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DRIL-QUIP INC - Quarter Report: 2016 March (Form 10-Q)

UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
_______________________________________________________
FORM 10-Q
_______________________________________________________
(MARK ONE)
ý
QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
For the Quarterly Period Ended March 31, 2016
or
¨
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  ý    No  ¨
Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of 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  ý    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 the definitions of “large accelerated filer,” “accelerated filer” and “smaller reporting company” in Rule 12b-2 of the Exchange Act.
Large accelerated filer
ý
Accelerated filer
¨
Non-accelerated filer
¨ (Do not check if a smaller reporting company)
Smaller reporting company
¨
Indicate by check mark whether the registrant is a shell company (as defined in Exchange Act Rule 12b-2).    Yes  ¨    No  ý
As of April 25, 2016, the number of shares outstanding of the registrant’s common stock, par value $0.01 per share, was 37,957,052.


TABLE OF CONTENTS
 
 
Page
PART I
Item 1.
 
 
 
 
 
Item 2.
Item 3.
Item 4.
PART II
Item 1.
Item 1A.
Item 2.
 
 


Table of Contents

PART I—FINANCIAL INFORMATION
Item 1.        Financial Statements
DRIL-QUIP, INC.
CONDENSED CONSOLIDATED BALANCE SHEETS
(UNAUDITED)
 
March 31,
2016
 
December 31,
2015
 
(In thousands)
ASSETS
 
 
 
Current assets:
 
 
 
Cash and cash equivalents
$
423,366

 
$
381,336

Trade receivables, net
328,060

 
319,780

Inventories, net
343,073

 
344,458

Deferred income taxes
24,934

 
24,613

Prepaids and other current assets
45,183

 
54,111

Total current assets
1,164,616

 
1,124,298

Property, plant and equipment, net
294,941

 
294,251

Other assets
10,901

 
9,701

Total assets
$
1,470,458

 
$
1,428,250

LIABILITIES AND STOCKHOLDERS’ EQUITY
 
 
 
Current liabilities:
 
 
 
Accounts payable
$
33,509

 
$
30,934

Accrued income taxes
28,143

 
14,052

Customer prepayments
12,540

 
18,388

Accrued compensation
11,391

 
17,957

Other accrued liabilities
19,316

 
19,484

Total current liabilities
104,899

 
100,815

Deferred income taxes
2,264

 
2,977

Total liabilities
107,163

 
103,792

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, 37,957,052 and 37,951,223 shares issued and outstanding at March 31, 2016 and December 31, 2015
378

 
378

Additional paid-in capital
3,334

 
—

Retained earnings
1,462,113

 
1,425,344

Accumulated other comprehensive losses
(102,530
)
 
(101,264
)
Total stockholders’ equity
1,363,295

 
1,324,458

Total liabilities and stockholders’ equity
$
1,470,458

 
$
1,428,250

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

3
Table of Contents

DRIL-QUIP, INC.
CONDENSED CONSOLIDATED STATEMENTS OF INCOME
(UNAUDITED)
 
Three months ended
March 31,
 
2016
 
2015
 
(In thousands, except per share data)
Revenues:
 
 
 
Products
$
135,194

 
$
187,524

Services
31,367

 
38,478

Total revenues
166,561

 
226,002

Cost and expenses:
 
 
 
Cost of sales:
 
 
 
Products
76,922

 
106,007

Services
16,174

 
19,131

Total cost of sales
93,096

 
125,138

Selling, general and administrative
13,221

 
16,958

Engineering and product development
10,901

 
12,213

Total costs and expenses
117,218

 
154,309

Operating income
49,343

 
71,693

Interest income
482

 
49

Interest expense
(4
)
 
(3
)
Income before income taxes
49,821

 
71,739

Income tax provision
13,052

 
18,075

Net income
$
36,769

 
$
53,664

Earnings per common share:
 
 
 
Basic
$
0.97

 
$
1.38

Diluted
$
0.97

 
$
1.38

Weighted average common shares outstanding:
 
 
 
Basic
37,752

 
38,773

Diluted
37,847

 
38,940

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

4
Table of Contents

DRIL-QUIP, INC.
CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME
(UNAUDITED)
 
Three months ended
March 31,
 
2016
 
2015
 
(In thousands)
Net income
$
36,769

 
$
53,664

Other comprehensive loss, net of tax:
 
