Edgar Filing: DRIL-QUIP INC

Large accelerated filer

Accelerated filer

Non-accelerated filer

¨ (Do not check if a smaller reporting company)

Smaller reporting company

Form 10-Q

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

(MARK ONE)

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

FOR THE QUARTERLY PERIOD ENDED JUNE 30, 2015

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

Commission file number 001-13439

DRIL-QUIP, INC.

(Exact name of registrant as specified in its charter)

DELAWARE

74-2162088

(State or other jurisdiction of

incorporation or organization)

(I.R.S. Employer

Identification No.)

6401 N. ELDRIDGE PARKWAY

HOUSTON, TEXAS

77041

(Address of principal executive offices) (Zip Code)

(713) 939-7711

(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 regulations 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.

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

As of July 27, 2015, the number of shares outstanding of the registrant’s common stock, par value $.01 per share, was 38,705,278.

PART I—FINANCIAL INFORMATION

Item 1.

FINANCIAL STATEMENTS

DRIL-QUIP, INC.

CONDENSED CONSOLIDATED BALANCE SHEETS

(UNAUDITED)


	June 30, 2015			December 31, 2014
	(In thousands)
ASSETS
Current assets:
Cash and cash equivalents	$	382,673		$	298,705
Trade receivables, net		299,398			373,993
Inventories, net		383,773			392,559
Deferred income taxes		27,028			23,569
Prepaids and other current assets		38,099			38,314

Total current assets		1,130,971			1,127,140
Property, plant and equipment, net		301,635			309,525
Other assets		14,180			12,586

Total assets	$	1,446,786		$	1,449,251

LIABILITIES AND STOCKHOLDERS’ EQUITY
Current liabilities:
Accounts payable	$	39,520		$	53,837
Accrued income taxes		9,515			16,903
Customer prepayments		39,608			71,177
Accrued compensation		19,097			21,527
Other accrued liabilities		18,977			35,198

Total current liabilities		126,717			198,642
Deferred income taxes		4,298			5,417

Total liabilities		131,015			204,059

Commitments and contingencies (Note 7)
Stockholders’ equity:
Preferred stock, 10,000,000 shares authorized at $0.01 par value (none issued)		—			—
Common stock:
100,000,000 shares authorized at $0.01 par value at June 30, 2015 and December 31, 2014, 38,705,278 and 38,932,508 shares issued and outstanding at June 30, 2015 and December 31, 2014		385			388
Additional paid-in capital		4,880			16,480
Retained earnings		1,371,403			1,278,528
Accumulated other comprehensive losses		(60,897	)		(50,204	)

Total stockholders’ equity		1,315,771			1,245,192

Total liabilities and stockholders’ equity	$	1,446,786		$	1,449,251

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

DRIL-QUIP, INC.

CONDENSED CONSOLIDATED STATEMENTS OF INCOME

(UNAUDITED)


	Three months ended June 30,						Six months ended June 30,
	2015			2014			2015			2014
	(In thousands, except per share data)
Revenues:
Products	$	176,099		$	189,914		$	363,623		$	361,915
Services		39,177			40,401			77,655			72,473

Total revenues		215,276			230,315			441,278			434,388
Cost and expenses:
Cost of sales:
Products		98,349			104,208			204,356			195,539
Services		19,315			20,785			38,446			40,241

Total cost of sales		117,664			124,993			242,802			235,780
Selling, general and administrative		33,633			25,520			50,591			49,455
Engineering and product development		11,400			10,848			23,613			21,632

Total costs and expenses		162,697			161,361			317,006			306,867

Operating income		52,579			68,954			124,272			127,521
Interest income		165			266			214			349
Interest expense		(3	)		(5	)		(6	)		(12	)

Income before income taxes		52,741			69,215			124,480			127,858
Income tax provision		13,528			17,891			31,603			33,916

Net income	$	39,213		$	51,324		$	92,877		$	93,942

Earnings per common share:
Basic	$	1.01		$	1.27		$	2.40		$	2.32

Diluted	$	1.01		$	1.27		$	2.39		$	2.31

Weighted average common shares outstanding:
Basic		38,686			40,327			38,729			40,501

Diluted		38,888			40,562			38,912			40,723

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

DRIL-QUIP, INC.

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME

(UNAUDITED)


	Three months ended June 30,				Six months ended June 30,
	2015		2014		2015			2014
	(In thousands)
Net income	$	39,213	$	51,324	$	92,877		$	93,942
Other comprehensive income (loss), net of tax:
Foreign currency translation adjustments		21,841		10,699		(10,693	)		16,428

Total comprehensive income	$	61,054	$	62,023	$	82,184		$	110,370

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

DRIL-QUIP, INC.

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(UNAUDITED)


	Six months ended June 30,
	2015			2014
	(In thousands)
Operating activities
Net income	$	92,877		$	93,942
Adjustments to reconcile net income to net cash provided by (used in) operating activities:
Depreciation and amortization		15,139			15,126
Stock-based compensation expense		6,482			5,660
Loss (gain) on sale of equipment		75			(149	)
Deferred income taxes		(4,935	)		(2,507	)
Changes in operating assets and liabilities:
Trade receivables, net		70,508			(33,272	)
Inventories, net		3,348			(32,708	)
Prepaids and other assets		(2,958	)		3,194
Excess tax benefits of stock options and awards		(57	)		(251	)
Accounts payable and accrued expenses		(67,468	)		17,637

Net cash provided by operating activities		113,011			66,672
Investing activities
Purchase of property, plant and equipment		(11,204	)		(23,218	)
Proceeds from sale of equipment		136			470

Net cash used in investing activities		(11,068	)		(22,748	)
Financing activities
Repurchase of common stock		(19,943	)		(90,022	)
Proceeds from exercise of stock options		1,952			1,386
Excess tax benefits of stock options and awards		57			251

Net cash used in financing activities		(17,934	)		(88,385	)
Effect of exchange rate changes on cash activities		(41	)		2,726

Increase (decrease) in cash and cash equivalents		83,968			(41,735	)
Cash and cash equivalents at beginning of period		298,705			384,356

Cash and cash equivalents at end of period	$	382,673		$	342,621

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

DRIL-QUIP, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

1. Organization and Principles of Consolidation

Dril-Quip, Inc., a Delaware corporation (the “Company” or “Dril-Quip”), designs, manufactures, sells and services highly engineered offshore drilling and production equipment that is well suited for use in deepwater, harsh environment and severe service applications. The Company’s principal products consist of subsea and surface wellheads, subsea and surface production trees, subsea control systems and manifolds, mudline hanger systems, specialty connectors and associated pipe, drilling and production riser systems, liner hangers, wellhead connectors and diverters. Dril-Quip’s products are used by major integrated, large independent and foreign national oil and gas companies in offshore areas throughout the world. Dril-Quip also provides technical advisory assistance on an as-requested basis during installation of its products, as well as rework and reconditioning services for customer-owned Dril-Quip products. In addition, Dril-Quip’s customers may rent or purchase running tools from the Company for use in the installation and retrieval of the Company’s products.

