and the Company as a nominal defendant. The lawsuit alleged that the officer and board member defendants breached their fiduciary duties by permitting the Company’s internal controls to be inadequate, failing to prevent the restatements, and wasting corporate assets, and that the defendants were unjustly enriched. The defendants sought dismissal of the lawsuit on the grounds that the plaintiff failed to make demand upon the Company’s board to bring the lawsuit, and, on February 23, 2016, the court sustained the defendants’ motion and dismissed the lawsuit with prejudice. On March 10, 2016, the plaintiff filed a motion for reconsideration and asked the court for leave to amend its lawsuit. The court granted the plaintiff’s motion in part, allowing an amended petition, which was filed on April 18, 2016. The Plaintiff’s Second Amended Petition added Ravi Kumararatne as a plaintiff and added claims for breach of fiduciary duty against the former officers and officer and Board of Director defendants related to the departure of former Company executives, financial controls,

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WILLBROS GROUP, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

13. Contingencies, Commitments and Other Circumstances (continued)

~~Contingencies~~and compliance with the Company’s debt covenants. The Company sought dismissal of the amended petition on the grounds the plaintiffs failed to make a demand upon the Company’s board to bring the lawsuit. In response, plaintiffs filed a Third Amended Petition on June 24, 2016, purporting to add additional facts to support their allegations, including their allegation that they were excused from making a demand upon the board because, they claimed, such demand would be futile. Believing the claims added by plaintiffs were without merit, the Company sought to dismiss this latest pleading. After hearing argument on the motion, the court issued an order on October 24, 2016, sustaining the Company’s objections to plaintiffs’ latest pleading and again dismissed the lawsuit with prejudice. Plaintiffs’ motion for reconsideration was denied on December 21, 2016. Plaintiffs filed a Notice of Appeal on January 20, 2017. The appeal is assigned to the 14th Court of Appeals, Houston, Texas; the court heard oral argument in the appeal on January 30, 2018 but has not yet issued an opinion.

Litigation ~~and Regulatory Matters~~ Related to ~~the Company’s October 21, 2014 Press Release Announcing the Restatement of Condensed Consolidated Financial Statements for the Quarterly Period Ended June 30, 2014~~Proxy

~~After~~On ~~the~~April ~~Company~~11, ~~announced~~2018, itthe ~~would~~Company besubmitted ~~restating~~for ~~its~~review ~~Condensed~~to ~~Consolidated Financial Statements for~~ the ~~quarterly~~SEC ~~period ended June 30, 2014,~~ a ~~complaint~~preliminary ~~was~~proxy ~~filed~~concerning in the ~~United~~pending ~~States~~merger ~~District~~between ~~Court for~~ the ~~Southern~~Company ~~District~~and ofPrimoris. ~~Texas~~A ~~(“USDC”)~~securities ~~on October 28, 2014 seeking~~ class action ~~status~~suit onwas ~~behalf~~filed ~~of purchasers of the Company’s stock and alleging damages~~ on ~~their~~April ~~behalf~~24, ~~arising~~2018 ~~from~~by ~~the~~a ~~matters~~purported ~~that~~stockholder ~~led~~in to the ~~restatement.~~United ~~The~~States ~~original~~District ~~defendants~~Court infor the ~~case~~Southern ~~were~~District ~~the~~of ~~Company,~~Texas ~~its~~seeking ~~former~~injunctive ~~chief~~relief ~~executive~~with ~~officer,~~regards ~~Robert~~to R.the ~~Harl,~~pending ~~and its former chief financial officer, Van A~~merger. ~~Welch.~~The Onsuit ~~January~~Karl ~~30,~~Graulich ~~2015, the court named two employee retirement systems as Lead Plaintiffs~~v. ~~Lead Plaintiffs filed their consolidated complaint, captioned In re~~ Willbros Group, Inc. ~~Securities Litigation~~[sic], onet ~~March 31~~al., ~~2015~~Case 4:18-cv-01286, ~~adding~~names as adefendants ~~defendant John T. McNabb, II,~~ the ~~former~~Company ~~chief~~and ~~executive~~its ~~officer who had succeeded Mr~~directors. ~~Harl,~~The ~~and~~suit claims ~~regarding~~that the ~~restatement~~defendants ofviolated the Company's Condensed Consolidated Financial Statements for the quarterly period ended March 31, 2014. On June 15, 2015, Lead Plaintiffs filed a second amended consolidated complaint, seeking unspecified damages and asserting violations of Sections 1014(ba) and 20(a) of the ~~Securities~~ Exchange Act ~~of 1934, as amended (the “Act”), based on alleged misrepresentations~~ and ~~omissions in the~~ SEC ~~filings~~Rule ~~and~~14a-9 ~~other~~by ~~public~~filing ~~disclosures~~a inmaterially ~~2014,~~incomplete ~~primarily regarding internal controls, the performance of the Oil & Gas segment, compliance with debt covenants~~ and ~~liquidity,~~misleading ~~certain~~preliminary ~~financial~~proxy ~~results~~statement ~~and the circumstances surrounding Mr. Harl's departure. On July 27, 2015, the Company filed a motion to dismiss the case. At a hearing~~ on ~~May~~April 2411, ~~2016, the court granted the motion to dismiss in part and denied it in part~~2018. OnThe ~~July~~complaint ~~22,~~seeks ~~2016,~~a ~~the~~variety ~~Company filed an answer to the suit denying the remaining allegations in the case, which complain~~ of ~~alleged~~equitable ~~misrepresentations~~ and ~~omissions~~preliminary ininjunctive ~~violation~~remedies ~~of the Act regarding internal controls~~including, ~~the~~among ~~performance~~other ~~of the Oil & Gas segment and Mr. Harl's departure. On June 28~~things, ~~2017,~~enjoining ~~Lead Plaintiffs filed a motion asking~~ the ~~Court~~consummation ~~to reconsider its order in 2016 dismissing certain claims and allow Lead Plaintiffs to replead two~~ of the ~~claims~~merger ~~the~~and ~~Court~~awarding ~~has dismissed;~~ the ~~Company~~plaintiff ~~opposes the motion; the Court has heard oral argument but has not ruled. The Company continues to vigorously defend against the Lead Plaintiffs' allegations~~damages, ~~which~~costs ~~the~~and ~~Company~~attorney’s ~~believes are without merit~~fees. ~~The Company is not able at this time to determine the likelihood of loss, if any, arising from this matter.~~

InThe ~~addition,~~Company ~~two~~believes ~~shareholder derivative lawsuits were filed purportedly on behalf of~~ the ~~Company~~claims in ~~connection~~this ~~with~~complaint ~~the~~are ~~restatement.~~without ~~The first, Markovich v~~merit. ~~Harl~~At etthis altime, ~~was~~however, ~~filed~~it onis ~~November~~not 6,possible ~~2014~~to inpredict the ~~District~~outcome ~~Court~~ of ~~Harris~~this ~~County,~~matter ~~Texas.~~or ~~The~~its ~~second, Kumararatne~~effect ~~v. McNabb et al, was filed~~ on ~~March 4, 2015 in~~ the ~~USDC,~~Company ~~but~~or ~~was voluntarily dismissed by~~ the ~~plaintiff on April 23, 2015~~merger. ~~The Markovich lawsuit~~A ~~named~~preliminary ~~certain~~injunction ~~former~~could ~~officers~~delay ~~and~~or ~~current~~jeopardize ~~and former members of~~ the ~~Company's~~completion ~~board~~ of ~~directors as defendants and~~ the ~~Company as a nominal defendant. The lawsuit alleged that the officer and board member defendants breached their fiduciary duties by permitting the Company’s internal controls to be inadequate~~merger, ~~failing to prevent the restatements,~~ and ~~wasting~~an ~~corporate~~adverse ~~assets,~~judgment ~~and~~granting ~~that~~permanent ~~the~~injunctive ~~defendants~~relief ~~were~~could ~~unjustly~~indefinitely ~~enriched.~~enjoin ~~The~~completion ~~defendants sought dismissal~~ of the lawsuit on the grounds that the plaintiff failed to make demand upon the Company’s board to bring the lawsuit, and, on February 23, 2016, the court sustained the defendants’ motion and dismissed the lawsuit with prejudicemerger. OnAn ~~March~~adverse ~~10,~~judgment ~~2016, the plaintiff filed a motion~~ for ~~reconsideration~~money ~~and~~damages ~~asked~~could ~~the~~have ~~court for leave to amend its lawsuit. The court granted the plaintiff’s motion in part, allowing~~ an ~~amended~~adverse ~~petition,~~effect ~~which was filed~~ on ~~April 18, 2016. The Plaintiff’s Second Amended Petition added Ravi Kumararatne as a plaintiff and added claims for breach of fiduciary duty against~~ the ~~former officers and officer and board of director defendants related to the departure of former~~ Company ~~executives, financial controls, and compliance with the Company’s debt covenants~~. The Company sought dismissal of the amended petition on the grounds the plaintiffs failed to make a demand upon the Company’s board to bring the lawsuit. In response, plaintiffs filed a Third Amended Petition on June 24, 2016, purporting to add additional facts to support their allegations, including their allegation that they were excused from making a demand upon the board because, they claimed, such demand would be futile. Believing the claims added by plaintiffs were without merit, the Company sought to dismiss this latest pleading. After hearing argument on the motion, the court issued an order on October 24, 2016, sustaining the Company's objections to plaintiffs' latest pleading and again dismissed the lawsuit with prejudice. Plaintiffs' motion for reconsideration was denied on December 21, 2016. Plaintiffs filed a Notice of Appeal on January 20, 2017. The appeal is assigned to the 14th Court of Appeals, Houston, Texas; the court has set the appeal for oral argument.

Other

The SEC issued an order of investigation on January 29, 2015 and a subpoena on February 3, 2015, requesting information regarding the restatement of the Company'’s previously issued Condensed Consolidated Financial Statements for the quarterly periods ended March 31, 2014 and June 30, 2014. The Company provided its full cooperation to the SEC, who on January 25, 2016, sent the Company a letter stating it had concluded its investigation and, based on the information it had, did not intend to recommend an enforcement action against the Company.

24In addition to the matters discussed above, the Company is party to a number of other legal proceedings. Management believes that the nature and number of these proceedings are typical for a firm of similar size engaged in a similar type of business and that none of these proceedings is material to the Company’s consolidated results of operations, financial position or cash flows.

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WILLBROS GROUP, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

13. Contingencies, Commitments and Other Circumstances (continued)

the quarterly periods ended March 31, 2014 and June 30, 2014. The Company provided its full cooperation to the SEC, who on January 25, 2016, sent the Company a letter stating it had concluded its investigation and, based on the information it had, did not intend to recommend an enforcement action against the Company.

In addition to the matters discussed above, the Company is party to a number of other legal proceedings. Management believes that the nature and number of these proceedings are typical for a firm of similar size engaged in a similar type of business and that none of these proceedings is material to the Company’s consolidated results of operations, financial position or cash flows.

Commitments

From time to time, the Company enters into commercial commitments, usually in the form of commercial and standby letters of credit, surety bonds and financial guarantees. Contracts with the Company’s customers may require the Company to secure letters of credit or surety bonds to secure the Company’s performance of contracted services. In such cases, the letters of credit or bond commitments can be called upon in the event of the Company'’s failure to perform contracted services. Likewise, contracts may allow the Company to issue letters of credit or surety bonds in lieu of contract retention provisions, where the client otherwise withholds a percentage of the contract value until project completion or expiration of a warranty period. Retention letters of credit or bond commitments can be called upon in the event of warranty or project completion issues, as prescribed in the contracts. The Company also issues letters of credit from time to time to secure deductible obligations under its workers compensation, automobile and general liability policies. At ~~September~~March 3031, ~~2017~~2018, the Company had approximately $5540.58 million of outstanding letters of credit. This amount represents the maximum amount of payments the Company could be required to make if these letters of credit are drawn upon. Additionally, the Company issues surety bonds (primarily performance in nature) that are customarily required by commercial terms on construction projects. At ~~September~~March 3031, ~~2017~~2018, these bonds outstanding had a face value of $~~145~~152.40 million. This amount represents the bond penalty amount of future payments the Company could be required to make if the Company fails to perform its obligations under such contracts. The performance bonds do not have a stated expiration date; rather, each is released when the Company'’s performance of the contract is accepted by the customer. The Company’s maximum exposure as it relates to the value of the bonds outstanding is lowered on each bonded project as the cost to complete is reduced. As of ~~September~~March 3031, ~~2017~~2018, no liability has been recognized for letters of credit or surety bonds.

Other Circumstances

The Company has the usual liability of contractors for the completion of contracts and the warranty of its work. In addition, the Company acts as prime contractor on a majority of the projects it undertakes and is normally responsible for the performance of the entire project, including subcontract work. Management is not aware of any material exposure related thereto which has not been provided for in the accompanying Condensed Consolidated Financial Statements.

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WILLBROS GROUP, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

14. Fair Value Measurements

The FASB’s standard on fair value measurements defines fair value as the price that would be received from selling an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date. When determining the fair value measurements for assets and liabilities required or permitted to be recorded at fair value, the Company considers the principal or most advantageous market in which it would transact and considers assumptions that market participants would use when pricing the asset or liability, such as inherent risk, transfer restrictions and risk of nonperformance.

Fair Value Hierarchy

The FASB’s standard on fair value measurements establishes a fair value hierarchy that requires an entity to maximize the use of observable inputs and minimize the use of unobservable inputs when measuring fair value. A financial instrument’s categorization within the fair value hierarchy is based upon the lowest level of input that is significant to the fair value measurement. This standard establishes three levels of inputs that may be used to measure fair value:

Level 1 – Quoted prices in active markets for identical assets or liabilities.

Level 2 – Observable inputs other than Level 1 prices such as quoted prices for similar assets or liabilities.

Level 3 – Unobservable inputs to the valuation methodology that are significant to the measurement of fair value of assets or liabilities.

There were no transfers between levels in the ~~third~~first quarter of ~~2017~~2018 and ~~2016~~2017.

The Company’s financial instruments consist of cash and cash equivalents, accounts receivable, accounts payable and debt obligations. The fair value estimates of the Company’s financial instruments have been determined using available market information and appropriate valuation methodologies and approximate carrying value.

Hedging Arrangements

The Company is exposed to market risk associated with changes in non-U.S. currency exchange rates. To mitigate its risk, the Company may borrow in Canadian dollars under its Canadian Facility to settle U.S. dollar account balances.

The Company attempts to negotiate contracts that provide for payment in U.S. dollars, but it may be required to take all or a portion of payment under a contract in another currency. To mitigate non-U.S. currency exchange risk, the Company seeks to match anticipated non-U.S. currency revenue with expenses in the same currency whenever possible. To the extent it is unable to match non-U.S. currency revenue with expenses in the same currency, the Company may use forward contracts, options or other common hedging techniques in the same non-U.S. currencies. The Company had no forward contracts or options at ~~September~~March 3031, ~~2017~~2018 or December 31, ~~2016~~2017.

The Company is subject to interest rate risk on its debt and investment of cash and cash equivalents arising in the normal course of business and had previously entered into hedging arrangements to fix or otherwise limit the interest cost of its variable interest rate borrowings.

Termination of Interest Rate Swap Agreement

In August 2013, the Company entered into an interest rate swap agreement (the “Swap Agreement”) for a notional amount of $124.1 million to hedge changes in the variable rate interest expense on $124.1 million of its existing or replacement LIBOR indexed debt. The Swap Agreement was designated and qualified as a cash flow hedging instrument with the effective portion of the Swap Agreement'’s change in fair value recorded in Other Comprehensive Income (“OCI”). The Swap Agreement was highly effective in offsetting changes in interest expense and no hedge ineffectiveness was recorded in the Consolidated Statements of Operations. The Swap Agreement was terminated in the third quarter of 2015 for $5.7 million, which was recorded in OCI as fair value. In the fourth quarter of 2015, the Company made an early payment of $93.6 million against its 2014 Term Loan Facility and therefore reclassified approximately $1.2 million of the fair value of the Swap Agreement from OCI to interest expense. In the first quarter of 2016, the Company made an early payment of $3.1 million against its 2014 Term Loan Facility and therefore reclassified approximately $0.1 million of the fair value of the Swap Agreement from OCI to interest expense. The remaining fair value of the Swap Agreement included in OCI will be reclassified to interest expense over the remaining life of the underlying debt with approximately $1.1 million expected to be recognized in the coming twelve months.

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WILLBROS GROUP, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

15. Other Charges

The following table reflects the Company’s other charges for the three months ended March 31, 2018 and 2017 (in thousands):

	Three Months Ended September 30,						Nine Months Ended September 30,
	Three Months Ended March 31,
	2017			2016			2017			2016
	2018			2017
Equipment and facility lease abandonment	$	(345	)	$	217		$	(251	)	$	3,338
Legal and consulting costs (1)	$	7,384		$	274
Loss on sale of subsidiary (1)	—			207			—			330
Equipment and facility lease abandonment	—			(21		)
Employee severance charges	254			91			786			1,249
Employee severance costs	946			344
Restatement costs (2)	240			4			617			(42		)
Accelerated stock vesting	35			165
Accelerated stock vesting	—			—			194			271
Total	$	8,365		$	762
Total	$	149		$	519		$	1,346		$	5,146

(1) ~~Resulted~~2018 ~~from~~costs are primarily associated with the ~~2016~~Company’s ~~sale~~evaluation of various strategic alternatives, which culminated with the ~~Oil~~signing &of ~~Gas~~the ~~segment'~~Merger Agreement with Primoris. 2017 costs are associated with the restatements of the Company’s ~~fabrication~~Condensed ~~business~~Consolidated Financial Statements for the quarterly periods ended March 31, 2014 and June 30, 2014.

Activity in the accrual related to the equipment and facility lease abandonment charges during the three months ended March 31, 2018 is as follows (in thousands):

(2) Includes legal fees associated with the restatements of the Company's Condensed Consolidated Financial Statements for the quarterly periods ended March 31, 2014 and June 30, 2014. See Note 13 - Contingencies, Commitments and Other Circumstances for more information.



