UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, D. C. 20549

FORM 10-Q

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

For the quarterly period ended:~~March 31, 2016~~June 30, 2016

☐	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: 0-27140

NORTHWEST PIPE COMPANY

(Exact name of registrant as specified in its charter)

OREGON

93-0557988

(State or other jurisdiction of

incorporation or organization)

(I.R.S. Employer

Identification No.)

5721 SE Columbia Way

Suite 200

Vancouver, Washington 98661

(Address of principal executive offices and zip code)

360-397-6250

(Registrant’s telephone number including area code)

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 ☒ 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 ☒ No ☐

Indicate by check mark whether the Registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, or a smaller reporting company. See definitions of “large accelerated filer”, “accelerated filer”, and “smaller reporting company” in Rule 12b-2 of the Exchange Act. (Check one):


Large accelerated filer	☐	Accelerated filer	☒

Non-accelerated filer	☐	Smaller reporting company	☐

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). Yes ☐ No ☒


Common Stock, par value $.01 per share	~~9,573,371~~9,596,335
(Class)	(Shares outstanding at~~April~~July 29, ~~2016~~2016)

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NORTHWEST PIPE COMPANY

FORM 10-Q

INDEX


	Page
PART I - FINANCIAL INFORMATION

Item 1. Financial Statements (Unaudited):

Condensed Consolidated Balance Sheets as of ~~March 31,~~June 30, 2016 and December 31, 2015	12

Condensed Consolidated Statements of Operations for the three and six months ended ~~March 31,~~June 30, 2016 and 2015	23

Condensed Consolidated Statements of Comprehensive Loss for the three and six months ended ~~March 31,~~June 30, 2016 and 2015	34

Condensed Consolidated Statements of Cash Flows for the ~~three~~six months ended ~~March 31,~~June 30, 2016 and 2015	45

Notes to Condensed Consolidated Financial Statements	56

Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations	1417

Item 3. Quantitative and Qualitative Disclosures About Market Risk	1822

Item 4. Controls and Procedures	1822

PART II - OTHER INFORMATION

Item 1. Legal Proceedings	1822

Item 1A. Risk Factors	1822

Item 5. Other Information	23

Item 6. Exhibits	1923

Signatures	2024

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Part ~~I -~~I - Financial Information

Item1. Financial Statements (unaudited):

NORTHWEST PIPE COMPANY

CONDENSEDCONSOLIDATED BALANCE SHEETS

(Unaudited)

(In thousands, except share and per share data)

	March 31, 2016			December 31, 2015			June 30, 2016			December 31, 2015
Assets
Current assets:
Cash and cash equivalents	$	9,402		$	10,309		$	9,065		$	10,309
Trade and other receivables, less allowance for doubtful accounts of $743 and $751		21,969			27,567
Trade and other receivables, less allowance for doubtful accounts of $571 and $751								16,835			27,567
Costs and estimated earnings in excess of billings on uncompleted contracts		41,409			42,592			47,894			42,592
Inventories		29,379			29,475			25,542			29,475
Refundable income taxes		3,441			3,413			349			3,413
Assets held for sale								6,607			-
Prepaid expenses and other		1,454			1,923			1,121			1,923
Total current assets		107,054			115,279			107,413			115,279
Property and equipment, less accumulated depreciation and amortization of $88,613 and $86,451		130,198			131,848
Property and equipment, less accumulated depreciation and amortizationof $81,043 and $86,451								121,568			131,848
Other assets		11,958			12,253			11,800			12,253
Total assets	$	249,210		$	259,380		$	240,781		$	259,380

Liabilities and Stockholders’ Equity
Current liabilities:
Current portion of capital lease obligations	$	366		$	340		$	384		$	340
Accounts payable		3,739			4,739			4,976			4,739
Accrued liabilities		15,488			15,971			14,271			15,971
Billings in excess of costs and estimated earnings on uncompleted contracts		3,771			520			929			520
Total current liabilities		23,364			21,570			20,560			21,570
Capital lease obligations, less current portion		667			718			739			718
Deferred income taxes		5,473			5,124			5,344			5,124
Pension and other long-term liabilities		12,526			14,408			12,450			14,408
Total liabilities		42,030			41,820			39,093			41,820

Commitments and contingencies (Note 5)
Commitments and contingencies (Note 6)

Stockholders’ equity:
Preferred stock, $.01 par value, 10,000,000 shares authorized, none issued or outstanding		-			-
Common stock, $.01 par value, 15,000,000 shares authorized, 9,573,371 and 9,564,752 shares issued and outstanding		96			96
Preferred stock, $.01 par value, 10,000,000 shares authorized, none issued oroutstanding								-			-
Common stock, $.01 par value, 15,000,000 shares authorized, 9,596,335 and 9,564,752shares issued and outstanding								96			96
Additional paid-in-capital		117,054			117,819			117,689			117,819
Retained earnings		91,600			101,183			85,358			101,183
Accumulated other comprehensive loss		(1,570	)		(1,538	)		(1,455	)		(1,538	)
Total stockholders’ equity		207,180			217,560			201,688			217,560
Total liabilities and stockholders’ equity	$	249,210		$	259,380		$	240,781		$	259,380

The accompanying notes are an integral part of these condensed consolidated financial statements.

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NORTHWEST PIPE COMPANY

CONDENSEDCONSOLIDATED STATEMENTS OF OPERATIONS

(Unaudited)

(In thousands, except per share amounts)

	Three Months Ended March 31,						Three Months Ended June 30,						Six Months Ended June 30,
	2016			2015			2016			2015			2016			2015

Net sales	$	33,928		$	84,865		$	42,061		$	53,846		$	75,989		$	138,711
Cost of sales		39,365			80,974			44,223			56,439			83,588			137,413
Gross profit (loss)		(5,437	)		3,891			(2,162	)		(2,593	)		(7,599	)		1,298
Selling, general and administrative expense		4,599			6,974			4,091			5,452			8,690			12,426
Impairment of Water Transmission goodwill								-			5,282			-			5,282
Operating loss		(10,036	)		(3,083	)		(6,253	)		(13,327	)		(16,289	)		(16,410	)
Other income		40			44
Other income (expense)								(4	)		14			35			58
Interest income		-			82			3			81			3			163
Interest expense		(119	)		(417	)		(119	)		(286	)		(237	)		(703	)
Loss before income taxes		(10,115	)		(3,374	)		(6,373	)		(13,518	)		(16,488	)		(16,892	)
Income tax benefit		(532	)		(1,273	)		(131	)		(1,439	)		(663	)		(2,712	)
Net loss	$	(9,583	)	$	(2,101	)	$	(6,242	)	$	(12,079	)	$	(15,825	)	$	(14,180	)

Basic loss per share	$	(1.00	)	$	(0.22	)

Diluted loss per share	$	(1.00	)	$	(0.22	)
Net loss per share:
Basic and diluted							$	(0.65	)	$	(1.26	)	$	(1.65	)	$	(1.48	)

Shares used in per share calculations:
Basic		9,572			9,553

Diluted		9,572			9,553
Basic and diluted								9,580			9,557			9,576			9,555

The accompanying notes are an integral part of these condensed consolidated financial statements.

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NORTHWEST PIPE COMPANY

CONDENSEDCONSOLIDATED STATEMENTS OF COMPREHENSIVE LOSS

(Unaudited)

(In thousands)

	Three Months Ended March 31,						Three Months Ended June 30,						Six Months Ended June 30,
	2016			2015			2016			2015			2016			2015

Net loss	$	(9,583	)	$	(2,101	)	$	(6,242	)	$	(12,079	)	$	(15,825	)	$	(14,180	)

Other comprehensive income (loss):
Pension liability adjustment, net of tax		100			109			99			109			199			218
Deferred gain (loss) on cash flow derivatives, net of tax		(132	)		(15	)
Other comprehensive income (loss)		(32	)		94
Deferred income (loss) on cash flow derivatives, net of tax								16			(16	)		(116	)		(31	)
Other comprehensive income								115			93			83			187

Comprehensive loss	$	(9,615	)	$	(2,007	)	$	(6,127	)	$	(11,986	)	$	(15,742	)	$	(13,993	)

The accompanying notes are an integral part of these condensed consolidated financial statements.

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NORTHWEST PIPE COMPANY

CONDENSEDCONSOLIDATED STATEMENTS OF CASH FLOWS

(Unaudited)

(In thousands)

	Three Months Ended March 31,						Six Months Ended June 30,
	2016			2015			2016			2015
Cash flows from operating activities:
Net loss	$	(9,583	)	$	(2,101	)	$	(15,825	)	$	(14,180	)
Adjustments to reconcile net loss to net cash provided by operating activities:
Adjustments to reconcile net loss to net cash provided byoperating activities:
Depreciation		2,181			2,630			4,979			4,651
Impairment of goodwill								-			5,282
Amortization of intangible assets		131			149			262			280
Provision for doubtful accounts		(8	)		(83	)		(180	)		(113	)
Amortization of debt issuance costs		41			68			83			136
Deferred income taxes		(602	)		(552	)		(732	)		888
Stock based compensation expense		178			650			813			1,133
Unrealized (gain) loss on foreign currency forward contracts		415			(91	)		430			(50	)
Adjustments to contingent consideration								(599	)		62
Other, net		(10	)		45			(10	)		(3	)
Changes in operating assets and liabilities:
Trade and other receivables, net		5,606			23,630			10,912			27,052
Insurance settlements		-			2,625			-			2,625
Costs and estimated earnings in excess of billings on uncompleted contracts, net		4,434			(8,079	)
Costs and estimated earnings in excess of billings onuncompleted contracts, net								(4,893	)		(5,849	)
Inventories		119			11,502			3,968			21,931
Refundable income taxes		12			774			3,104			(2,084	)
Prepaid expenses and other assets		273			(603	)		581			667
Accounts payable		(735	)		(5,295	)		515			(356	)
Accrued and other liabilities		(1,263	)		(696	)		(1,878	)		(307	)
Net cash provided by operating activities		1,189			24,573			1,530			41,765
Cash flows from investing activities:
Additions to property and equipment		(736	)		(3,689	)		(1,336	)		(6,016	)
Other investing activities		-			161
Proceeds from sale of business								-			4,300
Proceeds from sale of property & equipment								20			55
Collections on notes receivable								-			1,080
Net cash used in investing activities		(736	)		(3,528	)		(1,316	)		(581	)
Cash flows from financing activities:
Tax withholdings related to net share settlements of restricted stock and performance stock awards		(31	)		(423	)
Tax withholdings related to net share settlementsof restricted stock and performance stock awards								(31	)		(423	)
Borrowings on line of credit		-			34,000			-			56,250
Repayments on line of credit		-			(54,765	)		-			(94,785	)
Payments on capital lease obligations								(194	)		(2,084	)
Payments of contingent consideration		(1,233	)		-			(1,233	)		-
Payments on capital lease obligations		(96	)		(287	)
Other financing activities		-			19			-			19
Net cash used in financing activities		(1,360	)		(21,456	)		(1,458	)		(41,023	)
Change in cash and cash equivalents		(907	)		(411	)		(1,244	)		161
Cash and cash equivalents, beginning of period		10,309			527			10,309			527
Cash and cash equivalents, end of period	$	9,402		$	116		$	9,065		$	688

Non-cash investing activity:
Non-Cash Investing Activity:
Accrued property and equipment purchases	$	131		$	479		$	118		$	718
Capital lease additions	$	71			-			259			-

The accompanying notes are an integral part of these condensed consolidated financial statements.