The Company’s operations are organized into three geographic segments—Western Hemisphere (including North and South America; headquartered in Houston, Texas), Eastern Hemisphere (including Europe and Africa; headquartered in Aberdeen, Scotland) and Asia-Pacific (including the Pacific Rim, Southeast Asia, Australia, India and the Middle East; headquartered in Singapore). Each of these segments sells similar products and services and the Company has major manufacturing facilities in all three of its headquarter locations as well as in Macae, Brazil.

The condensed consolidated financial statements included herein are unaudited. The balance sheet at December 31, 2014, has been derived from the audited consolidated financial statements at that date. In the opinion of management, the unaudited condensed consolidated interim financial statements include all normal recurring adjustments necessary for a fair presentation of the financial position as of June 30, 2015 and the results of operations and comprehensive income for the three- and six-month periods ended June 30, 2015 and 2014 and the cash flows for the six-month periods ended June 30, 2015 and 2014. Certain information and footnote disclosures normally included in the annual audited 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. Management believes the unaudited interim related disclosures in these condensed consolidated financial statements are adequate. The results of operations, comprehensive income and the cash flows for the six-month period ended June 30, 2015 are not necessarily indicative of the results to be expected for the full year. The condensed consolidated financial statements included herein should be read in conjunction with the audited consolidated financial statements and notes thereto included in the Company’s Annual Report on Form 10-K for the year ended December 31, 2014.

2. Significant Accounting Policies

Principles of Consolidation

The condensed consolidated financial statements include the accounts of the Company and its subsidiaries. All material intercompany accounts and transactions have been eliminated.

Revisions

The Company has corrected its Condensed Consolidated Statements of Cash Flow for the six-month period ended June 30, 2014, to reflect a $6.7 million reclassification adjustment from changes in prepaids and other assets to changes in accounts payable and accrued expenses related to the 2014 beginning balances. There was no impact on the net cash provided by operating activities or any other reported cash flow amounts as a result of the reclassifications. The Company has evaluated the impact of this revision and determined that it was not material.

Use of Estimates

The preparation of financial statements in conformity with accounting principles generally accepted in the United States of America requires management to make estimates and assumptions that affect reported amounts of assets and liabilities and disclosure of contingent assets and liabilities as of the date of the financial statements and reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates. Some of the Company’s more significant estimates are those affected by critical accounting policies for revenue recognition, inventories and contingent liabilities.

Revenue Recognition

Product Revenue

The Company earns product revenues from two methods:

•

product revenues recognized under the percentage-of-completion method; and

•

product revenues from the sale of products that do not qualify for the percentage-of-completion method.

Revenues recognized under the percentage-of-completion method

The Company uses the percentage-of-completion method on long-term project contracts that have the following characteristics:

•

The contracts call for products which are designed to customer specifications;

•

The structural designs are unique and require significant engineering and manufacturing efforts generally requiring more than one year in duration;

•

The contracts contain specific terms as to milestones, progress billings and delivery dates; and

•

Product requirements cannot be filled directly from the Company’s standard inventory.

For each project, the Company prepares a detailed analysis of estimated costs, profit margin, completion date and risk factors which include availability of material, production efficiencies and other factors that may impact the project. On a quarterly basis, management reviews the progress of each project, which may result in revisions of previous estimates, including revenue recognition. The Company calculates the percent complete and applies the percentage to determine the revenues earned and the appropriate portion of total estimated costs. Losses, if any, are recorded in full in the period they become known. Historically, the Company’s estimates of total costs and costs to complete have approximated actual costs incurred to complete the project.

Under the percentage-of-completion method, billings may not correlate directly to the revenue recognized. Based upon the terms of the specific contract, billings may be in excess of the revenue recognized, in which case the amounts are included in customer prepayments as a liability on the Condensed Consolidated Balance Sheets. Likewise, revenue recognized may exceed customer billings in which case the amounts are reported in trade receivables. Unbilled revenues are expected to be billed and collected within one year. At June 30, 2015 and December 31, 2014, receivables included $77.6 million and $68.0 million of unbilled receivables, respectively. For the quarter ended June 30, 2015, there were 10 projects representing approximately 17% of the Company’s total revenue and approximately 21% of its product revenues that were accounted for using percentage-of-completion accounting, compared to 12 projects during the second quarter of 2014, which represented approximately 5% of the Company’s total revenues and approximately 6% of its product revenues. For the six months ended June 30, 2015, there were 13 projects representing approximately 16% of the Company’s total revenues and approximately 19% of its product revenues, compared to 16 projects that represented approximately 8% of the Company’s total revenues and approximately 10% of its product revenues for the six months ended June 30, 2014, all of which were accounted for using percentage-of-completion accounting.

Revenues not recognized under the percentage-of-completion method

Revenues from the sale of inventory products, not accounted for under the percentage-of-completion method, are recorded at the time the manufacturing processes are complete and ownership is transferred to the customer.

Service revenue

The Company earns service revenues from three sources:

•

technical advisory assistance;

•

rental of running tools; and

•

rework and reconditioning of customer-owned Dril-Quip products.

The Company does not install products for its customers, but it does provide technical advisory assistance. At the time of delivery of the product, the customer is not obligated to buy or rent the Company’s running tools and the Company is not obligated to perform any subsequent services relating to installation. Technical advisory assistance service revenue is recorded at the time the service is rendered. Service revenues associated with the rental of running and installation tools are recorded as earned. Rework and reconditioning service revenues are recorded when the refurbishment process is complete.

The Company normally negotiates contracts for products, including those accounted for under the percentage-of-completion method, and services separately. For all product sales, it is the customer’s decision as to the timing of the product installation as well as whether Dril-Quip running tools will be purchased or rented. Furthermore, the customer is under no obligation to utilize the Company’s technical advisory assistance services. The customer may use a third party or their own personnel.

Fair Value of Financial Instruments

The Company’s financial instruments consist primarily of cash and cash equivalents, receivables and payables. The carrying values of these financial instruments approximate their respective fair values as they are short-term in nature.

Earnings Per Share

Basic earnings per common share is computed by dividing net income by the weighted average number of shares of common stock outstanding during the period. Diluted earnings per common share is computed considering the dilutive effect of stock options and awards using the treasury stock method.

In each relevant period, the net income used in the basic and dilutive earnings per share calculations is the same. The following table reconciles the weighted average basic number of common shares outstanding and the weighted average diluted number of common shares outstanding for the purpose of calculating basic and diluted earnings per share:


	Three months ended June 30,				Six months ended June 30,
	2015		2014		2015		2014
	(In thousands)
Weighted average common shares outstanding—basic		38,686		40,327		38,729		40,501
Dilutive effect of common stock options and awards		202		235		183		222

Weighted average common shares outstanding—diluted		38,888		40,562		38,912		40,723

3. New Accounting Standards

In May 2014, the FASB issued ASU 2014-09 “Revenue from Contracts with Customers (Topic 606).” The amendment applies a new five-step revenue recognition model to be used in recognizing revenues associated with customer contracts. The amendment requires disclosure sufficient to enable readers of financial statements to understand the nature, amount, timing, and uncertainty of revenue and cash flows arising from contracts with customers, including qualitative and quantitative disclosures, significant judgments and changes in judgments, and assets recognized from the costs to obtain or fulfill the contract. The standard’s effective date was originally for fiscal years beginning after December 15, 2016, including interim periods within that reporting period. On April 1, 2015, the FASB voted to defer the effective date by one year to December 15, 2017 and interim periods within annual reporting periods beginning after December 15, 2017. The Company is currently evaluating the new guidance to determine the impact on its consolidated financial statements.