	Utility T&D			Canada			Oil & Gas			Corporate			Total
Accrued cost at December 31, 2017	$	172		$	211		$	545		$	2,947		$	3,875
Cash payments	(29		)	(32		)	(43		)	(535		)	(639		)
Non-cash charges (1)	—			5			8			101			114
Change in estimates	—			—			—			—			—
Accrued cost at March 31, 2018	$	143		$	184		$	510		$	2,513		$	3,350

	Oil & Gas			Canada			Utility T&D			Corporate			Total
Accrued cost at December 31, 2016	$	793		$	290		$	348		$	4,048		$	5,479
Cash payments	(225		)	(102		)	(136		)	(930		)	(1,393		)
Non-cash charges (1)	—			—			—			247			247
Change in estimates	22			41			—			(314		)	(251		)
Accrued cost at September 30, 2017	$	590		$	229		$	212		$	3,051		$	4,082

(1) Non-cash charges consist of accretion expense.

The Company will continue to evaluate the need for additional equipment and facility lease abandonment charges, including the adequacy of its existing accrual, as conditions warrant.

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WILLBROS GROUP, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

16. Discontinued Operations

The following disposals qualify for discontinued operations treatment under ASU 2014-08, which the Company adopted on January 1, 2015.

Professional Services

On November 30, 2015, the Company sold the balance of its Professional Services segment to TRC Companies (“TRC”) for $130.0 million in cash, subject to working capital and other adjustments. At closing, TRC held back $7.5 million from the purchase price (the “Holdback Amount”) until the Company effects the novation of a customer contract from one of the subsidiaries sold in the transaction to the Company (or obtains written approval of a subcontract of all the work that is the subject of such contract) and obtains certain consents. If such novation, subcontract or consents were not approved by March 15, 2016, TRC would pay the Holdback Amount to the Company. In connection with this transaction, the Company recorded a ~~net~~ gain on sale of $97.0 million during the year ended December 31, 2015.

During the year ended December 31, 2016, the Company reached an agreement with TRC on substantially all of the outstanding items related to the sale of the Professional Services segment. As a result, the Company received $4.6 million during the year ended December 31, 2016 in relation to the sale and inclusive of the final settlement of working capital and the Holdback Amount and recorded $2.5 million in charges against the ~~net~~original gain on sale in relation to working capital and other post-closing adjustments.

Certain assets and liabilities associated with one Professional Services contract were retained by the Company and have been excluded from the transaction.

In 2015, and prior to the sale of the balance of the Professional Services segment, the Company sold the following three subsidiaries that were historically part of the Professional Services segment.

Downstream Professional Services

On June 12, 2015, the Company sold all of its issued and outstanding equity of Downstream Professional Services to BR Engineers, LLC for approximately $10.0 million in cash. In connection with this transaction, the Company recorded a ~~net~~ loss on sale of $2.2 million during the year ended December 31, 2015.

Premier

On March 31, 2015, the Company sold all of its membership units in Premier to USIC Locating Services, LLC for approximately $51.0 million in cash, of which $4.0 million was deposited into an escrow account for a period of up to eighteen months to cover post-closing adjustments and any indemnification obligations of the Company. In connection with this transaction, the Company recorded a ~~net~~ gain on sale of $37.1 million during the year ended December 31, 2015. The Company received $3.7 million as full and final settlement of the outstanding escrow amount during the year ended December 31, 2016.

UtilX

On March 17, 2015, the Company sold all of its equity interests of UtilX to Novinium, Inc. for approximately $40.0 million in cash, of which $0.5 million was deposited into an escrow account for a period of six months to cover post-closing adjustments and any indemnification obligations of the Company. In the third quarter of 2015, the Company cleared the $0.5 million amount recorded in the escrow account as a post-closing adjustment. As a result of this transaction, the Company recorded a ~~net~~ gain on sale of $20.3 million during the year ended December 31, 2015.

Hawkeye

In the fourth quarter of 2013, the Company sold certain assets comprising its Hawkeye business to Elecnor Hawkeye,

LLC, a subsidiary of Elecnor, Inc. ~~The Maine Power Reliability Program Project was retained by the Company and subsequently completed in 2015.~~

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WILLBROS GROUP, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

16. Discontinued Operations (continued)

Results of Discontinued Operations

Condensed Statements of Operations with respect to discontinued operations are as follows (in thousands) and are primarily related to the Professional Services segment:

	Three Months Ended September 30, 2017
	Three Months Ended March 31, 2018
	Professional Services			Hawkeye			Total
Contract revenue	$	2413		$	—		$	2413
Contract costs	~~154~~78			—			~~154~~78
General and administrative	~~501~~134			~~340~~25			~~841~~159
Other charges	~~525~~6			—			~~525~~6
Operating loss	(~~1,156~~205		)	(~~340~~25		)	(~~1,496~~230		)
Non-operating expenses	—			—			—
Pre-tax loss	(~~1,156~~205		)	(~~340~~25		)	(~~1,496~~230		)
Provision for income taxes	—			—			—
Loss from discontinued operations	$	(~~1,156~~205	)	$	(~~340~~25	)	$	(~~1,496~~230	)

	Three Months Ended September 30, 2016
	Three Months Ended March 31, 2017
	Professional Services			Hawkeye			Total
Contract revenue	$	—679		$	—		$	—679
Contract costs	~~276~~238			—			~~276~~238
General and administrative	~~651~~472			~~296~~—			~~947~~472
Other charges	102			—			102
Operating loss	(31		)	—			(31		)
Operating loss	(1,029		)	(296		)	(1,325		)
Non-operating expenses	—			—			—
Pre-tax loss	(~~1,029~~31		)	~~(296~~—		)	(~~1,325~~31		)
Provision for income taxes	—			—			—
Loss from discontinued operations	$	(~~1,029~~31	)	$	~~(296~~—	)	$	(~~1,325~~31	)

	Nine Months Ended September 30, 2017
	Professional Services			Hawkeye			Total
Contract revenue	$	707		$	—		$	707
Contract costs	415			—			415
Loss on sale of subsidiary	—			—			—
General and administrative	1,246			20			1,266
Other charges	525			—			525
Operating loss	(1,479		)	(20		)	(1,499		)
Non-operating expenses	—			—			—
Pre-tax loss	(1,479		)	(20		)	(1,499		)
Provision for income taxes	9			—			9
Loss from discontinued operations	$	(1,488	)	$	(20	)	$	(1,508	)

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WILLBROS GROUP, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

16. Discontinued Operations (continued)

	Nine Months Ended September 30, 2016
	Professional Services			Hawkeye			Total
Contract revenue	$	1,869		$	—		$	1,869
Contract costs	2,293			—			2,293
Loss on sale of subsidiary	2,456			—			2,456
General and administrative	1,949			67			2,016
Other income	(1,060		)	—			(1,060		)
Operating loss	(3,769		)	(67		)	(3,836		)
Non-operating expenses	—			—			—
Pre-tax loss	(3,769		)	(67		)	(3,836		)
Provision for income taxes	—			—			—
Loss from discontinued operations	$	(3,769	)	$	(67	)	$	(3,836	)

Condensed Balance Sheets with respect to discontinued operations are as follows (in thousands):

	September 30, 2017
	March 31, 2018
	Professional Services			Hawkeye			Total
Accounts receivable, net	$	44336		$	—		$	44336
Contract cost and recognized income not yet billed	25			—			25
Total assets associated with discontinued operations	336			—			336
Total assets associated with discontinued operations	69			—			69
Accounts payable and accrued liabilities	6			520			526
Accounts payable and accrued liabilities	341			638			979
Other current liabilities	502			—			502
Other current liabilities	575			—			575
Other long-term liabilities	794			—			794
Other long-term liabilities	1,035			—			1,035
Total liabilities associated with discontinued operations	1,302			520			1,822
Total liabilities associated with discontinued operations	1,951			638			2,589
Net liabilities associated with discontinued operations	$	(966	)	$	(520	)	$	(1,486	)
Net liabilities associated with discontinued operations	$	(1,882	)	$	(638	)	$	(2,520	)

	December 31, 2016
	December 31, 2017
	Professional Services			Hawkeye			Total
Accounts receivable, net	$	313		$	—		$	313
Contract cost and recognized income not yet billed	$	324		$	—		$	324
Contract cost and recognized income not yet billed	192			—			192
Total assets associated with discontinued operations	324			—			324
Total assets associated with discontinued operations	505			—			505
Accounts payable and accrued liabilities	337			180			517
Accounts payable and accrued liabilities	412			277			689
Other current liabilities	574			—			574
Contract billings in excess of costs and recognized income	358			—			358
Other long-term liabilities	893			—			893
Other current liabilities	531			—			531
Total liabilities associated with discontinued operations	1,804			180			1,984
Other long-term liabilities	995			—			995
Net liabilities associated with discontinued operations	$	(1,480	)	$	(180	)	$	(1,660	)
Total liabilities associated with discontinued operations	2,296			277			2,573
Net liabilities associated with discontinued operations	$	(1,791	)	$	(277	)	$	(2,068	)

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ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

The following discussion and analysis should be read in conjunction with the unaudited Condensed Consolidated Financial Statements for the three ~~and nine~~ months ended ~~September~~March 3031, ~~2017~~2018 and ~~2016~~2017, included in Item 1 of Part I of this Form 10-Q, and the Consolidated Financial Statements and Management’s Discussion and Analysis of Financial Condition and Results of Operations, including Critical Accounting Policies, included in our Annual Report on Form 10-K for the fiscal year ended December 31, ~~2016~~2017.

OVERVIEW

Company ~~Information~~Description

Willbros is a specialty energy infrastructure contractor serving the ~~oil~~power and ~~gas~~oil and ~~power~~gas industries with offerings that primarily include construction, maintenance and facilities development services. Our principal markets for continuing operations are the United States and Canada. We obtain our work through competitive bidding and negotiations with prospective clients. Contract values range from several thousand dollars to several hundred million dollars, and contract durations range from a few weeks to more than two years.

~~Willbros~~Business has three reportable segments: Oil & Gas, Utility T&D and Canada. These segments are comprised of strategic businesses that are defined by the industries or geographic regions they serve. Each segment is managed as an operation with well-established strategic directions and performance requirements. Each segment is led by a separate segment President who reports directly to the Company's Chief Operating Decision Maker (“CODM”).Segments

~~The~~Willbros ~~CODM~~has ~~evaluates~~three ~~segment~~reportable ~~performance~~segments: ~~using~~Utility ~~operating~~T&D, ~~income~~Canada ~~which~~and isOil ~~defined~~& asGas. ~~contract~~These ~~revenue~~segments ~~less~~are ~~contract~~comprised ~~costs~~of ~~and~~strategic ~~segment~~businesses ~~overhead,~~that ~~such~~are asdefined ~~amortization~~by ~~related~~the toindustries ~~intangible~~or ~~assets~~geographic ~~and~~regions ~~general~~they ~~and~~serve. ~~administrative~~Our ~~expenses~~Chief ~~that~~Operating ~~are~~Decision ~~directly~~Maker ~~attributable~~evaluates tosegment ~~the~~performance ~~segment.~~using Inoperating ~~2016,~~income wewhich ~~implemented~~is adefined ~~change~~as tocontract ~~our~~revenue ~~organizational~~less ~~structure~~contract ~~such~~costs ~~that~~and ~~corporate~~segment overhead ~~costs~~, such as ~~executive~~amortization ~~management,~~related ~~public~~to ~~company,~~intangible ~~accounting,~~assets ~~tax~~ and ~~professional~~general ~~services,~~and ~~human~~administrative ~~resources~~expenses ~~and~~that ~~treasury,~~ are nodirectly ~~longer~~attributable ~~allocated~~ to ~~each~~the segment~~. Previously reported segment information has been revised to conform to this new presentation.~~

Our Oil & Gas segment provides construction, maintenance and lifecycle extension services to the midstream markets. These services include pipeline construction to support the transportation and storage of hydrocarbons, including gathering, lateral and mainline pipeline systems, as well as, facilities construction such as pump stations, flow stations, gas compressor stations and metering stations. In addition, our Oil & Gas segment provides integrity construction and pipeline systems maintenance to a number of different customers. See Note 1 - Company and Organization for more information related to our future plans regarding our Oil & Gas segment.

Our Oil & Gas segment's tank services business is classified as held for sale at September 30, 2017. See Note 5 - Assets Held for Sale for more information.

Our Utility T&D segment provides a wide range of services in electric and natural gas transmission and distribution, including comprehensive engineering, procurement, maintenance and construction, repair and restoration of utility infrastructure. These services include engineering, design, installation, maintenance, procurement and repair of electrical transmission, distribution, substation, wireless and gas distribution systems. Our Utility T&D segment conducts projects ranging from small engineering and consulting projects to multi-million dollar turnkey distribution, substation and transmission line projects, including those required for renewable energy facilities.

Our Canada segment provides construction, maintenance and fabrication services, including integrity and supporting civil work, pipeline construction, general mechanical and facility construction, American Petroleum Institute (“API”) storage tanks, general and modular fabrication, along with electrical and instrumentation projects serving the Canadian energy and water industries.

~~General~~Our ~~economic~~Oil ~~and~~& ~~market~~Gas ~~conditions~~segment provides construction, ~~coupled~~maintenance ~~with~~and lifecycle extension services to the ~~highly~~midstream ~~competitive~~markets. ~~nature~~These ofservices ~~our~~include ~~industry~~facilities construction such as tank terminals, ~~continue~~pump tostations, ~~result~~flow instations, ~~pricing~~gas ~~pressure~~compressor onstations ~~the~~and ~~services~~metering westations, ~~provide~~as inwell ~~our~~as ~~Oil~~small-diameter &midstream ~~Gas~~pipeline construction, integrity construction and ~~Canada~~system ~~segments~~maintenance.

~~Looking~~On ~~Forward~~January 2, 2018, we sold our tank services business, which was historically included in our Oil & Gas segment, to ATS Group, Inc. (“ATS”) for a $3.0 million purchase price subject to working capital and other adjustments. In connection with this transaction, we received $2.5 million of cash proceeds and recorded a gain on sale of $1.0 million, which is included in the line item “Gain on sale of assets” in our Condensed Consolidated Statement of Operations for the three months ended March 31, 2018. See Note 5 – Assets Held for Sale included in Item 1 of Part I of this Form 10-Q for more information.

AsOn aJanuary ~~result~~9, of2018, ~~our~~we ~~third~~entered ~~quarter~~into ~~performance,~~an weAsset ~~have~~Purchase ~~determined~~Agreement ~~that~~to ~~the~~sell ~~nature~~assets ofcomprising our ~~U.S.~~ mainline pipeline construction ~~contracts~~business ~~in our Oil & Gas segment do not provide sufficient return for~~ (the ~~level~~“Asset ofPurchase ~~associated risk. As such~~Agreement”), wewhich ~~are~~was ~~exiting~~historically ~~our~~included ~~U.S. mainline pipeline construction business~~ in our Oil & Gas segment., ~~We will continue~~ to ~~focus~~WB ~~our~~Pipeline, ~~efforts~~LLC, onan ~~our~~affiliate ~~facilities~~of ~~and~~Meridien ~~integrity~~Energy, ~~construction~~LLC. ~~services as well as our small-diameter pipeline services in the Northeast~~(“Meridien”). ~~The~~For ~~outlook~~more ~~for~~information, ~~these~~see ~~services remains positive with strong bidding activity expected for~~ the ~~remainder~~subsection “Sale of ~~2017~~Mainline ~~and~~Pipeline ~~into~~Construction ~~2018~~Business” below.

31Merger Agreement

On March 27, 2018, we entered into an Agreement and Plan of Merger (“the Merger Agreement”) with Primoris Services Corporation (“Primoris”) and Waco Acquisition Vehicle, Inc., a wholly-owned subsidiary of Primoris (“Merger Sub”). Pursuant to the Merger Agreement, Merger Sub will be merged into us, and we will become a wholly owned subsidiary of Primoris. The Merger Agreement includes customary representations, warranties and covenants. Primoris will pay $0.60 per share for all of our outstanding common stock. The Merger Agreement is expected to close in the second quarter of 2018, subject to satisfaction of customary closing conditions, including approval of the Merger Agreement by the requisite vote of our

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Westockholders. ~~anticipate~~Upon ~~continued~~termination ~~growth~~of ~~in our Utility T&D segment into 2018 as~~ the ~~electric~~Merger ~~transmission~~Agreement ~~and~~in ~~distribution~~certain ~~market~~circumstances, ~~remains~~we ~~robust.~~are ~~Our~~obligated ~~Canada segment continues~~ to ~~work~~pay ~~through~~Primoris a ~~challenging~~termination ~~market;~~fee ~~however,~~of we$4.3 ~~are~~million ~~beginning~~and, toin ~~see~~certain ~~increased~~other ~~bidding activities~~circumstances, ~~particularly~~a intermination ~~the~~fee ~~facilities~~of ~~and~~$8.0 ~~industrial construction market~~million.

Term Forbearance Agreement

On March 27, 2018, we entered into a Forbearance Agreement (the “Term Forbearance Agreement”) with the lenders under the 2014 Term Credit Agreement (the “Term Lenders”). Under the Term Forbearance Agreement, the Term Lenders agreed to, among other things, forbear from taking any action to enforce certain of their rights or remedies under the 2014 Term Credit Agreement with respect to certain defaults and events of default (the “Term Specified Defaults”). The Term Forbearance Agreement is effective until the earliest of (i) August 15, 2018 or the closing of the Merger Agreement or (ii) the occurrence of any one of several specified termination events including, among other things, the termination of the Merger Agreement (the “Term Forbearance Period”). Upon expiration of the Term Forbearance Agreement or if we were to default under the Term Forbearance Agreement or the 2014 Term Credit Agreement, other than Term Specified Defaults, the Term Lenders would be free to exercise any rights and remedies with respect to such defaults and events of defaults pursuant to the terms of the 2014 Term Credit Agreement.

ABL Forbearance Agreement

On March 27, 2018, we entered into a Limited Forbearance Agreement (the “ABL Forbearance Agreement”) with the lenders under the 2013 ABL Credit Facility (the “ABL Lenders”). Under the ABL Forbearance Agreement, the ABL Lenders agreed to, among other things, forbear from taking any action to enforce certain of their rights or remedies under the 2013 ABL Credit Facility with respect to certain defaults and events of default (the “ABL Specified Defaults”). The ABL Forbearance Agreement is effective until the earliest of (i) July 31, 2018 or the closing of the Merger Agreement or (ii) the occurrence of any one of several specified termination events including, among other things, the termination of the Merger Agreement (the “ABL Forbearance Period”). Upon expiration of the ABL Forbearance Agreement or if we were to default under the ABL Forbearance Agreement or the 2013 ABL Credit Facility, other than ABL Specified Defaults, the ABL Lenders would be free to exercise any rights and remedies with respect to such defaults and events of defaults pursuant to the terms of the 2013 ABL Credit Facility.

