NORTHWEST PIPE CO - Quarter Report: 2013 June (Form 10-Q)

NORTHWEST PIPE CO - Quarter Report: 2013 June (Form 10-Q)

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Form 10-Q

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, D.C. 20549

FORM 10-Q

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

For the quarterly period ended: June 30, 2013

¨	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 x No ¨

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

Indicate by check mark 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):

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


Common Stock, par value $.01 per share		9,449,299
(Class)		(Shares outstanding at August 1, 2013)

NORTHWEST PIPE COMPANY

FORM 10-Q

INDEX


	Page
PART I - FINANCIAL INFORMATION

Item 1. Financial Statements:

Condensed Consolidated Balance Sheets as of June 30, 2013 and December 31, 2012		2

Condensed Consolidated Statements of Operations for the three and six months ended June 30, 2013 and 2012		3

Condensed Consolidated Statements of Comprehensive Income for the three and six months ended June 30, 2013 and 2012		4

Condensed Consolidated Statements of Cash Flows for the six months ended June 30, 2013 and 2012		5

Notes to Condensed Consolidated Financial Statements		6

Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations		16

Item 3. Quantitative and Qualitative Disclosures About Market Risk		21

Item 4. Controls and Procedures		21

PART II - OTHER INFORMATION

Item 1. Legal Proceedings		21

Item 1A. Risk Factors		21

Item 6. Exhibits		22

Signatures		23

NORTHWEST PIPE COMPANY

CONDENSED CONSOLIDATED BALANCE SHEETS

(Unaudited)

(In thousands, except share and per share data)


	June 30, 2013			December 31, 2012
Assets
Current assets:
Cash and cash equivalents	$	194		$	46
Trade and other receivables, less allowance for doubtful accounts of $1,093 and $1,748		57,946			41,498
Costs and estimated earnings in excess of billings on uncompleted contracts		65,687			73,314
Inventories		115,845			113,545
Deferred income taxes		6,477			5,177
Prepaid expenses and other		1,636			2,558

Total current assets		247,785			236,138
Property and equipment, net		162,191			152,545
Goodwill		20,478			20,478
Other assets		14,867			13,261

Total assets	$	445,321		$	422,422

Liabilities and Stockholders’ Equity
Current liabilities:
Current portion of long-term debt	$	5,714		$	5,714
Current portion of capital lease obligations		4,658			3,295
Accounts payable		29,528			21,042
Accrued liabilities		17,586			23,424
Deferred revenue		5,916			8,793
Billings in excess of costs and estimated earnings on uncompleted contracts		3,635			6,478

Total current liabilities		67,037			68,746
Note payable to financial institution		60,750			47,533
Long-term debt, less current portion		2,071			6,357
Capital lease obligations, less current portion		6,797			9,179
Deferred income taxes		17,319			15,254
Pension and other long-term liabilities		16,002			15,921

Total liabilities		169,976			162,990

Commitments and contingencies (Note 5)

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, 9,449,299 and 9,382,994 shares issued and outstanding		94			94
Additional paid-in-capital		112,792			112,230
Retained earnings		164,448			149,381
Accumulated other comprehensive loss		(1,989	)		(2,273	)

Total stockholders’ equity		275,345			259,432

Total liabilities and stockholders’ equity	$	445,321		$	422,422

The accompanying notes are an integral part of these Condensed Consolidated Financial Statements.

NORTHWEST PIPE COMPANY

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS

(Unaudited)

(In thousands, except per share amounts)


	Three Months Ended June 30,						Six Months Ended June 30,
	2013			2012			2013			2012
Net sales	$	116,738		$	131,041		$	257,335		$	273,216
Cost of sales		101,070			117,464			220,463			243,139

Gross profit		15,668			13,577			36,872			30,077
Selling, general and administrative expense		6,288			6,607			12,672			13,928

Operating income		9,380			6,970			24,200			16,149
Other expense (income)		(4	)		(34	)		37			2
Interest income		(60	)		(46	)		(243	)		(87	)
Interest expense		956			1,526			2,005			3,166

Income before income taxes		8,488			5,524			22,401			13,068
Provision for income taxes		2,927			1,920			7,334			4,730

Net income	$	5,561		$	3,604		$	15,067		$	8,338

Basic earnings per share	$	0.59		$	0.38		$	1.60		$	0.89

Diluted earnings per share	$	0.59		$	0.38		$	1.59		$	0.88

Shares used in per share calculations:
Basic		9,443			9,374			9,440			9,372

Diluted		9,481			9,433			9,474			9,423

The accompanying notes are an integral part of these Condensed Consolidated Financial Statements

NORTHWEST PIPE COMPANY

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME

(Unaudited)

(In thousands)


	Three Months Ended June 30,				Six Months Ended June 30,
	2013		2012		2013		2012
Net income	$	5,561	$	3,604	$	15,067	$	8,338
Other comprehensive income (loss), net of tax:
Pension liability adjustment, net of tax		64		58		129		195
Deferred gain (loss) on cash flow derivatives, net of tax		44		14		155		(17	)

Other comprehensive income, net of tax		108		72		284		178

Comprehensive income	$	5,669	$	3,676	$	15,351	$	8,516

The accompanying notes are an integral part of these Condensed Consolidated Financial Statements

NORTHWEST PIPE COMPANY

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(Unaudited)

(In thousands)


	Six months ended June 30,
	2013			2012
Cash Flows From Operating Activities:
Net income	$	15,067		$	8,338
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization		7,195			7,459
Provision for doubtful accounts		(656	)		(452	)
Amortization of debt issuance costs		317			936
Deferred income taxes		765			610
Loss on disposal of property and equipment		26			14
Stock based compensation expense		1,292			1,275
Unrealized (gain) loss on foreign currency forward contracts		(291	)		86
Changes in operating assets and liabilities:
Trade and other receivables, net		(15,792	)		(1,883	)
Costs and estimated earnings in excess of billings on uncompleted contracts, net		4,784			(14,630	)
Inventories		(2,027	)		(13,285	)
Prepaid expenses and other assets		1,040			3,727
Accounts payable		9,710			10,394
Deferred revenue		(2,877	)		5,076
Accrued and other liabilities		(5,364	)		16,761