4. Stock-Based Compensation and Stock Awards

During the three months ended June 30, 2015 and 2014, the Company recognized approximately $3.1 million and $2.8 million, respectively, of stock-based compensation expense, which is included in the selling, general and administrative expense line on the Condensed Consolidated Statements of Income. For the six months ended June 30, 2015 and 2014, stock-based compensation expense totaled $6.5 million and $5.7 million, respectively. No stock-based compensation expense was capitalized during the three or six months ended June 30, 2015 or 2014.

5. Inventories, net

Inventories consist of the following:


	June 30, 2015			December 31, 2014
	(In thousands)
Raw materials	$	111,587		$	107,357
Work in progress		108,110			112,514
Finished goods		200,646			207,295

		420,343			427,166
Less: allowance for obsolete and excess inventory		(36,570	)		(34,607	)

Total inventory	$	383,773		$	392,559

6. Geographic Areas


	Three months ended June 30,						Six months ended June 30,
	2015			2014			2015			2014
	(In thousands)
Revenues:
Western Hemisphere
Products	$	82,560		$	115,953		$	174,375		$	210,342
Services		21,498			18,381			43,807			35,281
Intercompany		14,770			9,063			24,755			19,355

Total	$	118,828		$	143,397		$	242,937		$	264,978

Eastern Hemisphere
Products	$	60,818		$	43,814		$	140,239		$	97,737
Services		13,617			16,514			25,259			27,991
Intercompany		4,602			3,325			4,823			3,499

Total	$	79,037		$	63,653		$	170,321		$	129,227

Asia-Pacific
Products	$	32,721		$	30,147		$	49,009		$	53,836
Services		4,062			5,506			8,589			9,201
Intercompany		1,208			962			2,389			2,330

Total	$	37,991		$	36,615		$	59,987		$	65,367

Summary
Products	$	176,099		$	189,914		$	363,623		$	361,915
Services		39,177			40,401			77,655			72,473
Intercompany		20,580			13,350			31,967			25,184
Eliminations		(20,580	)		(13,350	)		(31,967	)		(25,184	)

Total	$	215,276		$	230,315		$	441,278		$	434,388

Income before income taxes:
Western Hemisphere	$	27,016		$	36,010		$	59,964		$	72,170
Eastern Hemisphere		13,875			15,827			45,583			31,174
Asia-Pacific		9,064			15,853			12,489			21,308
Eliminations		2,786			1,525			6,444			3,206

Total	$	52,741		$	69,215		$	124,480		$	127,858


	June 30, 2015			December 31, 2014
	(In thousands)
Total Long-Lived Assets:
Western Hemisphere	$	216,968		$	221,597
Eastern Hemisphere		45,318			45,517
Asia-Pacific		56,455			57,923
Eliminations		(2,926	)		(2,926	)

Total	$	315,815		$	322,111

Total Assets:
Western Hemisphere	$	718,918		$	731,448
Eastern Hemisphere		389,371			375,781
Asia-Pacific		344,788			354,329
Eliminations		(6,291	)		(12,307	)

Total	$	1,446,786		$	1,449,251

7. Commitments and Contingencies

Brazilian Tax Issue

From 2002 to 2007, the Company’s Brazilian subsidiary imported goods through the State of Espirito Santo in Brazil and subsequently transferred them to its facility in the State of Rio de Janeiro. During that period, the Company’s Brazilian subsidiary paid taxes to the State of Espirito Santo on its imports. Upon the final sale of these goods, the Company’s Brazilian subsidiary collected taxes from customers and remitted them to the State of Rio de Janeiro net of the taxes paid on importation of those goods to the State of Espirito Santo in accordance with the Company’s understanding of Brazilian tax laws.

In August 2007, the State of Rio de Janeiro served the Company’s Brazilian subsidiary with assessments to collect a state tax on the importation of goods through the State of Espirito Santo from 2002 to 2007 claiming that these taxes were due and payable to it under applicable law. The Company settled these assessments with payments to the State of Rio de Janeiro of $12.2 million in March 2010 and $3.9 million in December 2010. Approximately $7.8 million of these settlement payments were attributable to penalties, interest and amounts that had expired under the statute of limitations so that amount was recorded as an expense. The remainder of the settlement payments generated credits (recorded as a long-term prepaid tax) to be used to offset future state taxes on sales to customers in the State of Rio de Janeiro, subject to certification by the tax authorities. During the second quarter of 2015, the tax authorities certified approximately $8.3 million of those credits paid in 2010 and granted an additional $2.3 million in inflation-related credits. The additional amount of credits granted by the tax authorities increased long-term prepaid taxes and decreased selling, general and administrative expenses by $2.3 million.

In December 2010 and January 2011, the Company’s Brazilian subsidiary was served with two additional assessments totaling approximately $13.0 million from the State of Rio de Janeiro to cancel the credits associated with the tax payments to the State of Espirito Santo (“Santo Credits”) on the importation of goods from July 2005 to October 2007. The Santo Credits are not related to the credits described above. The Company has objected to these assessments on the grounds that they would represent double taxation on the importation of the same goods and that the Company is entitled to the credits under applicable Brazilian law. With regard to the December 2010 assessment, the Company’s Brazilian subsidiary filed an appeal with the relevant State of Rio de Janeiro judicial court to annul the tax assessment following a ruling against the Company by the tax administration’s highest council. In connection with that appeal, the Company was required to deposit with the court approximately $3.1 million as the full amount of the assessment with penalties and interest. The Company intends to file a similar appeal in the judicial system with regard to the January 2011 assessment as a result of a recent ruling against the Company by the tax administration’s highest council. The Company believes that these credits are valid and that success in the judicial court process is probable. Based upon this analysis, the Company has not accrued any liability in conjunction with this matter.

Since 2007, the Company’s Brazilian subsidiary has paid taxes on the importation of goods directly to the State of Rio de Janeiro and the Company does not expect any similar issues to exist for periods subsequent to 2007.

General

The Company operates its business and markets its products and services in most of the significant oil and gas producing areas in the world and is, therefore, subject to the risks customarily attendant to international operations and dependency on the condition of the oil and gas industry. Additionally, products of the Company are used in potentially hazardous drilling, completion, and production applications that can cause personal injury, product liability, and environmental claims. Although exposure to such risk has not resulted in any significant problems in the past, there can be no assurance that ongoing and future developments will not adversely impact the Company.

The Company is also involved in a number of legal actions arising in the ordinary course of business. Although no assurance can be given with respect to the ultimate outcome of such legal action, in the opinion of management, the ultimate liability with respect thereto will not have a material adverse effect on the Company’s operations, financial position or cash flows.

Item 2.