Seventh Amendment to the 2014 Term Credit Agreement

On March 27, 2018, we amended the 2014 Term Credit Agreement pursuant to a Seventh Amendment among Willbros Group, Inc., as borrower, the guarantors from time to time party thereto, Primoris as initial first-out lender, the lenders from time to time party thereto and Cortland Capital Market Services LLC, as administrative agent (the “Seventh Amendment”). Under the terms of the Seventh Amendment, Primoris provided us with an additional term loan in an amount equal to $10.0 million (the “Initial First-Out Loan”) that was drawn in full on March 30, 2018 and bears the same maturity date as the aggregate outstanding principal balance of our 2014 Term Loan Facility.

In addition, under the terms of the Seventh Amendment, Primoris may provide us with additional term loans in an aggregate amount not to exceed $10.0 million (the “Additional First-Out Loans”). Interest payable with respect to the Initial First-Out Loan and any Additional First-Out Loans will be paid in-kind through additions to the principal amount of such loans.

Going Concern

In 2017, we incurred significant operating losses, cash outflows from operating activities and a net working capital deficiency. These significant operating losses continued to generate negative cash outflows in the first quarter of 2018. We are not in compliance with the Maximum Total Leverage Ratio and Minimum Interest Coverage Ratio for the quarterly period ended March 31, 2018 and do not expect to be in compliance with the Maximum Total Leverage Ratio and Minimum Interest Coverage Ratio under the 2014 Term Credit Agreement for the next twelve months, primarily due to these significant operating losses. In addition, we are currently not in compliance with certain other provisions under the 2014 Term Credit Agreement and the 2013 ABL Credit Facility, which expires on August 7, 2018. Absent the temporary forbearance provided under the Term Forbearance Agreement and the ABL Forbearance Agreement, all of our debt obligations would become due under the default provisions in the 2014 Term Credit Agreement and the 2013 ABL Credit Facility. In addition, these significant operating losses and cash outflows have put a considerable strain on our overall liquidity. Although the Seventh Amendment provides us with

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additional short-term liquidity for the period between the signing of the Merger Agreement and the completion of the merger, we can provide no assurance that the merger will be completed. If we are unable to complete the merger, we will likely need to explore other strategic alternatives, which could include seeking protection under the U.S. Bankruptcy laws.

Our continuing failure to comply with financial covenants and other covenants, our inability to extend or refinance the 2013 ABL Credit Facility and our continuing liquidity issues raise substantial doubt about our ability to continue as a going concern, notwithstanding the temporary forbearance provided under the Term Forbearance Agreement and the ABL Forbearance Agreement and the short-term liquidity provided by the Seventh Amendment.

In consideration of the above facts and circumstances, at March 31, 2018, we have classified all of our debt obligations as current, which has caused our current liabilities to far exceed our current assets since such date. These debt obligations, net of unamortized discount and debt issuance costs, approximate $139.9 million at March 31, 2018.

Sale of Mainline Pipeline Construction Business

On January 9, 2018, we entered into an Asset Purchase Agreement to sell assets comprising our mainline pipeline construction business to Meridien. The Asset Purchase Agreement, among other things, states that funding will occur in various stages in 2018 and in conjunction with the completed valuation of the assets and final approval by Meridien.

In connection with the Asset Purchase Agreement, we recorded a gain on sale of $4.4 million, which is included in the line item “Gain on sale of assets” in our Condensed Consolidated Statement of Operations for the three months ended March 31, 2018. The remaining assets associated with the Asset Purchase Agreement are classified as “Assets held for sale” in our Condensed Consolidated Balance Sheet at March 31, 2018. See Note 5 – Assets Held for Sale included in Item 1 of Part I of this Form 10-Q for more information.

In addition, as part of the Asset Purchase Agreement, we retained the three mainline pipeline construction projects associated with our mainline pipeline construction business through completion. Two of these projects have reached mechanical completion with an existing letter of credit returned in the first quarter of 2018. The remaining right-of-way restoration and other clean-up activities associated with these projects are expected to be completed by the end of the third quarter of 2018.

With respect to the remaining mainline pipeline construction project, in the first quarter of 2018, we reached an agreement with the customer to mutually conclude the remaining work. In addition, the agreement releases us from further liability at the completion of the project. As such, we have withdrawn and released any outstanding change orders or claims associated with the project.

Other Financial Measures

Adjusted EBITDA from Continuing Operations

We define Adjusted EBITDA from continuing operations as income (loss) from continuing operations before interest expense (income), income tax expense (benefit) and depreciation and amortization, adjusted for items which management does not consider representative of our ongoing operations and certain non-cash items of the Company. These adjustments are itemized in the following table. You are encouraged to evaluate these adjustments and the reasons we consider them appropriate for supplemental analysis. In evaluating Adjusted EBITDA from continuing operations, you should be aware that in the future we may incur expenses that are the same as, or similar to, some of the adjustments in this presentation. Our presentation of Adjusted EBITDA from continuing operations should not be construed as an inference that our future results will be unaffected by unusual or non-recurring items.

Management uses Adjusted EBITDA from continuing operations as a supplemental performance measure for:


•	Comparing normalized operating results with corresponding historical periods and with the operational performance of other companies in our industry; and


•	Presentations made to analysts, investment banks and other members of the financial community who use this information in order to make investment decisions about us.

Adjusted EBITDA from continuing operations is not a financial measurement recognized under U.S. generally accepted accounting principles, or U.S. GAAP. When analyzing our operating performance, investors should use Adjusted EBITDA from continuing operations in addition to, and not as an alternative for, net income, operating income, or any other performance measure derived in accordance with U.S. GAAP, or as an alternative to cash flow from operating activities as a measure of our liquidity. Because not all companies use identical calculations, our presentation of Adjusted EBITDA from continuing operations may be different from similarly titled measures of other companies.

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A reconciliation of Adjusted EBITDA from continuing operations to U.S. GAAP financial information follows (in thousands):

	Nine Months Ended
	Three Months Ended
	September 30, 2017			September 30, 2016
	March 31, 2018			March 31, 2017
Loss from continuing operations	$	(5116,~~566~~735	)	$	(2917,~~720~~736	)
Interest expense	106,~~972~~528			103,~~433~~488
Interest income	(238		)	(~~443~~8		)
Provision (benefit) for income taxes	(1,665		)	1,146
Benefit for income taxes	(221		)	(600		)
Depreciation and amortization	144,~~600~~315			165,~~694~~037
EBITDA from continuing operations	(276,~~682~~121		)	(19,~~890~~819		)
Debt covenant suspension and extinguishment charges	—			63
Stock based compensation	524			906
Stock based compensation	2,121			3,269
Legal and consulting costs (1)	7,384			274
Restructuring and reorganization costs	535			4,587
Restructuring related costs	946			323
Legal fees associated with the restatements	617			(42		)
Gain on sale of assets	(6,080		)	(696		)
Fort McMurray wildfire related costs	—			523
Adjusted EBITDA from continuing operations	$	(3,347	)	$	(9,012	)
Gain on disposal of property and equipment	(2,545		)	(2,851		)
Adjusted EBITDA from continuing operations	$	(26,954	)	$	3,659

32(1) 2018 costs are primarily associated with the Company’s evaluation of various strategic alternatives, which culminated with the signing of the Merger Agreement with Primoris. 2017 costs are associated with the restatements of the Company’s Condensed Consolidated Financial Statements for the quarterly periods ended March 31, 2014 and June 30, 2014.

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Backlog

Backlog broadly consists of anticipated revenue from the uncompleted portions of existing contracts and contracts whose award is reasonably assured, subject only to the cancellation and modification provisions contained in various contracts. Additionally, due to the short duration of many jobs, revenue associated with jobs won and performed within a reporting period will not be reflected in quarterly backlog reports. We generate revenue from numerous sources, including contracts of long or short duration entered into during a year as well as from various contractual processes, including change orders, extra work and variations in the scope of work. These revenue sources are not added to backlog until realization is assured.

Our backlog presentation reflects not only the 12-month lump sum and work under a Master Service Agreement (“MSA”) but also the full-term value of work under contract, including MSA work, as we believe that this information is helpful in providing additional long-term visibility. We determine the amount of backlog for work under ongoing MSA maintenance and construction contracts by using recurring historical trends inherent in the MSAs, factoring in seasonal demand and projecting customer needs based upon ongoing communications with the customer.

At ~~September~~March 3031, ~~2017~~2018, 12-month backlog was $~~543~~425.93 million, which is ana ~~increase~~decrease of $~~124~~51.09 million compared to December 31, ~~2016 with an increase in both discrete projects and MSA work~~2017. The overall ~~increase~~decrease is ~~primarily~~ related to ~~discrete~~the ~~project~~work-off ~~additions~~of existing discrete contracts in our Oil & Gas segment, partially offset by ~~the~~increases ~~work-off of existing discrete projects~~ in our Utility T&D ~~segment~~and Canada segments.

At ~~September~~March 3031, ~~2017~~2018, total backlog was $~~741~~635.34 million, which is aan ~~decrease~~increase of $5119.20 million compared to December 31, ~~2016~~2017. The ~~decrease~~increase is primarily related to the ~~work-off~~March ~~of existing MSAs and discrete projects~~5, ~~specifically~~2018 inextension of our ~~Utility~~agreement ~~T&D~~with ~~segment.~~Oncor ~~MSAs~~for ~~are~~one ~~subject~~year, towhich ~~renewal~~significantly ~~options~~increased intotal ~~future years and we include~~ MSA ~~work in~~ backlog ~~that~~associated ~~extends~~with ~~only~~our ~~through~~Utility ~~the~~T&D ~~life of the contract~~segment. ~~We intend to pursue the renewal of these MSAs upon expiration.~~ The ~~decrease~~overall increase in total backlog iswas partially offset ~~with~~by ~~discrete~~the ~~project~~work-off ~~additions~~of existing discrete contracts in our Oil & Gas segment ~~and discrete project and MSA additions in our Canada segment~~.

Approximately $479.1 million and $520.47 million of 12-month and total backlog at ~~September 30~~March 31, ~~2017~~2018 and December 31, ~~2016~~2017, respectively, is attributed to our ~~U.S.~~ mainline pipeline construction business. ~~Our~~in Uour Oil & Gas segment.S. ~~mainline~~On ~~pipeline~~January ~~construction~~9, ~~business~~2018, iswe ~~included~~entered ininto an agreement to sell assets comprising our ~~Oil~~mainline &pipeline ~~Gas~~construction ~~segment~~business to Meridien. See ~~Note~~the 1discussion -under ~~Company~~the ~~and~~caption ~~Organization~~“Sale of Mainline Pipeline Construction Business” for more information.

Approximately $~~21.~~1.3 million and $1518.23 million of 12-month and total backlog at ~~September~~March 3031, ~~2017~~2018 and December 31, ~~2016~~2017, respectively, is attributed to our tank services business, ~~which~~in isour ~~classified~~Oil as& ~~held~~Gas ~~for~~segment. ~~sale~~On atJanuary ~~September 30~~2, ~~2017.~~2018, ~~Our~~we sold our tank services business isto ~~included in our Oil & Gas segment~~ATS. See Note 5 -– Assets Held for Sale for more information.

The following tables ~~(in thousands)~~ show our 12-month and total backlog (in thousands) by operating segment and type of contract as of ~~September~~March 3031, ~~2017~~2018 and December 31, ~~2016~~2017:

	12-Month Backlog
	September 30, 2017						December 31, 2016
	March 31, 2018						December 31, 2017
	MSA		Discrete Contract		12-Month		MSA		Discrete Contract		12-Month
Oil & Gas	$	—	$	159,213	$	159,213	$	—	$	28,827	$	28,827
Utility T&D	$	294,073	$	27,058	$	321,131	$	285,759	$	21,363	$	307,122
Utility T&D	309,923		19,608		329,531		312,681		37,317		349,998
Canada	46,629		8,452		55,081		45,759		5,955		51,714
Canada	43,157		11,970		55,127		33,430		7,611		41,041
Oil & Gas	—		49,042		49,042		—		118,278		118,278
12-Month Backlog	$	~~353~~340,~~080~~702	$	~~190~~84,~~791~~552	$	~~543~~425,~~871~~254	$	~~346~~331,~~111~~518	$	73145,~~755~~596	$	~~419~~477,~~866~~114

	Total Backlog
	September 30, 2017						December 31, 2016
	March 31, 2018						December 31, 2017
	MSA		Discrete Contract		Total		MSA		Discrete Contract		Total
Oil & Gas	$	—	$	159,213	$	159,213	$	—	$	28,827	$	28,827
Utility T&D	$	460,791	$	28,560	$	489,351	$	350,107	$	37,177	$	387,284
Utility T&D	426,761		32,656		459,417		607,061		49,777		656,838
Canada	88,518		8,452		96,970		104,815		5,955		110,770
Canada	110,398		12,246		122,644		99,182		7,611		106,793
Oil & Gas	—		49,042		49,042		—		118,278		118,278
Total Backlog	$	~~537~~549,~~159~~309	$	~~204~~86,~~115~~054	$	~~741~~635,~~274~~363	$	~~706~~454,~~243~~922	$	86161,~~215~~410	$	~~792~~616,~~458~~332

At March 31, 2018, we had remaining performance obligations (“RPOs”) of $340.7 million, which included $254.6 million of work under MSAs where we have obtained a signed purchase order or minimum work commitment and $86.1 million in discrete projects under contract.

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We have excluded from our RPOs approximately $294.7 million of additional estimated work under MSAs. This amount, which is included in our total backlog at March 31, 2018, is estimated based on recurring historical trends inherent in the MSAs and does not have a signed purchase order or minimum work commitment. For additional information regarding the Company’s backlog, see Note 4 – Revenue included in Item 1 of Part I of this Form 10-Q.

CRITICAL ACCOUNTING POLICIES AND ESTIMATES

In our Annual Report on Form 10-K for the year ended December 31, ~~2016~~2017, we identified and disclosed our significant accounting policies. Subsequent to December 31, ~~2016~~2017, there has been no change to our significant accounting policies.

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RESULTS OF OPERATIONS

Three Months Ended ~~September~~March 3031, ~~2017~~2018 Compared to Three Months Ended ~~September~~March 3031, ~~2016~~2017

(in thousands)

	2017			2016			Change
	2018			2017			Change
Contract revenue
Oil & Gas	$	75,284		$	33,100		$	42,184
Utility T&D	$	112,612		$	115,508		$	(2,896	)
Utility T&D	129,906			106,422			23,484
Canada	25,803			25,960			(157		)
Canada	35,583			35,355			228
Oil & Gas	62,639			22,432			40,207
Eliminations	—(74		)	~~(56~~—		)	56(74		)
Total	~~240~~200,~~773~~980			~~174~~163,~~821~~900			6537,~~952~~080
Contract costs	~~252~~193,~~961~~294			162,~~806~~219			9031,~~155~~075
Contract income (loss)	(12,188		)	12,015			(24,203		)
Contract income	7,686			1,681			6,005
Amortization of intangibles	2,~~416~~399			2,~~438~~417			(2218		)
General and administrative	13,~~036~~475			1514,~~377~~051			(~~2,341~~576		)
Other charges	149			519			(370		)
Gain on sale of assets	(6,080		)	(696		)	(5,384		)
Other charges	8,365			762			7,603
Operating income (loss)
Oil & Gas	(14,766		)	(4,383		)	(10,383		)
Utility T&D	1,908			784			1,124
Utility T&D	(7,475		)	4,262			(11,737		)
Canada	(850		)	(3,340		)	2,490
Canada	(296		)	(341		)	45
Oil & Gas	1,003			(7,336		)	8,339
Corporate	(512,~~252~~534		)	(54,~~857~~961		)	~~605~~(7,573		)
Total	(2710,~~789~~473		)	(614,~~319~~853		)	~~(21~~4,~~470~~380		)
Non-operating expenses	(36,~~788~~483		)	(3,~~550~~483		)	(~~238~~3,000		)
Loss from continuing operations before income taxes	(3116,~~577~~956		)	(918,~~869~~336		)	~~(21~~1,~~708~~380		)
Provision for income taxes	1,132			792			340
Benefit for income taxes	(221		)	(600		)	379
Loss from continuing operations	(3216,~~709~~735		)	(1017,~~661~~736		)	~~(22~~1,~~048~~001		)
Loss from discontinued operations net of provision for income taxes	(~~1,496~~230		)	(~~1,325~~31		)	(~~171~~199		)
Net loss	$	(3416,~~205~~965	)	$	(1117,~~986~~767	)	$	~~(22,219~~802	)

Consolidated Results

Contract Revenue

Contract revenue increased $6637.01 million in the ~~third~~first quarter of ~~2017~~2018 primarily driven by ansignificant ~~increased~~growth ~~volume of work~~ in ~~our~~large ~~Oil~~discrete &projects ~~Gas~~in ~~segment mainly within~~ our ~~mainline pipeline and~~ facilities construction ~~service~~services ~~offerings~~in ~~and~~ our ~~small-diameter~~Oil ~~pipeline~~& ~~construction~~Gas ~~service~~segment ~~offerings~~ in ~~the~~comparison ~~Northeast. The increase in contract revenue is also partly related~~ to ~~growth~~the infirst ~~discrete~~quarter ~~projects~~of ~~in our Utility T&D segment and incremental storm restoration work between periods~~2017. The overall increase in contract revenue iswas partially offset by a ~~reduction~~small ofdecrease ~~revenue~~in ~~related~~contract torevenue in our ~~alliance~~Utility ~~agreement~~T&D ~~with~~segment aprimarily ~~major~~driven ~~customer.~~by ~~Under the terms of the alliance agreement, the customer is entitled to~~ a ~~retroactive~~ reduction of price when certain levels of revenue are exceeded. We have consistently recorded revenue related to the alliance agreement based on the customer's estimate of annual volume. During the third quarter of 2017, we were advised of a substantial and unanticipated increase in ~~projected~~storm ~~activity~~restoration ~~related~~work ~~to the alliance agreement for the balance of 2017 that triggered an additional discount of revenue. The cumulative effect of this change~~ in ~~estimate for 2017 reduced revenue $5.5 million in~~ the ~~third~~first quarter of ~~2017 compared to the third quarter of 2016~~2018.