Net cash provided by operating activities		13,189			24,426

Cash Flows From Investing Activities:
Additions to property and equipment		(18,394	)		(8,013	)
Proceeds from the sale of property and equipment		1,680			959
Issuance of notes receivable		(2,850	)		(1,000	)

Net cash used in investing activities		(19,564	)		(8,054	)

Cash Flows From Financing Activities:
Proceeds from issuance of common stock		72			37
Tax withholdings related to net share settlements of restricted stock units and performance share awards		(802	)		(145	)
Payments on long-term debt		(4,286	)		(4,286	)
Borrowings under note payable to financial institution		85,971			71,800
Payments on note payable to financial institution		(72,754	)		(81,800	)
Payments on capital lease obligations		(1,678	)		(1,734	)
Payments of debt amendment costs		—			(401	)

Net cash provided by (used in) financing activities		6,523			(16,529	)

Change in cash and cash equivalents		148			(157	)
Cash and cash equivalents, beginning of period		46			182

Cash and cash equivalents, end of period	$	194		$	25

Non-cash investing activity:
Escrow account related to capital lease financing	$	898		$	897
Accrued property and equipment purchases		1,553			1,716
Capital lease additions		—			142

The accompanying notes are an integral part of these Condensed Consolidated Financial Statements.

NORTHWEST PIPE COMPANY

NOTES TO 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. Prior period deferred revenue, which was previously reflected within accrued liabilities, has been reclassified (separated) to its own line item within current liabilities and net cash provided by operating activities to conform to current period presentation in the Condensed Consolidated Balance Sheets and Condensed Consolidated Statements of Cash Flows. This reclassification has no impact on cash flows from operations, income from operations, net income, or total liabilities.

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, 2012 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, 2012 (the “2012 Form 10-K”). Certain information 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 2012 Form 10-K.

Operating results for the three and six months ended June 30, 2013 are not necessarily indicative of the results that may be expected for the entire fiscal year ending December 31, 2013.

2.	Inventories

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


	June 30, 2013		December 31, 2012
Short-term inventories:
Raw materials	$	54,094	$	56,913
Work-in-process		6,452		10,157
Finished goods		52,190		43,374
Supplies		3,109		3,101

		115,845		113,545
Long-term inventories:
Finished goods		1,463		1,608

Total inventories	$	117,308	$	115,153

Long-term inventories are recorded in other assets.

3.	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 which 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.

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


	Balance at June 30, 2013			Level 1		Level 2			Level 3
Description
Financial Assets
Escrow account	$	898		$	898	$	—		$	—
Deferred compensation plan assets		5,531			5,531		—			—
Derivatives		184			—		184			—

Total Assets	$	6,613		$	6,429	$	184		$	—


	Balance at December 31, 2012			Level 1		Level 2			Level 3
Description
Financial Assets
Escrow account	$	898		$	898	$	—		$	—
Deferred compensation plan assets		5,280			5,280		—			—

Total Assets	$	6,178		$	6,178	$	—		$	—

Financial Liabilities
Derivatives	$	(353	)	$	—	$	(353	)	$	—

The escrow account, consisting of a money market mutual fund, is valued using quoted market prices in active markets classified as Level 1 within the fair value hierarchy. 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. The Company’s derivatives consist of foreign currency 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, and are 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 net carrying amounts of cash and cash equivalents, trade and other receivables, accounts payable, accrued liabilities and note payable to financial institution approximate fair value due to the short-term nature of these instruments. The fair value of our debt is calculated using a coupon rate on borrowings with similar maturities, current remaining average life to maturity, borrower credit quality, and current market conditions, all of which are classified as Level 2 within the valuation hierarchy. The fair value of the Company’s long-term debt, including the current portion, was $7.5 million and the carrying value was $7.8 million at June 30, 2013, and $11.5 million with a carrying value of $12.1 million at December 31, 2012.

Financial Assets Measured and Recorded at Fair Value on a Non-Recurring Basis

We measure our financial assets, including loans receivable and non-marketable equity method investments, at fair value on a non-recurring basis when they are determined to be other-than-temporarily impaired. The fair value of these assets is determined using Level 3 unobservable inputs due to the absence of observable market inputs and the valuations requiring management judgment. There were no impairment charges taken during the three and six months ended June 30, 2013 or June 30, 2012. All loans receivable are categorized as Level 3 in the fair value hierarchy.

4.	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. These derivative contracts are consistent with the Company’s strategy for financial risk management. The Company uses cash flow hedge accounting treatment for qualifying foreign currency forward contracts. The Company initially reports any gain or loss on the effective portion of

a cash flow hedge as a component of other comprehensive income and subsequently reclassifies any gain or loss to net sales when the hedged revenues are recorded. Instruments that do not qualify for cash flow hedge accounting treatment are re-measured at fair value on each balance sheet date and resulting gains and losses are recognized in net income. As of June 30, 2013 and December 31, 2012, the total notional amount of the derivative contracts not designated as hedges was $0.9 million (CAD$0.9 million) and $2.7 million (CAD$2.6 million), respectively. As of June 30, 2013 and December 31, 2012, the total notional amount of the derivative contracts designated as hedges was $7.1 million (CAD$7.5 million) and $12.4 million (CAD$12.3 million), respectively.

For each derivative contract for 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. 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.

The balance sheet location and the fair values of derivative instruments are (in thousands):


	June 30, 2013		December 31, 2012
Foreign Currency Forward Contracts
Assets
Derivatives designated as hedging instruments
Prepaid expenses and other	$	61	$	—
Derivatives not designated as hedging instruments
Prepaid expenses and other		123		—

Total assets	$	184	$	—

Liabilities
Derivatives designated as hedging instruments
Accrued liabilities	$	—	$	197
Derivatives not designated as hedging instruments
Accrued liabilities		—		156

Total liabilities	$	—	$	353

All of the Company’s foreign currency forward contracts are subject to an enforceable master netting arrangement. The Company presents its foreign currency forward contract assets and liabilities within the Statement of Financial Position at their gross fair values.