Management’s Discussion and Analysis of Financial Condition and Results of Operations

The following is management’s discussion and analysis of certain significant factors that have affected aspects of the Company’s financial position, results of operations, comprehensive income and cash flows during the periods included in the accompanying unaudited condensed consolidated financial statements. This discussion should be read in conjunction with the unaudited condensed consolidated financial statements and notes therein presented elsewhere herein as well as the discussion under “Risk Factors,” “Management’s Discussion and Analysis of Financial Condition and Results of Operations” and the financial statements included in the Company’s Annual Report on Form 10-K for the year ended December 31, 2014.

Overview

Dril-Quip designs, manufactures, sells and services highly engineered offshore drilling and production equipment that is well suited for use in deepwater, harsh environment and severe service applications. The Company designs and manufactures subsea equipment, surface equipment and offshore rig equipment for use by major integrated, large independent and foreign national oil and gas companies in offshore areas throughout the world. The Company’s principal products consist of subsea and surface wellheads, subsea and surface production trees, subsea control systems and manifolds, mudline hanger systems, specialty connectors and associated pipe, drilling and production riser systems, liner hangers, wellhead connectors and diverters. Dril-Quip also provides technical advisory assistance services on an as-requested basis during installation of its products, as well as rework and reconditioning services for customer-owned Dril-Quip products. In addition, Dril-Quip customers may rent or purchase running tools from the Company for use in the installation and retrieval of the Company’s products.

Oil and Gas Prices

Both the market for offshore drilling and production equipment and services and the Company’s business are substantially dependent on the condition of the oil and gas industry and, in particular, the willingness of oil and gas companies to make capital expenditures on exploration, drilling and production operations offshore. Oil and gas prices and the level of offshore drilling activity have historically been characterized by significant volatility.

According to the Energy Information Administration (“EIA”) of the U.S. Department of Energy, Brent Crude oil and Henry Hub natural gas closing and average prices are listed below for the periods covered by this report:


	Three months ended June 30,				Six months ended June 30,
	2015		2014		2015		2014
Closing Crude oil ($/Bbl)	$	60.31	$	111.03	$	60.31	$	111.03
Average Crude oil ($/Bbl)	$	61.65	$	109.69	$	57.84	$	108.93
Closing Natural gas ($/Mcf)	$	2.89	$	4.53	$	2.89	$	4.53
Average Natural gas ($/Mcf)	$	2.83	$	4.75	$	2.91	$	5.04

During the second quarter of 2015, Brent Crude oil closing prices ranged between $55.73 per barrel and $66.33 per barrel with an average quarterly price of $61.65 per barrel, as compared to a range of $103.37 per barrel and $115.19 per barrel with an average quarterly price of $109.69 per barrel for the same period in 2014. For the six months ended June 30, 2015 and 2014, Brent Crude oil closing prices averaged $57.84 per barrel and $108.93 per barrel, respectively, and ranged between $45.13 per barrel and $66.33 per barrel for the 2015 period, as compared to a range of $103.37 per barrel to $115.19 per barrel for the same period in 2014. Brent Crude oil prices ended the second quarter of 2015 at $60.31 per barrel and closed at $56.42 per barrel on July 20, 2015. Average crude oil prices for the six-month periods ended June 30, 2014 and 2015 have dropped by approximately 47%. At June 30, 2015, the Henry Hub natural gas closing price was $2.89 per Mcf, compared to $4.53 per Mcf on June 30, 2014. The Henry Hub natural gas prices ranged from $2.58 per Mcf to $3.13 per Mcf for the quarter ended June 30, 2015 as compared to a low of $4.53 per Mcf and a high of $4.98 per Mcf for the quarter ended June 30, 2014. The Henry Hub natural gas price at June 30, 2015 was $2.89 per Mcf and on July 20, 2015, the closing price was $2.97 per Mcf.

According to the July 2015 release of the Short-Term Energy Outlook published by the EIA, Brent Crude oil prices are projected to average $60.15 per barrel in 2015 and $67.00 per barrel in 2016. In its July 2015 Oil Market Report, the International Energy Agency forecasted that world demand for oil will be approximately 94.0 million barrels per day in 2015, increasing to 95.2 million barrels per day in 2016. The EIA estimates U.S. output will rise to 9.47 million barrels per day in 2015 and slow to 9.32 million barrels per day in 2016. In July 2015, the EIA projected that Henry Hub natural gas prices will average $3.06 per Mcf in 2015 and $3.41 per Mcf in 2016.

Rig Count

Detailed below is the average contracted rig count for the Company’s geographic regions for the six months ended June 30, 2015 and 2014. The rig count data includes floating rigs (semi-submersibles and drillships) and jack-up rigs. The Company has included only these types of rigs as they are the primary end users of the Company’s products.


	Six months ended June 30,
	2015				2014
	Floating Rigs		Jack-up Rigs		Floating Rigs		Jack-up Rigs
Western Hemisphere		121		73		126		98
Eastern Hemisphere		90		90		99		96
Asia-Pacific		44		257		54		260

TOTAL		255		420		279		454

Source: IHS—Petrodata RigBase – June 30, 2015 and 2014

The table above represents rigs under contract and includes rigs currently drilling as well as rigs committed, but not yet drilling. According to IHS-Petrodata RigBase, as of June 30, 2015, there were 58 rigs under contract in the U.S. Gulf of Mexico (47 floating rigs and 11 jack-up rigs), 48 of which were actively drilling (37 floating rigs and 11 jack-up rigs). As of June 30, 2014, there were 71 rigs under contract in the U.S. Gulf of Mexico, (43 floating rigs and 28 jack-up rigs), 63 of which were actively drilling, (35 floating rigs and 28 jack-up rigs.)

The global offshore count for rigs under contract decreased 8.91% from December 2014 to June 2015 and another 1% by mid-July 2015.

The Company believes that the number of rigs (semi-submersibles, drillships and jack-up rigs) under construction impacts its revenues because in certain cases, its customers order some of the Company’s products during the construction of such rigs. As a result, an increase in rig construction activity tends to favorably impact the Company’s backlog while a decrease in rig construction activity tends to negatively impact the Company’s backlog. According to IHS-Petrodata RigBase, at the end of June 2015 and 2014, there were 209 and 244 rigs, respectively, under construction. The expected delivery dates for the rigs under construction as of June 30, 2015 are as follows:


	Floating Rigs		Jack-Up Rigs		Total
2015		15		51		66
2016		32		47		79
2017		15		24		39
2018		9		4		13
After 2018 or unspecified delivery date		9		3		12

		80		129		209

Regulation

The demand for the Company’s products and services is also affected by laws and regulations relating to the oil and gas industry in general, including those specifically directed to offshore operations. The adoption of new laws and regulations, or changes to existing laws or regulations that curtail exploration and development drilling for oil and gas for economic or other policy reasons could adversely affect the Company’s operations by limiting demand for its products.