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Contract Income (Loss)

Contract income decreased $24.2 million in the third quarter of 2017 to a loss of $12.2 million as contract margin was negative 5.1 percent compared to 6.9 percent in the third quarter of 2016. The decrease in contract income and related margin is primarily driven by significant losses on two mainline pipeline construction projects and a small-diameter pipeline construction project in our Oil & Gas segment mainly attributed to adverse weather conditions and lower than planned productivity through difficulties in execution. These three projects, which are all in the same geographic region and have similar risk profiles, incurred $13.0 million in losses in the third quarter of 2017. These three projects are expected to be completed in the fourth quarter of 2017. The decrease in contract income and related margin is also partly related to the increased volume discount of $5.5 million associated with our alliance agreement with a major customer discussed above as well as losses on two discrete projects in our Utility T&D segment mainly attributed to the negative execution impact of the late delivery of vendor supplied material coupled with lower than planned productivity. These two projects recorded $3.6 million in losses in the third quarter of 2017.

Amortization of Intangibles

We recorded $2.4 million of intangible amortization expense in the third quarter of 2017 primarily related to the amortization of customer relationship and trademark intangibles associated with our Utility T&D segment. The small decrease from the third quarter of 2016 is related to the lack of intangible amortization associated with our tank services business in our Oil & Gas segment, which is held for sale at September 30, 2017.

General and Administrative Expenses

General and administrative expenses decreased $2.3 million in the third quarter of 2017. The decrease is primarily driven by 2016 cost reduction initiatives in our corporate headquarters, as well as headcount reductions in our Oil & Gas and Canada segments. The decrease in general and administrative expenses is also partly related to increased gains on the sale of equipment, primarily in our Oil & Gas and Utility T&D segments, between periods.

Other Charges

We recorded other charges of $0.1 million in the third quarter of 2017 primarily related to employee severance and termination costs and legal fees associated with the restatement of our Condensed Consolidated Financial Statements for the quarterly periods ended March 31, 2014 and June 30, 2014. These charges are partially offset with changes in facility lease abandonment estimates in the current quarter. The $0.4 million decrease in other charges in comparison to the third quarter of 2016 is primarily driven by a reduction in facility lease abandonment estimates between periods.

Operating Loss

Operating loss increased $21.5 million in the third quarter of 2017 primarily driven by the decrease in contract income and related margin discussed above. The increased operating loss is partially offset by a decrease in general and administrative expenses and other charges, as well as increased gains on the sale of equipment, between periods.

Non-Operating Expenses

Non-operating expenses increased $0.2 million in the third quarter of 2017 primarily attributed to an increase in the amortization of debt issuance costs, which is inclusive of Term Loan amendment fees, between periods. We expect non-operating expenses, specifically interest expense, to increase in future periods in conjunction with the Sixth Amendment to the 2014 Term Credit Agreement.

Provision for Income Taxes

Provision for income taxes increased $0.3 million in the third quarter of 2017 primarily driven by a reduction of a 2017 income tax benefit related to our Canada segment partially offset with changes in discrete items between periods.

Loss from Discontinued Operations, Net of Taxes

Loss from discontinued operations increased $0.2 million in the third quarter of 2017 primarily driven by changes in facility lease abandonment estimates between periods. The increased loss is partially offset by a reduction of indirect costs and general and administrative expenses between periods.

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Segment Results

Oil & Gas Segment

Contract revenue increased $42.2 million in the third quarter of 2017 primarily driven by an increased volume of work in our mainline pipeline and facilities construction service offerings and our small-diameter pipeline construction service offerings in the Northeast. The increase in contract revenue is also partly related to an increased volume of work in our tank services business, which is held for sale at September 30, 2017.

Operating loss increased $10.4 million in the third quarter of 2017 primarily driven by significant losses on two mainline pipeline construction projects and a small-diameter pipeline construction project mainly attributed to adverse weather conditions and lower than planned productivity through difficulties in execution. These three projects, which are all in the same geographic region and have similar risk profiles, incurred $13.0 million in losses in the third quarter of 2017. These three projects are expected to be completed in the fourth quarter of 2017. The increased operating loss is partially offset by increased gains on the sale of equipment, improved equipment utilization across the segment and improved performance in our tank services business, which is held for sale at September 30, 2017.

Utility T&D Segment

Contract revenue increased $23.5 million in the third quarter of 2017 primarily driven by growth in discrete projects within a number of service offerings and incremental storm restoration work between periods. The increase in contract revenue is partially offset by a reduction of revenue related to our alliance agreement with a major customer. Under the terms of the alliance agreement, the customer is entitled to a retroactive reduction of price when certain levels of revenue are exceeded. We have consistently recorded revenue related to the alliance agreement based on the customer's estimate of annual volume. During the third quarter of 2017, we were advised of a substantial and unanticipated increase in projected activity related to the alliance agreement for the balance of 2017 that triggered an additional discount of revenue. The cumulative effect of this change in estimate for 2017 reduced revenue $5.5 million in comparison to the third quarter of 2016.

Operating income decreased $11.7 million to a loss of $7.5 million in the third quarter of 2017 primarily driven by the increased volume discount of $5.5 million associated with our alliance agreement with a major customer discussed above as well as losses on two discrete projects mainly attributed to the negative execution impact of the late delivery of vendor supplied material coupled with lower than planned productivity. These two projects recorded $3.6 million in operating losses in the third quarter of 2017. The decrease in operating income is also partly related to lower insurance and other employee-related indirect costs in the third quarter of 2016. The decrease in operating income was partially offset by incremental storm restoration work discussed above, as well as increased gains on the sale of equipment between periods.

Canada Segment

Contract revenue increased $0.2 million in the third quarter of 2017 primarily driven by an increase in capital projects within our construction and maintenance service offerings between periods. The increase in contract revenue is partially offset by a lower volume of work in our industrial and construction service offerings mainly attributed to the completion of a larger tank project in the third quarter of 2016 that did not recur in the third quarter of 2017.

Operating loss decreased slightly in the third quarter of 2017 primarily driven by a loss on a cross-country pipeline project in the third quarter of 2016 that did not recur in the third quarter of 2017, coupled with a reduction in employee severance and termination costs. The slight decrease was partially offset by the lower volume of work in our industrial construction services described above, as well as changes in the mix of work in our construction maintenance service offerings, where capital projects tend to yield lower margins.

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Nine Months Ended September 30, 2017 Compared to Nine Months Ended September 30, 2016

(in thousands)

	2017			2016			Change
Contract revenue
Oil & Gas	$	146,748		$	147,174		$	(426	)
Utility T&D	397,097			313,066			84,031
Canada	88,275			107,343			(19,068		)
Eliminations	—			(290		)	290
Total	632,120			567,293			64,827
Contract costs	625,548			526,322			99,226
Contract income	6,572			40,971			(34,399		)
Amortization of intangibles	7,250			7,315			(65		)
General and administrative	40,260			47,031			(6,771		)
Other charges	1,346			5,146			(3,800		)
Operating income (loss)
Oil & Gas	(25,536		)	(11,019		)	(14,517		)
Utility T&D	4,293			13,482			(9,189		)
Canada	(5,350		)	1,114			(6,464		)
Corporate	(15,691		)	(22,098		)	6,407
Total	(42,284		)	(18,521		)	(23,763		)
Non-operating expenses	(10,947		)	(10,053		)	(894		)
Loss from continuing operations before income taxes	(53,231		)	(28,574		)	(24,657		)
Provision (benefit) for income taxes	(1,665		)	1,146			(2,811		)
Loss from continuing operations	(51,566		)	(29,720		)	(21,846		)
Loss from discontinued operations net of provision for income taxes	(1,508		)	(3,836		)	2,328
Net loss	$	(53,074	)	$	(33,556	)	$	(19,518	)

Consolidated Results

Contract Revenue

Contract revenue increased $64.8 million in the first nine months of 2017 primarily driven by growth in discrete projects within our Utility T&D segment as well as incremental storm restoration work between periods. The increase in contract revenue is partially offset by a reduction of revenue related to our alliance agreement with a major customer. Under the terms of the alliance agreement, the customer is entitled to a retroactive reduction of price when certain levels of revenue are exceeded. We have consistently recorded revenue related to the alliance agreement based on the customer's estimate of annual volume. During the third quarter of 2017, we were advised of a substantial and unanticipated increase in projected activity related to the alliance agreement for the balance of 2017 that triggered an additional discount of revenue. The cumulative effect of this change in estimate for 2017 reduced revenue $7.4 million in the first nine months of 2017 compared to the first nine months of 2016.

Contract Income

Contract income ~~decreased~~increased $346.40 million in the first ~~nine~~quarter ~~months~~ of ~~2017~~2018 as contract margin was 13.08 percent compared to 71.20 percent in the first ~~nine~~quarter ~~months~~ of ~~2016~~2017. The ~~decrease~~increase in contract income and related margin is primarily driven by ~~significant~~a reduction of losses onassociated ~~two~~with our mainline pipeline ~~construction projects~~ and aintegrity ~~small-diameter pipeline~~ construction ~~project~~services in ~~our~~the Oil & Gas segment ~~mainly attributed to adverse weather conditions and lower than planned productivity through difficulties in execution~~. ~~These~~The ~~three~~overall ~~projects,~~increase ~~which are all~~ in the same geographic region and have similar risk profiles, incurred $12.7 million in losses in the first nine months of 2017. These three projects are expected to be completed in the fourth quarter of 2017. The decrease in contract income and related margin is also partly ~~related~~attributed to ~~the~~ increased ~~volume~~margins ~~discount~~in ~~of $7.4 million associated with~~ our ~~alliance~~fabrication ~~agreement~~services ~~with~~and amaintenance ~~major~~projects ~~customer~~in ~~discussed~~our ~~above~~Canada segment, ~~coupled~~improved ~~with reduced~~ productivity ~~associated~~in ~~with~~our ~~the~~electric ~~lower~~transmission ~~volume~~construction ofservices ~~work~~in Texas in our ~~Canada~~Utility T&D segment ~~discussed above~~ and ~~lower~~improved ~~insurance~~utilization ~~and other employee-related indirect costs in the first nine months~~ of ~~2016~~equipment in both our Utility T&D ~~segment.~~and Oil & Gas segments.

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Amortization of Intangibles

We recorded $72.34 million of intangible amortization expense in the first ~~nine~~quarter ~~months~~ of ~~2017~~2018 primarily related to the amortization of customer relationship and trademark intangibles associated with our Utility T&D segment. The small decrease from the first ~~nine~~quarter ~~months~~ of ~~2016~~2017 is related to the lack of intangible amortization associated with our ~~tank~~mainline ~~services~~pipeline business in our Oil & Gas segment. On January 9, ~~which~~2018, iswe ~~held~~signed ~~for~~an ~~sale~~agreement atto ~~September 30,~~sell ~~2017~~assets comprising our mainline construction business to Meridien and therefore disposed of the related intangible asset.

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General and Administrative Expenses

General and administrative expenses decreased $60.86 million in the first ~~nine~~quarter ~~months~~ of ~~2017~~2018. The decrease ~~was~~is primarily ~~due~~driven toby ~~2016~~headcount ~~cost~~reductions ~~reduction initiatives~~ in our ~~corporate~~Oil ~~headquarters,~~& asGas ~~well~~segment. asThese headcount reductions inwere ~~our~~mainly ~~Oil~~within &the ~~Gas~~segment’s ~~and~~tank ~~Canada~~services ~~segments.~~business, ~~The~~which ~~decrease~~was sold in ~~general~~the ~~and~~first ~~administrative~~quarter ~~expenses~~of is2018 ~~partially~~and ~~offset~~the bymainline apipeline ~~reduction~~construction ofbusiness, ~~gains~~which onis in the ~~sale~~process of ~~equipment~~completing ~~between~~its ~~periods,~~remaining ~~primarily in our Canada segment~~projects.

Gain on Sale of Assets

We recorded $6.1 million of gains on the sale of assets in the first quarter of 2018, which is an increase of $5.4 million in comparison to the first quarter of 2017. The increase is primarily driven by a $4.4 million gain on sale of assets comprising our mainline pipeline construction business as well as a $1.0 million gain on the sale of assets comprising our tank services business.

Other Charges

We recorded other charges of $18.34 million in the first ~~nine~~quarter ~~months~~ of ~~2017~~2018 primarily related to ~~employee severance and termination~~ costs ~~and legal fees~~ associated with ~~the~~our ~~restatement~~evaluation of ~~our~~various ~~Condensed~~strategic ~~Consolidated~~alternatives, ~~Financial~~which ~~Statements~~culminated ~~for~~with the ~~quarterly~~signing ~~periods~~of ~~ended~~the ~~March~~Merger ~~31,~~Agreement ~~2014~~with ~~and~~Primoris. ~~June~~The ~~30, 2014~~$7.6 ~~The~~million ~~decrease~~increase in other charges ~~of $3.8 million~~ in ~~comparison to~~ the first ~~nine~~quarter ~~months~~ of ~~2016~~2018 is primarily ~~related~~driven toby ~~equipment~~an ~~and~~increase ~~facility lease abandonment charges~~ in ~~the~~these ~~first~~types ~~nine months~~ of ~~2016~~costs ~~that~~in ~~did~~comparison ~~not~~to ~~recur in~~ the first ~~nine~~quarter ~~months~~ of 2017.

Operating Loss

Operating loss ~~increased~~decreased $234.84 million in the first ~~nine~~quarter ~~months~~ of ~~2017~~2018 primarily driven by the ~~decrease~~gains on the sale of assets associated with our mainline pipeline construction business and our tank services business as well as an increase in contract income and related margin discussed above. The ~~increased~~decreased operating loss is partially offset by aan ~~decrease~~increase in ~~general~~other ~~and~~charges ~~administrative~~mainly ~~expenses~~due ~~and~~to ~~other~~increased ~~charges~~costs in the first quarter of 2018 associated with our evaluation of various strategic alternatives, ~~including~~which ~~equipment~~culminated ~~and~~with ~~facility~~the ~~lease~~signing ~~abandonment~~of ~~charges~~the ~~between~~Merger ~~periods~~Agreement with Primoris.

Non-Operating Expenses

Non-operating expenses increased $03.90 million in the first ~~nine~~quarter ~~months~~ of ~~2017~~2018 primarily ~~attributed~~driven toby an increase in ~~the~~interest ~~amortization~~expense ofassociated ~~debt~~with ~~issuance~~the ~~costs,~~2014 ~~which is inclusive of~~ Term Loan ~~amendment~~Facility ~~fees,~~related ~~between~~to ~~periods.~~an ~~The~~increased ~~increase~~interest rate in ~~non-operating~~conjunction ~~expenses~~with isthe ~~also~~Sixth ~~partly~~Amendment ~~attributed~~ to the ~~favorable~~2014 ~~settlement~~Term ofCredit aAgreement ~~contract~~as ~~dispute~~well ~~with~~as aan ~~customer~~increase in ~~the~~interest ~~first~~expense ~~nine~~attributed ~~months~~to ofhigher ~~2016~~indebtedness ~~that~~under ~~did~~the ~~not~~2013 ~~recur~~ABL Credit Facility in comparison to the first ~~nine~~quarter ~~months~~ of 2017. The increase in non-operating expenses is ~~partially~~also ~~offset~~partly ~~with~~attributed ato ~~reduction~~increases in ~~interest~~the ~~expense~~amortization of debt issuance costs and the amortization of the repayment fee, both associated with ~~our~~the 2014 Term Loan ~~between periods~~Facility. WeThe ~~expect~~increase in non-operating expenses, ~~specifically~~is ~~interest~~also ~~expense,~~partly attributed to ~~increase~~the inunfavorable ~~future~~settlement ~~periods~~of ina ~~conjunction~~contract dispute with ~~the~~a ~~Sixth~~customer, ~~Amendment~~which toresulted in additional interest expense in the ~~2014~~first ~~Term~~quarter ~~Credit~~of ~~Agreement~~2018.

~~Provision (~~Benefit) for Income Taxes

~~Provision~~Benefit for income taxes decreased $20.84 million ~~to a benefit of $1.7 million~~ in the first ~~nine~~quarter ~~months~~ of ~~2017.~~2018 ~~The decrease in the provision is~~ primarily ~~attributed~~driven toby a ~~change~~first ~~from~~quarter aof ~~2016~~2017 ~~income~~refundable ~~tax~~alternative ~~provision~~minimum ~~to a 2017 income~~ tax ~~benefit~~credit ~~related~~carry-forward tothat ~~our~~did ~~Canada~~not ~~segment~~recur asin ~~well~~the asfirst aquarter ~~refund~~of ~~resulting from a Texas Margins Tax audit~~2018.

Loss from Discontinued Operations, Net of Taxes

Loss from discontinued operations ~~decreased~~increased $20.32 million in the first ~~nine~~quarter ~~months~~ of ~~2017~~2018 primarily ~~due~~driven toby ~~working capital adjustments in~~ the first ~~nine~~quarter ~~months~~ of ~~2016~~2018 ~~in connection with the sale of our Professional Service segment, that did not recur in the first nine months of 2017. Working capital and all other post~~close-~~closing~~out ~~adjustments associated with this sale were finalized during the year ended December 31, 2016. The decreased loss is also partly attributed to a reduction~~ of ~~insurance~~certain ~~liabilities~~projects ~~in the first nine months of 2017~~ associated with previously disposed businesses. ~~The decreased loss is partially offset by changes in facility abandonment estimates that generated income in the first nine months of 2016 compared to losses in the first nine months of 2017.~~

Segment Results

Oil & Gas Segment

Contract revenue decreased slightly in the first nine months of 2017 primarily driven by a lower volume of work in our facilities and integrity construction service offerings between periods. The slight decrease is partially offset with an increased volume of work in our tank services business and our small-diameter pipeline construction service offerings in the Northeast. Our tank services business is held for sale at September 30, 2017.