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NORTHWEST PIPE COMPANY

NOTESTO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

1.	Basis of Presentation

The condensed consolidated financial statements include the accounts of Northwest Pipe Company (the “Company”) and its subsidiaries in which the Company exercises control as of the financial statement date. Intercompany accounts and transactions have been eliminated.

The accompanying unaudited condensed consolidated financial statements have been prepared in conformity with accounting principles generally accepted in the United States of America. The financial information as of December 31, 2015 is derived from the audited consolidated financial statements presented in the Company’s Annual Report on Form 10-K for the year ended December 31, 2015 (the “2015 Form 10-K”). Certain information ~~and~~or footnote disclosures normally included in consolidated financial statements prepared in accordance with accounting principles generally accepted in the United States of America have been condensed or omitted, pursuant to the rules and regulations of the Securities and Exchange Commission (the “SEC”). In the opinion of management, the accompanying condensed consolidated financial statements include all adjustments necessary (which are of a normal and recurring nature) for the fair statement of the results of the interim periods presented. The condensed consolidated financial statements should be read in conjunction with the consolidated financial statements and notes thereto together with management’s discussion and analysis of financial condition and results of operations contained in the Company’s 2015 Form 10-K.

Certain amounts from the prior year financial statements have been reclassified in order to conform to the current year presentation.

Operating results for the three and six months ended ~~March 31,~~June 30, 2016 are not necessarily indicative of the results that may be expected for the entire fiscal year ending December 31, 2016.

2.	2. Inventories

Inventories are stated at the lower of cost or market and consist of the following (in thousands):

March 31,
2016

December 31,
2015

Current inventories:

Raw materials
$ 22,370 $ 21,486
Work-in-process
1,686 1,901
Finished goods
2,902 3,641
Supplies
2,421 2,447
29,379 29,475
Non-current inventories:

Finished goods
800 823
Total inventories
$ 30,179 $ 30,298

	June 30, 2016		December 31, 2015
Short-term inventories:
Raw materials	$	21,302	$	21,486
Work-in-process		1,213		1,901
Finished goods		631		3,641
Supplies		2,396		2,447
Total short-term inventories		25,542		29,475

Long-term inventories:
Finished goods		789		823
Total inventories	$	26,331	$	30,298

Long-term inventories are recorded in other assets.

3. Assets Held for Sale

The Company classifies assets as held for sale when all the following criteria are met: (i) management, having the authority to approve the action, commits to a plan to sell the asset or disposal group; (ii) the asset or disposal group is available for immediate sale in its present condition; (iii) an active program to locate a buyer and other actions required to complete the plan to sell the asset or disposal group have been initiated; (iv) the sale of the asset or disposal group is probable, and transfer of the asset or disposal group is expected to qualify for recognition as a completed sale, within one year, with a few exceptions; and (v) the asset or disposal group is being actively marketed for sale at a price that is reasonable, in relation to its current fair value.

As of June 30, 2016, assets held for sale of $6.6 million consists of a disposal group comprised of real estate and certain equipment at the Company's Denver, Colorado location, which is part of the Water Transmission segment. The decision to close the Denver facility and sell the property was driven primarily by the need to address the significant imbalance between production capacity and demand in the steel water pipe market. As the fair value less costs to sell of the disposal group exceeds the carrying value, no impairment charge has been recorded in the accompanying financial statements. Assets are no longer depreciated once classified as held for sale.

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For the three and six months ended June 30, 2016, pre-tax loss generated by the Denver facility was $1.4 million and $2.7 million, respectively. For the three and six months ended June 30, 2015, pre-tax loss of $.2 million and pre-tax income of $0.4 million, respectively, was generated by the Denver facility.

4. Fair Value Measurements

The Company records its financial assets and liabilities at fair value, which is defined as the price that would be received to sell an asset or paid to transfer a liability, in the principal or most advantageous market for the asset or liability, in an orderly transaction between market participants at the measurement date.

The authoritative guidance establishes a fair value hierarchy that prioritizes the inputs to valuation techniques used to measure fair value into three broad levels. These levels are: Level 1 (inputs are quoted prices in active markets for identical assets or liabilities); Level 2 (inputs are other than quoted prices that are observable, either directly or indirectly through corroboration with observable market data); and Level 3 (inputs are unobservable, with little or no market data that exists, such as internal financial forecasts). The Company is required to maximize the use of observable inputs and minimize the use of unobservable inputs when measuring fair value.

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The following table summarizes information regarding the Company’s financial assets and financial liabilities that are measured at fair value (in thousands):

Balance at

Description

March 31, 2016

Level 1

Level 2

Level 3

Financial assets

Deferred compensation plan
$ 6,309 $ 4,998 $ 1,311 $ -

Financial liabilities

Contingent consideration
$ (1,721 ) $ - $ - $ (1,721 )
Derivatives
(250 ) - (250 ) -
Total liabilities
$ (1,971 ) $ - $ (250 ) $ (1,721 )

Description	Balance at June 30, 2016			Level 1		Level 2			Level 3
Financial assets
Deferred compensation plan	$	6,358		$	5,025	$	1,333		$	-

Financial liabilities
Contingent consideration	$	(1,142	)	$	-	$	-		$	(1,142	)
Derivatives		(250	)		-		(250	)		-
Total liabilities	$	(1,392	)	$	-	$	(250	)	$	(1,142	)

	Balance at
Description	December 31, 2015			Level 1		Level 2		Level 3
Description											Balance at December 31, 2015			Level 1		Level 2		Level 3
Financial assets
Deferred compensation plan	$	6,357		$	5,075	$	1,282	$	-		$	6,357		$	5,075	$	1,282	$	-
Derivatives		296			-		296		-			296			-		296		-
Total assets	$	6,653		$	5,075	$	1,578	$	-		$	6,653		$	5,075	$	1,578	$	-

Financial liabilities
Contingent consideration	$	(2,974	)	$	-	$	-	$	(2,974	)	$	(2,974	)	$	-	$	-	$	(2,974	)

The deferred compensation plan assets consist of cash and several publicly traded stock and bond mutual funds, valued using quoted market prices in active markets classified as Level 1 within the fair value hierarchy, as well as securities that are not actively traded on major exchanges, valued using the Net Asset Value (“NAV”) of the underlying investments classified as Level 2 within the fair value hierarchy.

The Company’s derivatives consist of foreign currency forward contracts, which are accounted for as cash flow hedges, and are valued using various pricing models or discounted cash flow analyses that incorporate observable market parameters, such as interest rate yield curves and currency rates, classified as Level 2 within the valuation hierarchy. Derivative valuations incorporate credit risk adjustments that are necessary to reflect the probability of default by the counterparty or the Company.

The contingent consideration liability is associated with the acquisition of Permalok Corporation in December 2013 and represents the probability weighted average contingent payment as a percentage of high, mid, and low revenue projections. The inputs used to measure contingent consideration are classified as Level 3 within the valuation hierarchy. The valuation is not supported by market criteria and reflects the Company’s internal revenue forecasts. Changes in the fair value of the contingent consideration obligation will be reflected in cost of sales during the period the change occurs.

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The net carrying amounts of cash and cash equivalents, trade and other receivables, accounts payable, accrued liabilities and borrowings on line of credit approximate fair value due to the short-term nature of these instruments.

4
5. ~~Derivative Instruments and Hedging Activities~~
Derivative Instruments and Hedging Activities

The Company conducts business in various foreign countries and, from time to time, settles transactions in foreign currencies. The Company has established a program that utilizes foreign currency forward contracts to offset the risk associated with the effects of certain foreign currency exposures, typically arising from sales contracts denominated in Canadian currency. Instruments that do not qualify for cash flow hedge accounting treatment are remeasured at fair value on each balance sheet date and resulting gains and losses are recognized in income. As of ~~March 31,~~June 30, 2016 and December 31, 2015, all derivative contracts held by the Company were designated as cash flow hedges. As of ~~March 31,~~June 30, 2016 and December 31, 2015, the total notional amount of the derivative contracts designated as cash flow hedges was $6.3 million (CAD$8.2 million) and $6.3 million (CAD$8.7 million), respectively. Derivative assets are included within prepaid expenses and other current assets and derivative liabilities are included within accrued liabilities in the condensed consolidated balance sheets. All of the Company’s foreign currency forward contracts are subject to an enforceable master netting arrangement. The Company presents the assets and liabilities associated with its foreign currency forward contracts at their gross fair values within the condensed consolidated balance sheets.

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For each derivative contract entered into in which the Company seeks to obtain cash flow hedge accounting treatment, the Company formally documents all relationships between hedging instruments and hedged items, as well as its risk management objective and strategy for undertaking the hedge transaction, the nature of the risk being hedged, how the hedging instrument’s effectiveness in offsetting the hedged risk will be assessed prospectively and retrospectively, and a description of the method of measuring ineffectiveness. This process includes linking all derivatives to specific firm commitments or forecasted transactions and designating the derivatives as cash flow hedges. The Company also formally assesses, both at the hedge’s inception and on an ongoing basis, whether the derivative contracts that are used in hedging transactions are highly effective in offsetting changes in cash flows of hedged items. The effective portion of these hedged items is reflected in other comprehensive income in stockholders’ equity. If it is determined that a derivative contract is not highly effective, or that it has ceased to be a highly effective hedge, the Company will be required to discontinue hedge accounting with respect to that derivative contract prospectively.

All of the Company’s Canadian forward contracts have maturities of 12 months or less as of ~~March 31,~~June 30, 2016.