Business Environment

Oil and gas prices and the level of offshore drilling and production activity have been characterized by significant volatility in recent years. Worldwide military, political, economic and other events have contributed to oil and natural gas price volatility and are likely to continue to do so in the future. Lower crude oil and natural gas prices have resulted in a trend of customers seeking to renegotiate contract terms with the Company, including reductions in the prices of its products and services and extensions of delivery terms. In addition, some of the Company’s customers could experience liquidity or solvency issues or could otherwise be unable or unwilling to perform under a contract, which could ultimately lead a customer to enter bankruptcy or otherwise encourage a customer to seek to repudiate, cancel or renegotiate a contract. An extended period of reduced crude oil and natural gas prices may accelerate these trends. If the Company experiences significant contract terminations, suspensions or scope adjustments to its contracts, financial condition, results of operations and cash flows may be adversely impacted.

The Company expects continued volatility in both crude oil and natural gas prices, as well as in the level of drilling and production related activities. Even during periods of high prices for oil and natural gas, companies exploring for oil and gas may cancel or curtail programs, or reduce their levels of capital expenditures for exploration and production for a variety of reasons. In addition, a significant and prolonged decline in hydrocarbon prices would likely have a material adverse effect on the Company’s results of operations.

The Company believes that its backlog should help mitigate the impact of negative market conditions; however, a continued decline in commodity prices or an extended downturn in the global economy or future restrictions or declines in offshore oil and gas exploration and production could have a negative impact on the Company and/or its backlog. The Company’s backlog at June 30, 2015 was approximately $1.0 billion compared to approximately $1.3 billion at June 30, 2014 and $1.2 billion at December 31, 2014. In August 2012, the Company’s Brazilian subsidiary, Dril-Quip do Brasil LTDA, was awarded a four-year contract by Petroleo Brasileiro S.A. (“Petrobras”), Brazil’s national oil company. At exchange rates in effect at the signing date (2.04 Brazilian real to 1.00 U.S. dollar), the contract was valued at $650 million, net of Brazilian taxes, if all the equipment under the contract is ordered. The Company cannot provide assurance that Petrobras will order all of the equipment under the contract. Amounts are included in the Company’s backlog as purchase orders under this contract are received. Revenues of approximately $90 million have been recognized on this contract through June 30, 2015. As of June 30, 2015, the Company’s backlog included approximately $69 million (at June 30, 2015 exchange rate of 3.10 Brazilian real to 1.00 U.S. dollar) of purchase orders under this Petrobras contract. The Company has not yet recognized revenue of approximately $10 million as of June 30, 2015 for certain items of equipment that were completed but not yet accepted for delivery by Petrobras. If Petrobras does not ultimately accept these items for delivery or if they refuse to accept these or similar items completed in the future, the Company’s results of operations may be adversely affected.

The Company operates its business and markets its products and services in most of the significant oil and gas producing areas in the world and is, therefore, subject to the risks customarily attendant to international operations and investments in foreign countries. These risks include nationalization, expropriation, war, acts of terrorism and civil disturbance, restrictive action by local governments, limitation on repatriation of earnings, change in foreign tax laws and change in currency exchange rates, any of which could have an adverse effect on either the Company’s ability to manufacture its products in its facilities abroad or the demand in certain regions for the Company’s products or both. To date, the Company has not experienced any significant problems in foreign countries arising from local government actions or political instability, but there is no assurance that such problems will not arise in the future. Interruption of the Company’s international operations could have a material adverse effect on its overall operations.

Revenues. Dril-Quip’s revenues are generated from two sources: products and services. Product revenues are derived from the sale of offshore drilling and production equipment. Service revenues are earned when the Company provides technical advisory assistance for installation of the Company’s products, reconditioning services and rental of running tools for installation and retrieval of the Company’s products. For the three and six months ended June 30, 2015 and 2014, the Company derived 82% and 83%, respectively, of its revenues from the sale of its products and 18% and 17%, respectively, of its revenues from services. Service revenues generally correlate to revenues from product sales because increased product sales typically generate increased demand for technical advisory assistance services during installation and rental of running tools. The Company has substantial international operations, with approximately 67% and 57% of its revenues derived from foreign sales for the three months ended June 30, 2015 and 2014, respectively, and 65% and 60% for the six months ended June 30, 2015 and 2014, respectively. Substantially all of the Company’s domestic revenue relates to operations in the U. S. Gulf of Mexico. Domestic revenue approximated 33% and 43%, respectively, of the Company’s total revenues for the three months ended June 30, 2015 and 2014 and 35% and 40%, respectively, for the six months ended June 30, 2015 and 2014.

Product contracts are negotiated and sold separately from service contracts. In addition, service contracts are not typically included in the product contracts or related sales orders and are not offered to the customer as a condition of the sale of the Company’s products. The demand for products and services is generally based on world-wide economic conditions in the offshore oil and gas industry, and is not based on a specific relationship between the two types of contracts. Substantially all of the Company’s sales are made on a purchase order basis. Purchase orders are subject to change and/or termination at the option of the customer. In case of a change or termination, the customer is required to pay the Company for work performed and other costs necessarily incurred as a result of the change or termination.

Generally, the Company attempts to raise its prices as its costs increase. However, the actual pricing of the Company’s products and services is impacted by a number of factors, including global oil prices, competitive pricing pressure, the level of utilized capacity in the oil service sector, maintenance of market share, the introduction of new products and general market conditions.

The Company accounts for larger and more complex projects that have relatively longer manufacturing time frames on a percentage-of-completion basis. For the six months ended June 30, 2015, 13 projects representing approximately 16% of the Company’s total revenue and approximately 19% of its product revenue were accounted for using percentage-of-completion accounting, compared to 16 projects representing approximately 8% of the Company’s total revenue and approximately 10% of its product revenue for the first six months of 2014. For the quarter ended June 30, 2015, there were 10 projects representing approximately 17% of the Company’s total revenues and approximately 21% of its product revenues compared to 12 projects representing 5% of the Company’s total revenues and 6% of its product revenues. This percentage may fluctuate in the future. Revenues accounted for in this manner are generally recognized based upon a calculation of the percentage complete, which is used to determine the revenue earned and the appropriate portion of total estimated cost of sales. Accordingly, price and cost estimates are reviewed periodically as the work progresses, and adjustments proportionate to the percent complete are reflected in the period when such estimates are revised. Losses, if any, are recorded in full in the period they become known. Amounts received from customers in excess of revenues recognized are classified as a current liability.

Cost of Sales. The principal elements of cost of sales are labor, raw materials and manufacturing overhead. Cost of sales as a percentage of revenues is influenced by the product mix sold in any particular period, costs from projects accounted for under the percentage-of-completion method and market conditions. The Company’s costs related to its foreign operations do not significantly differ from its domestic costs.

Selling, General and Administrative Expenses. Selling, general and administrative expenses include the costs associated with sales and marketing, general corporate overhead, business development expenses, compensation expense, stock-based compensation expense, legal expenses, foreign currency transaction gains and losses and other related administrative functions.

Engineering and Product Development Expenses. Engineering and product development expenses consist of new product development and testing, as well as application engineering related to customized products.

Income Tax Provision. The Company’s effective income tax rate has historically been lower than the statutory rate primarily due to foreign income tax rate differentials, research and development credits and deductions related to domestic manufacturing activities.