 
 
Foreign currency translation adjustments
(1,266
)
 
(32,534
)
Total comprehensive income
$
35,503

 
$
21,130

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

5
Table of Contents

DRIL-QUIP, INC.
CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS
(UNAUDITED)
 
Three months ended
March 31,
 
2016
 
2015
 
(In thousands)
Operating activities
 
 
 
Net income
$
36,769

 
$
53,664

Adjustments to reconcile net income to net cash provided by (used in) operating activities:
 
 
 
Depreciation and amortization
7,775

 
7,455

Stock-based compensation expense
3,192

 
3,363

Loss (gain) on sale of equipment
(13
)
 
(63
)
Deferred income taxes
(962
)
 
(2,755
)
Changes in operating assets and liabilities:
 
 
 
Trade receivables, net
(8,942
)
 
62,837

Inventories, net
1,899

 
(7,010
)
Prepaids and other assets
8,050

 
(1,259
)
Excess tax benefits of stock options and awards
(11
)
 
(24
)
Accounts payable and accrued expenses
4,766

 
(29,139
)
Net cash provided by operating activities
52,523

 
87,069

Investing activities
 
 
 
Purchase of property, plant and equipment
(7,732
)
 
(6,156
)
Proceeds from sale of equipment
76

 
121

Net cash used in investing activities
(7,656
)
 
(6,035
)
Financing activities
 
 
 
Repurchase of common stock
—

 
—

Proceeds from exercise of stock options
155

 
282

Excess tax benefits of stock options and awards
11

 
24

Net cash used in financing activities
166

 
306

Effect of exchange rate changes on cash activities
(3,003
)
 
(5,914
)
Increase (decrease) in cash and cash equivalents
42,030

 
75,426

Cash and cash equivalents at beginning of period
381,336

 
298,705

Cash and cash equivalents at end of period
$
423,366

 
$
374,131

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

6
Table of Contents

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 Macae, Brazil.
The condensed consolidated financial statements included herein are unaudited. The balance sheet at December 31, 2015 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 March 31, 2016 and the results of operations, comprehensive income and the cash flows for the three-month periods ended March 31, 2016 and 2015. Certain information and footnote disclosures normally included in 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 cash flows for the three-month period ended March 31, 2016 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, 2015.
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.
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 revenues
The Company recognizes 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.


7
Table of Contents

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 March 31, 2016 and December 31, 2015, receivables included $61.5 million and $70.8 million of unbilled receivables, respectively. For the quarter ended March 31, 2016, there were 9 projects representing approximately 15% of the Company’s total revenues and approximately 18% of its product revenues that were accounted for using percentage-of-completion accounting, compared to 11 projects during the first quarter of 2015, which represented approximately 15% of the Company’s total revenues and approximately 18% of its product revenues.
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 revenues
The Company recognizes 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.


8
Table of Contents

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
March 31,
 
2016
 
2015
 
(In thousands)
Weighted average common shares outstanding—basic
37,752

 
38,773

Dilutive effect of common stock options and awards
95

 
167

Weighted average common shares outstanding—diluted
37,847

 
38,940

3. New Accounting Standards
In February 2016, the Financial Accounting Standards Board (FASB) issued Accounting Standards Update (ASU) 2016-02 “Leases (Topic 842).” The new standard requires lessees to recognize lease assets (right of use) and lease obligations (lease liability) for leases previously classified as operating leases under generally accepted accounting principles on the balance sheet for leases with terms in excess of 12 months. The standard is effective for annual periods beginning after December 15, 2018, including interim periods within those fiscal years. The Company is evaluating the impact of the new standard on its consolidated financial statements.
In November 2015, the FASB issued ASU 2015-17 “Income Taxes (Topic 740).” In an effort to reduce complexity, the requirement to separate deferred income tax liabilities and assets into current and noncurrent amounts will no longer be necessary. In the future, all deferred income taxes will be considered noncurrent and will continue to be offset into a single amount within each country. The standard is effective for fiscal years beginning after December 15, 2016 and interim periods within those fiscal years. The Company’s financial statements will be revised to reflect this amendment beginning in the first quarter of 2017.
In July 2015, the FASB issued ASU 2015-11 “Simplifying the Measurement of Inventory (Topic 330).” This standard states that inventory within the scope of this update should be measured at the lower of cost and net realizable value. Net realizable value is defined as the estimated selling price in the normal course of business, less reasonably predictable costs of completion, disposal, and transportation. The standard is effective for fiscal years beginning after December 15, 2016, including interim periods within those fiscal years. The Company is evaluating the impact of the new standard on its consolidated financial statements.
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 evaluating the impact of the new standard on its consolidated financial statements.
4. Stock-Based Compensation and Stock Awards
During the three months ended March 31, 2016 and 2015, the Company recognized approximately $3.2 million and $3.4 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. No stock-based compensation expense was capitalized during the three months ended March 31, 2016 or 2015.