	(i)		(ii)		(iii) = (i) - (ii)		(iv)				(v) = (iii) - (iv)
							Gross Amounts Not Offset in the Statement of Financial Position
	Gross Amount of Recognized Assets		Gross Amount Offset in the Statement of Financial Position		Net Amount of Assets Presented in the Statement of Financial Position		Financial Instruments		Cash Collateral Received		Net Amount
Derivative Assets
June 30, 2013	$	184	$	—	$	184	$	184	$	—	$	—

December 31, 2012	$	—	$	—	$	—	$	—	$	—	$	—


	(i)		(ii)		(iii) = (i) - (ii)		(iv)				(v) = (iii) - (iv)
							Gross Amounts Not Offset in the Statement of Financial Position
	Gross Amount of Recognized Liabilities		Gross Amount Offset in the Statement of Financial Position		Net Amount of Liabilities Presented in the Statement of Financial Position		Financial Instruments		Cash Collateral Received		Net Amount
Derivative Liabilities
June 30, 2013	$	—	$	—	$	—	$	—	$	—	$	—

December 31, 2012	$	353	$	—	$	353	$	353	$	—	$	—

The amounts of the gains and losses related to the Company’s derivative contracts designated as hedging instruments for the three and six months ended June 30, 2013 and June 30, 2012 are (in thousands):


	Pretax Gain (Loss) Recognized in Comprehensive Income on Effective Portion of Derivative
	Three months ended June 30,				Six months ended June 30,
	2013		2012		2013		2012
Derivatives in Cash Flow Hedging Relationships
Foreign currency forward contracts	$	111	$	49	$	311	$	(52	)


		Pretax Gain Recognized in Income on Effective Portion of Derivative as a Result of Reclassification from Accumulated Other Comprehensive Loss
		Three months ended June 30,				Six months ended June 30,
	Location	2013		2012		2013		2012
Derivatives in Cash Flow Hedging Relationships
Foreign currency forward contracts	Net sales	$	39	$	23	$	65	$	8


		Loss on Ineffective Portion of Derivative and Amount Excluded from Effectiveness Testing Recognized in Income
		Three months ended June 30,						Six months ended June 30,
	Location	2013			2012			2013			2012
Derivatives in Cash Flow Hedging Relationships
Foreign currency forward contracts	Net sales	$	(1	)	$	(93	)	$	(53	)	$	(94	)

At June 30, 2013, there is $0.1 million of unrealized pretax gain on outstanding derivatives accumulated in other comprehensive loss, all of which 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.

For the three and six months ended June 30, 2013, the gains and losses from our derivative contracts not designated as hedging instruments recognized in net sales were a gain of $0.1 million and a loss of $12,000, respectively. For the three and six months ended June 30, 2012, the gains and losses from our derivative contracts not designated as hedging instruments recognized in net sales were a gain of $47,000 and a loss of $0.1 million, respectively.

5.	Commitments and Contingencies

Portland Harbor Superfund

On December 1, 2000, a section of the lower Willamette River known as the Portland Harbor 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 (the “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). By agreement with the EPA, the ODEQ is responsible for overseeing remedial investigation and source control activities for all upland sites to investigate sources and prevent future contamination to the river. A remedial investigation and feasibility study (“RI/FS”) of the Portland Harbor has been directed by a group of potentially responsible parties known as the Lower Willamette Group (the “LWG”) under agreement with the EPA. The Company made a payment of $175,000 to the LWG in June 2007 as part of an interim settlement, and is under no obligation to make any further payment. The final draft RI was submitted to the EPA by the LWG in fall of 2011 and the draft FS was submitted by the LWG to the EPA in March 2012. As of the date of this filing, the final RI is scheduled to be submitted to the EPA in February 2014, and the final FS is scheduled to be submitted to the EPA in the Spring of 2014.

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 in 2002 and 2003 to further characterize the groundwater was consistent with the initial conclusion that the source of the VOCs is located off of Company-owned property. In February 2005, the Company entered into a Voluntary Agreement for Remedial Investigation and Source Control Measures (the “Agreement”) with the ODEQ. The Company is one of many Upland Source Control Sites working with the ODEQ on Source Control and is considered a “medium” priority site by the ODEQ. The Company performed remedial investigation (“RI”) work required under the Agreement and submitted a draft RI/Source Control Evaluation Report in December 2005. The conclusions of the report indicated that the VOCs found in the groundwater do not present an unacceptable risk to human or ecological receptors in the Willamette River. The report also indicated there is no evidence at this time showing a connection between detected VOCs in groundwater and Willamette River sediments. In 2009, the ODEQ requested that the Company revise its RI/Source Control Evaluation Report from 2005 to include more recent information from focused supplemental sampling at the Portland facility and more recent information that has become available related to nearby properties. The Company submitted the Expanded Risk Assessment for the VOCs in Groundwater in May 2012, and comments from the ODEQ were received in November 2012. In February 2013, the ODEQ requested the Company revise the presented information in the 2012 Expanded Risk Assessment for the VOCs in Groundwater a second time, for submittal with the Final RI/Source Control Evaluation report in the second half of 2013.

Also, based on sampling associated with the Portland facility’s RI and on sampling and reporting required under the Portland, Oregon manufacturing facility’s National Pollutant Discharge Elimination System permit for storm water, the Company and the ODEQ have periodically detected low concentrations of polynuclear aromatic hydrocarbons (“PAHs”), polychlorinated biphenyls (“PCBs”), and trace amounts of zinc in storm water. Storm water from the Portland, Oregon manufacturing facility site is discharged into a communal storm water system that ultimately discharges into the neighboring property’s privately owned slip. The slip was historically used for shipbuilding and subsequently for ship breaking and metal recycling. Studies of the river sediments have revealed trace concentrations of PAHs, PCBs and zinc, along with other constituents which are common constituents in urban storm water discharges. To minimize the zinc traces in its storm water, the Company painted a substantial part of the Portland facility’s roofs, and zinc has remained below storm water benchmark levels ever since.