Results of Operations

The following table sets forth, for the periods indicated, certain condensed statements of income data expressed as a percentage of revenues:


	Three months ended June 30,						Six months ended June 30,
	2015			2014			2015			2014
Revenues:
Products		81.8	%		82.5	%		82.4	%		83.3	%
Services		18.2			17.5			17.6			16.7

Total revenues		100.0			100.0			100.0			100.0
Cost of sales:
Products		45.7			45.2			46.3			45.0
Services		9.0			9.1			8.7			9.3

Total cost of sales		54.7			54.3			55.0			54.3
Selling, general and administrative expenses		15.6			11.0			11.4			11.4
Engineering and product development expenses		5.3			4.7			5.4			5.0

Operating income		24.4			30.0			28.2			29.3
Interest income		0.1			0.1			—			0.1

Income before income taxes		24.5			30.1			28.2			29.4
Income tax provision		6.3			7.8			7.2			7.8

Net income		18.2	%		22.3	%		21.0	%		21.6	%

The following table sets forth, for the periods indicated, a breakdown of our product and service revenues:


	Three months ended June 30,				Six months ended June 30,
	2015		2014		2015		2014
	(In millions)
Revenues:
Products
Subsea equipment	$	160.6	$	175.6	$	328.6	$	328.1
Surface equipment		5.8		4.9		11.3		12.7
Offshore rig equipment		9.7		9.4		23.7		21.1

Total products		176.1		189.9		363.6		361.9
Services		39.2		40.4		77.7		72.5

Total revenues	$	215.3	$	230.3	$	441.3	$	434.4

Three Months Ended June 30, 2015 Compared to Three Months Ended June 30, 2014.

Revenues. Revenues decreased by $15.0 million, or approximately 6.5%, to $215.3 million in the three months ended June 30, 2015 from $230.3 million in the three months ended June 30, 2014. Product revenues decreased by approximately $13.8 million for the three months ended June 30, 2015 compared to the same period in 2014 as a result of decreased revenues of $15.0 million in subsea equipment, partially offset by an increase of $900,000 in surface equipment, and $300,000 in offshore rig equipment. The decrease in subsea equipment is primarily due to decreased activity in the U.S. Gulf of Mexico. Product revenues decreased in the Western Hemisphere by approximately $33.4 million, partially offset by an increase in the Eastern Hemisphere of approximately $17.0 million and in Asia-Pacific by $2.6 million. In any given time period, the revenues recognized between the various product lines and geographic areas will vary depending upon the timing of shipments to customers, completion status of the projects accounted for under the percentage-of-completion accounting method, market conditions and customer demand. Service revenues decreased by approximately $1.2 million as a result of decreases of $2.9 million in the Eastern Hemisphere and $1.4 million in Asia-Pacific, slightly offset by an increase of $3.1 million in the Western Hemisphere. The majority of the decreases in service revenues relate to decreases in technical advisory assistance revenues and rental of running tools.

Cost of Sales. Cost of sales decreased by $7.3 million, or approximately 5.8%, to $117.7 million for the three months ended June 30, 2015 from $125.0 million for the same period in 2014. The decrease is a result of lower revenue, particularly in the U. S. Gulf of Mexico. As a percentage of revenues, cost of sales were approximately 54.7% and 54.3% for the three-month period ended June 30, 2015 and 2014, respectively.

Selling, General and Administrative Expenses. Selling, general and administrative expenses increased by $8.1 million, or approximately 31.8%, to $33.6 million for the three months ended June 30, 2015 from $25.5 million for the same period in 2014. The increase is mostly attributable to $11.8 million in foreign currency transaction losses for the three months ended June 30, 2015 compared to a $2.0 million loss for the three months ended June 30, 2014. The majority of the loss was due to the strengthening of the British pound sterling compared to the United States dollar. Stock-based compensation expense for the second quarter of 2015 was $3.1 million compared to $2.8 million for the quarter ended June 30, 2014. Selling, general and administrative expenses as a percentage of revenues increased to 15.6% in 2015 from 11.0% in 2014.

Engineering and Product Development Expenses. For the three months ended June 30, 2015, engineering and product development expenses increased by $600,000 in the second quarter of 2015 compared to the same period in 2014 due to increases in personnel and related costs. Engineering and product development expenses as a percentage of revenues increased to 5.3% in 2015 from 4.7% in 2014.

Income tax provision. Income tax expense for the three months ended June 30, 2015 was $13.5 million on income before taxes of $52.7 million, resulting in an effective income tax rate of approximately 26%. Income tax expense for the three months ended June 30, 2014 was $17.9 million on income before taxes of $69.2 million, resulting in an effective income tax rate of approximately 26%.

Net Income. Net income was approximately $39.2 million for the three months ended June 30, 2015 and $51.3 million for the same period in 2014 for the reasons set forth above.

Six Months Ended June 30, 2015 Compared to Six Months Ended June 30, 2014.

Revenues. Revenues increased by $6.9 million, or approximately 1.6%, to $441.3 million in the six months ended June 30, 2015 from $434.4 million in the six months ended June 30, 2014. Product revenues increased by approximately $1.7 million for the six months ended June 30, 2015 compared to the same period in 2014 as a result of increased revenues of $500,000 in subsea equipment and $2.6 million in offshore rig equipment, partially offset by a $1.4 million decrease in surface equipment. The majority of the increases occurred in the Eastern Hemisphere. Product revenues increased in the Eastern Hemisphere by $42.5 million, partially offset by decreases in the Western Hemisphere of $36.0 million and Asia-Pacific of $4.8 million. In any given time period, the revenues recognized between the various product lines and geographic areas will vary depending upon the timing of shipments to customers, completion status of the projects accounted for under the percentage-of-completion accounting method, market conditions and customer demand. Service revenues increased by approximately $5.2 million due to increased service revenues in the Western Hemisphere of $8.5 million, partially offset by a decrease of $2.7 million in the Eastern Hemisphere and $600,000 in Asia-Pacific. The majority of the increase in service revenues related to an increase in rental of running tools and reconditioning services.

Cost of Sales. Cost of sales increased by $7.0 million, or approximately 3.0%, to $242.8 million for the six months ended June 30, 2015 from $235.8 million for the same period in 2014. The increase was primarily due to an increase in product revenues. As a percentage of revenues, cost of sales were approximately 55.0% and 54.3% for the six months ended June 30, 2015 and 2014, respectively.

Selling, General and Administrative Expenses. For the six months ended June 30, 2015, selling, general and administrative expenses increased by approximately $1.1 million, or 2.2%, to $50.6 million from $49.5 million for the same period in 2014. The Company experienced approximately $5.4 million in foreign currency transaction losses in the first six months of 2015 compared to approximately $3.0 million in foreign currency transaction losses for the same period in 2014. Stock-based compensation expense for the first six months of 2015 was $6.5 million compared to $5.7 million for the same period in 2014. Selling, general and administrative expenses as a percentage of revenues were flat in 2015 and 2014 at 11.4%.

Engineering and Product Development Expenses. For the six months ended June 30, 2015 engineering and product development expenses increased by $2.0 million, or approximately 9.3%, to $23.6 million from $21.6 million for the same period in 2014. Engineering and product development expenses as a percentage of revenues was 5.4% in 2015 and 5.0% in 2014 due to increases in personnel and related costs.