For the three and six months ended ~~March 31,~~June 30, 2016, gains (losses) recognized in net sales from derivative contracts not designated as hedging instruments were $5,000 and ~~March 31,~~($209,000), respectively. For the three and six months ended June 30, 2015, losses recognized in net sales from derivative contracts not designated as hedging instruments were ~~$212,000~~$26,000 and ~~$18,000,~~$44,000, respectively. At ~~March 31,~~June 30, 2016 and ~~March 31,~~June 30, 2015, there ~~were ($78,000)~~was $54,000 and ~~$21,000,~~$5,000, respectively, of unrealized pretax ~~gains (losses)~~loss on outstanding derivatives in accumulated other comprehensive loss. Substantially all of the amount in accumulated other comprehensive loss at ~~March 31,~~June 30, 2016 is expected to be reclassified to net sales within the next 12 months as a result of underlying hedged transactions also being recorded in net sales. See Note ~~10,~~11, “Accumulated Other Comprehensive Loss” for additional quantitative information regarding derivative gains and losses.

5.6.	Commitments and Contingencies

Portland Harbor Superfund

On December 1, 2000, a section of the lower Willamette River known as the Portland Harbor Site was included on the National Priorities List at the request of the United States Environmental Protection Agency (the “EPA”). While the Company’s Portland, Oregon manufacturing facility does not border the Willamette River, an outfall from the facility’s stormwater system drains into a neighboring property’s privately owned stormwater system and slip. Since the listing of the site, the Company was notified by the EPA and the Oregon Department of Environmental Quality (“ODEQ”) of potential liability under the Comprehensive Environmental Response, Compensation and Liability Act (“CERCLA”). In 2008, the Company was asked to file information disclosure reports with the EPA (CERCLA 104 (e) information request). A remedial investigation and feasibility study (“RI/FS”) of the Portland Harbor Site has been directed by a group of 14 potentially responsible parties known as the Lower Willamette Group (the “LWG”) under agreement with the EPA. The remedial investigation report was finalized in February 2016. The ~~draft~~ feasibility study (“FS”) was ~~submitted~~finalized in June 2016 by the ~~LWG to the~~ EPA, and identified multiple remedial alternatives. The EPA published its Proposed Plan for public comment in ~~March 2012. A revised draft FS submitted in 2015 identifies six possible remedial alternatives which range in estimated cost from approximately $790~~June 2016. The Proposed Plan recommends an Alternative Remedy that EPA believes will take 7 years and $745 million to ~~$2.5 billion and estimates it will take up to 18 years to implement the remedial work, depending on the selected alternative.~~construct. The ~~report~~Proposed Plan does not determine who is responsible for the costs of cleanup or how the cleanup costs will be allocated among the potentially responsible parties. ~~As of the date of this filing, the revised FS is pending approval of the EPA.~~

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In 2001, groundwater containing elevated volatile organic compounds (“VOCs”) was identified in one localized area of leased property adjacent to the Portland facility furthest from the river. Assessment work was conducted in 2002 and 2003 to further characterize the groundwater. In February 2005, the Company entered into a Voluntary Agreement for Remedial Investigation and Source Control Measures (the “Agreement”) with ODEQ. The Company performed RI work required under the Agreement and submitted a draft RI/Source Control Evaluation Report (“SCE”) in December 2005, a revised draft RI/SCE Report in January 2014, and a further revised RI/SCE Report in March 2015. In May 2015, and subsequently in August and October 2015, the Company received the EPA’s and ODEQ’s comments, respectively, requesting additional information and modifications to the revised RI/SCE Report, including the request to conduct additional groundwater sampling. The Company provided a Supplemental Groundwater Sampling Work Plan (“proposed Work Plan”) in December 2015. The DEQ and EPA provided comments to the proposed Work Plan in January 2016 and made additional requests in February 2016. The Company expects to provide a Final Supplemental Groundwater Sampling Work Plan in the ~~second~~third quarter of 2016.

Concurrent with the activities of the EPA and ODEQ, the Portland Harbor Natural Resources Trustee Council (“Trustees”) sent some or all of the same parties, including the Company, a notice of intent to perform a Natural Resource Damage Assessment (“NRDA”) for the Portland Harbor Site to determine the nature and extent of natural resource damages under CERCLA section 107. The Trustees for the Portland Harbor Site consist of representatives from several Northwest Indian Tribes, three federal agencies and one state agency. The Trustees act independently of the EPA and ODEQ. The Trustees have encouraged potentially responsible parties to voluntarily participate in the funding of their injury assessments and several of those parties have agreed to do so. In June 2014, the Company agreed to participate in the injury assessment process, which included funding $0.4 million of the assessment; of this amount, $0.2 million was paid in July 2014 and the remainder was paid in January 2015. The Company has not assumed any additional payment obligations or liabilities with the participation with the NRDA.

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The Company’s potential liability is a portion of the costs of the remedy the EPA will select for the entire Portland Harbor Superfund Site. The cost of that remedy is expected to be allocated among more than 100 potentially responsible parties. Because of the large number of responsible parties and the variability in the range of remediation alternatives, the Company is unable to estimate an amount or an amount within a range of costs for its obligation with respect to the Portland Harbor Site matters, and no further adjustment to the consolidated financial statements has been recorded as of the date of this filing. The Company has insurance policies for defense costs, as well as indemnification policies it believes will provide reimbursement for any share of the remediation assessed. However, the Company can provide no assurance that those policies will cover all of the costs which the Company may incur.

In December 2014, a federal district court approved settlements between the Company and two of its insurance carriers. The Company released its interests in the related insurance policies, and received $2.6 million in January 2015 for reimbursement of past indemnification and defense costs incurred by the Company associated with the Portland Harbor Site, substantially all of which reduced cost of sales in 2014. Notwithstanding these settlements, the Company continues to have insurance coverage for indemnification and defense costs related to the Portland Harbor Site as described above.

Houston EnvironmentalIssue

In connection with the Company’s sale of its oil country tubular goods (“OCTG”) business, a Limited Phase II Environmental Site Assessment was conducted at the Houston, Texas plant and completed in March 2014, which revealed the presence of VOCs in the groundwater and certain metals in the soil. In June 2014, the Company was accepted into the Texas Commission on Environmental Quality (“TCEQ”) Voluntary Cleanup Program (“VCP”) to address these issues and obtain a Certificate of Completion from TCEQ. The cost of any potential assessment and cleanup will not be covered by insurance. However, any costs incurred will be reimbursed by the purchaser of the OCTG business if the purchaser exercises its option to purchase the property under certain circumstances after the Certificate of Completion is obtained.

The proposed remediation approach includes a municipal ordinance to prevent consumption of shallow groundwater from beneath the property, thereby eliminating the need for more costly remediation measures. In February 2016, the Company submitted an application to the City of Houston under the municipal ordinance, and is currently in the process of satisfying the requirements of the City and TCEQ to obtain approval of the application.

While the final remediation approach has not yet been determined, the Company has completed an initial assessment and currently estimates that the future costs associated with the VCP will be between $0.2 million and ~~$2.2~~$1.6 million. At ~~March 31,~~June 30, 2016, the Company has a ~~$0.3~~$0.2 million accrual for remediation costs based on the low-end estimate of future costs using a probability-weighted analysis of remediation approaches, and estimates that completion of the VCP process will occur between the ~~second~~third quarter of 2017 and the ~~first~~second quarter of 2019.

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All Sites

The Company operates its facilities under numerous governmental permits and licenses relating to air emissions, storm water run-off, and other environmental matters. The Company’s operations are also governed by many other laws and regulations, including those relating to workplace safety and worker health, principally the Occupational Safety and Health Act and regulations there under which, among other requirements, establish noise and dust standards. The Company believes it is in material compliance with its permits and licenses and these laws and regulations, and the Company does not believe that future compliance with such laws and regulations will have a material adverse effect on its financial position, results of operations or cash flows.

From time to time, the Company is involved in litigation relating to claims arising out of its operations in the normal course of its business. The Company maintains insurance coverage against potential claims in amounts that are believed to be adequate. To the extent that insurance does not cover legal, defense, and indemnification costs associated with a loss contingency, such costs will be expensed as incurred. The Company believes that it is not presently a party to any other litigation, the outcome of which would have a material adverse effect on its business, financial condition, results of operations or cash flows.

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Guarantees

The Company has entered into certain stand-by letters of credit that total $2.0 million at ~~March 31,~~June 30, 2016. The stand-by letters of credit relate to workers’ compensation insurance.

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7. ~~Segment Information~~
Segment Information

The Company’s business is the manufacturing of welded steel pipe. Within this business, the Company’s operations are organized into two reportable segments: the Water Transmission Group and the Tubular Products Group. These reportable segments are based on the nature of the products and the manufacturing process. The two segments represent distinct business activities, which management evaluates based on segment gross profit and operating income. Transfers between segments in the periods presented were not material.

The Water Transmission Group manufactures large-diameter, high-pressure steel pipeline systems for use in water infrastructure applications, which are primarily related to drinking water systems. These products are also used for hydroelectric power systems, wastewater systems and other applications. In addition, the Water Transmission Group makes products for industrial plant piping systems and certain structural applications.

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The Tubular Products Group manufactures and markets smaller diameter, electric resistance welded steel pipe used in a wide range of applications, including energy, construction, agriculture and industrial systems.

	Three Months Ended March 31,						Three Months Ended June 30,						Six Months Ended June 30,
	2016			2015			2016			2015			2016			2015
	(in thousands)						(in thousands)
Net sales:
Water transmission	$	29,358		$	56,242		$	39,775		$	38,445		$	69,133		$	94,687
Tubular products		4,570			28,623			2,286			15,401			6,856			44,024
Total	$	33,928		$	84,865		$	42,061		$	53,846		$	75,989		$	138,711

Gross profit (loss):
Water transmission	$	(5,750	)	$	7,519		$	(1,272	)	$	1,255		$	(7,022	)	$	8,774
Tubular products		313			(3,628	)		(890	)		(3,848	)		(577	)		(7,476	)
Total	$	(5,437	)	$	3,891		$	(2,162	)	$	(2,593	)	$	(7,599	)	$	1,298


Operating income (loss):
Operating loss:
Water transmission(1)	$	(7,256	)	$	5,633		$	(2,648	)	$	(5,815	)	$	(9,904	)	$	(182	)
Tubular products		104			(4,617	)		(1,002	)		(4,254	)		(898	)		(8,871	)
Corporate		(2,884	)		(4,099	)		(2,603	)		(3,258	)		(5,487	)		(7,357	)
Total	$	(10,036	)	$	(3,083	)	$	(6,253	)	$	(13,327	)	$	(16,289	)	$	(16,410	)

(1) Operating loss for the Water Transmission Group for the three and six months ended June 30, 2015 includes the write-off of Water Transmission goodwill of $5.3 million.

78. Share-based Compensation

The Company has one active stock incentive plan for employees and directors: the 2007 Stock Incentive Plan, which provides for awards of stock options to purchase shares of common stock, stock appreciation rights, restricted and unrestricted shares of common stock, restricted stock units (RSUs) and performance share awards (PSAs). In addition, the Company has one inactive stock option plan, the 1995 Stock Option Plan for Nonemployee Directors, under which previously granted options remain outstanding.