Operating loss increased $14.5 million in the first nine months of 2017 primarily driven by significant losses on two mainline pipeline construction projects and a small-diameter pipeline construction project mainly attributed to adverse weather conditions and lower than planned productivity through difficulties in execution. These three projects, which are all in the same

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geographic region and have similar risk profiles, incurred $12.7 million in losses in the first nine months of 2017. These three projects are expected to be completed in the fourth quarter of 2017. The increased operating loss is also partly due to the lower volume of work in our facilities and integrity construction service offerings discussed above. The increased operating loss is partially offset by improved equipment utilization across the segment and improved performance in our tank services business, which is held for sale at September 30, 2017. In addition, the increased operating loss is partially offset by charges related to the abandonment of certain equipment leases in the first nine months of 2016 that did not recur in the first nine months of 2017 and a decrease in general and administrative expenses primarily related to headcount reductions.

Utility T&D Segment

Contract revenue ~~increased~~decreased $842.09 million in the first ~~nine~~quarter ~~months~~ of ~~2017~~2018 primarily driven by ~~growth in discrete projects within~~ a ~~number~~reduction of ~~service offerings, as well as incremental~~ storm restoration work ~~between~~associated ~~periods.~~with ~~The~~our ~~increase~~electric intransmission ~~contract~~construction ~~revenue~~services isin ~~partially~~Texas ~~offset~~and by a ~~reduction~~decreased volume of ~~revenue~~work ~~related~~in to our ~~alliance~~distribution ~~agreement~~services ~~with~~in ~~a major customer. Under~~ the ~~terms~~East ofCoast ~~the~~in ~~alliance~~comparison ~~agreement, the customer is entitled~~ to ~~a retroactive reduction of price when certain levels of revenue are exceeded. We have consistently recorded revenue related to~~ the ~~alliance~~first ~~agreement based on the customer's estimate of annual volume. During the third~~ quarter of 2017,. weThe ~~were~~overall ~~advised~~decrease ~~of a substantial and unanticipated increase~~ in ~~projected~~contract ~~activity related to the alliance agreement for the balance of 2017 that triggered an additional discount of~~ revenue. ~~The~~is ~~cumulative~~partially ~~effect~~offset ofby ~~this~~growth ~~change~~ in ~~estimate~~our ~~for~~distribution ~~2017~~services ~~reduced revenue $7.4 million~~ in the ~~first~~Southeast ~~nine~~in ~~months of 2017 compared to~~ the first ~~nine~~quarter ~~months~~ of ~~2016~~2018.

Operating income ~~decreased~~increased $91.21 million in the first ~~nine~~quarter ~~months~~ of ~~2017~~2018 primarily driven by improved margins in our electric transmission construction services in comparison to the ~~increased~~first ~~volume~~quarter ~~discount~~of 2017. These improvements were mainly due to an overall improvement in productivity of $7services performed and an increase in the utilization of equipment.4 ~~million~~The ~~associated~~overall ~~with~~increase in operating income is also partly attributed to margin improvement in our ~~alliance~~distribution ~~agreement~~services ~~with~~in athe ~~major~~Southeast ~~customer~~mainly due to revenue growth previously discussed. ~~above~~The ~~coupled~~overall ~~with~~increase ~~lower~~in ~~insurance~~operating ~~and~~income ~~other~~is ~~employee-related~~also ~~indirect~~partly ~~costs~~attributed to increased gains on the sale of assets in the first ~~nine~~quarter ~~months~~ of ~~2016~~2018. The ~~decrease~~overall increase in operating income is partially offset bywith ~~increased~~margin ~~storm~~deterioration ~~restoration~~in ~~work~~our distribution services in the East Coast mainly due to a reduction in volume previously discussed, ~~above~~as well as a change in the mix of work in comparison to the first quarter of 2017.

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Canada Segment

Contract revenue ~~decreased~~remained ~~$19.1~~relatively ~~million~~flat in the first ~~nine~~quarter ~~months~~ of ~~2017~~2018, ~~primarily~~decreasing ~~driven~~$0.2 bymillion ~~a lower volume of work~~ in ~~our~~comparison ~~industrial~~to ~~and~~the ~~construction~~first ~~service~~quarter ~~offerings~~of ~~including~~2017. ~~the~~The ~~completion~~decrease ofis ~~certain~~primarily ~~larger~~driven ~~tank~~by ~~projects~~a decrease in ~~the~~our ~~first~~cross-country ~~nine~~pipeline ~~months~~services ofand ~~2016~~other ~~that~~capital ~~did~~projects ~~not recur~~ in the first ~~nine~~quarter ~~months~~ of ~~2017~~2018. The overall decrease in contract revenue is partially offset with aan ~~$1.5~~increase ~~million~~in ~~revenue~~maintenance ~~recovery~~projects, ~~associated~~as ~~with~~well aas ~~claim~~fabrication onservices, ain ~~cross-country~~the ~~pipeline~~first ~~project~~quarter of 2018.

Operating ~~income~~loss decreased $62.5 million ~~to a loss of $5.4 million~~ in the first ~~nine~~quarter ~~months~~ of ~~2017.~~2018 ~~The decrease is~~ primarily driven by ~~the~~increased ~~lower volume of work discussed above, coupled with reduced~~ margins in ~~our~~fabrication ~~construction~~services and maintenance ~~service offerings mainly attributed to changes in the mix of work and lower productivity. In addition~~projects, ~~the~~as ~~overall decrease is partly attributed to~~ a ~~reduction~~result of ~~gains~~higher onmaintenance ~~the~~volumes ~~sale~~and ofspecialty ~~equipment~~fabrication ~~between periods~~projects. The overall decrease in operating ~~income~~loss is ~~partially~~also ~~offset~~partly byattributed ato ~~$2.0 million income recovery associated with~~ a ~~claim~~reduction onof aloss ~~cross-country pipeline project~~projects, ~~coupled~~as ~~with~~well as a ~~decrease~~reduction in ~~general~~employee ~~and~~severance ~~administrative~~ costs ~~primarily~~in ~~related~~comparison to ~~headcount~~the ~~reductions~~first quarter of 2017.

Oil & Gas Segment

Contract revenue increased $40.2 million in the first quarter of 2018 primarily driven by significant growth in large discrete projects in our facilities construction services, coupled with a small increase in volume associated with our mainline pipeline construction services. On January 9, 2018, we signed an agreement to sell assets comprising our mainline construction business to Meridien. The overall increase to revenue was partially offset with a decrease in our tank services business, which was sold on January 2, 2018.

Operating income increased $8.3 million in the first quarter of 2018 to $1.0 million primarily driven by a $4.4 million gain on the sale of assets comprising our mainline pipeline construction business as well as a $1.0 million gain on the sale of assets comprising our tank services business. The overall increase in operating income is also partly attributed to a reduction of losses associated with our mainline pipeline and integrity construction services, as well as an increase in the utilization of equipment in comparison to the first quarter of 2017.

Corporate

Corporate costs represent overhead costs, such as executive management, public company, accounting, tax and professional services, human resources and treasury, that are not directly related to the operations of the segments. The $67.46 million ~~decrease~~increase in corporate costs in the first ~~nine~~quarter ~~months~~ of ~~2017~~2018 is primarily driven by ~~2016~~costs ~~cost~~associated ~~reduction~~with ~~initiatives, including employee headcount reductions, across~~ our ~~corporate~~evaluation ~~headquarters.~~of Invarious ~~addition~~strategic alternatives, ~~the~~which ~~overall~~culminated ~~decrease~~with ~~is partly attributed to a facility lease abandonment charge in~~ the ~~first~~signing ~~nine months~~ of ~~2016 that did not recur in~~ the ~~first~~Merger ~~nine~~Agreement ~~months~~with ~~of 2017~~Primoris.

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LIQUIDITY AND CAPITAL RESOURCES

Additional Sources and Uses of Capital

Due to significant operating losses during the third quarter of 2017 primarily driven by losses on two mainline pipeline construction projects and a small-diameter pipeline construction project in our Oil & Gas segment, an increased volume discount associated with our alliance agreement with a major customer and losses on two discrete projects in our Utility T&D segment, we were not in compliance with the Maximum Total Leverage Ratio and Minimum Interest Coverage Ratio for the quarterly period ended September 30, 2017. In addition, in combination with our current forecast, we did not expect to be in compliance with the Maximum Total Leverage Ratio and Minimum Interest Coverage Ratio for the period from December 31, 2017 through December 31, 2018. We also generated negative operating cash flow of approximately $22.6 million in the third quarter of 2017.

In response to the above, we performed the following mitigating actions to ensure we have sufficient liquidity and capital resources to meet our obligations for the next twelve months:

• Announced plans to de-risk the company by exiting our U.S. mainline pipeline construction business in our Oil & Gas segment. We plan to continue to perform facilities and integrity construction services as well as small-diameter pipeline construction services in the Northeast;

• Obtained additional liquidity of $15.0 million in the form of a commitment for an additional term loan pursuant to a Sixth Amendment to our 2014 Term Loan Facility (the “Sixth Amendment”);

• Borrowed an additional $17.0 million under our 2013 ABL Credit Facility; and

• Obtained covenant relief pursuant to the Sixth Amendment as follows.

The Sixth Amendment suspends compliance with the Maximum Total Leverage Ratio and the Minimum Interest Coverage Ratio covenants through December 31, 2017. In addition, under the Sixth Amendment, the Maximum Total Leverage Ratio will be 5.50 to 1.00 as of March 31, 2018 and will decrease to 4.50 to 1.00 as of June 30, 2018, 4.25 to 1.00 as of September 30, 2018 and 3.00 to 1.00 as of March 31, 2019, and thereafter. The Minimum Interest Coverage Ratio will be 1.75 to 1.00 as of March 31, 2018, will increase to 2.00 to 1.00 as of June 30, 2018, decrease to 1.50 to 1.00 as of December 31, 2018 and increase to 2.75 to 1.00 as of March 31, 2019, and thereafter. The Sixth Amendment also provides that, for the four-quarter period ending March 31, 2018, Consolidated EBITDA shall be equal to the sum of Consolidated EBITDA for the quarterly periods ending December 31, 2017 and March 31, 2018 multiplied by two, and, for the four-quarter period ending June 30, 2018, Consolidated EBITDA shall be equal to the annualized sum of Consolidated EBITDA for the quarterly periods ending December 31, 2017, March 31, 2018 and June 30, 2018.

In addition to the decision to exit our U.S. mainline pipeline construction business in our Oil & Gas segment, obtain additional liquidity pursuant to the Sixth Amendment and increase our revolver borrowings, we are evaluating options to extend, modify or refinance the 2013 ABL Credit Facility.

Concurrent with the effectiveness of the Sixth Amendment, the decision to exit our U.S. mainline pipeline construction business in our Oil & Gas segment and the expected ability to extend, modify or refinance the 2013 ABL Credit Facility, coupled with our cash on hand, including recent and additional anticipated borrowings under the 2013 ABL Credit Facility and the 2014 Term Loan Facility, our current forecasts and our projected cash flow from operations, we expect to meet our required financial covenants and have sufficient liquidity and capital resources to meet our obligations for at least the next twelve months. However, our results of operations must improve in the fourth quarter of 2017 and into 2018 in order to meet our forecasts and required financial covenants. In addition, while we expect to extend, modify or refinance the 2013 ABL Credit Facility, there can be no assurance that we will be able to extend, modify or negotiate agreeable refinancing terms prior to the expiration of the 2013 ABL Credit Facility.

2014 Term Loan Facility

On December 15, 2014, we entered into ~~a credit agreement (~~the “2014 Term Credit Agreement”) among Willbros Group, Inc., certain of its subsidiaries, as guarantors, the lenders from time to time party thereto, and JPMorgan Chase Bank, N.A., as administrative agent. Cortland Capital Market Services LLC currently serves as administrative agent under the 2014 Term Credit Agreement.

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Principal, Interest and Maturity

The 2014 Term Credit Agreement initially provided for a five-year $270.0 million term loan facility (the “2014 Term Loan Facility”), which we drew in full on the effective date of the 2014 Term Credit Agreement. ~~At September 30, 2017, the aggregate outstanding principal balance of the 2014 Term Loan Facility was $92.2 million.~~ Effective November 6, 2017, we amended the 2014 Term Credit Agreement pursuant to a Sixth Amendment (the “Sixth Amendment”). The Sixth Amendment, among other things, provides for an additional term loan in an amount equal to $15.0 million, which ~~will~~is be pari passu in right of payment with, and secured on a pari passu basis with the aggregate outstanding principal balance of ~~our~~the 2014 Term Loan Facility. The additional term loan iswas ~~expected to be~~ drawn in full ~~during~~on November 17, 2017 ~~and~~(the ~~will~~“Sixth ~~bear~~Amendment Funding Date”) and bears the same maturity date as the aggregate outstanding principal balance of ~~our~~the 2014 Term Loan Facility. At March 31, 2018, the aggregate outstanding principal balance of the 2014 Term Loan Facility was approximately $107.2 million.

The 2014 Term Loan Facility initially bore interest at the “Adjusted Base Rate” plus an applicable margin of 8.75 percent, or the “Eurodollar Rate” plus an applicable margin of 9.75 percent. ~~The~~On ~~interest~~the ~~rate~~Sixth inAmendment ~~effect~~Funding ~~at September 30~~Date, ~~2017~~the ~~and~~interest ~~December 31,~~rate ~~2016~~increased ~~was~~to 1113 percent, ~~which~~consisting ~~consisted~~ of an applicable margin of 911.75 percent for Eurodollar Rate loans plus a LIBOR floor of 1.25 percent. ~~Beginning~~The ~~with the date on which the additional term loan is funded (the "Sixth Amendment Funding Date"), the~~ interest rate ~~will~~in ~~increase~~effect toat ~~13 percent~~March 31, ~~consisting~~2018 ofand anDecember 31, ~~applicable~~2017 ~~margin~~was of13 ~~11.75~~ percent ~~for Eurodollar Rate loans plus a LIBOR floor of 1~~.25 ~~percent.~~ Beginning September 30, 2018, the applicable margin will increase an additional 100 basis points each quarterly period until maturity.

On March 27, 2018, we amended the 2014 Term Credit Agreement pursuant to the Seventh Amendment. Under the terms of the Seventh Amendment, Primoris provided us with an Initial First-Out Loan in an amount equal to $10.0 million that was drawn in full on March 30, 2018 and bears the same maturity date as the aggregate outstanding principal balance of our 2014 Term Loan Facility. In addition, Primoris may provide us with Additional First-Out Loans up to $10.0 million. See Note 1 – Company Description and Financial Condition included in Item 1 of Part I of this Form 10-Q for more information.

Makewhole

Under the 2014 Term Credit Agreement, with respect to prepayments made from inception of the Term Loan through ~~September~~March 3031, ~~2017~~2018, we have not been required to pay prepayment premiums in respect of the “makewhole amount.” However, future prepayments or refinancing of the balance of the 2014 Term Loan Facility ~~will~~may require us to pay a prepayment premium equal to the makewhole amount and the repayment fee described below. Pursuant to the Sixth Amendment and beginning with the Sixth Amendment Funding Date, if a prepayment is made on or before September 30, 2018, the makewhole amount will be calculated as the present value of all interest payments that would have been made on the amount prepaid from the date of the prepayment to June 15, 2019 at a rate per annum equal to the sum of the applicable margin on the date of the prepayment plus the greater of 1.25 percent and the Eurodollar rate in effect on the date of the repayment. If a prepayment is made after September 30, 2018, the makewhole amount will be calculated as the present value of all interest payments that would have been made on the amount prepaid from the date of the prepayment to December 15, 2019 at a rate per annum equal to the sum of the applicable margin on the date of the prepayment plus the greater of 1.25 percent and the Eurodollar rate in effect on the date of the repayment.

Should a prepayment ~~occur~~ in full occur under the Sixth Amendment, the estimated makewhole amount due at future prepayment dates would be as follows (in thousands):

December 31, 2017

March 31, 2018

June 30, 2018

September 30, 2018

December 31, 2018

March 31, 2019

June 30, 2019

September 30, 2019

June 30, 2018

September 30, 2018

December 31, 2018

March 31, 2019

June 30, 2019

September 30, 2019

Makewhole

2013,~~328~~358

169,~~843~~874

1316,~~358~~888

912,~~874~~331

167,~~888~~595

123,~~331~~350

~~7,595~~

~~3,350~~

Prior to the Sixth Amendment Funding Date, the makewhole amount was calculated as the present value of all interest payments that would have been made on the amount prepaid from the date of the prepayment to December 15, 2019 (or June 15, 2019 if the prepayment is made on or after June 15, 2018) at a rate per annum equal to the sum of 9.75 percent plus the greater of 1.25 percent and the Eurodollar rate in effect on the date of the repayment.

Repayment Fee

WePrior to the Sixth Amendment, we were also required to pay a repayment fee on the date of any prepayment and on the maturity date of the 2014 Term Loan Facility equal to a total of $4.6 million, which was 5.0 percent of the amount prepaid or 5.0 percent of the aggregate remaining outstanding principal balance on the maturity date. WePursuant ~~are~~to ~~amortizing~~the Sixth Amendment and beginning with the Sixth Amendment Funding Date, the repayment fee asincreased to a ~~discount,~~total ~~from~~of ~~that~~$9.7 ~~date~~million, ~~through~~which ~~the~~is ~~maturity~~9.0 ~~date~~percent of the ~~2014~~amount ~~Term~~prepaid ~~Loan~~or ~~Facility,~~9.0 ~~using~~percent of the ~~effective~~aggregate ~~interest~~remaining ~~method.~~outstanding ~~The~~principal ~~unamortized~~balance ~~amount~~on of the ~~repayment~~maturity ~~fee was $2~~date.8 ~~million~~We ~~and~~are ~~$3.6~~amortizing ~~million~~the atrepayment ~~September 30,~~fee ~~2017~~as ~~and~~a ~~December 31~~discount, ~~2016,~~from ~~respectively~~that ~~based~~date onthrough the ~~5.0~~maturity ~~percent~~date ~~repayment~~of ~~fee~~the in2014 ~~effect~~Term asLoan ofFacility, ~~those~~using ~~dates.~~the

Pursuant to the Sixth Amendment and beginning with the Sixth Amendment Funding Date, the repayment fee will increase to a total of $9.7 million, which is 9.0 percent of the amount prepaid or 9.0 percent of the aggregate remaining outstanding principal balance on the maturity date. 44

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effective interest method. The unamortized amount of the repayment fee was $6.2 million and $7.2 million at March 31, 2018 and December 31, 2017, respectively, based on the 9.0 percent repayment fee in effect as of those dates.