Income tax provision. Income tax expense for the six months ended June 30, 2015 was $31.6 million on income before taxes of $124.5 million, resulting in an effective income tax rate of approximately 25%. Income tax expense for the six months ended June 30, 2014 was $33.9 million on income before taxes of $127.9 million, resulting in an effective income tax rate of approximately 27%. The decrease in the effective income tax rate percentage primarily reflects the changes in taxable income among the Company’s three geographical areas which have different income tax rates.

Net Income. Net income was approximately $92.9 million for the six months ended June 30, 2015 and $93.9 million for the same period in 2014 for the reasons set forth above.

Liquidity and Capital Resources

Cash flows provided by (used in) type of activity were as follows:


	Six months ended June 30,
	2015			2014
	(In thousands)
Operating activities	$	113,011		$	66,672
Investing activities		(11,068	)		(22,748	)
Financing activities		(17,934	)		(88,385	)

		84,009			(44,461	)
Effect of exchange rate changes on cash activities		(41	)		2,726

Increase (decrease) in cash and cash equivalents	$	83,968		$	(41,735	)

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

The primary liquidity needs of the Company are (i) to fund capital expenditures to improve and expand facilities and manufacture additional running tools and (ii) to fund working capital. The Company’s principal sources of funds have been cash flows from operations.

Net cash provided from operating activities increased by $46.3 million for the first six months of 2015 compared to the same period in 2014, primarily due to an increase in cash from operating assets and liabilities of $48.8 million.

The increase in cash from operating assets and liabilities for the first six months of 2015 of $3.4 million primarily reflected a decrease in trade receivables of $70.5 million, partially offset by a $67.5 million decrease in accounts payable and accrued expenses. Trade receivables decreased in 2015 largely due to significant collections attributable to milestone billings on our percentage-of-completion projects in the first quarter of 2015. Inventory decreased due to lower balances in finished goods. Accounts payable and accrued expenses decreased due to a decrease in customer prepayments from recognition of revenues under the percentage-of-completion method and payments of accrued federal and local taxes.

The decrease in cash from operating assets and liabilities for the first six months of 2014 of $45.4 million primarily reflected an increase in trade receivables of $33.3 million and an increase in inventory of $32.7 million, partially offset by a $24.3 million increase in accounts payable and accrued expenses. Trade receivables increased in 2014 largely due to increased billings directly attributable to significant milestone billings on our percentage-of-completion projects and an increase in revenues in the second quarter of 2014. Inventory increased due to higher balances in raw materials, work in progress and finished goods to accommodate the higher backlog requirements related to long-term projects. Accounts payable and accrued expenses increased due to purchases of raw materials and an increase in customer prepayments from billings in excess of revenues.

Capital expenditures by the Company were $11.2 million and $23.2 million in the first six months of 2015 and 2014, respectively. Capital expenditures in 2015 and 2014 included increased expenditures on machinery and equipment and running tools. The capital expenditures for the first six months of 2015 were primarily $5.3 million for machinery and equipment, $4.9 million for running tools and other expenditures of $1.0 million. Capital expenditures for the first six months of 2014 were $1.9 million for facilities, $16.5 million for machinery and equipment, $2.6 million for running tools and other expenditures of $2.2 million.

The exercise of stock options generated cash to the Company of $2.0 million in the first six months of 2015 as compared to $1.4 million in the same period of 2014.

On February 26, 2015, the Company announced that its Board of Directors authorized a stock repurchase plan under which the Company is authorized to repurchase up to $100 million of its common stock. Under the plan, the Company repurchased and cancelled 260,200 shares at a total cost of $19.9 million during the second quarter of 2015. The repurchase program has no expiration date and any repurchased shares are expected to be cancelled.

As of June 30, 2015, the Company has no commercial lending arrangement or lines of credit. The Company believes that cash generated from operations plus cash on hand will be sufficient to fund operations, working capital needs and anticipated capital expenditure requirements for the next twelve months. However, continued significant declines in hydrocarbon prices, catastrophic events or significant changes in regulations affecting the Company or its customers could have a material adverse effect on the Company’s liquidity. Should market conditions result in unexpected cash requirements, the Company believes that borrowing from commercial lending institutions would be available and adequate to meet such requirements.

Off-Balance Sheet Arrangements

The Company has no derivative instruments and no off-balance sheet hedging or financing arrangements, contracts or operations.

Critical Accounting Policies

Refer to the Company’s Annual Report on Form 10-K for the year ended December 31, 2014 for a discussion of its critical accounting policies. During the six months ended June 30, 2015, there were no material changes in our judgments and assumptions associated with the development of our critical accounting policies.

Item 3.

Quantitative and Qualitative Disclosures About Market Risk

The Company is currently exposed to certain market risks related to interest rate changes on its short-term investments and fluctuations in foreign exchange rates. There have been no material changes in market risks for the Company from December 31, 2014.

Foreign Exchange Rate Risk

The Company has operations in various countries around the world and conducts business in a number of different currencies. Our significant foreign subsidiaries may also have monetary assets and liabilities not denominated in their functional currency. These monetary assets and liabilities are exposed to changes in currency exchange rates which may result in non-cash gains and losses primarily due to fluctuations between the U.S. dollar and each subsidiary’s functional currency.

The Company experienced a foreign currency pre-tax loss of approximately $11.8 million during the three months ended June 30, 2015 and a $5.4 million pre-tax loss during the six months ended June 30, 2015, compared to approximately $2.0 million and $3.0 million in pre-tax losses during the three and six months ended June 30, 2014, respectively. These losses were primarily due to exchange rate fluctuations between the U.S. dollar and the British pound sterling.

The Company does not engage in any material hedging transactions, forward contracts or currency trading which could mitigate the effects and risks inherent in such transactions. Additionally, there is no assurance that the Company will be able to protect itself against currency fluctuations in the future.

Item 4.

Controls and Procedures

In accordance with Exchange Act Rules 13a-15 and 15d-15, the Company carried out an evaluation, under the supervision and with the participation of management, including the Company’s Chief Executive Officer and Chief Financial Officer, of the effectiveness of the Company’s disclosure controls and procedures as of the end of the period covered by this report. Based on that evaluation, the Company’s Chief Executive Officer and Chief Financial Officer concluded that the Company’s disclosure controls and procedures were effective as of June 30, 2015 to provide reasonable assurance that information required to be disclosed in the Company’s reports filed or submitted under the Exchange Act is recorded, processed, summarized and reported within the time periods specified in the Securities and Exchange Commission’s rules and forms, and such information is accumulated and communicated to management, including the Company’s Chief Executive Officer and Chief Financial Officer, as appropriate to allow timely decisions regarding disclosure.

There has been no change in the Company’s internal controls over financial reporting that occurred during the quarter ended June 30, 2015 that has materially affected, or is reasonably likely to materially affect, the Company’s internal controls over financial reporting.

PART II—OTHER INFORMATION

Item 1.

Legal Proceedings.

For a description of the Company’s legal proceedings, see “Commitments and Contingencies,” Note 7 to the Notes to Condensed Consolidated Financial Statements.

Item 1A.

Risk Factors.