9
Table of Contents

5. Inventories, net
Inventories consist of the following:
 
March 31,
2016
 
December 31,
2015
 
(In thousands)
Raw materials
$
97,107

 
$
101,311

Work in progress
94,474

 
104,102

Finished goods
191,002

 
178,292

 
382,583

 
383,705

Less: allowance for obsolete and excess inventory
(39,510
)
 
(39,247
)
Net inventory
$
343,073

 
$
344,458


10
Table of Contents


6. Geographic Areas
 
Three months ended
March 31,
 
2016
 
2015
 
(In thousands)
Revenues:
 
 
 
Western Hemisphere
 
 
 
Products
$
78,600

 
$
91,815

Services
16,993

 
22,309

Intercompany
10,711

 
9,985

Total
$
106,304

 
$
124,109

Eastern Hemisphere
 
 
 
Products
$
33,161

 
$
79,421

Services
13,004

 
11,642

Intercompany
185

 
221

Total
$
46,350

 
$
91,284

Asia-Pacific
 
 
 
Products
$
23,433

 
$
16,288

Services
1,370

 
4,527

Intercompany
280

 
1,181

Total
$
25,083

 
$
21,996

Summary
 
 
 
Products
$
135,194

 
$
187,524

Services
31,367

 
38,478

Intercompany
11,176

 
11,387

Eliminations
(11,176
)
 
(11,387
)
Total
$
166,561

 
$
226,002

Income before income taxes:
 
 
 
Western Hemisphere
$
24,956

 
$
32,948

Eastern Hemisphere
16,684

 
31,708

Asia-Pacific
6,113

 
3,425

Eliminations
2,068

 
3,658

Total
$
49,821

 
$
71,739

 
March 31,
2016
 
December 31,
2015
 
(In thousands)
Total Long-Lived Assets:
 
 
 
Western Hemisphere
$
212,069

 
$
208,408

Eastern Hemisphere
42,332

 
43,449

Asia-Pacific
54,367

 
55,021

Eliminations
(2,926
)
 
(2,926
)
Total
$
305,842

 
$
303,952

Total Assets:
 
 
 
Western Hemisphere
$
710,691

 
$
677,460

Eastern Hemisphere
398,324

 
391,672

Asia-Pacific
380,114

 
372,823

Eliminations
(18,671
)
 
(13,705
)
Total
$
1,470,458

 
$
1,428,250


11
Table of Contents

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, which were 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 has 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 in December 2014 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 ruling against the Company by the tax administration’s highest council once that ruling is finalized. 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 results of operations, financial position or cash flows.

12
Table of Contents

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 Company's 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, 2015.
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 and drilling contractors 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 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 prices per barrel are listed below for the periods covered by this report:

Brent Crude Oil Prices
Three Months Ended
Low

High

Average

Closing
March 31, 2016
$26.01

$40.54

$33.84

$36.75
March 31, 2015
45.13

61.89

53.98

53.69

According to the April 2016 release of the Short-Term Energy Outlook published by the EIA, Brent Crude oil prices are expected to average approximately $34.73 per barrel in 2016 and $40.58 per barrel in 2017. In its March 2016 Oil Market Report, the International Energy Agency projected the 2016 global oil demand will grow to 95.8 million barrels per day, a 1.2 million barrels per day increase over 2015.
Rig Count
Detailed below is the average contracted offshore rig count (rigs currently drilling as well as rigs committed, but not yet drilling) for the Company’s geographic regions for the three months ended March 31, 2016 and 2015. 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 assets used to deploy the Company’s products.