Term Loan Discounted Payoff

The Seventh Amendment provides that the payment by the borrower of an amount equal to $100.0 million plus the expenses of the administrative agent in an amount not to exceed $1.1 million shall constitute payment in full and satisfaction and discharge of all obligations of the borrower and the other loan parties under the 2014 Term Credit Agreement, but solely if such payment is made in connection with the consummation of the merger. Accordingly, if the 2014 Term Loan Facility is paid off in connection with the closing of the merger, no amounts will be owed in respect of the makewhole amount and the repayment fee. Based on the above information, the settlement of the debt at the discounted amount is considered a troubled debt restructuring transaction. However, given the settlement of the debt at the discounted amount is contingent upon the consummation of the merger, we have not recorded an adjustment to our Condensed Consolidated Financial Statements.

Debt Covenants

On March 31, 2015 (the “First Amendment Closing Date”), March 1, 2016, July 26, 2016 and March 3, 2017, the Company amended the 2014 Term Credit Agreement pursuant to a First Amendment (the “First Amendment”), a Third Amendment, a Fourth Amendment and a Fifth Amendment (the “Fifth Amendment”). These amendments, among other things, suspended the calculation of the Maximum Total Leverage Ratio and Minimum Interest Coverage Ratio for the period from December 31, 2014 through June 30, 2017 (the “Covenant Suspension Periods”) so that any failure by us to comply with the Maximum Total Leverage Ratio or Minimum Interest Coverage Ratio during the Covenant Suspension Periods shall not be deemed to result in a default or event of default.

In consideration of the initial suspension of the calculation of the Maximum Total Leverage Ratio and Minimum Interest Coverage Ratio under the First Amendment, we issued 10.1 million shares, which was equivalent to 19.9 percent of the then outstanding shares of common stock immediately prior to the First Amendment Closing Date, to KKR Lending Partners II L.P. and other entities indirectly advised by KKR Credit Advisers (US) LLC, which made them a related party. In connection with this transaction, we recorded debt covenant suspension charges of approximately $33.5 million, which represented the fair value of the 10.1 million outstanding shares of common stock issued, multiplied by the closing stock price on the First Amendment Closing Date. In addition, the Company recorded debt extinguishment charges of approximately $0.8 million related to the write-off of debt issuance costs associated with the Company’s 2014 Term Credit Agreement.

In consideration for the Fifth Amendment, we paid a $2.3 million amendment fee during the three months ended March 31, 2017. The amendment fee is recorded as a direct deduction from the carrying amount of the 2014 Term Loan Facility and is being amortized through the maturity date of the 2014 Term Loan Facility using the effective interest method.

The Sixth Amendment suspended compliance with the Maximum Total Leverage Ratio and the Minimum Interest Coverage Ratio covenants through December 31, 2017. In addition, under the Sixth Amendment, the Maximum Total Leverage Ratio was 5.50 to 1.00 as of March 31, 2018 and will decrease to 4.50 to 1.00 as of June 30, 2018, 4.25 to 1.00 as of September 30, 2018 and 3.00 to 1.00 as of March 31, 2019, and thereafter. The Minimum Interest Coverage Ratio was 1.75 to 1.00 as of March 31, 2018, will increase to 2.00 to 1.00 as of June 30, 2018, decrease to 1.50 to 1.00 as of December 31, 2018 and increase to 2.75 to 1.00 as of March 31, 2019, and thereafter. The Sixth Amendment also provided that, for the four-quarter period ending March 31, 2018, Consolidated EBITDA was equal to the sum of Consolidated EBITDA for the quarterly periods ending December 31, 2017 and March 31, 2018 multiplied by two, and, for the four-quarter period ending June 30, 2018, Consolidated EBITDA shall be equal to the annualized sum of Consolidated EBITDA for the quarterly periods ending December 31, 2017, March 31, 2018 and June 30, 2018.

We are not in compliance with the Maximum Total Leverage Ratio and Minimum Interest Coverage Ratio for the quarterly period ended March 31, 2018 and do not expect to be in compliance with the Maximum Total Leverage Ratio and Minimum Interest Coverage Ratio under the 2014 Term Credit Agreement for the next twelve months. In addition, we are currently not in compliance with certain other provisions under the 2014 Term Credit Agreement and the 2013 ABL Credit Facility, which expires on August 7, 2018. Absent the temporary forbearance provided under the Term Forbearance Agreement and the ABL Forbearance Agreement, the lenders would have the right to require immediate repayment of all of our debt obligations under the default provisions in the 2014 Term Credit Agreement and the 2013 ABL Credit Facility.

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Other

We are the borrower under the 2014 Term Credit Agreement, with all of our obligations guaranteed by our material U.S. subsidiaries, other than excluded subsidiaries. Obligations under the 2014 Term Loan Facility are secured by a first priority security interest in, among other things, the borrower’s and the guarantors’ equipment, subsidiary capital stock and intellectual property (the “2014 Term Loan Priority Collateral”) and a second priority security interest in, among other things, the borrower’s and the guarantors’ inventory, accounts receivable, deposit accounts and similar assets.

Unamortized debt issuance costs, primarily related to amendment fees associated with the 2014 Term Loan Facility, were $53.18 million and $4.15 million at ~~September~~March 3031, ~~2017~~2018 and December 31, ~~2016~~2017, respectively. These costs are being amortized through the maturity date of the 2014 Term Loan Facility using the effective interest method.

We made no early payments during the nine months ended September 30, 2017 and $3.1 million of early payments during the nine months ended September 30, 2016 against our 2014 Term Loan Facility. As a result of these early payments, we recorded no debt extinguishment charges during the nine months ended September 30, 2017 and $0.1 million of debt extinguishment charges, which consisted of the write-off of debt issuance costs, during the nine months ended September 30, 2016.

On March 31, 2015 (the “First Amendment Closing Date”), March 1, 2016, July 26, 2016 and March 3, 2017, we amended the 2014 Term Credit Agreement pursuant to a First Amendment (the “First Amendment”), a Third Amendment (the “Third Amendment”), a Fourth Amendment (the “Fourth Amendment”) and a Fifth Amendment (the “Fifth Amendment”). These amendments, among other things, suspended the calculation of the Maximum Total Leverage Ratio and Minimum Interest Coverage Ratio for the period from December 31, 2014 through June 30, 2017 (the “Covenant Suspension Periods”) so that any failure by us to comply with the Maximum Total Leverage Ratio or Minimum Interest Coverage Ratio during the Covenant Suspension Periods shall not be deemed to result in a default or event of default.

In consideration of the initial suspension of the calculation of the Maximum Total Leverage Ratio and Minimum Interest Coverage Ratio under the First Amendment, we issued 10.1 million shares, which was equivalent to 19.9 percent of the outstanding shares of common stock immediately prior to the First Amendment Closing Date, to KKR Lending Partners II L.P. and other entities indirectly advised by KKR Credit Advisers (US) LLC, which made them a related party. In connection with this transaction, we recorded debt covenant suspension charges of approximately $33.5 million which represented the fair value of the 10.1 million outstanding shares of common stock issued, multiplied by the closing stock price on the First Amendment Closing Date. In addition, we recorded debt extinguishment charges of approximately $0.8 million related to the write-off of debt issuance costs associated with our 2014 Term Credit Agreement.

In consideration for the Third Amendment, Fourth Amendment and Fifth Amendment, we paid a total of $4.6 million in amendment fees in 2016 and $2.3 million in amendment fees during the nine months ended September 30, 2017. The amendment fees are recorded as direct deductions from the carrying amount of the 2014 Term Loan Facility and are being amortized through the maturity date of the 2014 Term Loan Facility using the effective interest method.

2013 ABL Credit Facility

On August 7, 2013, we entered into a five-year asset based senior revolving credit facility maturing on August 7, 2018 with Bank of America, N.A. serving as sole administrative agent for the lenders thereunder, collateral agent, issuing bank and swingline lender (as amended, the “2013 ABL Credit Facility”).

The aggregate amount of commitments for the 2013 ABL Credit Facility is $100.0 million, which is comprised of $90.0 million for the U.S. facility (the “U.S. Facility”) and $10.0 million for the Canadian facility (the “Canadian Facility”). InAt ~~the~~March 31, ~~third~~2018, ~~quarter~~the ofCompany ~~2017,~~had weapproximately ~~borrowed~~ $1223.0 million in outstanding borrowings under the 2013 ABL Credit Facility for working capital purposes ~~and to fund revenue growth and operating losses~~. ~~On November 6, 2017, we borrowed an additional $17.0 million under the 2013 ABL Credit Facility.~~

The 2013 ABL Credit Facility includes a sublimit of $80.0 million for letters of credit. The borrowers under the U.S. Facility consist of all our U.S. operating subsidiaries with assets included in the borrowing base, and the U.S. Facility is guaranteed by Willbros Group, Inc. and its material U.S. subsidiaries, other than excluded subsidiaries. The borrower under the Canadian Facility is Willbros Construction Services (Canada) LP, and the Canadian Facility is guaranteed by Willbros Group, Inc. and all of its material U.S. and Canadian subsidiaries, other than excluded subsidiaries.

Advances under the U.S. and Canadian Facilities are limited to a borrowing base consisting of the sum of the following, less applicable reserves:

• 85 percent of the value of “eligible accounts” (as defined in ~~our~~the 2013 ABL Credit Facility);

• the lesser of (i) 75 percent of the value of “eligible unbilled accounts” (as defined in ~~our~~the 2013 ABL Credit Facility) and (ii) $33.0 million minus the amount of eligible unbilled accounts then included in the borrowing base; and

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•	“eligible pledged cash”.

We are also required, as part of our borrowing base calculation, to include a minimum of $25.0 million of the net proceeds of the sale of Bemis, LLC and the balance of the Professional Services segment as eligible pledged cash. We have included $40.0 million as eligible pledged cash in our ~~September~~March 3031, ~~2017~~2018 borrowing base calculation, which is included in “Restricted cash” on our Condensed Consolidated Balance Sheets.

The interest rate margins will be adjusted each quarter based on our fixed charge coverage ratio as of the end of the previous quarter as follows:



Fixed Charge Coverage Ratio	U.S. Base Rate, Canadian Base Rate and Canadian Prime Rate Loans	LIBOR Loans, BA Rate Loans and Letter of Credit Fees
>1.25 to 1	1.25%	2.25%
<1.25 to 1 and >1.15 to 1	1.50%	2.50%
<1.15 to 1	1.75%	2.75%

We will also pay an unused line fee on each of the U.S. and Canadian Facilities equal to 50 basis points when usage under the applicable facility during the preceding calendar month is less than 50 percent of the commitments or 37.5 basis points when usage under the applicable facility equals or exceeds 50 percent of the commitments for such period. With respect to the letters of credit, we will pay a letter of credit fee equal to the applicable LIBOR margin, shown in the table above, on all letters of credit and a 0.125 percent fronting fee to the issuing bank, in each case, payable monthly in arrears.

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AsIn ofthe ~~September 30,~~first ~~2017,~~quarter ~~our unused availability was $32.5 million, net~~ of ~~outstanding letters of credit of $55.5 million and outstanding revolver borrowings of $12.0 million. On November 6~~2018, ~~2017,~~ we ~~borrowed~~repaid ~~an additional~~ $175.0 million ~~under~~of ~~the 2013 ABL Credit Facility. If~~ our unused availability under the 2013 ABL Credit Facility is less than the greater of (i) 15.0 percent of the revolving commitments or $15.0 million for five consecutive days, or (ii) 12.5 percent of the revolving commitments or $12.5 million at any time, or upon the occurrence of certain events of default under the 2013 ABL Credit Facility, we are subject to increased reporting requirements, the administrative agent shall have exclusive control over any deposit account, we will not have any right of access to, or withdrawal from, any deposit account, or any right to direct the disposition of funds in any deposit account, and amounts in any deposit account will be applied to reduce the outstanding ~~amounts~~borrowings under the 2013 ABL Credit Facility. Inusing ~~addition,~~available ifcash ~~our unused availability under the 2013 ABL Credit Facility is less than the amounts described above, we would be required to comply with a Minimum Fixed Charge Coverage Ratio of 1.15 to 1.00. Based~~ on our current forecasts, we do not expect our unused availability under the 2013 ABL Credit Facility to be less than the amounts described above and therefore do not expect the Minimum Fixed Charge Coverage Ratio to be applicable over the next twelve monthshand. ~~If the Minimum Fixed Charge Coverage Ratio were to become applicable, we would not expect to be in compliance over the next twelve months and would therefore be in default under our credit agreements.~~

If our unused availability under the 2013 ABL Credit Facility is less than the greater of (i) 15.0 percent of the revolving commitments or $15.0 million for five consecutive days, or (ii) 12.5 percent of the revolving commitments or $12.5 million at any time, or upon the occurrence of certain events of default under the 2013 ABL Credit Facility (“Cash Dominion”), we are subject to increased reporting requirements, the administrative agent shall have exclusive control over any deposit account, we will not have any right of access to, or withdrawal from, any deposit account, or any right to direct the disposition of funds in any deposit account, and amounts in any deposit account will be applied to reduce the outstanding amounts under the 2013 ABL Credit Facility. In addition, if our unused availability under the 2013 ABL Credit Facility is less than the amounts described above, we would be required to comply with a Minimum Fixed Charge Coverage Ratio of 1.15 to 1.00.

Pursuant to the ABL Forbearance Agreement, the aggregate amount of commitments under the 2013 ABL Credit Facility has been reduced from $100.0 million to $90.0 million, which is comprised of $80.0 million for the U.S. Facility and $10.0 million for the Canadian Facility. In addition, during the ABL Forbearance Period, we may not request any additional loans or any new or increased letters of credit. The ABL Forbearance Agreement also provides that Cash Dominion will occur if our unused availability under the 2013 ABL Credit Facility is less than $10.0 million at any time. Under our March 31, 2018 borrowing base certificate, our unused availability under the 2013 ABL Credit Facility was $12.3 million, which is in accordance with the ABL Forbearance Agreement.

We give no assurance that we will continue to be able to avoid Cash Dominion under the 2013 ABL Credit Facility. If the Minimum Fixed Charge Coverage Ratio were to become applicable, we would not expect to be in compliance over the next twelve months and would therefore be in default under our credit agreements.

Events of Default

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The 2014 Term Credit Agreement and the 2013 ABL Credit Facility also include customary representations and warranties and affirmative and negative covenants, including:


•	the preparation of financial statements in accordance with GAAP;


•	the ability to deliver an audit opinion without a going concern explanation;


•	the identification of any events or circumstances, either individually or in the aggregate, that has had or could reasonably be expected to have a material adverse effect on our business, results of operations, properties or financial condition;


•	limitations on liens and indebtedness;


•	limitations on dividends and other payments in respect of capital stock;


•	limitations on capital expenditures; and


•	limitations on modifications of the documentation of the 2013 ABL Credit Facility.

~~Cash~~Our ~~Balances~~inability to deliver our 2017 audited financial statements without a going concern explanation constitutes an event of default under the 2014 Term Credit Agreement and the 2013 ABL Credit Facility. See Note 1 – Company Description and Financial Condition in Item 1 of Part I of this Form 10-Q for more information.

AsOn ofMarch ~~September 30~~27, ~~2017~~2018, we ~~had~~entered ~~cash~~into ~~and~~a ~~cash~~Term ~~equivalents~~Forbearance ofAgreement ~~$31.3~~with ~~million.~~the ~~Our~~Term ~~cash~~Lenders and ~~cash~~an ~~equivalent~~ABL ~~balances~~Forbearance ~~held~~Agreement inwith the ~~United~~ABL ~~States~~Lenders. ~~and~~If ~~foreign~~the ~~countries~~merger ~~were~~with ~~$20.3~~Primoris ~~million~~is ~~and~~not ~~$11.0 million~~completed, ~~respectively.~~or Inif ~~2011,~~these weforbearance ~~discontinued~~agreements ~~our~~were ~~strategy~~to ofexpire ~~reinvesting~~or ~~non-U.S.~~be ~~earnings~~terminated inprior ~~foreign~~to ~~operations.~~the ~~Accordingly~~completion of the merger, wethe ~~may~~Term ~~repatriate~~Lenders ~~cash~~and ~~for~~ABL ~~corporate~~Lenders ~~purposes~~would ~~without~~be ~~incurring~~free ~~additional~~to ~~tax~~exercise ~~expense.~~any

Our working capital position (defined as current assets minus current liabilities) for continuing operations decreased $32.3 million to $58.1 million at September 30, 2017 from $90.4 million at December 31, 2016. The decrease is primarily driven by a reduction in operating cash flow driven by increased operating losses between periods.47

InTable ~~the third quarter~~ of 2017, we borrowed $12.0 million under the 2013 ABL Credit Facility for working capital purposes and to fund revenue growth and operating losses. In November 2017, we borrowed an additional $17.0 million under the 2013 ABL Credit Facility and obtained a commitment for an additional term loan of $15.0 million pursuant to the Sixth Amendment. We continue to take the necessary measures to manage our cash balance by focusing on cash collections, monitoring capital expenditures and taking steps to improve our cash flow from operations. Contents

rights and remedies with respect to such defaults and events of defaults pursuant to the terms of the 2014 Term Credit Agreement and the 2013 ABL Credit Facility, respectively. See Note 1 – Company Description and Financial Condition in Item 1 of Part I of this Form 10-Q for more information.

Cash Balances and Working Capital

As of March 31, 2018, we had cash and cash equivalents of $21.4 million. Our cash and cash equivalent balances held in the United States and foreign countries were $17.9 million and $3.5 million, respectively. In 2011, we discontinued our strategy of reinvesting non-U.S. earnings in foreign operations. Accordingly, we may repatriate foreign cash for corporate purposes without incurring additional tax expense.

In 2017, we borrowed a net $28.1 million under the 2013 ABL Credit Facility and obtained an additional term loan of $15.0 million pursuant to the Sixth Amendment to support working capital needs and fund operating losses and revenue growth. However, our significant operating losses in 2017 have led to significant negative operating cash flow in recent months, which has put a considerable strain on our overall liquidity.

In the first quarter of 2018, we borrowed $10.0 million as an Initial First-Out Loan under the 2014 Term Credit Agreement and repaid $5.0 million of our outstanding revolver borrowings under the 2013 ABL Credit Facility. In addition, Primoris may provide us with Additional First-Out Loans up to an additional $10.0 million.