In June 2009, under the ODEQ Agreement, the Company submitted a Final Supplemental Work Plan to evaluate and assess soil and storm water, and further assess groundwater risk, as requested by the ODEQ. In May 2010, the Company submitted a remediation plan related to soil contamination, which the ODEQ approved in August 2010. The Company has completed the approved remediation plan in 2011 and 2012, which included the excavation of localized soil and paving pervious surfaces. A final report on storm water source control with the Final RI/Source Control Evaluation report will be submitted in the second half of 2013.

During the localized soil excavation in 2011, additional stained soil was discovered. At the request of the ODEQ, the Company developed an additional Work Plan to characterize the nature and extent of soil and/or groundwater impacts from the staining. The Company began implementing this Work Plan in the second quarter of 2012 and submitted sampling results to the ODEQ in the third quarter of 2012. Comments from the ODEQ were received in November 2012. In February 2013, the ODEQ clarified its comments from November 2012, and the Company has completed its second round of groundwater sampling for the Stained Soil Investigation Area. The results will be reported to ODEQ in the second half of 2013.

The Company anticipates having to spend less than $0.1 million for further Source Control work in 2013.

Concurrent with the activities of the EPA and the 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 the ODEQ. In 2009, the Trustees completed phase one of their three-phase NRDA. Phase one of the NRDA consisted of environmental studies to fill gaps in the information available from the EPA, and development of a framework for evaluating, quantifying and determining the extent of injuries to the natural resource. Phase two of the NRDA began in 2010 and consists largely of implementing the framework developed in phase one.

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 2009, one of the Tribal Trustees (the Yakima Nation) resigned and has requested funding from the same parties to support its own assessment. The Company has not assumed any payment obligation or liability related to either request.

At this time, the Company is unable to estimate an amount or an amount within a range of costs for it’s obligation with respect to the Portland Harbor matters, and no further adjustment to the Condensed Consolidated Financial Statements has been recorded as of June 30, 2013.

All Sites

We operate our facilities under numerous governmental permits and licenses relating to air emissions, storm water run-off, and other environmental matters. Our 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. We believe we are in material compliance with our permits and licenses and these laws and regulations, and we do not believe that future compliance with such laws and regulations will have a material adverse effect on our 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. 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.

Guarantees

The Company has entered into certain stand-by letters of credit that total $3.1 million at June 30, 2013. The stand-by letters of credit relate to workers’ compensation insurance and equipment financing.

6.	Segment Information

The Company’s operations are organized in two reportable segments, the Water Transmission Group and the Tubular Products Group, which are based on the nature of the products and the manufacturing process. The Water Transmission Group manufactures large-diameter, high-pressure steel pipeline systems for use in water infrastructure applications, 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. 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. These 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.


	Three months ended June 30,						Six months ended June 30,
	2013			2012			2013			2012
	(in thousands)						(in thousands)
Net sales:
Water Transmission	$	58,148		$	59,050		$	136,761		$	117,481
Tubular Products		58,590			71,991			120,574			155,735

Total	$	116,738		$	131,041		$	257,335		$	273,216

Gross profit:
Water Transmission	$	12,125		$	8,149		$	31,995		$	17,848
Tubular Products		3,543			5,428			4,877			12,229

Total	$	15,668		$	13,577		$	36,872		$	30,077

Operating income (loss):
Water Transmission	$	10,499		$	6,130		$	28,532		$	14,154
Tubular Products		2,885			4,651			3,551			10,847
Corporate		(4,004	)		(3,811	)		(7,883	)		(8,852	)

Total	$	9,380		$	6,970		$	24,200		$	16,149

7.	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.

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


	Three months ended June 30,				Six months ended June 30,
	2013		2012		2013		2012
Cost of sales	$	139	$	57	$	267	$	142
Selling, general and administrative expenses		627		638		1,025		1,133

Total	$	766	$	695	$	1,292	$	1,275

As of June 30, 2013, unrecognized compensation expense related to the unvested portion of the Company’s RSUs and PSAs was $5.7 million which is expected to be recognized over a weighted average period of 2.1 years.

Stock Option Awards

A summary of the status of the Company’s stock options as of June 30, 2013 and changes during the 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, 2013		47,000		$	23.19
Options granted		—			—
Options exercised or exchanged		(7,000	)		10.31
Options canceled		—			—

Balance, June 30, 2013		40,000			25.44		5.15	$	141

Exercisable, June 30, 2013		40,000			25.44		5.15	$	141

The total intrinsic value, defined as the difference between the current market value and the grant price, of options exercised or exchanged during the six months ended June 30, 2013 was $117,000.

Restricted Stock Units and Performance Awards

A summary of the status of the Company’s RSUs and PSAs as of June 30, 2013 and changes during the six months then ended is presented below:


	Number of RSUs and PSAs			Weighted Average Grant Date Fair Value
Unvested RSUs and PSAs at January 1, 2013		243,141		$	26.11
RSUs and PSAs granted		113,626			34.23
RSUs and PSAs vested		(88,018	)		23.37
RSUs and PSAs canceled		(9,142	)		25.22

Unvested RSUs and PSAs at June 30, 2013		259,607			30.62

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 with a market-based vesting 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 and ranges from two to three years. The unvested balance of RSUs and PSAs at June 30, 2013 includes approximately 198,000 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

For the six months ended June 30, 2013 and 2012, stock awards of 4,912 and 4,807 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 $27.49 and $23.40 in 2013 and 2012, respectively.

8.	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. The Company is currently under examination by the Internal Revenue Service for years 2009, 2010 and 2011. With few exceptions, the Company is no longer subject to U.S. Federal, state or foreign income tax examinations for years before 2008.

The Company had $5.7 million and $5.2 million of unrecognized tax benefits at June 30, 2013 and December 31, 2012, respectively. 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. Of the balance of unrecognized tax benefits, $2.3 million 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. The Company provided for income taxes at estimated effective tax rates of 34.5% and 32.7%, respectively, for the three and six month periods ended June 30, 2013, and estimated effective tax rates of 34.8% and 36.2%, respectively, for the three and six month periods ended June 30, 2012.