Three months ended March 31,

2016

2015

Floating Rigs

Jack-up Rigs

Floating Rigs

Jack-up Rigs
Western Hemisphere
97


48


123


75

Eastern Hemisphere
71


73


94


92

Asia-Pacific
30


226


48


256

TOTAL
198


347


265


423


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Source: IHS—Petrodata RigBase – March 31, 2016 and 2015
According to IHS-Petrodata RigBase, as of March 31, 2016, there were 540 rigs under contract for the Company’s geographic regions (193 floating rigs and 347 jack-up rigs), which represents a 20.6% decrease from the rig count of 680 rigs (261 floating rigs and 419 jack-up rigs) as of March 31, 2015.
The Company believes that the number of rigs (semi-submersibles, drillships and jack-up rigs) under construction impacts its revenues and backlog 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, as of March 31, 2016 and 2015, there were 191 and 214 rigs, respectively, under construction, which represents an approximate 10.7% decline in rigs under construction. The expected delivery dates for the rigs under construction at March 31, 2016 are as follows:

Floating

Jack-Up



Rigs

Rigs

Total
2016
22


76


98

2017
22


32


54

2018
11


7


18

2019
12


2


14

After 2019 or unspecified delivery date
2


5


7


69


122


191

However, given the sustained low level in oil and gas prices and oversupply of offshore drilling rigs, the Company believes it possible that delivery of some rigs under construction could be postponed or cancelled, limiting the opportunity for supply of the Company’s products.
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, extensions of delivery terms and, in some instances, contract cancellations or revisions. In some cases, a customer may already hold an inventory of the Company's equipment, which may delay the placement of new orders. 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, then its 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, seek to renegotiate contract terms, including the price of products and services, or reduce their levels of capital expenditures for exploration and production for a variety of reasons. A continued 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 on or declines in offshore oil and gas exploration and production could have a negative impact on the Company and its backlog. The Company’s backlog at March 31, 2016 was approximately $522 million, compared to approximately $1.1 billion at March 31, 2015 and approximately $685 million at December 31, 2015. The Company’s backlog balance during the first three months of 2016 has been negatively impacted by purchase order cancellations and revisions totaling approximately $63 million, and, due primarily

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to the strengthening of the Brazilian real versus the U.S. dollar, positively impacted by approximately $3 million in translation adjustments. Of the approximately $63 million in cancellations and revisions during the three months ended March 31, 2016, approximately $52 million was attributable to the cancellation of one contract for wellhead equipment for a development project.
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. The contract was valued at $650 million, net of Brazilian taxes, at exchange rates in effect at that time (approximately $372 million based on the March 31, 2016 exchange rate of 3.56 Brazilian real to 1.00 U.S. dollar) if all equipment under the contract was ordered. Amounts are included in the Company’s backlog as purchase orders under the contract are received. Revenues of approximately $113 million have been recognized on this contract through March 31, 2016. As of March 31, 2016, the Company’s backlog included $46 million of purchase orders under this Petrobras contract. The Company has not yet recognized revenue of approximately $12 million as of March 31, 2016 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 is in ongoing discussions with Petrobras regarding this contract and does not expect that Petrobras will order all of the equipment under the contract during its current four-year term.
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 and rental tools during installation and retrieval of the Company’s products. Additionally, the Company earns service revenues when rework and reconditioning services are provided. For the three months ended March 31, 2016 and 2015, the Company derived 81% and 83%, respectively, of its revenues from the sale of its products and 19% 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 57% and 62% of its revenues derived from foreign sales for the three months ended March 31, 2016 and 2015, respectively. Substantially all of the Company’s domestic revenue relates to operations in the U.S. Gulf of Mexico. Domestic revenue approximated 43% and 38% of the Company’s total revenues for the three months ended March 31, 2016 and 2015, respectively.
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 quarter ended March 31, 2016, there were 9 projects representing approximately 15% of the Company’s total revenues and approximately 18% of its product revenues that were accounted for using percentage-of-completion accounting, compared to 11 projects during the first quarter of 2015, which represented approximately 15% of the Company’s total revenues and approximately 18% 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

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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, over/under manufacturing overhead absorption 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.