There have been no material changes from the risk factors disclosed in the Company’s Annual Report on Form 10-K for the year ended December 31, 2014.

Item 2.

Unregistered Sales of Equity Securities and Use of Proceeds.

In February 2015, the Company announced that its Board of Directors authorized a stock repurchase plan under which the Company is authorized to repurchase up to $100 million of its common stock. The following table summarizes the repurchase and cancellation of common stock during the three months ended June 30, 2015.

Issuer Purchase of Equity Securities


	Total Number of Shares Purchased		Average Price paid Per Share		Total Number of Shares Purchased as Part of a Publicly Announced Plan or Program		Maximum Dollar Value (in millions) of Shares that May Yet Be Purchased Under the Program
April 1 – 30, 2015		—	$	—		—	$	100.0
May 1 – 31, 2015		207,900		76.71		207,900		84.1
June 1 – 30, 2015		52,300		76.39		52,300		80.1

Total		260,200	$	76.65		260,200	$	80.1

FORWARD LOOKING STATEMENTS

This Quarterly Report on Form 10-Q includes certain statements that may be deemed to be “forward-looking statements” within the meaning of Section 27A of the Securities Act of 1933, as amended (the “Securities Act”), and Section 21E of the Securities Exchange Act of 1934, as amended (the “Exchange Act”). Statements contained in all parts of this document that are not historical facts are forward-looking statements that involve risks and uncertainties that are beyond the control of Dril-Quip, Inc. (the “Company” or “Dril-Quip”). You can identify the Company’s forward-looking statements by the words “anticipate,” “estimate,” “expect,” “may,” “project,” “believe” and similar expressions, or by the Company’s discussion of strategies or trends. Although the Company believes that the expectations reflected in such forward-looking statements are reasonable, no assurance can be given that these expectations will prove to be correct. These forward-looking statements include the following types of information and statements as they relate to the Company:

•

future operating results and cash flow;

•

scheduled, budgeted and other future capital expenditures;

•

working capital requirements;

•

the availability of expected sources of liquidity;

•

the introduction into the market of the Company’s future products;

•

the market for the Company’s existing and future products;

•

the Company’s ability to develop new applications for its technologies;

•

the exploration, development and production activities of the Company’s customers;

•

compliance with present and future environmental regulations and costs associated with environmentally related penalties, capital expenditures, remedial actions and proceedings;

•

effects of pending legal proceedings;

•

changes in customers’ future product and service requirements that may not be cost effective or within the Company’s capabilities; and

•

future operations, financial results, business plans and cash needs.

These statements are based on assumptions and analyses in light of the Company’s experience and perception of historical trends, current conditions, expected future developments and other factors the Company believes were appropriate in the circumstances when the statements were made. Forward-looking statements by their nature involve substantial risks and uncertainties that could significantly impact expected results, and actual future results could differ materially from those described in such statements. While it is not possible to identify all factors, the Company continues to face many risks and uncertainties. Among the factors that could cause actual future results to differ materially are the risks and uncertainties discussed under “Item 1A. Risk Factors” in Part I of the Company’s Annual Report on Form 10-K for the year ended December 31, 2014 and the following:

•

the volatility of oil and natural gas prices;

•

the cyclical nature of the oil and gas industry;

•

uncertainties associated with the United States and worldwide economies;

•

uncertainties regarding political tensions in the Middle East, Africa and elsewhere;

•

current and potential governmental regulatory actions in the United States and regulatory actions and political unrest in other countries;

•

uncertainties regarding future oil and gas exploration and production activities in the U.S. Gulf of Mexico and elsewhere, including new regulations, customs requirements and product testing requirements;

•

operating interruptions (including explosions, fires, weather-related incidents, mechanical failure, unscheduled downtime, labor difficulties, transportation interruptions, spills and releases and other environmental risks);

•

project terminations, suspensions or scope adjustments to contracts reflected in the Company’s backlog;

•

the Company’s reliance on product development;

•

technological developments;

•

the Company’s reliance on third-party technologies;

•

the Company’s dependence on key employees and skilled machinists, fabricators and technical personnel;

•

the Company’s reliance on sources of raw materials;

•

impact of environmental matters, including future environmental regulations;

•

competitive products and pricing pressures;

•

fluctuations in foreign currency;

•

the ability of the Organization of Petroleum Exporting Countries (“OPEC”) to set and maintain production levels and pricing;

•

the Company’s reliance on significant customers;

•

creditworthiness of the Company’s customers;

•

fixed-price contracts;

•

changes in general economic, market or business conditions;

•

access to capital markets;

•

negative outcome of litigation, threatened litigation or government proceedings;

•

terrorist threats or acts, war and civil disturbances; and

•

the interpretation of foreign tax law with respect to our foreign subsidiaries.

Many of such factors are beyond the Company’s ability to control or predict. Any of the factors, or a combination of these factors, could materially affect the Company’s future results of operations and the ultimate accuracy of the forward-looking statements. Management cautions against putting undue reliance on forward-looking statements or projecting any future results based on such statements or present or prior earnings levels. Every forward-looking statement speaks only as of the date of the particular statement, and the Company undertakes no obligation to publicly update or revise any forward-looking statement.

Item 6.

(a) Exhibits

The following exhibits are filed herewith:


Exhibit No.		Description

*3.1		Restated Certificate of Incorporation of the Company (incorporated herein by reference to Exhibit 3.1 to the Company’s report on Form 8-K filed on May 20, 2014)).

*3.2		Certificate of Designations of Series A Junior Participating Preferred Stock of the Company (incorporated herein by reference to Exhibit 3.1 to the Company’s report on Form 8-K dated November 25, 2008).

*3.3		Amended and Restated Bylaws of the Company (incorporated herein by reference to Exhibit 3.2 to the Company’s report on Form 8-K filed on May 20, 2014).

*4.1		Form of certificate representing Common Stock (incorporated herein by reference to Exhibit 4.2 to the Company’s Registration Statement on Form S-1 (Registration No. 333-33447)).

*4.2		Rights Agreement dated as of November 24, 2008 between Dril-Quip, Inc. and Mellon Investor Services LLC, as Rights Agent (incorporated herein by reference to Exhibit 4.1 to the Company’s Current Report on Form 8-K filed on November 25, 2008).

31.1		Rule 13a-14(a)/15d-14(a) Certification of Blake T. DeBerry.

31.2		Rule 13a-14(a)/15d-14(a) Certification of Jerry M. Brooks.

32.1		Section 1350 Certification of Blake T. DeBerry.

32.2		Section 1350 Certification of Jerry M. Brooks.

101.INS		XBRL Instance Document

101.SCH		XBRL Schema Document

101.CAL		XBRL Calculation Document

101.DEF		XBRL Definition Linkbase Document.

101.LAB		XBRL Label Linkbase Document

101.PRE		XBRL Presentation Linkbase Document

*	Incorporated herein by reference as indicated.

SIGNATURE

Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.


DRIL-QUIP, INC.

By:		/s/ JERRY M. BROOKS
		Jerry M. Brooks,
		Vice-President—Finance and Chief Financial Officer (Principal Accounting Officer and Duly Authorized Signatory)

Date: July 30, 2015