9.	Earnings per Share

Earnings per basic and diluted weighted average common share outstanding were calculated as follows for the three and six months ended June 30, 2013 and 2012 (in thousands, except per share data):


	Three Months Ended June 30,				Six Months Ended June 30,
	2013		2012		2013		2012
Net income	$	5,561	$	3,604	$	15,067	$	8,338

Basic weighted-average common shares outstanding		9,443		9,374		9,440		9,372
Effect of potentially dilutive common shares⁽¹⁾		38		59		34		51

Diluted weighted-average common shares outstanding		9,481		9,433		9,474		9,423

Earnings per common share:
Earnings per basic common share	$	0.59	$	0.38	$	1.60	$	0.89
Earnings per diluted common share	$	0.59	$	0.38	$	1.59	$	0.88

Antidilutive shares not included in diluted common share calculation		95		60		124		45

(1)	Represents the effect of the assumed exercise of stock options and the vesting of restricted stock units and performance stock awards, based on the treasury stock method.

10.

Changes in Accumulated Other Comprehensive Income (Loss)

The following table summarizes changes in the components of accumulated other comprehensive income (loss) during the six months ended June 30, 2013 (in thousands). All amounts are net of tax:


	Defined Benefit Pension Items			Gains (Losses) on Cash Flow Hedges			Total
Balance, December 31, 2012	$	(2,188	)	$	(85	)	$	(2,273	)

Other comprehensive income before reclassifications		—			196			196
Amounts reclassified from accumulated other comprehensive income (loss)		129			(41	)		88

Net current period other comprehensive income		129			155			284

Balance, June 30, 2013	$	(2,059	)	$	70		$	(1,989	)

The following table provides additional detail about accumulated other comprehensive income (loss) components which were reclassified to the Condensed Consolidated Statement of Operations during the six months ended June 30, 2013 (in thousands):


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
Defined Benefit Pension Items
Net periodic pension cost	$	(196	)	Cost of sales
		67		Tax benefit

	$	(129	)	Net of tax

Gains and losses on cash flow hedges
Foreign currency forward contracts	$	65		Net sales
		(24	)	Tax expense

	$	41		Net of tax



Total reclassifications for the period	$	(88	)

11.

Recent Accounting and Reporting Developments

In December 2011, the FASB issued ASU 2011-11 which requires companies to disclose information regarding offsetting and other arrangements for derivatives and other financial instruments. In January 2013, the FASB issued ASU 2013-01, which limited the scope of the balance sheet offsetting disclosures to derivatives, repurchase agreements, and securities lending transactions to the extent that they are (1) offset in the financial statements or (2) subject to an enforceable master netting arrangement or similar agreement. This guidance is effective for interim and annual periods beginning on or after January 1, 2013. The Company adopted this guidance on January 1, 2013 and has made the required additional disclosures.

In February 2013, the FASB issued ASU 2013-02, which clarified the reclassification requirements of ASU 2011-05 which were previously delayed by the FASB in October 2011. Reclassification adjustments which are not reclassified from other comprehensive income to net income in their entirety may instead be parenthetically cross referenced to the related footnote on the face of the financial statements for additional information. This guidance is effective for interim and annual reporting periods beginning after December 15, 2012. The Company adopted this guidance on January 1, 2013 and has made the required additional disclosures.

Item 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, excess or shortage of production capacity, international trade policy and regulations and other risks discussed in our 2012 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

We are a leading North American manufacturer of large-diameter, high-pressure steel pipeline systems for use in water infrastructure applications, primarily related to drinking water systems, and we also manufacture other welded steel pipe products for use in a wide range of applications, including energy, construction, agriculture, and industrial systems. Our pipeline systems are also used for hydroelectric power systems, wastewater systems and other applications, and we also make products for industrial plant piping systems and certain structural applications. These pipeline systems are produced by our Water Transmission Group from six manufacturing facilities located in Portland, Oregon; Denver, Colorado; Adelanto, California; Parkersburg, West Virginia; Saginaw, Texas; and Monterrey, Mexico. Our Water Transmission Group accounted for approximately 53.1% of net sales in the first six months of 2013.

Our water infrastructure products are generally sold to installation contractors, who include our products in their bids to municipal agencies or privately-owned water companies for specific projects. Within the total pipeline system, our products best fit the larger-diameter, higher-pressure applications. We believe our sales are substantially driven by spending on new water infrastructure with additional spending on water infrastructure upgrades, replacements, and repairs. Pricing of our water infrastructure products is largely determined by the competitive environment in each regional market, and the regional markets generally operate independently of each other. We operate our Water Transmission business 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. In the near-term, we expect strained municipal budgets will continue to impact the Water Transmission Group, although increased infrastructure needs in Colorado, Michigan, and Texas and drought-related projects in Texas will help offset the effects of strained municipal budgets in other parts of the United States.

Our Tubular Products Group manufactures other welded steel products in three facilities: Atchison, Kansas; Houston, Texas; and Bossier City, Louisiana. We produce a range of products used in several different markets, including energy, construction, agriculture, and industrial systems, which are sold to distributors and used in many different applications. Our Tubular Products Group’s sales volume is typically driven by energy spending, non-residential construction spending, and general economic conditions. Our Tubular Products Group generated approximately 46.9% of net sales in the first six months of 2013.

We believe the greatest long-term potential for significant sales growth in our Tubular Products Group is through our energy products. In the energy markets, drilling activity, as represented by rig counts, has declined since the end of 2012 but has remained steady during the first six months of 2013 and is expected to remain steady during the second half of 2013. Significant foreign imports of energy products have continued to place downward pressure on our energy sales. A trade case was filed in July 2013 for an investigation of imports of Oil Country Tubular Goods, particularly casing and tubing, from nine countries and possible imposition of anti-dumping duties. However, in the near term, we expect downward pressure on our energy sales due to imports, and we believe that uncertain steel prices have caused pipe buyers to delay their inventory replenishment activity, and to maintain lower levels of inventory.

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. This correlation is the greatest in our Tubular Products Group as its margins are highly sensitive to changes in steel costs, although the amounts of margins are also influenced by the current level of demand in the marketplace.

Critical Accounting Policies and Estimates

The discussion and analysis of our financial condition and results of operations are based upon our 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 consolidated financial statements is set forth in our 2012 Form 10-K.

Recent Accounting Pronouncements

See Note 11 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.