Our working capital position (defined as current assets minus current liabilities) for continuing operations decreased $8.6 million to a negative $91.7 million at March 31, 2018 from a negative $83.1 million at December 31, 2017. The decrease is primarily driven by a reduction in operating cash flow driven by recent operating losses.

Cash Flows

Statements of cash flows for entities with international operations that use the local currency as the functional currency exclude the effects of the changes in foreign currency exchange rates that occur during any given period, as these are non-cash charges. As a result, changes reflected in certain accounts on the Condensed Consolidated Statements of Cash Flows may not reflect the changes in corresponding accounts on the Condensed Consolidated Balance Sheets.

Cash flows provided by (used in) continuing operations by type of activity were as follows for the ~~nine~~three months ended ~~September~~March 3031, ~~2017~~2018 and ~~2016~~2017 (in thousands):

	2017			2016			Increase(Decrease)
	2018			2017			Increase(Decrease)
Operating activities	$	(2125,~~557~~939	)	$	(83,~~232~~685	)	$	(1322,~~325~~254	)
Investing activities	29,~~280~~963			61,~~639~~551			(48,~~359~~412		)
Financing activities	94,~~152~~517			(82,~~570~~454		)	176,~~722~~971
Effect of exchange rate changes	~~1,055~~(139		)	~~620~~86			~~435~~(225		)
Cash used in all continuing activities	$	(911,~~070~~598	)	$	(94,~~543~~502	)	$	~~473~~(7,096	)

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Operating Activities

Cash flow from ~~operations~~operating activities is primarily influenced by demand for our services, operating margins and the type of services we provide, but can also be influenced by working capital needs such as the timing of collection of receivables and the settlement of payables and other obligations. Working capital needs are generally higher during the summer and fall months when the majority of our capital-intensive projects are executed. Conversely, working capital assets are typically converted to cash during the late fall and winter months.

Operating activities from continuing operations used net cash of $2125.69 million during the ~~nine~~three months ended ~~September~~March 3031, ~~2017~~2018 compared to $83.27 million used during the same period in ~~2016~~2017. The $1322.42 million decrease in operating cash flow is primarily a result of the following:

• AAn ~~decrease~~increase in cash flow ~~provided~~used byin ~~accounts~~contracts ~~receivable~~in progress of $6013.47 million primarily related to ~~higher~~increased ~~accounts~~business ~~receivable~~activity ~~balances~~between ~~that are mainly attributed to a higher volume of work~~periods;

• A decrease in cash flow provided by ~~continuing~~accounts ~~operations~~payable of $~~24.~~6.4 million primarily related to an increase inof ~~project~~vendor ~~losses~~payments ~~for~~between ~~the nine months ended September 30, 2017~~periods;

• AAn ~~decrease~~increase in cash flow ~~provided~~used byin ~~contracts~~continuing inoperations, ~~progress~~adjusted for any non-cash items, of $64.54 million primarily related to ~~decreased~~an ~~billings~~increase onin ~~projects~~cash ~~during~~operating ~~the~~losses ~~nine~~between ~~months ended September 30, 2017~~periods; and

• AAn ~~decrease~~increase in cash flow ~~provided~~used byin ~~assets~~prepaids ~~held~~and ~~for~~other ~~sale~~assets of $13.75 million primarily related to ~~higher~~changes ~~accounts receivable balances~~ in ~~our tank services~~ business ~~that is mainly attributed to a higher volume of work~~activity.

These items were partially offset by:

• An increase in cash flow provided by accounts ~~payable~~receivable of $767.60 million primarily related to alower ~~reduction~~accounts inreceivable ~~vendor~~balances ~~payments~~that ~~during~~are ~~the~~mainly ~~nine~~attributed ~~months~~to ~~ended~~a ~~September~~higher ~~30,~~volume ~~2017;~~of ~~and~~collections.

• An increase in cash flow provided by other assets and liabilities of $3.4 million primarily related to changes in business activity during the period.

Investing Activities

Investing activities from continuing operations provided net cash of $210.30 million during the ~~nine~~three months ended ~~September~~March 3031, ~~2017~~2018 as compared to $61.6 million provided during the same period in ~~2016~~2017. The $48.34 million ~~decrease~~increase in investing cash flow is primarily related to a $96.08 million ~~decrease~~increase in proceeds from the sale of ~~subsidiaries~~property, plant and equipment and a $1.76 million ~~decrease~~increase in proceeds from ~~property,~~the ~~plant~~sale ~~and~~of ~~equipment~~subsidiaries. ~~which~~These increases were ~~partially~~mainly ~~offset~~generated bythrough athe ~~$6.0~~sale ~~million~~of ~~decrease~~our intank ~~restricted~~services ~~cash~~business ~~deposits~~ and amainline ~~$0.4~~pipeline ~~million~~construction ~~decrease~~business in ~~purchases~~the offirst ~~property,~~quarter ~~plant~~of ~~and equipment between periods~~2018.

Financing Activities

Financing activities from continuing operations provided net cash of $94.25 million during the ~~nine~~three months ended ~~September~~March 3031, ~~2017~~2018 as compared to $82.65 million used during the same period of ~~2016~~2017. The $177.80 million increase in financing cash flow is primarily related to $1210.0 million in proceeds from ~~our~~the ~~revolving~~Initial ~~credit~~First-Out ~~facility~~Loan during the ~~nine~~first ~~months~~quarter ~~ended~~of ~~September~~2018 ~~30,~~and ~~2017 as well as~~ a $3.1.8 million decrease in ~~payments~~debt ~~against~~issuance ~~our~~costs ~~Term~~between ~~Loan, a $2~~periods.3 ~~million~~These ~~decrease~~items inwere ~~debt~~partially ~~issuance~~offset ~~costs~~with ~~and~~an aincrease of $05.40 million ~~decrease~~of in payments against our ~~capital~~revolving ~~leases~~credit ~~between~~facility ~~periods~~in the first quarter of 2018.

Discontinued Operations

Discontinued operations used net cash of $10.14 million during the ~~nine~~three months ended ~~September~~March 3031, ~~2017~~2018 as compared to $7.0.2 million used during the ~~nine~~three months ended ~~September~~March 3031, ~~2016~~2017. The $50.92 million ~~increase~~decrease in discontinued operations cash flow is primarily due to changes in business activity between periods ~~from services previously~~ associated with ~~our~~previously ~~Professional~~disposed ~~Services segment~~businesses.

Interest Rate Risk

We are subject to interest rate risk on our debt and investment of cash and cash equivalents arising in the normal course of business and have entered into hedging arrangements to fix or otherwise limit the interest costs of our variable interest rate borrowings.

Termination of Interest Rate Swap Agreement

In August 2013, we entered into an interest rate swap agreement (the “Swap Agreement”) for a notional amount of $124.1 million to hedge changes in the variable rate interest expense on $124.1 million of our existing or replacement LIBOR indexed debt. The Swap Agreement was designated and qualified as a cash flow hedging instrument with the effective portion of the Swap Agreement’s change in fair value recorded in Other Comprehensive Income (“OCI”). The Swap Agreement was highly effective in offsetting changes in interest expense and no hedge ineffectiveness was recorded in the Consolidated Statements of Operations. The Swap Agreement was terminated in the third quarter of 2015 for $5.7 million, which was recorded in OCI as fair value. In the fourth quarter of 2015, we made an early payment of $93.6 million against our 2014 Term Loan Facility and

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Swap Agreement's change in fair value recorded in Other Comprehensive Income (“OCI”). The Swap Agreement was highly effective in offsetting changes in interest expense and no hedge ineffectiveness was recorded in the Consolidated Statements of Operations. The Swap Agreement was terminated in the third quarter of 2015 for $5.7 million, which was recorded in OCI as fair value. In the fourth quarter of 2015, we made an early payment of $93.6 million against our 2014 Term Loan Facility and therefore reclassified approximately $1.2 million of the fair value of the Swap Agreement from OCI to interest expense. In the first quarter of 2016, we made an early payment of $3.1 million against our 2014 Term Loan Facility and therefore reclassified approximately $0.1 million of the fair value of the Swap Agreement from OCI to interest expense. The remaining fair value of the Swap Agreement included in OCI will be reclassified to interest expense over the remaining life of the underlying debt with approximately $1.1 million expected to be recognized in the coming twelve months.

Capital Requirements

~~Our~~We ~~financing~~continue ~~objective~~to iswork totowards ~~maintain~~effective ~~financial~~liquidity ~~flexibility~~management to meet the material, equipment and personnel needs to support our project and MSA commitments. ~~Our~~In ~~industry~~2017, iswe ~~also~~borrowed $28.1 million under the 2013 ABL Credit Facility for working capital~~-intensive,~~ purposes and weobtained ~~expect~~an ~~the~~additional ~~need~~term ~~for~~loan ~~capital~~of ~~expenditures~~$15.0 million pursuant to ~~continue~~the ~~into~~Sixth Amendment. In the ~~foreseeable~~first ~~future~~quarter toof ~~meet~~2018, we borrowed an additional $10.0 million as an Initial First-Out Loan under the ~~anticipated~~2014 ~~demand~~Term ~~for~~Credit Agreement and repaid $5.0 million of our ~~services~~outstanding revolver borrowings under the 2013 ABL Credit Facility. AsPursuant ~~such~~to the ABL Forbearance Agreement, we ~~are~~may ~~focused~~not onrequest ~~providing~~any ~~working~~additional ~~capital~~loans ~~for~~or ~~projects~~any innew ~~process~~or inincreased ~~2017~~letters asof ~~well~~credit asunder ~~for~~the ~~projects~~2013 ~~included~~ABL inCredit ~~our~~Facility. ~~2018~~In ~~capital~~addition, ~~budget~~Primoris may provide us with Additional First-Out Loans up to an additional $10.0 million.

In the third quarter of 2017, we borrowed $12.0 million under the 2013 ABL Credit Facility for working capital purposes and to fund revenue growth and operating losses. In November 2017, we borrowed an additional $17.0 million under the 2013 ABL Credit Facility and obtained a commitment for an additional term loan of $15.0 million pursuant to the Sixth Amendment. In addition, in order to further enhance our liquidity, we may consider, from time to time, the issuance of equity securities.

During the second quarter of 2017, in order to maintain our financial flexibility, we renewed our universal shelf registration statement, which provides us with the ability to offer and sell equity and debt securities, subject to market conditions and our capital needs.

Contractual Obligations

Other commercial commitments, as detailed in our Annual Report on Form 10-K for the year ended December 31, ~~2016~~2017, did not materially change except for payments made in the normal course of business.

NEW ACCOUNTING STANDARDS

See Note 3 -– New Accounting Standards in the Notes to Condensed Consolidated Financial Statements included in this Form 10-Q for a summary of any recently issued accounting standards.

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FORWARD-LOOKING STATEMENTS

This Form 10-Q includes “forward-looking statements” within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended. All statements, other than statements of historical facts, included in this Form 10-Q that address activities, events or developments which we expect or anticipate will or may occur in the future, including such things as our ability to continue as a going concern, our ability to complete our planned merger with Primoris, future capital expenditures (including the amount and nature thereof), oil, gas, gas liquids and power prices, demand for our services, the amount and nature of future investments by governments, expansion and other development trends of the oil and gas and power industries, business strategy, expansion and growth of our business and operations, the outcome of legal proceedings and other such matters are forward-looking statements. These forward-looking statements are based on assumptions and analyses we made in light of our experience and our perception of historical trends, current conditions and expected future developments as well as other factors we believe are appropriate under the circumstances. However, whether actual results and developments will conform to our expectations and predictions is subject to a number of risks and uncertainties. As a result, actual results could differ materially from our expectations. Factors that could cause actual results to differ from those contemplated by our forward-looking statements include, but are not limited to, the following:

• ~~curtailment~~our ofstockholders ~~capital~~fail ~~expenditures due~~ to ~~low~~approve ~~prevailing commodity prices or other factors, and~~ the ~~unavailability~~proposed ofmerger ~~project~~transaction ~~funding~~with ~~in the oil and gas and power industries~~Primoris;


•	we or the other parties to the Merger Agreement are unable to satisfy the conditions to the completion of the merger, or are unable to obtain any regulatory approvals required for the merger on the terms expected, on the anticipated schedule, or at all;


•	we are unable to close the merger or the merger is delayed, either as a result of litigation related to the transaction or otherwise;


•	the parties are unable to achieve the anticipated benefits of the merger transaction;


•	completing the merger may distract our management from other important matters;


•	inability to comply with the terms of the ABL Forbearance Agreement or Term Forbearance Agreement;


•	inability to comply with the covenants in or to obtain waivers under our credit facilities;


•	the loss of customers, suppliers and key personnel that may occur as a result of our issuing financial statements with a “going concern” qualification or explanation, and the possibility that we may seek protection under the U.S. Bankruptcy Code;


•	inability to obtain adequate financing on reasonable terms;


•	curtailment of capital expenditures due to low prevailing commodity prices or other factors, and the unavailability of project funding in the power and oil and gas industries;


•	inability to execute fixed-price and cost-reimbursable projects within the target cost, thus eroding contract margin and, potentially, contract income on any such project;


•	increased capacity and decreased demand for our services in the more competitive industry segments that we serve;


•	the demand for energy moderating or diminishing;


•	cancellation or delay of projects, in whole or in part, for any reason;

• inability to comply with the financial and other covenants in, or to obtain waivers under our credit facilities;

• inability to obtain adequate financing on reasonable terms;


•	failure to obtain the timely award of one or more projects;


•	inability to obtain sufficient surety bonds or letters of credit;


•	reduced creditworthiness of our customer base and higher risk of non-payment of receivables;


•	project cost overruns, unforeseen schedule delays and the application of liquidated damages;

• inability to execute fixed-price and cost-reimbursable projects within the target cost, thus eroding contract margin and, potentially, contract income on any such project;

• inability to satisfy New York Stock Exchange continued listing requirements for our common stock;

• increased capacity and decreased demand for our services in the more competitive industry segments that we serve;


•	inability to lower our cost structure to remain competitive in the market or to achieve anticipated operating margins;


•	inability of the energy service sector to reduce costs when necessary to a level where our customers’ project economics support a reasonable level of development work;


•	reduction of services to existing and prospective clients when they bring historically out-sourced services back in-house to preserve intellectual capital and minimize layoffs;


•	the consequences we may encounter if, in the future, we identify any material weaknesses in our internal control over financial reporting which may adversely affect the accuracy and timing of our financial reporting;

• the impact of any litigation, including class actions associated with our restatement of first and second quarter 2014 financial results on our financial position and results of operations, including our defense costs and the costs and other effects of settlements or judgments;51

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•	the impact of any litigation associated with our restatement of first and second quarter 2014 financial results on our financial position and results of operations, including our defense costs and the costs and other effects of settlements or judgments;


•	adverse weather conditions not anticipated in bids and estimates;


•	the occurrence during the course of our operations of accidents and injuries to our personnel, as well as to third parties, that negatively affect our safety record, which is a factor used by many clients to pre-qualify and otherwise award work to contractors in our industry;


•	failing to realize cost recoveries on claims or change orders from projects completed or in progress within a reasonable period after completion of the relevant project;


•	political or social circumstances impeding the progress of our work and increasing the cost of performance;


•	inability to predict the timing of an increase in energy sector capital spending, which results in staffing below the level required to service such an increase;

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•	inability to hire and retain sufficient skilled labor to execute our current work, our work in backlog and future work we have not yet been awarded;

• inability to obtain sufficient surety bonds or letters of credit;


•	loss of the services of key management personnel;

•

the consequences we may encounter if we violate the Foreign Corrupt Practices Act (the “FCPA”) or other anti-corruption laws in view of the 2008 final settlements with the Department of Justice and the Securities and Exchange Commission (“SEC”) in which we admitted prior FCPA violations, including the imposition of civil or criminal fines, penalties, enhanced monitoring arrangements, or other sanctions that might be imposed;


•	the dishonesty of employees and/or other representatives or their refusal to abide by applicable laws and our established policies and rules;


•	inability to obtain and maintain legal registration status in one or more foreign countries in which we are seeking to do business;


•	downturns in general economic, market or business conditions in our target markets;


•	changes in and interpretation of U.S. and foreign tax laws that impact our worldwide provision for income taxes and effective income tax rate;


•	changes in applicable laws or regulations, or changed interpretations thereof, including climate change regulation;


•	changes in the scope of our expected insurance coverage;


•	inability to manage insurable risk at an affordable cost;


•	enforceable claims for which we are not fully insured;


•	incurrence of insurable claims in excess of our insurance coverage;


•	the occurrence of the risk factors listed elsewhere in this Form 10-Q or described in our periodic filings with the SEC; and


•	other factors, most of which are beyond our control.

Consequently, all of the forward-looking statements made in this Form 10-Q are qualified by these cautionary statements and there can be no assurance that the actual results or developments we anticipate will be realized or, even if substantially realized, that they will have the consequences for, or effects on, our business or operations that we anticipate today. We assume no obligation to update publicly any such forward-looking statements, whether as a result of new information, future events or otherwise, except as may be required by law.

Unless the context requires or is otherwise noted, all references in this Form 10-Q to “Willbros,” the “Company,” “we,” “us” and “our” refer to Willbros Group, Inc., its consolidated subsidiaries and their predecessors.

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ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

Interest Rate Risk

Termination of Interest Rate Swap Agreement

In August 2013, we entered into an interest rate swap agreement for a notional amount of $124.1 million to hedge changes in the variable rate interest expense on $124.1 million of our existing or replacement LIBOR indexed debt. The Swap Agreement was designated and qualified as a cash flow hedging instrument with the effective portion of the Swap Agreement'’s change in fair value recorded in OCI. The Swap Agreement was highly effective in offsetting changes in interest expense and no hedge ineffectiveness was recorded in the Consolidated Statements of Operations. The Swap Agreement was terminated in the third quarter of 2015 for $5.7 million, which was recorded in OCI as fair value. In the fourth quarter of 2015, we made an early payment of $93.6 million against our 2014 Term Loan Facility and therefore reclassified approximately $1.2 million of the fair value of the Swap Agreement from OCI to interest expense. In the first quarter of 2016, we made an early payment of $3.1 million against our 2014 Term Loan Facility and therefore reclassified approximately $0.1 million of the fair value of the Swap Agreement from OCI to interest expense. The remaining fair value of the Swap Agreement included in OCI will be reclassified to interest expense over the remaining life of the underlying debt with approximately $1.1 million expected to be recognized in the coming twelve months.