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The Company recognizes compensation cost as service is rendered based on the fair value of the awards. The following table summarizes share-based compensation expense recorded (in thousands):

	Three Months Ended March 31,					Three Months Ended June 30,				Six Months Ended June 30,
	2016			2015		2016		2015		2016		2015

Cost of sales	$	(28	)	$	81	$	67	$	99	$	39	$	180
Selling, general and administrative expenses		206			569		568		384		774		953
Total	$	178		$	650	$	635	$	483	$	813	$	1,133

As of ~~March 31,~~June 30, 2016, unrecognized compensation expense related to the unvested portion of the Company’s RSUs and PSAs was ~~$.8~~$1.9 million, which is expected to be recognized over a weighted average period of .81.3 years.

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Stock Option Awards

A summary of the status of the Company’s stock options as of ~~March 31,~~June 30, 2016 and changes during the ~~three~~six months then ended is presented below:

Options
Outstanding

Weighted
Average
Exercise Price
per Share

Weighted
Average
Remaining
Contractual
Life

Aggregate
Intrinsic Value

(In thousands)

Balance, January 1, 2016
28,000 $ 25.21
Options granted
- -
Options exercised
- -
Options cancelled
(2,000 ) 28.31
Balance, June 30, 2016
26,000 24.97 3.53 $ -
Exercisable, June 30, 2016
26,000 24.97 3.53 $ -

Restricted Stock Units and PerformanceStockAwards

A summary of the status of the Company’s RSUs and PSAs as of ~~March 31,~~June 30, 2016 and changes during the ~~three~~six months then ended is presented below:

Number of RSUs and PSAs

Weighted Average Grant Date Fair Value

Balance, January 1, 2016
127,852 $ 38.87
RSUs and PSAs granted
- -
RSUs and PSAs vested
(12,212 ) 31.50
RSUs and PSAs canceled
(63,126 ) 36.93
Balance, March 31, 2016
52,514 42.91

Number of RSUs
and PSAs

Weighted Average
Grant Date Fair Value

Balance, January 1, 2016
127,852 $ 38.87
RSUs and PSAs granted
161,080 9.38
RSUs and PSAs vested
(12,212 ) 31.50
RSUs and PSAs canceled
(63,126 ) 36.93
Balance, June 30, 2016
213,594 17.62

RSUs and PSAs are measured at the estimated fair value on the date of grant. RSUs are service-based awards and vest according to vesting schedules, which range from immediate to ratably over a three-year period. PSAs are service-based awards that vest over a three-year period and have a market-based payout condition. Vesting of the market-based PSAs is dependent upon the performance of the market price of the Company’s stock relative to a peer group of companies. The unvested balance of RSUs and PSAs at ~~March 31,~~June 30, 2016 includes approximately 47,000 PSAs at a target level of performance; the actual number of common shares that will ultimately be issued will be determined by multiplying this number of PSAs by a payout percentage ranging from 0% to 200%.

Stock Awards

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For the six months ended June 30, 2016 and 2015, stock awards of 22,964 and 10,464 shares, respectively, were granted to non-employee directors, which vested immediately upon issuance. The Company recorded compensation expense based on the fair market value per share of the awards on the grant date of $9.58 and $21.02 in 2016 and 2015, respectively.

8~~. Income Taxes~~
9.
Income Taxes

The Company files income tax returns in the United States Federal jurisdiction, in a limited number of foreign jurisdictions, and in many state jurisdictions. Internal Revenue Service examinations have been completed for years prior to 2011. With few exceptions, the Company is no longer subject to U.S. Federal, state or foreign income tax examinations for years before 2012. The Company is currently under Colorado income tax audit for the years 2009 to 2013. It is reasonably possible that the Company will close the audit within the next 12-month period. Such resolution is not anticipated to have a significant impact on our results of operations. There are no other income tax audits in progress.

The Company had $4.9 million of unrecognized tax benefits at ~~March 31,~~June 30, 2016 and December 31, ~~2015, respectively.~~2015. The Company does not believe it is reasonably possible that the total amounts of unrecognized tax benefits will change in the following twelve months; however, actual results could differ from those currently expected. Effectively all the unrecognized tax benefits would affect the Company’s effective tax rate if recognized at some point in the future. The Company recognizes interest and penalties related to uncertain tax positions in income tax expense.

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The Company recorded an income tax benefit at an estimated effective tax rate of ~~5.3%~~2.1% and ~~37.7%~~4.0% for the three and six months ended ~~March 31,~~June 30, 2016, and ~~March 31, 2015, respectively. The~~an income tax benefit at an estimated effective tax rate of 10.6% and 16.1% for the three and six months ended ~~March 31,~~June 30, 2015. The Company’s effective tax benefit rate in the three and six months ended June 30, 2016 is significantly lower than statutory rates because the Company’s net operating losses from the period are subject to a valuation allowance.

10.	9. Loss per Share

Loss per basic and diluted weighted average common share outstanding were calculated as follows for the three and six months ended ~~March 31,~~June 30, 2016 and 2015 (in thousands, except per share data):

							Three Months Ended June 30,						Six Months Ended June 30,
	Three Months Ended March 31,						2016			2015			2016			2015
	2016			2015
Net loss	$	(9,583	)	$	(2,101	)	$	(6,242	)	$	(12,079	)	$	(15,825	)	$	(14,180	)

Basic weighted-average common shares outstanding		9,572			9,553			9,580			9,557			9,576			9,555
Effect of potentially dilutive common shares		-			-			-			-			-			-
Diluted weighted-average common shares outstanding		9,572			9,553			9,580			9,557			9,576			9,555

Loss per common share:
Loss per basic common share	$	(1.00	)	$	(0.22	)
Loss per diluted common share		(1.00	)		(0.22	)

Loss per basic and diluted common share							$	(0.65	)	$	(1.26	)	$	(1.65	)	$	(1.48	)

Due to the Company’s ~~net~~ loss in the three and six month periods ended ~~March 31,~~June 30, 2016 and 2015, the assumed exercise of stock options and the vesting of restricted stock units and performance stock awards using the treasury stock method would have had an antidilutive effect and were therefore excluded from the computation of diluted loss per share. The weighted average number of such antidilutive shares not included in the computation of diluted loss per share was ~~94,000~~209,000 and ~~204,000~~151,000 for the three and six month periods ended ~~March 31,~~June 30, 2016, and ~~2015, respectively.~~

188,000 and 196,000 for the three and six month periods ended June 30, 2015.

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110. ~~Accumulated Other Comprehensive Loss~~

Accumulated Other Comprehensive Loss

The following tables summarize changes in the components of accumulated other comprehensive loss during the ~~three~~six months ended ~~March 31,~~June 30, 2016 and ~~March 31,~~ 2015 (in thousands). All amounts are net of tax:

Defined Benefit
Pension Items

Gains (Losses) on
Cash Flow
Hedges

Total

Balance, December 31, 2015
$ (1,624 ) $ 86 $ (1,538 )

Other comprehensive income (loss) before reclassifications
63 (86 ) (23 )
Amounts reclassified from accumulated other comprehensive income (loss)
136 (30 ) 106
Net current period other comprehensive income (loss)
199 (116 ) 83

Balance, June 30, 2016
$ (1,425 ) $ (30 ) $ (1,455 )

Defined Benefit Pension Items

Gains (Losses) on Cash Flow Hedges

Total

Defined Benefit
Pension Items

Gains (Losses) on
Cash Flow
Hedges

Total

Balance, December 31, 2014
$ (1,862 ) $ 29 $ (1,833 ) $ (1,862 ) $ 29 $ (1,833 )

Other comprehensive income before reclassifications
56 61 117 111 48 159
Amounts reclassified from accumulated other comprehensive income (loss)
53 (76 ) (23 ) 107 (79 ) 28
Net current period other comprehensive income (loss)
109 (15 ) 94 218 (31 ) 187

Balance, March 31, 2015
$ (1,753 ) $ 14 $ (1,739 )
Balance, June 30, 2015
$ (1,644 ) $ (2 ) $ (1,646 )

The following table provides additional detail about accumulated other comprehensive income (loss) components that were reclassified to the condensed consolidated statement of operations during the ~~three~~six months ended ~~March 31,~~June 30, 2016 and 2015 (in thousands):

Three Months Ended March 31,

2016

2015

Details about Accumulated Other Comprehensive Income (Loss) Components

Amount reclassified from Accumulated Other Comprehensive Income (Loss)

Pension liability adjustment

Net periodic pension cost
$ (71 ) $ (85 )
Associated tax benefit
4 32
$ (67 ) $ (53 )

Deferred gain on cash flow derivatives

Gain on cash flow derivatives
$ 74 $ 122
Hedge ineffectiveness
- (1 )
Associated tax expense
(28 ) (45 )
$ 46 $ 76

Total reclassifications for the period
$ (21 ) $ 23

Six Months Ended June 30,

2016

2015

Details about Accumulated Other
Comprehensive Income (Loss) Components

Amount reclassified from Accumulated
Other Comprehensive Income (Loss)

Affected line item in the
Condensed Consolidated
Statement of Operations

Pension liability adjustment

Net periodic pension cost
$ (142 ) $ (170 )
Cost of sales
Associated tax benefit
6 63
Income tax benefit
$ (136 ) $ (107 )
Net of tax

Deferred gain on cash flow derivatives

Gain on cash flow derivatives
$ 48 $ 127
Net sales
Hedge ineffectiveness
(1 ) (1 )
Net sales
Associated tax expense
(17 ) (47 )
Income tax benefit
$ 30 $ 79
Net of tax

Total reclassifications for the period
$ (106 ) $ (28 )

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11.~~Recent Accounting and Reporting Developments~~
12.
Recent Accounting and Reporting Developments

There have been no developments to recently issued accounting standards, including the expected dates of adoption and estimated effects on the Company’s consolidated financial statements and footnote disclosures, from those disclosed in the Company’s 2015 Annual Report on Form 10-K, except for the following:

In May 2014, the FASB issued Accounting Standards Update (“ASU”) No. 2014-09, “Revenue from Contracts with Customers,” which will replace most existing revenue recognition guidance in accordance with U.S. GAAP. The core principle of the ASU is that an entity should recognize revenue for the transfer of goods or services equal to the amount that it expects to be entitled to receive for those goods or services. The ASU 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. The ASU will be effective for the Company beginning January 1, 2018, including interim periods in 2018, and allows for both retrospective and prospective methods of adoption. The Company is in the process of evaluating its revenue streams to determine accounting treatment under the ASU. In March 2016, the FASB issued ASU No. 2016-08, “Revenue from Contracts with Customers (Topic 606): Principal versus Agent Considerations (Reporting Revenue Gross versus Net)”. In April 2016, the FASB issued ASU No. 2016-10, “Revenue from Contracts with Customers: Identifying Performance Obligations and Licensing”. In May 2016, the FASB issued ASU No. 2016-11, “Revenue from Contracts with Customers (Topic 606) and Derivatives and Hedging (Topic 815) – Rescission of SEC Guidance Because of ASU 2014-09 and 2014-16” and ASU No. 2016-12, “Revenue from Contracts with Customers (Topic 606): Narrow-Scope Improvements and Practical Expedients”. These four ASUs do not change the core principle of the guidance in ASU 2014-09, but rather provide further clarification to improve the operability and understandability of the implementation guidance included in ASU 2014-09.The effective date for these ASUs is the same as the effective date of ASU 2014-09. The Company is currently assessing the impact of these ASUs on its consolidated financial statements.
In March 2016, the FASB issued Accounting Standards Update No. 2016-07, ~~Investments~~“Investments – Equity Method and Joint Ventures (Topic 323): Simplifying the Transition to the Equity Method of ~~Accounting~~Accounting” (“ASU 2016-07”). Among other things, the amendments in ASU 2016-07 eliminate the requirement that when an investment qualifies for use of the equity method as a result of an increase in the level of ownership interest or degree of influence, an investor must adjust the investment, results of operations, and retained earnings retroactively on a step-by-step basis as if the equity method had been in effect during all previous periods that the investment had been held. The amendments require that the equity method investor add the cost of acquiring the additional interest in the investee to the current basis of the investor’s previously held interest and adopt the equity method of accounting as of the date the investment becomes qualified for equity method accounting. Therefore, upon qualifying for the equity method of accounting, no retroactive adjustment of the investment is required. The amendments are effective for all entities for fiscal years, and interim periods within those fiscal years, beginning after December 15, 2016. The amendments should be applied prospectively upon their effective date to increases in the level of ownership interest or degree of influence that result in the adoption of the equity method. Early adoption is permitted. The Company is currently assessing the impact of this ASU on its consolidated financial statements.

In March 2016, the FASB issued Accounting Standards Update No. 2016-08, Revenue from Contracts with Customers (Topic 606): Principal versus Agent Considerations (Reporting Revenue Gross versus Net) (“ASU 2016-08”). ASU 2016-08 clarifies the implementation guidance on principal versus agent considerations contained in Accounting Standards Update No. 2014-09 “Revenue from Contracts with Customers”. The guidance in ASU 2016-08 includes indicators to assist an entity in determining whether it controls a specified good or service before it is transferred to the customers. The Company is currently assessing the impact of this ASU on its consolidated financial statements.
~~In March 2016, the FASB issued Accounting Standards Update No.~~ 2016-09, ~~Compensation~~“Compensation – Stock Compensation (Topic 718)” (“ASU 2016-09”). ASU 2016-09 identifies areas for simplification involving several aspects of accounting for share-based payment transactions, including the income tax consequences, classification of awards as either equity or liabilities, an option to recognize gross stock compensation expense with actual forfeitures recognized as they occur, as well as certain classifications on the statement of cash flows. The guidance will be effective for the fiscal year beginning after December 15, 2016, including interim periods within that year. The Company is currently assessing the impact of this ASU on its consolidated financial statements.

13.
Restructuring
In April 2015, the Company initiated a production curtailment at its Atchison, Kansas facility within the Tubular Products Group. Severance related restructuring costs associated with the production curtailment of approximately $0.5 million were incurred and paid during the three months ended June 30, 2015, and included in Cost of sales for that period.
14.
Goodwill
Goodwill represents the excess of the purchase price over the assigned fair values of the assets and liabilities assumed in conjunction with an acquisition, and is reviewed for impairment annually at December 31 or whenever events occur or circumstances change that indicate goodwill may be impaired.
Goodwill of $5.3 million related to the Company’s Water Transmission Group was quantitatively evaluated using a weighted average of income and market approaches. The income approach is primarily driven by inputs from the Company’s internal financial forecasts. The market approach incorporates inputs from market participant data, as well as inputs derived from Company assumptions. Due to Water Transmission market conditions in 2015, the Company determined that its Water Transmission Group goodwill was impaired at June 30, 2015, and it was completely written off in the second quarter of 2015.

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15.
Related Party Transaction
In the second quarter of 2015, the Company engaged Raymond James & Associates, an affiliate of Eagle Asset Management, to provide investment banking services related to a possible disposition of the Company’s Tubular Products business. Eagle Asset Management was a substantial stockholder of the Company (owning more than 10 percent of the Company’s common stock) until September 30, 2015, when Eagle Asset Management reported that it then owned less than 5 percent of the Company’s common stock.
Less than $5,000 was billed by Raymond James during the three and six month periods ended June 30, 2016. Approximately $12,000 of reimbursable expenses were billed by Raymond James during the three and six month periods ended June 30, 2015. Professional fees payable to Raymond James will be contingent upon completion of a future transaction, which may or may not occur.
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Item 2.2. Management’s Discussion and Analysis of Financial Condition and Results of Operations

Forward Looking Statements

This Management’s Discussion and Analysis of Financial Condition and Results of Operations and other sections of this Report contain forward-looking statements within the meaning of the Securities Litigation Reform Act of 1995 and Section 21E of the Exchange Act that are based on current expectations, estimates and projections about our business, management’s beliefs, and assumptions made by management. Words such as “expects,” “anticipates,” “intends,” “plans,” “believes,” “seeks,” “estimates,” “forecasts,” “should,” “could,” and variations of such words and similar expressions are intended to identify such forward-looking statements. These statements are not guarantees of future performance and involve risks and uncertainties that are difficult to predict. Therefore, actual outcomes and results may differ materially from what is expressed or forecasted in such forward-looking statements as a result of a variety of important factors. While it is impossible to identify all such factors, those that could cause actual results to differ materially from those estimated by us include changes in demand and market prices for our products, product mix, bidding activity, the timing of customer orders and deliveries, production schedules, the price and availability of raw materials, price and volume of imported product, excess or shortage of production capacity, international trade policy and regulations and other risks discussed in our Annual Report on Form 10-K for the year ended December 31, 2015 (the “2015 Form 10-K”) and from time to time in our other SEC filings and reports. Such forward-looking statements speak only as of the date on which they are made, and we do not undertake any obligation to update any forward-looking statement to reflect events or circumstances after the date of this Report. If we do update or correct one or more forward-looking statements, investors and others should not conclude that we will make additional updates or corrections with respect thereto or with respect to other forward-looking statements.

Overview

Water Transmission Group. We are the largest manufacturer of engineered steel pipe water systems in North America. With ~~eight~~our strategically located Water Transmission manufacturing facilities, we are positioned to meet North America’s growing needs for water and wastewater infrastructure. We serve a wide range of markets and our solutions-based products are a good fit for applications including water transmission, plant piping, tunnels and river crossings. With a history that dates back more than 100 years, we have become a leading manufacturer in the welded steel pipe industry. These pipeline systems are produced by our Water Transmission Group from eight manufacturing facilities, which are located in Portland, Oregon; Denver, Colorado; Adelanto, California; Parkersburg, West Virginia; Saginaw, Texas; Salt Lake City, Utah; St. Louis, Missouri; and Monterrey, Mexico. On July 12, 2016, we announced plans to close our Denver, Colorado facility. Production at the facility is scheduled to conclude in the fourth quarter of 2016 with final shipments planned into the first quarter of 2017. Our Water Transmission Group accounted for approximately ~~87%~~91% of our net sales in the first ~~quarter~~six months of 2016.

Our water infrastructure products are sold generally to installation contractors, who include our products in their bids to municipal agencies or privately-owned water companies for specific projects. We believe our sales are substantially driven by spending on new water infrastructure with a recent trend towards spending on water infrastructure replacement, repair and upgrade. Within the total range of pipe products, our products tend to fit the larger diameter, higher-pressure applications.

Tubular Products Group. Our Tubular Products Group manufactures ERW steel pipe at our Atchison, Kansas facility, producing a range of line pipe products used in several different applications including energy, industrial, construction, and agricultural. Our Tubular Products Group generated approximately 13% of our net sales in the first quarter of 2016. Our Tubular Products Group’s sales volume is typically driven by energy spending, non-residential construction spending and general economic conditions. We announced on July 20, 2015 that we are in the process of exploring the sale of our remaining ~~Energy~~ Tubular Products business, which includes line, structural and standard pipe, and is located in Atchison, Kansas. This decision reflects our long-term objective to focus on our core Water Transmission business through organic growth initiatives as well as through merger and acquisition activity. The Atchison facility operated at reduced levels from April 2015 to January 2016, when we idled the Atchison facility to reduce operating expenses until market conditions improve or a sale is completed. We ~~are continuing to sell~~completed the sale of all remaining previously manufactured tubular products ~~inventory.~~inventory during the second quarter of 2016. Our Tubular Products Group generated approximately 9% of our net sales in the first six months of 2016. Our Tubular Products Group’s sales volume is typically driven by energy spending, non-residential construction spending and general economic conditions.

Our Current Economic Environment.We operate our Water Transmission Group with a long-term time horizon. Projects are often planned for many years in advance, and are sometimes part of fifty-year build out plans. Long-term demand for water infrastructure projects in the United States appears strong. However, in the near term, we expect strained governmental and water agency budgets and increased capacity from competitors to impact the Water Transmission Group. Fluctuating steel costs will also be a factor, as the ability to adjust our selling prices as steel costs fluctuate will depend on market conditions. Purchased steel represents a substantial portion of our cost of sales, and changes in our selling prices often correlate directly to changes in steel costs.

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Demand for line pipe, the primary product of our Tubular Products Group, is correlated to oil and gas exploration activity in the United States, which is itself correlated to global oil prices. Historically low oil prices led to reduced demand in 2015 and the first six months of 2016, and we continue to expect weak demand inthrough the remainder of 2016.

In addition to the macroeconomic factors described above, we continue to face pressures from significant volumes of foreign imports of tubular products. We also face increased pressures due to recent domestic capacity expansions by our competitors.

Critical Accounting Policies and Estimates

The discussion and analysis of our financial condition and results of operations are based upon our condensed consolidated financial statements, which have been prepared in accordance with accounting principles generally accepted in the United States. The preparation of these financial statements requires us to make estimates and judgments that affect the reported amounts of assets, liabilities, revenues and expenses, and related disclosure of contingent assets and liabilities. We evaluate our estimates on an on-going basis. We base our estimates on historical experience and on various other assumptions that are believed to be reasonable under the circumstances. Actual results may differ from these estimates under different assumptions or conditions. A description of our critical accounting policies and related judgments and estimates that affect the preparation of our condensed consolidated financial statements is set forth in our 2015 Form 10-K.