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 June 30, 2013						Three months ended June 30, 2012
	$			% of Net Sales			$			% of Net Sales
Net sales
Water Transmission	$	58,148			49.8	%	$	59,050			45.1	%
Tubular Products		58,590			50.2			71,991			54.9

Total net sales		116,738			100.0			131,041			100.0
Cost of sales		101,070			86.6			117,464			89.6

Gross profit		15,668			13.4			13,577			10.4
Selling, general and administrative expense		6,288			5.4			6,607			5.0

Operating income		9,380			8.0			6,970			5.4
Other expense		(4	)		(0.0	)		(34	)		(0.0	)
Interest income		(60	)		(0.1	)		(46	)		(0.0	)
Interest expense		956			0.8			1,526			1.2

Income before income taxes		8,488			7.3			5,524			4.2
Provision for income taxes		2,927			2.5			1,920			1.5

Net income	$	5,561			4.8	%	$	3,604			2.7	%

Gross profit as a percentage of segment net sales:
Water Transmission					20.9	%					13.8	%
Tubular Products					6.0						7.5

	Six months ended June 30, 2013						Six months ended June 30, 2012
	$			% of Net Sales			$			% of Net Sales
Net sales
Water Transmission	$	136,761			53.1	%	$	117,481			43.0	%
Tubular Products		120,574			46.9			155,735			57.0

Total net sales		257,335			100.0			273,216			100.0
Cost of sales		220,463			85.7			243,139			89.0

Gross profit		36,872			14.3			30,077			11.0
Selling, general and administrative expense		12,672			4.9			13,928			5.1

Operating income		24,200			9.4			16,149			5.9
Other income		37			0.0			2			0.0
Interest income		(243	)		(0.1	)		(87	)		(0.0	)
Interest expense		2,005			0.8			3,166			1.2

Income before income taxes		22,401			8.7			13,068			4.7
Provision for income taxes		7,334			2.8			4,730			1.7

Net income	$	15,067			5.9	%	$	8,338			3.0	%

Gross profit as a percentage of segment net sales:
Water Transmission					23.4	%					15.2	%
Tubular Products					4.0						7.9

Three Months and Six Months Ended June 30, 2013 Compared to Three Months and Six Months Ended June 30, 2012

Net sales. Net sales decreased 10.9% to $116.7 million for the second quarter of 2013 compared to $131.0 million for the second quarter of 2012 and decreased 5.8% to $257.3 million for the first six months of 2013 compared to $273.2 million in the same period of 2012. One customer in the Water Transmission segment accounted for 12.7% of total net sales in the second quarter of 2013. The same customer accounted for 17.1% of total net sales in the first six months of 2013. One customer in the Water Transmission segment accounted for 11.6% of total net sales in the second quarter of 2012. No single customer accounted for more than 10% of total net sales in the first six months of 2012.

Water Transmission sales decreased by 1.5% to $58.1 million in the second quarter of 2013 from $59.1 million in the second quarter of 2012 and increased 16.4% to $136.8 million in the first six months of 2013 from $117.5 million in the first six months of 2012. The decrease in sales in the second quarter of 2013 compared to the second quarter of 2012 was due to a 34% decrease in tons produced, offset by a 49% increase in average selling prices per ton. These variances largely resulted from the timing of production on the Lake Texoma project, which was substantially completed during the second quarter of 2013. The decrease in tons produced was also impacted by continued weakness in municipal markets. The increase in average selling prices per ton in the second quarter of 2013 was due to a 37% increase in materials costs per ton including steel. Higher materials costs generally lead to higher contract values. The increase in sales in the first six months of 2013 compared to the first six months of 2012 was due to a 7% increase in tons produced and a 9% increase in average selling price per ton. The increase in average selling prices per ton in the first six months of 2013 was due to a 5% increase in material costs per ton including steel. Bidding activity, backlog and production levels may vary significantly from period to period affecting sales volumes.

Tubular Products sales decreased 18.6% to $58.6 million in the second quarter of 2013 from $72.0 million in the second quarter of 2012 and decreased 22.6% to $120.6 million in the first six months of 2013 from $155.7 million in the first six months of 2012. The sales decrease in the second quarter of 2013 as compared to the second quarter of 2012 was due to a 6% decrease in tons sold and a 13% decrease in selling price per ton. We sold 52,900 tons in the second quarter of 2013 as compared to 56,500 tons in the second quarter of 2012. The decrease in selling price for the second quarter of 2013 as compared to the second quarter of 2012 was due to a 12% decrease in steel cost per ton along with continued downward pricing pressure from imported pipe. The sales decrease in the first six months of 2013 compared to the same period in 2012 was due to a 13% decrease in tons sold from 122,700 tons to 106,800 tons and an 11% decrease in the average selling price per ton. The decrease in selling price for the first six months of 2013 as compared to the first six months of 2012 was due to an 11% decrease in steel cost per ton along with the downward pricing pressure from imported pipe. Increased imports of energy pipe, decreases in rig counts from 2012, low natural gas prices, and volatility of steel prices have negatively impacted sales volumes and selling prices, particularly in energy pipe. Energy pipe sales volume decreased 3% from 41,700 tons in the second quarter of 2012 to 40,500 tons in the second quarter of 2013, and decreased 13% from 92,300 tons in the first six months of 2012 to 80,800 tons in the first six months of 2013.

Gross profit. Gross profit increased 15.4% to $15.7 million (13.4% of total net sales) in the second quarter of 2013 from $13.6 million (10.4% of total net sales) in the second quarter of 2012 and increased 22.6% to $36.9 million (14.3% of total net sales) in the first six months of 2013 from $30.1 million (11.0% of total net sales) in the first six months of 2012.

Water Transmission gross profit increased $4.0 million, or 48.8%, to $12.1 million (20.9% of segment net sales) in the second quarter of 2013 from $8.1 million (13.8% of segment net sales) in the second quarter of 2012. Water Transmission gross profit also increased $14.1 million, or 79.3%, to $32.0 million (23.4% of segment net sales) in the first six months of 2013 compared to the same period in the prior year when gross profit was $17.8 million (15.2% of segment net sales). The increase in gross profit for the second quarter of 2013 and the first six months of 2013 was primarily driven by the increase in selling price per ton. The positive impacts of the increased selling prices per ton were partially offset by the decline in tons produced, as discussed above. The increase in gross profit as a percentage of net sales in the second quarter of 2013 was driven by a favorable mix of projects. The increase in gross profit as a percentage of net sales in the first six months of 2013 was driven by a favorable mix of projects as well as the higher volume described above, which had a positive impact on the fixed portion of our cost of goods sold as a percentage of net sales.