Foreign Currency Risk

We are exposed to market risk associated with changes in non-U.S. (primarily Canada) currency exchange rates. To mitigate our risk, we may borrow in Canadian dollars under our Canadian Facility to settle U.S. dollar account balances.

We attempt to negotiate contracts which provide for payment in U.S. dollars, but we may be required to take all or a portion of payment under a contract in another currency. To mitigate non-U.S. currency exchange risk, we seek to match anticipated non-U.S. currency revenue with expense in the same currency whenever possible. To the extent we are unable to match non-U.S. currency revenue with expense in the same currency, we may use forward contracts, options or other common hedging techniques in the same non-U.S. currencies. We had no forward contracts or options at ~~September~~March 3031, ~~2017~~2018 and ~~2016~~2017.

Other

The carrying amounts for cash and cash equivalents, accounts receivable and accounts payable and accrued liabilities shown in the Condensed Consolidated Balance Sheets approximate fair value at ~~September~~March 3031, ~~2017~~2018 due to the generally short maturities of these items. At ~~September~~March 3031, ~~2017~~2018, we invested primarily in short-term dollar denominated bank deposits. We have the ability and expect to hold our investments to maturity.

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ITEM 4. CONTROLS AND PROCEDURES

Evaluation of Disclosure Controls and Procedures

Disclosure controls and procedures are designed to provide reasonable assurance that information required to be disclosed by us in reports filed or submitted under the Securities Exchange Act of 1934, as amended (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 provide reasonable assurance that information required to be disclosed under the Exchange Act is accumulated and communicated to management, including its principal executive and financial officers, as appropriate to allow timely decisions regarding required disclosure. There are inherent limitations to the effectiveness of any system of disclosure controls and procedures, including the possibility of human error and the circumvention or overriding of the controls and procedures. Accordingly, even effective disclosure controls and procedures can only provide reasonable assurance of achieving their control objectives.

As of ~~September~~March 3031, ~~2017~~2018, we have carried out an evaluation under the supervision of, and with the participation of our management, including our Chief Executive Officer and Chief Financial Officer, of the effectiveness of our disclosure controls and procedures as defined in Rules 13a-15(e) and 15d-15(e) of the Exchange Act. Based on our evaluation, our Chief Executive Officer and Chief Financial Officer concluded that, as of ~~September~~March 3031, ~~2017~~2018, our disclosure controls and procedures were effective in providing the reasonable assurance described above.

Changes in Internal Control over Financial Reporting

There were no changes in our internal control over financial reporting (as defined in Rules 13a-15(f) and 15d-15(f) under the Exchange Act) during the quarterly period ended ~~September~~March 3031, ~~2017~~2018, that materially affected, or is reasonably likely to materially affect, our internal control over financial reporting.

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PART II. OTHER INFORMATION

ITEM 1. LEGAL PROCEEDINGS

For information regarding legal proceedings, see the discussion under the caption “Contingencies” in Note 13 -– Contingencies, Commitments and Other Circumstances, of our “Notes to Condensed Consolidated Financial Statements” in Item 1 of Part I of this Form 10-Q, which information from Note 13 is incorporated by reference herein.

ITEM 1A. RISK FACTORS

~~Except~~There ~~as set forth below, there~~ have been no material changes to the risk factors involving us from those previously disclosed in Item 1A of Part I included in our Annual Report on Form 10-K for the fiscal year ended December 31, ~~2016~~2017.

We face a risk of non-compliance with certain covenants in our credit facilities.

We are subject to a number of financial and other covenants under our credit facilities, including a Maximum Total Leverage Ratio and a Minimum Interest Coverage Ratio. On March 31, 2015, March 1, 2016, July 26, 2016 and March 3, 2017, we amended our 2014 Term Credit Agreement pursuant to a first amendment, third amendment, fourth amendment and fifth amendment and on November 6, 2017, we amended our 2014 Term Credit Agreement pursuant to a sixth amendment (the “Sixth Amendment”). These amendments, among other things, suspend the calculation of the Maximum Total Leverage Ratio and Minimum Interest Coverage Ratio for the period from December 31, 2014 through December 31, 2017 (the “Covenant Suspension Periods”) so that any failure by us to comply with the Maximum Total Leverage Ratio or Minimum Interest Coverage Ratio covenants during the Covenant Suspension Periods will not be deemed to result in a default or event of default. Prior to obtaining the Sixth Amendment, we did not expect to be in compliance with the Maximum Total Leverage Ratio and Minimum Interest Coverage Ratio for the period from September 30, 2017 through December 31, 2018.

We can provide no assurance that we will remain in compliance with our financial covenants in the periods following the completion of the Covenant Suspension Periods or that we would be successful in obtaining additional waivers or amendments to these covenants should they become necessary. Under the Sixth Amendment, the Maximum Total Leverage Ratio will be 5.50 to 1.00 as of March 31, 2018 and will decrease to 4.50 to 1.00 as of June 30, 2018, 4.25 to 1.00 as of September 30, 2018 and 3.00 to 1.00 as of March 31, 2019, and thereafter. The Minimum Interest Coverage Ratio will be 1.75 to 1.00 as of March 31, 2018 and will increase to 2.00 to 1.00 as of June 30, 2018, decrease to 1.50 to 1.00 as of December 31, 2018 and increase to 2.75 to 1.00 as of March 31, 2019, and thereafter. If our results of operations do not improve in the fourth quarter of 2017 and into 2018, we will be unable to meet our required financial covenants.

In order to ensure future compliance with our financial covenants, we may elect to prepay our credit agreement indebtedness by accessing capital markets or with cash on hand. However, we can provide no assurance that we will be successful in accessing capital markets on terms we consider favorable or reducing costs in amounts sufficient to comply with our financial covenants. Moreover, future prepayments or refinancing of the balance of the 2014 Term Credit Agreement will require us to pay a prepayment premium equal to the “makewhole” amount. If a prepayment is made on or before September 30, 2018, the makewhole amount will be calculated as the present value of all interest payments that would have been made on the amount prepaid from the date of the prepayment to June 15, 2019 at a rate per annum equal to the sum of the applicable margin on the date of the prepayment plus the greater of 1.25 percent and the Eurodollar rate in effect on the date of the repayment. If a prepayment is made after September 30, 2018, the makewhole amount will be calculated as the present value of all interest payments that would have been made on the amount prepaid from the date of the prepayment to December 15, 2019 at a rate per annum equal to the sum of the applicable margin on the date of the prepayment plus the greater of 1.25 percent and the Eurodollar rate in effect on the date of the repayment.

Even if we successfully comply with our financial covenants, we may suffer adverse consequences if our unused availability under our 2013 ABL Credit Facility drops below certain levels. If our unused availability under the 2013 ABL Credit Facility is less than the greater of (i) 15 percent of the revolving commitments or $15.0 million for five consecutive days, or (ii) 12.5 percent of the revolving commitments or $12.5 million at any time, we are subject to increased reporting requirements, the administrative agent will have exclusive control over any deposit account, we will not have any right of access to, or withdrawal from, any deposit account, or any right to direct the disposition of funds in any deposit account, and amounts in any deposit account will be applied to reduce the outstanding amounts under the 2013 ABL Credit Facility. In addition, if our unused availability under the 2013 ABL Credit Facility is less than the amounts described in the preceding sentence, we would be required to comply with a Minimum Fixed Charge Coverage Ratio financial covenant.

Our unused availability under the 2013 ABL Credit Facility was $32.5 million at September 30, 2017. On November 6, 2017, we borrowed an additional $17.0 million under the 2013 ABL Credit Facility. We do not expect our availability under the 2013 ABL Credit Facility to drop to levels which would require us to comply with the Minimum Fixed Charge Coverage Ratio covenant over the next 12 months. However, if the Minimum Fixed Charge Coverage Ratio were to become applicable, we would not expect to be in compliance with this covenant.

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A default under the 2013 ABL Credit Facility would permit the lenders to terminate their commitment to make cash advances or issue letters of credit, require us to immediately repay any outstanding cash advances with interest and require us to cash collateralize outstanding letter of credit obligations. A default under the 2014 Term Credit Agreement would permit the lenders to require immediate repayment of all principal, interest, fees and other amounts payable thereunder. If the maturity of our credit agreement indebtedness were accelerated, we may not have sufficient funds to pay such indebtedness. In such an event, our lenders would be entitled to proceed against the collateral securing the indebtedness, which includes substantially all of our assets, to the extent permitted by the credit agreements and applicable law.

We are evaluating options to extend, modify or refinance the 2013 ABL Credit Facility. However, there can be no assurance that we will be able to extend, modify or negotiate acceptable refinancing terms prior to the expiration of the 2013 ABL Credit Facility on August 7, 2018.

ITEM 2. UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS

The following table provides information about purchases of our common stock by us during the quarter ended ~~September~~March 3031, ~~2017~~2018:

	TotalNumber ofSharesPurchased (1)	AveragePrice Paid PerShare (2)		Total Numberof SharesPurchased asPart ofPubliclyAnnouncedPlans orPrograms	Maximum Number(or ApproximateDollar Value) ofShares That MayYet Be PurchasedUnder the Plans orPrograms
July 1, 2017 - July 31, 2017	11,706	$	2.45	—	—
January 1, 2018 – January 31, 2018	5,919	$	1.27	—	—
August 1, 2017 - August 31, 2017	2,038	2.19		—	—
February 1, 2018 – February 28, 2018	—	—		—	—
September 1, 2017 - September 30, 2017	317	2.24		—	—
March 1, 2018 – March 31, 2018	22,980	0.84		—	—
Total	1428,~~061~~899	$	20.4193	—	—

(1) Represents shares of common stock acquired from certain of our officers and key employees under the share withholding provisions of our 2010 Stock and Incentive Compensation Plan and our 2017 Stock and Incentive Compensation Plan for the payment of taxes associated with the vesting of shares of restricted stock and restricted stock units granted under such plan.

(2) The price paid per common share represents the closing sales price of a share of our common stock, as reported in the ~~New~~NYSE ~~York~~composite ~~Stock~~transactions ~~Exchange~~or ~~composite~~in ~~transactions~~the over-the-counter market, on the day that the stock was acquired by us.

ITEM 3. DEFAULTS UPON SENIOR SECURITIES

Not applicable.

ITEM 4. MINE SAFETY DISCLOSURES

Not applicable.

ITEM 5. OTHER INFORMATION

OnNot November 6, 2017, the Company amended the Credit Agreement dated December 15, 2014 (as amended by the First Amendment dated as of March 31, 2015, the Second Amendment dated as of September 28, 2015, the Resignation of Administrative Agent and Appointment of Administrative Agent Agreement dated as of February 4, 2016, the Third Amendment dated as of March 1, 2016, the Fourth Amendment dated as of July 26, 2016 and the Fifth Amendment dated as of March 3, 2017 (the “Fifth Amendment”), the “2014 Term Credit Agreement”), pursuant to the Sixth Amendment thereto dated as of November 6, 2017 (the “Sixth Amendment”), by and among the Company, as borrower, the guarantors from time to time party thereto, the lenders from time to time party thereto, and Cortland Capital Market Services LLC, as administrative agentapplicable.

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The interest rate in effect at September 30, 2017 under the 2014 Term Credit Agreement was 11 percent, which consisted of an applicable margin of 9.75 percent for Eurodollar Rate loans plus a LIBOR floor of 1.25 percent. Beginning with the date on which the additional term loan is funded (the “Sixth Amendment Funding Date”), the interest rate will increase to 13 percent, consisting of an applicable margin of 11.75 percent for Eurodollar Rate loans plus a LIBOR floor of 1.25 percent. Beginning September 30, 2018, the applicable margin will increase an additional 100 basis points each quarterly period until maturity.

Under the 2014 Term Credit Agreement, with respect to prepayments made from inception of the term loan through September 30, 2017, the Company has not been required to pay prepayment premiums in respect of the “makewhole amount.” However, future prepayments or refinancing of the balance of the 2014 Term Loan Facility will require the Company to pay a prepayment premium equal to the makewhole amount and the repayment fee described below. Pursuant to the Sixth Amendment and beginning with the Sixth Amendment Funding Date, if a prepayment is made on or before September 30, 2018, the makewhole amount will be calculated as the present value of all interest payments that would have been made on the amount prepaid from the date of the prepayment to June 15, 2019 at a rate per annum equal to the sum of the applicable margin on the date of the prepayment plus the greater of 1.25 percent and the Eurodollar rate in effect on the date of the repayment. If a prepayment is made after September 30, 2018, the makewhole amount will be calculated as the present value of all interest payments that would have been made on the amount prepaid from the date of the prepayment to December 15, 2019 at a rate per annum equal to the sum of the applicable margin on the date of the prepayment plus the greater of 1.25 percent and the Eurodollar rate in effect on the date of the repayment.

Under the 2014 Term Credit Agreement, the Company was also required to pay a repayment fee on the date of any prepayment and on the maturity date of the 2014 Term Loan Facility equal to 5.0 percent of the amount prepaid or 5.0 percent of the aggregate remaining outstanding principal balance on the maturity date. Pursuant to the Sixth Amendment and beginning with the Sixth Amendment Funding Date, the repayment fee will increase to 9.0 percent of the amount prepaid or 9.0 percent of the aggregate remaining outstanding principal balance on the maturity date.

The Sixth Amendment suspends compliance with the Maximum Total Leverage Ratio and the Minimum Interest Coverage Ratio covenants through December 31, 2017. Pursuant to the Fifth Amendment, the covenant suspension period currently runs through the quarterly calculation period ending June 30, 2017. Any failure by the Company to comply with such financial covenants during the covenant suspension period will not be deemed to result in a default or event of default under the 2014 Term Credit Agreement. In addition, under the Sixth Amendment, the Maximum Total Leverage Ratio will be 5.50 to 1.00 as of March 31, 2018 and will decrease to 4.50 to 1.00 as of June 30, 2018, 4.25 to 1.00 as of September 30, 2018 and 3.00 to 1.00 as of March 31, 2019, and thereafter. The Minimum Interest Coverage Ratio will be 1.75 to 1.00 as of March 31, 2018, will increase to 2.00 to 1.00 as of June 30, 2018, decrease to 1.50 to 1.00 as of December 31, 2018 and increase to 2.75 to 1.00 as of March 31, 2019, and thereafter. The Sixth Amendment also provides that, for the four-quarter period ending March 31, 2018, Consolidated EBITDA shall be equal to the sum of Consolidated EBITDA for the quarterly periods ending December 31, 2017 and March 31, 2018 multiplied by two, and, for the four-quarter period ending June 30, 2018, Consolidated EBITDA shall be equal to the annualized sum of Consolidated EBITDA for the quarterly periods ending December 31, 2017, March 31, 2018 and June 30, 2018.

A copy of the Sixth Amendment is attached hereto as Exhibit 10.1 and incorporated into this Item 5 by reference.

KKR Credit Advisors (US) LLC, which serves as sole lead arranger and sole bookrunner under the 2014 Term Credit Agreement, and certain of its affiliates beneficially own 10,125,410 shares of the Company's common stock.

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ITEM 6. EXHIBITS

The following documents are included as exhibits to this Form 10-Q. Those exhibits below incorporated by reference herein are indicated as such by the information supplied in the parenthetical thereafter. If no parenthetical appears after an exhibit, such exhibit is filed herewith.

ExhibitNumber	Description
10.1	Sixth Amendment to Credit Agreement dated as of November 6, 2017, by and among Willbros Group, Inc., as borrower, certain subsidiary guarantors party thereto, the Lender party thereto, KKR Credit Advisors (US) LLC, as arranger, and Cortland Capital Market Services LLC, as administrative agent.
2	Agreement and Plan of Merger dated as of March 27, 2018 among Primoris Services Corporation, Waco Acquisition Vehicle, Inc. and Willbros Group, Inc. (filed as Exhibit 2 to our current report on Form 8-K dated March 26, 2018, filed March 28, 2018).*
3	Amended and Restated Bylaws of Willbros Group, Inc., a Delaware corporation (filed as Exhibit 3.3 to our report on Form 10-K for the year ended December 31, 2017, filed March 30, 2018).
10.1	Limited Forbearance Agreement dated as of March 27, 2018 to ABL Credit Agreement (filed as Exhibit 10.1 to our current report on Form 8-K dated March 26, 2018, filed March 28, 2018).
10.2	Forbearance Agreement dated as of March 27, 2018 to Credit Agreement (filed as Exhibit 10.2 to our current report on Form 8-K dated March 26, 2018, filed March 28, 2018).
10.3	Seventh Amendment to Credit Agreement dated as of March 27, 2018 (filed as Exhibit 10 to our current report on Form 8-K dated March 27, 2018, filed March 29, 2018).
31.1	Certification of Chief Executive Officer pursuant to Rule 13a-14(a) of the Securities Exchange Act of 1934, as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
31.2	Certification of Chief Financial Officer pursuant to Rule 13a-14(a) of the Securities Exchange Act of 1934, as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
32.1	Certification of Chief Executive Officer pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
32.2	Certification of Chief Financial Officer pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
101.INS	XBRL Instance Document.
101.SCH	XBRL Taxonomy Extension Schema Document.
101.CAL	XBRL Taxonomy Extension Calculation Linkbase Document.
101.DEF	XBRL Taxonomy Extension Definition Linkbase Document.
101.LAB	XBRL Taxonomy Extension Label Linkbase Document.
101.PRE	XBRL Taxonomy Extension Presentation Linkbase Document.

54* Schedules and exhibits may have been omitted pursuant to Item 601(b)(2) of Regulation S-K. The Company hereby undertakes to furnish supplementally copies of any of the omitted schedules or exhibits upon request by the U.S. Securities and Exchange Commission; provided, however, that the Company may request confidential treatment pursuant to Rule 24b-2 of the Exchange Act for any schedules or exhibits so furnished.

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SIGNATURE

Pursuant to the requirements 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.

	WILLBROS GROUP, INC.
Date: November 8, 2017	By:	/s/ Jeffrey B. Kappel
Date: May 9, 2018	By:	/s/ Jeffrey B. Kappel
		Jeffrey B. Kappel
		Senior Vice President and Chief Financial Officer(Principal Financial Officer)

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