Valuation of Goodwill
See Note 14 of the condensed consolidated financial statements in Part I—Item I, “Financial Statements” for discussion of the impairment of Water Transmission Group goodwill during the three months ended June 30, 2015.
Recent Accounting Pronouncements

See Note 1112 of the condensed consolidated financial statements in Part I—Item I, “Financial Statements” for a description of recent accounting pronouncements, including the dates of adoption and estimated effects on financial position, results of operations and cash flows.
18
Table Of Contents

Results of Operations

The following tables set forth, for the period indicated, certain financial information regarding costs and expenses expressed as a percentage of total net sales and net sales of our business segments.

Three months ended
March 31, 2016

Three months ended
March 31, 2015

Three months ended June 30, 2016

Three months ended June 30, 2015

$
% of Net Sales
$
% of Net Sales
$
% of Net Sales
$
% of Net Sales

Net sales

Water Transmission
$ 29,358 86.5
%
$ 56,242 66.3
%
$ 39,775 94.6
%
$ 38,445 71.4
%
Tubular Products
4,570 13.5 28,623 33.7 2,286 5.4 15,401 28.6
Total net sales
33,928 100.0 84,865 100.0 42,061 100.0 53,846 100.0
Cost of sales
39,365 116.0 80,974 95.4 44,223 105.1 56,439 104.8
Gross profit (loss)
(5,437 ) (16.0 ) 3,891 4.6
Gross loss
(2,162 ) (5.1 ) (2,593 ) (4.8 )
Selling, general and administrative expense
4,599 13.6 6,974 8.2 4,091 9.7 5,452 10.1
Impairment of Water Transmission goodwill
- - 5,282 9.8
Operating loss
(10,036 ) (29.6 ) (3,083 ) (3.6 ) (6,253 ) (14.8 ) (13,327 ) (24.7 )
Other income
40 0.1 44 -
Other income (expense)
(4 ) - 14 -
Interest income
- - 82 0.1 3 - 81 0.1
Interest expense
(119 ) (0.3 ) (417 ) (0.5 ) (119 ) (0.3 ) (286 ) (0.5 )
Loss before income taxes
(10,115 ) (29.8 ) (3,374 ) (4.0 ) (6,373 ) (15.1 ) (13,518 ) (25.1 )
Income tax benefit
(532 ) (1.6 ) (1,273 ) (1.5 ) (131 ) (0.3 ) (1,439 ) (2.7 )
Net loss
$ (9,583 ) (28.2
)%
$ (2,101 ) (2.5
)%
$ (6,242 ) (14.8
)%
$ (12,079 ) (22.4
)%

Gross profit (loss) as a percentage of segment net sales:

Water Transmission
(19.6
)%
13.4
%
(3.2
)%
3.3
%
Tubular Products
6.8 (12.7 ) (38.9 ) (25.0 )

Six months ended June 30, 2016

Six months ended June 30, 2015

$
% of Net Sales
$
% of Net Sales

Net sales

Water Transmission
$ 69,133 91.0
%
$ 94,687 68.3
%
Tubular Products
6,856 9.0 44,024 31.7
Total net sales
75,989 100.0 138,711 100.0
Cost of sales
83,588 110.0 137,413 99.1
Gross profit (loss)
(7,599 ) (10.0 ) 1,298 0.9
Selling, general and administrative expense
8,690 11.4 12,426 8.9
Impairment of Water Transmission goodwill
- - 5,282 3.8
Operating loss
(16,289 ) (21.4 ) (16,410 ) (11.8 )
Other income
35 - 58 -
Interest income
3 - 163 0.1
Interest expense
(237 ) (0.3 ) (703 ) (0.5 )
Loss before income taxes
(16,488 ) (21.7 ) (16,892 ) (12.2 )
Income tax benefit
(663 ) (0.9 ) (2,712 ) (2.0 )
Net loss
$ (15,825 ) (20.8
)%
$ (14,180 ) (10.2
)%

Gross profit (loss) as a percentage of segment net sales:

Water Transmission
(10.2
)%
9.3
%
Tubular Products
(8.4 ) (17.0 )

Three Monthsand Six MonthsEnded~~March 31~~June 30, 2016 Compared to Three Monthsand Six MonthsEnded~~March 31, 2015~~June 30, 2015
Net sales. Net sales decreased ~~60.0%~~21.9% to ~~$33.9~~$42.1 million for the ~~first~~second quarter of 2016 compared to ~~$84.9~~$53.8 million for the second quarter of 2015 and decreased 45.2% to $76.0 million for the first ~~quarter~~six months of 2016 compared to $138.7 million for the first six months of 2015. ~~Two customers~~One customer in the Water Transmission segment, Garney Construction, ~~and Bar Constructors, Inc.,~~ accounted for ~~32.1%~~24.4% of total net sales in the second quarter of 2016 and ~~14.0%, respectively,~~27.9% of total net sales in the first six months of 2016. One customer in the Water Transmission segment, Garney Construction, accounted for 16.2% of total net sales in the second quarter of ~~2016. No sales to a~~2015. There was no single customer ~~were~~that accounted for 10% or more of total net sales in the first ~~quarter~~six months of 2015.
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Table Of Contents

Water Transmission sales ~~decreased 47.8%~~increased 3.5% to ~~$29.4~~$39.8 million for the ~~first~~second quarter of 2016 compared to ~~$56.2~~$38.4 million for the second quarter of 2015 and decreased 27.0% to $69.1 million for the first ~~quarter~~six months of 2016 compared to $94.7 million for the first six months of 2015. The ~~decrease~~increase in sales in the ~~first~~second quarter of 2016 compared to the ~~first~~second quarter of 2015 was due to a ~~52%~~123% increase in tons produced, significantly offset by a 54% decrease in selling price per ~~ton, partially offset by a 10%~~ton. The increase in tons ~~produced.~~produced was due to project timing. The decrease in selling prices per ton in the ~~first~~second quarter of 2016 was ~~primarily~~ due to a ~~39%~~change in the product mix, as well as increased competition combined with a 10% decrease in steel costs per ton. Lower material costs generally lead to lower contract values and, therefore, lower net sales as contractors and municipalities are aware of the input costs and market conditions. The decrease in sales in the first six months of 2016 compared to the first six months of 2015 was due to a 53% decrease in selling price per ton, partially offset by a 54% increase in tons ~~produced~~produced. The decrease in selling prices per ton in the first six months of 2016 was due to ~~project timing.~~a change in the product mix, as well as increased competition combined with a 27% decrease in steel costs per ton. Bidding activity, backlog and production levels may vary significantly from period to period affecting sales volumes.

15
~~Table Of Contents~~
Tubular Products sales decreased ~~84.0%~~85.2% to ~~$4.6~~$2.3 million in the ~~first~~second quarter of 2016 compared to ~~$28.6~~$15.4 million in the second quarter of 2015 and decreased 84.4% to $6.9 million for the first six months of 2016 compared to $44.0 million for the first six months of 2015. The sales decrease in the second quarter of 2016 compared to the second quarter of 2015 was due to a 77% decrease in tons sold and a 34% decrease in selling price per ton. We sold 4,000 tons in the second quarter of 2016 compared to 17,700 tons in the second quarter of 2015. The sales decrease in the first ~~quarter~~six months of 2016 compared to the first ~~quarter~~six months of 2015 was due to a ~~73%~~74% decrease in tons sold from 46,000 tons to 11,700 tons and a ~~42%~~39% decrease in selling price per ton. ~~We sold approximately 8,000 tons in the first quarter of 2016 compared to approximately 28,000 tons in the first quarter of 2015.~~ The decrease in ~~tons sold was primarily~~volume and sales prices are due to ~~decreased demand for line pipe as a result~~the shutdown of Atchison with the worldwide downturn in ~~crude~~ oil ~~prices~~ and ~~large volumes of imported pipe. Energy~~natural gas prices. No pipe sales volume decreased 77% from approximately 18,000 tons in the first quarter of 2015 to approximately 4,000 tons in the first quarter of 2016. The decrease in selling price per ton was also due to decreased demand, as well as due to a change in product mix. We are experiencing continued pricing pressures from imported pipe in 2016.has been produced since January 2016 at Atchison.

Gross profit. Gross profit decreased ~~240.0%~~16.6% to a ~~$5.4~~$2.2 million gross loss (negative ~~16.0%~~5.1% of total net sales) in the second quarter of 2016 compared to $2.6 million gross loss (negative 4.8% of total net sales) in the second quarter of 2015 and decreased 685.4% to a $7.6 million gross loss (negative 10.0% of total net sales) in the first ~~quarter~~six months of 2016 compared to ~~$3.9~~$1.3 million ~~gross profit (4.6%~~(0.9% of total net sales) in the first ~~quarter~~six months of 2015.

Water Transmission gross profit decreased ~~$13.3~~$2.5 million, or ~~176.5%~~201.4%, to a ~~$5.8~~$1.3 million gross loss (negative ~~19.6%~~3.2% of segment net sales) for the ~~first~~second quarter of 2016 compared to ~~$7.5~~$1.3 million ~~(13.4%~~(3.3% of segment net sales) for the second quarter of 2015 and decreased $15.8 million, or 180.0% to a $7.0 million gross loss (negative 10.2% of segment net sales) in the first ~~quarter~~six months of 2016 compared to $8.8 million (9.3% of segment net sales) in the first six months of 2015. The decrease in gross profit as a percent of net sales in the second quarter and first ~~quarter~~six months of 2016 compared to the second quarter and first ~~quarter~~six months of 2015 was due to the significant competition that we have experienced on recent project bids which has led to decreased selling prices, combined with the mix of projects produced in the quarter.

Gross profit from Tubular Products increased ~~$3.9~~$3.0 million, or 76.9%, to a ~~$0.3~~$0.9 million gross ~~profit (6.8%~~loss (negative 38.9% of segment net sales) in the second quarter of 2016 compared to a $3.8 million gross loss (negative 25.0% of segment net sales) in the second quarter of 2015 and increased $6.9 million, or 92.3%, to a $0.6 million gross loss (negative 8.4% of segment net sales) in the first ~~quarter~~six months of 2016 compared to a ~~$3.6~~$7.5 million gross loss (negative ~~12.7%~~17.0% of segment net sales) in the first ~~quarter~~six months of 2015. Gross profit in the second quarter ~~ended March 31, 2016~~and six months year to date was positively impacted by higher realized selling prices than we expected when we recorded the lower of cost or market inventory adjustment in 2015. The gross ~~profit~~loss in the ~~quarter~~six months ended ~~March 31,~~June 30, 2015 was negatively impacted by the recording of $2.8 million of lower of cost or market inventory ~~adjustments.~~adjustments as well as $0.5 million in severance expense due to the production curtailment.