Gross profit from Tubular Products decreased $1.9 million, or 34.7%, to $3.5 million (6.0% of segment net sales) in the second quarter of 2013 from $5.4 million (7.5% of segment net sales) in the second quarter of 2012 and decreased $7.4 million, or 60.1%, to $4.9 million (4.0% of segment net sales) in the first six months of 2013 from $12.2 million (7.9% of segment net sales) in the first six months of 2012. As noted above, sales of our Tubular Products weakened during the second quarter of 2013, particularly in our energy products, which had sales revenue of $54.6 million in the second quarter of 2012 and decreased 12% to $47.9 million in the second quarter of 2013, and decreased 23% from $124.8 million in the first six months of 2012 to $96.5 million in the first six months of 2013. The lower sales volume had a significant negative impact on the fixed portion of our cost of goods sold as a percent of net sales.

This was partially offset by lower material costs per ton, which decreased 10% in the second quarter of 2013 compared to the second quarter of 2012 and decreased 5% in the first six months of 2013 compared to the first six months of 2012. The decrease in gross profit was also partially offset by a $1.2 million refundable state tax credit accrued during the second quarter of 2013.

Selling, general and administrative expenses. Selling, general and administrative expenses decreased to $6.3 million (5.4% of total net sales) in the second quarter of 2013 from $6.6 million (5.0% of total net sales) in the second quarter of 2012 and decreased to $12.7 million (4.9% of total net sales) in the first six months of 2013 from $13.9 million (5.1% of total net sales) in the first six months of 2012. The decrease in the first six months of 2013 as compared to the first six months of 2012 was due to a decrease of $1.1 million in professional fees, primarily due to a reduction in audit related fees.

Interest expense. Interest expense was $1.0 million in the second quarter of 2013 and $1.5 million in the second quarter of 2012 and $2.0 million in the first six months of 2013 and $3.2 million in the first six months of 2012. Lower average borrowings and lower average interest rates resulted in decreased interest expense in the second quarter of 2013 compared to the second quarter of 2012. Average borrowings and average interest rates were also lower in the first six months of 2013 compared to the same period in 2012, which decreased interest expense in the first six months of 2013 compared to 2012.

Income Taxes. The tax provision was $2.9 million in the second quarter of 2013 (an effective tax rate of 34.5%) compared to $1.9 million in the second quarter of 2012 (an effective tax rate of 34.8%) and $7.3 million in the first six months of 2013 (an effective tax rate of 32.7%) compared to $4.7 million (an effective tax rate of 36.2%) in the first six months of 2012. Our effective tax rate in the second quarter of 2013 and in the first six months of 2013 was less than our federal statutory rate of 35% primarily due to the favorable impact of the retroactive extension of the federal research and development tax credit. Our effective tax rate in the first six months of 2012 exceeded our federal statutory rate of 35% due primarily to state taxes and the relationship of permanent income tax deductions and tax credits to estimated pre-tax income for the respective years.

Liquidity and Capital Resources

Sources and Uses of Cash

Our principal sources of liquidity generally include operating cash flows and our bank credit agreement. Our principal uses of liquidity generally include capital expenditures, working capital and debt service. Information regarding our cash flows for the six months ended June 30, 2013 is presented in our Condensed Consolidated Statements of Cash Flows contained in this Form 10-Q, and is further discussed below.

As of June 30, 2013, our working capital (current assets minus current liabilities) was $180.7 million as compared to $167.4 million as of December 31, 2012. The primary reason for the increase in working capital was an increase in accounts receivable and a decrease in accrued liabilities, partially offset by a decrease in costs and estimated earnings in excess of billings and an increase in accounts payable.

Net cash provided by operating activities in the first six months of 2013 was $13.2 million. Our primary source of operating cash flow in the first six months of 2013 was net income of $15.1 million. This was partially offset by fluctuations in working capital accounts including a decrease in costs and estimated earnings in excess of billings, an increase in accounts payable, and an increase in accounts receivable.

Net cash provided by operating activities in the first six months of 2012 was $24.4 million. This was primarily the result of fluctuations in working capital including a decrease in accounts receivable and an increase in accounts payable, partially offset by an increase in costs and estimated earnings in excess of billings on uncompleted contracts.

Fluctuations in our working capital accounts result from timing differences between production, shipment and invoicing of our products, as well as changes in levels of production and costs of materials. We typically have a relatively large investment in working capital, as we are generally obligated to pay for goods and services early in the project while cash is not received until much later in the project. Our revenues in the Water Transmission segment are recognized on a percentage-of-completion method; therefore, there is little correlation between revenue and cash receipts and the elapsed time 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 from period to period.

Net cash used in investing activities in the first six months of 2013 was $19.6 million, primarily related to capital expenditures for previously disclosed strategic investment projects and funds disbursed under a notes receivable arrangement of $2.9 million. We will distribute an additional $2.8 million under the arrangement during the third quarter of 2013. Capital expenditures in 2013 are expected to be approximately $26 million to $30 million for standard capital replacement and recently announced strategic investment projects. These projects include the installation of an additional horizontal accumulator and hydrotester, and the replacement of the existing

front end of the 16 inch mill at our Atchison plant, as well as expansion at our Saginaw plant, which will enable production of pipe up to 126 inches in diameter as well as increase overall capacity. Expenditures for these strategic investments during the first six months of 2013 included $3.6 million for the replacement of the existing front end of the 16 inch mill and $1.4 million for a new hydrotester at our Atchison plant, and $7.5 million for expansion projects at our Saginaw plant. This was partially offset by proceeds received from the sale of property and equipment of $1.7 million.

Net cash used in investing activities in the first six months of 2012 was $8.1 million, primarily for capital expenditures for storm water upgrades at our Portland, Oregon facility and planned capacity expansion in our Tubular Products plants.