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Results of Operations
The following table sets forth, for the periods indicated, certain statement of operations data expressed as a percentage of revenues:

 
Three months ended
March 31,
 
2016
 
2015
Revenues:
 
 
 
Products
81.2
%
 
83.0
%
Services
18.8

 
17.0

Total revenues:
100.0

 
100.0

Cost of sales:
 
 
 
Products
46.2

 
46.9

Services
9.7

 
8.5

Total cost of sales:
55.9

 
55.4

Selling, general and administrative expenses
8.0

 
7.5

Engineering and product development expenses
6.5

 
5.4

Operating income
29.6

 
31.7

Interest income
0.3

 
—

Income before income taxes
29.9

 
31.7

Income tax provision
7.8

 
8.0

Net income
22.1
%
 
23.7
%

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

Three months ended
March 31,

2016

2015

(In millions)
Revenues:



Products



Subsea equipment
$
121.1


$
168.0

Surface equipment
4.1


5.5

Offshore rig equipment
10.0


14.0

Total products
135.2


187.5

Services
31.4


38.5

Total revenues
$
166.6


$
226.0


Three Months Ended March 31, 2016 Compared to Three Months Ended March 31, 2015
Revenues. Revenues decreased by $59.4 million, or approximately 26.3%, to $166.6 million in the three months ended March 31, 2016 from $226.0 million in the three months ended March 31, 2015. Product revenues decreased by approximately $52.3 million for the three months ended March 31, 2016 compared to the same period in 2015 as a result of decreased revenues of $46.9 million in subsea equipment, $1.4 million in surface equipment and $4.0 million in offshore rig equipment. Product revenues decreased in the Eastern Hemisphere and the Western Hemisphere by $46.3 million and $13.2 million,

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respectively, largely due to the decline in oil and gas prices resulting in decreases in the demand for exploration and production equipment, especially subsea equipment. These decreases were offset by an increase in Asia-Pacific product revenues of $7.2 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 $7.1 million resulting from decreased service revenues in the Western Hemisphere of $5.3 million and $3.2 million in Asia-Pacific, partially offset by an increase of $1.4 million in the Eastern Hemisphere. The majority of the decreases in service revenues related to decreased rental of the Company’s running and installation tools, largely due to the decline in oil and gas prices leading to decreased exploration and production activities.
 
Cost of Sales. Cost of sales decreased by $32.0 million, or approximately 25.6%, to $93.1 million for the three months ended March 31, 2016 from $125.1 million for the same period in 2015 as a result of lower revenues. As a percentage of revenues, cost of sales increased slightly to 55.9% from 55.4% in the three months ended March 31, 2016 as compared to the same period in 2015, primarily as result of pricing concessions.
Selling, General and Administrative Expenses. For the three months ended March 31, 2016, selling, general and administrative expenses decreased by approximately $3.8 million, or 22.1%, to $13.2 million from $17.0 million for the same period in 2015, primarily due to a reduction in personnel and related costs associated with lower headcount. In addition, the Company experienced a pre-tax foreign currency transaction gain of $7.3 million in the first quarter of 2016 compared to a gain of $6.5 million in the first quarter of 2015. Stock award expense totaled $3.2 million for the first quarter of 2016 as compared to $3.4 million in 2015. Selling, general and administrative expenses as a percentage of revenues increased to 8.0% in the first quarter of 2016 from 7.5% in the first quarter of 2015.
Engineering and Product Development Expenses. For the three months ended March 31, 2016, engineering and product development expenses totaled $10.9 million compared to $12.2 million for the same period in 2015, a decrease of $1.3 million, or 10.7%. The majority of the decrease was due to a reduction in personnel and related costs associated with lower headcount. Engineering and product development expenses as a percentage of revenues increased to 6.5% in the first quarter of 2016 from 5.4% in the first quarter of 2015.
Income tax provision. Income tax expense for the three months ended March 31, 2016 was $13.1 million on income before taxes of $49.8 million, resulting in an effective income tax rate of approximately 26.2%. Income tax expense for the three months ended March 31, 2015 was $18.1 million on income before taxes of $71.7 million, resulting in an effective income tax rate of approximately 25.2%. The increase in the effective income tax rate percentage primarily reflects the changes in taxable income among the Company’s three geographic areas, which have different income tax rates.
Net Income. Net income was approximately $36.8 million for the three months ended March 31, 2016 and $53.7 million for the same period in 2015 for the reasons set forth above.