Selling, general and administrative expenses. Selling, general and administrative expenses decreased ~~34.1%~~$1.4 million, or 25.0%, to ~~$4.6~~$4.1 million ~~(13.6%~~(9.7% of total net sales) for the ~~first~~second quarter of 2016 compared to ~~$7.0~~$5.5 million ~~(8.2%~~(10.1% of total net sales) for the second quarter of 2015 and decreased $3.7 million, or 30.1%, to $8.7 million (11.4% of net sales) in the first ~~quarter~~six months of 2016 compared to $12.4 million (8.9% of net sales) in the first six months of 2015. The decrease for the ~~first~~second quarter of 2016 compared to the ~~first~~second quarter of 2015 was primarily due to a ~~$1.1~~$1.3 million reduction in wages and benefits due to lower headcount. The decrease for the first six months of 2016 compared to the first six months of 2015 was due primarily to a $2.4 million reduction in wages and benefits due to lower headcount, as well as a ~~$0.6~~$0.9 million ~~decrease~~reduction in professional ~~fees~~fees.
Impairment of Water Transmission goodwill.Goodwill related to the Company’s Water Transmission segment of $5.3 million was evaluated for impairment in the second quarter of 2015 due to then current market conditions. We concluded that the business enterprise value of the Water Transmission segment was less than its carrying amount at June 30, and engaged a ~~$0.2 million decrease~~consultant to assist the Company in ~~travel and entertainment expense.~~calculating implied fair value of goodwill for the reporting unit. As a result of that analysis, the entire balance of Water Transmission segment goodwill was written off as of June 30, 2015.

Interest expense. Interest expense was $0.1 million for the ~~first~~second quarter of 2016 compared to ~~$0.4~~$0.3 million for the second quarter of 2015 and decreased to $0.2 million for the first ~~quarter~~six months of 2016 compared to $0.7 million for the first six months of 2015. The decrease in interest expense primarily was a result of lower average borrowings and lower capital lease balances ~~at lower average rates,~~ during the second quarter and first ~~quarter~~six months of 2016 compared to the second quarter and first ~~quarter~~six months of 2015.

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Table Of Contents
Income ~~taxes.~~taxes. The tax benefit was ~~$0.5~~$0.1 million in the ~~first~~second quarter of 2016 (an effective tax benefit rate of ~~5.3%~~2.1%) compared to athe tax benefit of ~~$1.3~~$1.4 million in the ~~first~~second quarter of 2015 (an effective tax benefit rate of ~~37.7%~~10.6%), and the tax benefit of $0.7 million in the first six months of 2016 (an effective tax benefit rate of 4.0%) compared to the tax benefit of $2.7 million in the first six months of 2015 (an effective tax benefit rate of 16.1%).

~~The~~Our effective tax rate for the three and six months ended ~~March 31,~~June 30, 2016 is significantly lower than statutory rates because our net operating losses from the period are subject to a valuation allowance. Our effective tax benefit rate in the three and six months ended June 30, 2015 was significantly lower than statutory rates due to the non-deductibility of expense related to impairment of goodwill, as well as a valuation allowance recorded during the three months ended June 30, 2015. The effective income tax rate can change significantly depending on the relationship of permanent income tax deductions and tax credits to estimated pre-tax income or loss, and the changes in valuation allowances. Accordingly, the comparison of effective rates between periods is not meaningful in all situations.

Liquidity and Capital Resources

Sources and Uses of Cash

Our principal sources of liquidity generally include operating cash flows and our ~~line of credit.~~bank credit agreement (“Credit Agreement”). From time to time our long-term capital needs may be met through the issuance of long-term debt or additional equity. Our principal uses of liquidity generally include capital expenditures, working capital and debt service. ~~Information regarding our cash flows for the three months ended March 31, 2016 is presented in our consolidated statements of cash flows contained in this Form 10-Q, and is further discussed below.~~

As of ~~March 31,~~June 30, 2016, our working capital (current assets minus current liabilities) was ~~$83.7~~$86.9 million compared to $93.7 million as of December 31, 2015. The primary ~~reasons~~reason for the decrease in working capital ~~were decreases~~was a decrease in trade and other receivables ~~and net costs and estimated earnings in excess of billings on uncompleted contracts,~~ due to lower sales ~~billings,~~ and ~~production~~billings in the ~~first~~second quarter compared to the fourth quarter of ~~2016.~~2015. In addition, our Tubular Products inventories have decreased following the production curtailment at the Atchison plant which began in April 2015. Net cash provided by operating activities in the first ~~three~~six months of 2016 was ~~$1.2~~$1.5 million. Cash from operating activities was primarily the result of ~~our net loss, offset by~~ fluctuations in working capital accounts that included ~~the~~a decrease in trade receivables and ~~costs and estimated earnings in excess of billings on uncompleted contracts, net.~~inventories.
16
~~Table Of Contents~~

Fluctuations in our working capital accounts result from timing differences between production, shipment, invoicing, and collection, as well as changes in levels of production and costs of materials. We typically have a relatively large investment in working capital, as we generally pay for materials, labor, and other production costs in the initial stages of a project, while payments from our customers are generally received after finished product is delivered. Our revenues in the Water Transmission segment are recognized on a percentage-of-completion method; therefore, cash receipts typically occur subsequent to when revenue is recognized and the elapsed time between when revenue is recorded and when cash is received can be significant. As such, our payment cycle is a significantly shorter interval than our collection cycle, although the effect of this difference in the cycles may vary by project, and from period to period.

Net cash used in investing activities in the first ~~three~~six months of 2016 was ~~$0.7~~$1.3 million of capital expenditures, which was primarily standard capital replacement spending. Total capital expenditures are expected to be approximately ~~$3.0~~$2.7 million for 2016.

Net cash used in financing activities in the first ~~three~~six months of 2016 was ~~$1.4~~$1.5 million, primarily from the payment of contingent consideration in January 2016 for amounts earned on 2015 revenues of Permalok Corporation.

We anticipate that our existing cash and cash equivalents, cash flows expected to be generated by operations, and amounts available to borrow under our ~~line of credit~~Credit Agreement will be adequate to fund our working capital and capital requirements for the foreseeable future. To the extent necessary, we may also satisfy capital requirements through additional bank borrowings, senior notes, term notes, subordinated debt, and capital and operating leases, if such resources are available on satisfactory terms. We have from time to time evaluated and continue to evaluate opportunities for acquisitions and expansion. Any such transactions, if consummated, may use a portion of our working capital or necessitate additional bank borrowings or other sources of funding.

Borrowings onLine of Credit

At ~~March 31,~~June 30, 2016, we had no outstanding borrowings, and $2.0 million of outstanding letters of credit, under our Loan and Security Agreement (the “Agreement”) with Bank of America, N.A. dated October 26, 2015. The Agreement expires on October 25, 2018 and provides for revolving loans and letters of credit up to the maximum principal amount (the Revolver Commitment) of $60 million, subject to a borrowing base. We have the ability to increase the Revolver Commitment to $100 million, subject to the provisions of the Credit Agreement.

The borrowing base is calculated by applying various advance rates to eligible accounts receivable, costs and expected earnings in excess of billings, inventories, and fixed assets, subject to various exclusions, adjustments, and sublimits by asset class. Additionally, the Agreement effectively limits availability under the borrowing base during times when our Fixed Charge Coverage Ratio, as defined in the Credit Agreement, is not met for the previous 12-month period. As of ~~March 31,~~June 30, 2016, the Fixed Charge Coverage Ratio was not met, and therefore the availability limit applied. Including the effect of this limit, we had additional borrowing capacity of ~~$19.6~~$13.1 million, net of outstanding letters of credit, under the Agreement at ~~March 31,~~June 30, 2016. Based on our business plan and forecasts of operations, we expect to have sufficient credit availability to support our operations in 2016.
21
Table Of Contents

Borrowings under the Agreement bear interest at rates related to LIBOR plus 1.75% to 2.25%, or at Bank of America’s prime rate plus 0.75% to 1.25%. Borrowings under the Agreement are secured by substantially all of the Company’s assets.

Capital Leases

We had a total of ~~$1.0~~$1.1 million in capital lease obligations outstanding at ~~March 31,~~June 30, 2016. The weighted average interest rate on all of our capital leases is ~~4.79%~~4.69%. Our capital leases are for certain equipment used in the manufacturing process.

Off Balance Sheet Arrangements

We do not have any off balance sheet arrangements that are reasonably likely to have a current or future material effect on our financial position, results of operations or cash flows.

17
~~Table Of Contents~~
Item 3.3.Quantitative and Qualitative Disclosure About Market Risk

For a discussion of the Company’s market risk associated with foreign currencies and interest rates, see Item 7A, “Quantitative and Qualitative Disclosures about Market Risk” in Part II of the Company’s 2015 Form 10-K.

Item 4.Controls and Procedures

Evaluation of Disclosure Controls and Procedures

Disclosure controls and procedures (as defined in Rules 13a-15(e) and 15d-15(e) under the Securities Exchange Act of 1934, as amended (“Exchange Act”)) are designed to provide reasonable assurance that information required to be disclosed in reports we file or submit under the Exchange Act is recorded, processed, summarized and reported within the time periods specified in the rules and forms of the SEC and that such information is accumulated and communicated to our management, including the Chief Executive Officer (“CEO”) and Chief Financial Officer (“CFO”), as appropriate, to allow timely decisions regarding required disclosures.

In connection with the preparation of this Quarterly Report on Form 10-Q for the quarter ended ~~March 31,~~June 30, 2016, our management, under the supervision and with the participation of our CEO and CFO, evaluated the effectiveness of the design and operation of our disclosure controls and procedures as of ~~March 31,~~June 30, 2016. As a result of the assessment, our CEO and CFO have concluded that, as of ~~March 31,~~June 30, 2016, our disclosure controls and procedures were effective.

Changes in Internal Control over Financial Reporting

There were no significant changes in the Company’s internal control over financial reporting during the quarter ended ~~March 31,~~June 30, 2016, that have materially affected, or are reasonably likely to materially affect, the Company’s internal controls over financial reporting.

PartII – Other Information

Item 1.Legal Proceedings

Information required by this Item 1 is contained in Note 56 to the condensed consolidated financial statements, Part I—Item 1, “Financial Statements” of this report, under the caption “Commitments and Contingencies.” The text under such caption is incorporated by reference into this Item 1.

Item 1A.Risk Factors

In addition to the other information set forth in this report, the factors discussed in Part I—Item 1A, “Risk Factors” in our Annual Report on Form 10-K for the fiscal year ended December 31, 2015 could materially affect our business, financial condition or operating results. The risks described in our Annual Report on Form 10-K are not the only risks facing us. There are additional risks and uncertainties not currently known to us or that we currently deem to be immaterial, that may also materially adversely affect our business, financial condition, or operating results.