Net cash provided by financing activities in the first six months of 2013 was $6.5 million, which resulted primarily from borrowings under our Credit Agreement totaling $86.0 million, partially offset by repayments under our Credit Agreement and Note Purchase Agreement totaling $77.0 million.

Net cash used in financing activities in the first six months of 2012 was $16.5 million, which resulted primarily from repayments under our Credit Agreement and Note Purchase Agreement totaling $86.1 million, partially offset by net borrowings of $71.8 million.

We anticipate that our existing cash and cash equivalents, cash flows expected to be generated by operations, and amounts available under our credit agreements will be adequate to fund our working capital and capital requirements for the forseeable future. We also expect to continue to rely on cash generated from operations or funds available from our line of credit to make required principal payments on our long-term debt during 2013. 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.

Line of Credit and Long-Term Debt

We had the following significant components of debt at June 30, 2013: a $165.0 million Credit Agreement, under which $60.8 million was outstanding; $2.1 million of Series A Term Notes, $1.5 million of Series B Term Notes, $2.9 million of Series C Term Notes and $1.3 million of Series D Term Notes.

The Credit Agreement bears interest at rates related to LIBOR plus 1.75% to 2.75%, or the lending institution’s prime rate, plus 0.75% to 1.75%. We were able to borrow at LIBOR plus 2.0% under the Credit Agreement at June 30, 2013. Borrowings under the Credit Agreement are collateralized by substantially all of our personal property. The Credit Agreement will expire on October 24, 2017. At June 30, 2013 we had $101.1 million available under the Credit Agreement while remaining in compliance with our financial covenants, net of outstanding letters of credit. The Credit Agreement bears interest at a weighted average rate of 2.48% at June 30, 2013.

The Series A Term Note in the principal amount of $2.1 million matures on February 25, 2014 and requires annual payments in the amount of $2.1 million plus interest of 10.50% paid quarterly on February 25, May 25, August 25 and November 25. The Series B Term Notes in the principal amount of $1.5 million mature on June 21, 2014 and require annual payments in the amount of $1.5 million plus interest of 10.22% paid quarterly on March 21, June 21, September 21 and December 21. The Series C Term Notes in the principal amount of $2.9 million mature on October 26, 2014 and require annual payments of $1.4 million plus interest of 9.11% paid quarterly on January 26, April 26, July 26 and October 26. The Series D Term Notes in the principal amount of $1.3 million mature on January 24, 2015 and require annual payments in the amount of $643,000 plus interest of 9.07% paid quarterly on January 24, April 24, July 24 and October 24. The Series A Term Note, the Series B Term Notes, the Series C Term Notes, and the Series D Term Notes (together, the “Term Notes”) are collateralized by accounts receivable, inventory and certain equipment.

We had a total of $11.5 million in capital lease obligations outstanding at June 30, 2013. The weighted average interest rate on all of our capital leases is 7.73%. Our capital leases are for certain equipment used in the manufacturing process, with $6.0 million of our capital leases outstanding as of June 30, 2013 representing an agreement entered into as of September 2009 to finance our Bossier City, Louisiana facility (the “Financing Arrangement”) under which certain equipment used in the manufacturing process at the facility is leased. As part of the Financing Arrangement, a $10 million escrow account was provided for the Company by a local government entity through a financial institution and funds are released upon qualifying purchase requisitions. As we purchase equipment for the facility, we enter into a sale-leaseback transaction with the governmental entity as part of the Financing Arrangement. As of June 30, 2013, $0.9 million was held in the escrow account, which is included in other assets, as a result of proceeds from the Financing Arrangement. The Financing Arrangement requires us to meet certain loan covenants, measured at the end of each fiscal quarter. These loan covenants follow the covenants required by our Credit Agreement.

The Credit Agreement, the Note Purchase Agreement and certain of our leases place various restrictions on our ability to, among other things, incur certain additional indebtedness, create liens or other encumbrances on assets, and incur additional capital expenditures.

The Credit Agreement, Note Purchase Agreement, and certain of our leases require us to be in compliance with certain financial covenants. The results of our financial covenants as of June 30, 2013 are below.

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The Consolidated Total Leverage Ratio must not be greater than 3.5:1.0. Our ratio as of June 30, 2013 is 1.45:1.0.

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The Consolidated Tangible Net Worth must be greater than $209.8 million. Our Tangible Net Worth as of June 30, 2013 is $254.9 million.

•

The Consolidated Fixed Charge Coverage Ratio must not be less than 1.25:1.0. Our ratio at June 30, 2013 is 1.93:1.0

As of June 30, 2013, we are in compliance with all financial covenants.

Based on our business plan and forecasts of operations, we believe we will remain in compliance with our covenants for the next twelve months.

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.

Item 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 2012 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 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 June 30, 2013, 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 June 30, 2013. As a result of the assessment, our CEO and CFO have concluded that, as of June 30, 2013, our disclosure controls and procedures were effective.

Changes in Internal Control over Financial Reporting

There were no changes in our internal control over financial reporting that occurred during the quarter ended June 30, 2013 that materially affected or are reasonably likely to materially affect our internal control over financial reporting.

Part II – Other Information

Item 1. Legal Proceedings

Information required by this Item 1 is contained in Note 5 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, 2012 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.

Item 6. Exhibits

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


Exhibit Number		Description

10.1		Form of Restricted Stock Unit Agreement, incorporated by reference to the Company’s Current Report on Form 8-K, as filed with the Securities and Exchange Commission on June 5, 2013*

10.2		Form of Performance Share Award Agreement, incorporated by reference to the Company’s Current Report on Form 8-K, as filed with the Securities and Exchange Commission on June 5, 2013*

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

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

*	This exhibit constitutes a management contract or compensatory plan or arrangement.

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: August 6, 2013


NORTHWEST PIPE COMPANY

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

By:		/s/ ROBIN GANTT
		Robin Gantt
		Senior Vice President, Chief Financial Officer, and Assistant Secretary
		(Principal Financial Officer)

Large accelerated filer

Accelerated filer

Non-accelerated filer

Smaller reporting company