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Liquidity and Capital Resources
Cash flows provided by (used in) type of activity were as follows:
 
Three Months Ended March 31,
 
2016
 
2015
 
(In thousands)
Operating activities
$
52,523

 
$
87,069

Investing activities
(7,656
)
 
(6,035
)
Financing activities
166

 
306

 
45,033

 
81,340

Effect of exchange rate changes on cash activities
(3,003
)
 
(5,914
)
Increase (decrease) in cash and cash equivalents
$
42,030

 
$
75,426


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 source of funds is cash flows from operations.
Net cash provided by operating activities decreased $34.5 million for the first quarter of 2016 compared to the same period in 2015, primarily due to decreases in operating assets and liabilities of $19.6 million and lower net income of $16.9 million.
The change in operating assets and liabilities for the three months ended March 31, 2016 resulted in a $5.8 million increase in cash. Trade receivables increased $8.9 million primarily due to delays in customer collections from a tightening oil and gas market. Inventory slightly decreased by $1.9 million. Prepaids and other assets decreased by $8.1 million due to decreases in vendor prepayments. Accounts payable and accrued expenses decreased by approximately $4.8 million due to a reduction in customer prepayments of $5.8 million.
 
The change in operating assets and liabilities for the three months ended March 31, 2015 primarily reflected a decrease in trade receivables of $62.8 million and an increase in inventory of $7.0 million. Trade receivables primarily decreased due to strong collection efforts. Inventory increased due to higher balances in raw materials and work in progress (excluding foreign currency translation) to accommodate the backlog requirements related to long-term projects. Accounts payable and accrued expenses decreased by approximately $29.1 million due to a decrease in customer prepayments of $28.2 million.
Capital expenditures by the Company were $7.7 million and $6.2 million in the three months ended March 31, 2016 and 2015, respectively. The capital expenditures for the first quarter of 2016 were $6.2 million for machinery and equipment and other expenditures of $1.5 million. The capital expenditures for the first quarter of 2015 were $5.6 million for machinery and equipment and other expenditures of $600,000.
The exercise of stock options generated cash to the Company of $155,000 in the first quarter of 2016 as compared to $282,000 in the same period of 2015.
On February 26, 2015, the Company announced that its Board of Directors had authorized a stock repurchase plan under which the Company was authorized to repurchase up to $100 million of its common stock. The Company repurchased and cancelled 1,184,700 shares under this plan in 2015 for a total cost of $75.8 million. There were no repurchases during the first quarter of 2016. The repurchase program has no expiration date and any repurchased shares are expected to be cancelled.
As of March 31, 2016, 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

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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.
Other Matters
From time to time, the Company enters into discussions or negotiations to acquire other businesses or enter into joint ventures. The timing, size or success of any such efforts and the associated potential capital commitments are unpredictable and dependent on market conditions and opportunities existing at the time. The Company may seek to fund all or part of any such efforts with proceeds from debt or equity issuances. Debt or equity financing may not, however, be available at that time due to a variety of events, including, among others, the Company’s credit ratings, industry conditions, general economic conditions and market conditions.
Critical Accounting Policies
Refer to our Annual Report on Form 10-K for the year ended December 31, 2015 for a discussion of our critical accounting policies. During the three months ended March 31, 2016, 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. The Company does not engage in any material hedging transactions, forward contracts or currency trading which could mitigate the market risks inherent in such transactions. There have been no material changes in market risks for the Company from December 31, 2015.
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 gain of approximately $7.3 million during the three-month period ended March 31, 2016 and a pre-tax gain of $6.5 million in the same quarter of 2015. These gains were primarily due to the 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 March 31, 2016 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.

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There has been no change in the Company’s internal controls over financial reporting that occurred during the quarter ended March 31, 2016 that has materially affected, or is reasonably likely to materially affect, the Company’s internal controls over financial reporting.

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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, 2015.

Item 2.        Unregistered Sales of Equity Securities and Use of Proceeds
None.


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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 need for and 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, 2015 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, 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;

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•
acquisition and merger activities involving the Company or its competitors;
•
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 laws 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.

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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 Current 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 Current Report on Form 8-K filed on November 25, 2008).
 
 
 
*3.3
—
Amended and Restated Bylaws of the Company (incorporated herein by reference to Exhibit 3.2 to the Company’s Current 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.

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SIGNATURE
Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.
 
 
 
 
DRIL-QUIP, INC.
 
 
 
Date: April 26, 2016
BY:
/s/ Jerry M. Brooks
 
 
Jerry M. Brooks,
 
 
Vice President—Finance and
 
 
Chief Financial Officer
 
 
(Principal Accounting Officer and
 
 
Duly Authorized Signatory)


26