1822
Table Of Contents

Item 6.5. Other Information
On August 1, 2016, the Company entered into an amended and restated Change in Control Agreement (the “Amended Agreements”) with each of Scott Montross, Robin Gantt, Martin Dana and Bill Smith (each, an "Executive Officer"). The Amended Agreements reflect certain changes in the definition of "Change in Control," including (i) making the date of consummation of specified transactions the date of the "Change in Control" rather than the date of shareholder approval of the transaction as previously provided; (ii) expanding the types of mergers that are excluded from the definition of "Change in Control," and (iii) reducing the size of a third party stock purchase that would constitute a "Change in Control." The Amended Agreements also reflect certain administrative and clarifying changes, including, but not limited to, (i) providing that if an Executive Officer becomes entitled to severance benefits under both the Company's Long Term Incentive Plan Agreement dated April 19, 2016 and the Amended Agreement, the Executive Officer will be entitled to receive a cash severance payment equal to the larger of the cash severance benefit provided under the Long Term Incentive Plan Agreement or the benefit provided under the Amended Agreement; and (ii) authorizing the Company to make adjustments to the timing and amounts of payments to be made to Executive Officers under the Amended Agreements as necessary to limit certain potential tax payments and penalties.
The foregoing description of the Amended Agreements does not purport to be complete and is qualified in its entirety by reference to the full text of the Amended Agreements, which are filed herewith as Exhibit 10.3 and 10.4 and are incorporated herein by reference.
Item6.Exhibits

(a) The exhibits filed as part of this Report are listed below:

Exhibit
Number

Description

10.1
Form of Long Term Incentive Plan Agreement (incorporated by reference to the Company’s Current Report on Form 8-K as filed with the Securities and Exchange Commission on April 19, 2016)
10.2
Third Amended and Restated Bylaws (incorporated by reference to the Company’s Current Report on Form 8-K as filed with the Securities and Exchange Commission on June 2, 2016)
10.3
Amended and Restated Change in Control Agreement between Scott Montross and Northwest Pipe Company dated August 1, 2016
10.4
Form of Amended and Restated Change in Control Agreement between Northwest Pipe Company and each of Robin Gantt, Martin Dana and Bill Smith dated August 1, 2016
31.1

Certification Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 302 of the Sarbanes-Oxley Act of2002

31.2

Certification Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002

32.1 Certification Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002

32.2

Certification 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 Document

101.DEF

XBRL Taxonomy Definition Linkbase Document

101.LAB XBRL Taxonomy Extension Label Linkbase Document

101.PRE XBRL Taxonomy Extension Presentation Linkbase Document

1923
Table Of Contents

SIGNATURES

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.

Dated: ~~May 5,~~August 3, 2016

NORTHWEST PIPE COMPANY
By:
/s/ Scott Montross

~~By:~~
~~/s/~~ Scott Montross
~~Scott Montross~~

Director, President and Chief Executive Officer

By:
~~By:~~
/s/ Robin Gantt
Robin Gantt
Senior Vice President, Chief Financial Officer and Corporate Secretary
(Principal Financial Officer)

20

	March 31, 2016		December 31, 2015
Current inventories:
Raw materials	$	22,370	$	21,486
Work-in-process		1,686		1,901
Finished goods		2,902		3,641
Supplies		2,421		2,447
		29,379		29,475
Non-current inventories:
Finished goods		800		823
Total inventories	$	30,179	$	30,298

	Options Outstanding		Weighted Average Exercise Price per Share		Weighted Average Remaining Contractual Life		Aggregate Intrinsic Value
							(In thousands)
Balance, January 1, 2016		28,000	$	25.21
Options granted		-		-
Options exercised		-		-
Options cancelled		-		-
Balance, March 31, 2016		28,000		25.21		3.52	$	-
Exercisable, March 31, 2016		28,000		25.21		3.52	$	-

	Options Outstanding			Weighted Average Exercise Price per Share		Weighted Average Remaining Contractual Life		Aggregate Intrinsic Value
								(In thousands)
Balance, January 1, 2016		28,000		$	25.21
Options granted		-			-
Options exercised		-			-
Options cancelled		(2,000	)		28.31
Balance, June 30, 2016		26,000			24.97		3.53	$	-
Exercisable, June 30, 2016		26,000			24.97		3.53	$	-

	Number of RSUs and PSAs			Weighted Average Grant Date Fair Value
Balance, January 1, 2016		127,852		$	38.87
RSUs and PSAs granted		-			-
RSUs and PSAs vested		(12,212	)		31.50
RSUs and PSAs canceled		(63,126	)		36.93
Balance, March 31, 2016		52,514			42.91

	Number of RSUs and PSAs			Weighted Average Grant Date Fair Value
Balance, January 1, 2016		127,852		$	38.87
RSUs and PSAs granted		161,080			9.38
RSUs and PSAs vested		(12,212	)		31.50
RSUs and PSAs canceled		(63,126	)		36.93
Balance, June 30, 2016		213,594			17.62

	Defined Benefit Pension Items			Gains (Losses) on Cash Flow Hedges			Total
Balance, December 31, 2015	$	(1,624	)	$	86		$	(1,538	)

Other comprehensive income (loss) before reclassifications		33			(86	)		(53	)
Amounts reclassified from accumulated other comprehensive income (loss)		67			(46	)		21
Net current period other comprehensive income (loss)		100			(132	)		(32	)

Balance, March 31, 2016	$	(1,524	)	$	(46	)	$	(1,570	)

	Defined Benefit Pension Items			Gains (Losses) on Cash Flow Hedges			Total
Balance, December 31, 2015	$	(1,624	)	$	86		$	(1,538	)

Other comprehensive income (loss) before reclassifications		63			(86	)		(23	)
Amounts reclassified from accumulated other comprehensive income (loss)		136			(30	)		106
Net current period other comprehensive income (loss)		199			(116	)		83

Balance, June 30, 2016	$	(1,425	)	$	(30	)	$	(1,455	)

	Three months ended March 31, 2016						Three months ended March 31, 2015						Three months ended June 30, 2016						Three months ended June 30, 2015
		$		% of Net Sales				$		% of Net Sales				$		% of Net Sales				$		% of Net Sales
Net sales
Water Transmission	$	29,358			86.5	%	$	56,242			66.3	%	$	39,775			94.6	%	$	38,445			71.4	%
Tubular Products		4,570			13.5			28,623			33.7			2,286			5.4			15,401			28.6
Total net sales		33,928			100.0			84,865			100.0			42,061			100.0			53,846			100.0
Cost of sales		39,365			116.0			80,974			95.4			44,223			105.1			56,439			104.8
Gross profit (loss)		(5,437	)		(16.0	)		3,891			4.6
Gross loss														(2,162	)		(5.1	)		(2,593	)		(4.8	)
Selling, general and administrative expense		4,599			13.6			6,974			8.2			4,091			9.7			5,452			10.1
Impairment of Water Transmission goodwill														-			-			5,282			9.8
Operating loss		(10,036	)		(29.6	)		(3,083	)		(3.6	)		(6,253	)		(14.8	)		(13,327	)		(24.7	)
Other income		40			0.1			44			-
Other income (expense)														(4	)		-			14			-
Interest income		-			-			82			0.1			3			-			81			0.1
Interest expense		(119	)		(0.3	)		(417	)		(0.5	)		(119	)		(0.3	)		(286	)		(0.5	)
Loss before income taxes		(10,115	)		(29.8	)		(3,374	)		(4.0	)		(6,373	)		(15.1	)		(13,518	)		(25.1	)
Income tax benefit		(532	)		(1.6	)		(1,273	)		(1.5	)		(131	)		(0.3	)		(1,439	)		(2.7	)
Net loss	$	(9,583	)		(28.2	)%	$	(2,101	)		(2.5	)%	$	(6,242	)		(14.8	)%	$	(12,079	)		(22.4	)%

Gross profit (loss) as a percentage of segment net sales:
Water Transmission					(19.6	)%					13.4	%					(3.2	)%					3.3	%
Tubular Products					6.8						(12.7	)					(38.9	)					(25.0	)

	Six months ended June 30, 2016						Six months ended June 30, 2015
		$		% of Net Sales				$		% of Net Sales
Net sales
Water Transmission	$	69,133			91.0	%	$	94,687			68.3	%
Tubular Products		6,856			9.0			44,024			31.7
Total net sales		75,989			100.0			138,711			100.0
Cost of sales		83,588			110.0			137,413			99.1
Gross profit (loss)		(7,599	)		(10.0	)		1,298			0.9
Selling, general and administrative expense		8,690			11.4			12,426			8.9
Impairment of Water Transmission goodwill		-			-			5,282			3.8
Operating loss		(16,289	)		(21.4	)		(16,410	)		(11.8	)
Other income		35			-			58			-
Interest income		3			-			163			0.1
Interest expense		(237	)		(0.3	)		(703	)		(0.5	)
Loss before income taxes		(16,488	)		(21.7	)		(16,892	)		(12.2	)
Income tax benefit		(663	)		(0.9	)		(2,712	)		(2.0	)
Net loss	$	(15,825	)		(20.8	)%	$	(14,180	)		(10.2	)%

Gross profit (loss) as a percentage of segment net sales:
Water Transmission					(10.2	)%					9.3	%
Tubular Products					(8.4	)					(17.0	)


Exhibit Number		Description


10.1		Form of Long Term Incentive Plan Agreement (incorporated by reference to the Company’s Current Report on Form 8-K as filed with the Securities and Exchange Commission on April 19, 2016)

10.2		Third Amended and Restated Bylaws (incorporated by reference to the Company’s Current Report on Form 8-K as filed with the Securities and Exchange Commission on June 2, 2016)

10.3		Amended and Restated Change in Control Agreement between Scott Montross and Northwest Pipe Company dated August 1, 2016

10.4		Form of Amended and Restated Change in Control Agreement between Northwest Pipe Company and each of Robin Gantt, Martin Dana and Bill Smith dated August 1, 2016

31.1		Certification Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 302 of the Sarbanes-Oxley Act of2002

31.2		Certification Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002

32.1		Certification Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002

32.2		Certification 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 Document

101.DEF		XBRL Taxonomy Definition Linkbase Document

101.LAB		XBRL Taxonomy Extension Label Linkbase Document

101.PRE		XBRL Taxonomy Extension Presentation Linkbase Document


NORTHWEST PIPE COMPANY
By:	/s/ Scott Montross

	~~By:~~	~~/s/~~ Scott Montross
		~~Scott Montross~~
		Director, President and Chief Executive Officer

By:	~~By:~~	/s/ Robin Gantt
		Robin Gantt
		Senior Vice President, Chief Financial Officer and Corporate Secretary
		(Principal Financial Officer)