Innovex International - 10-Q quarterly report FY2017 Q3

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

_______________________________________________________

FORM 10-Q

_______________________________________________________

(MARK ONE)



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

For the Quarterly Period Ended September 30, 2017



¨	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, a smaller reporting company, or an emerging growth company. See the definitions of “large accelerated filer,” “accelerated filer”, “smaller reporting company,” and “emerging growth company” in Rule 12b-2 of the Exchange Act.



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

If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. ¨

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

As of October 25, 2017, the number of shares outstanding of the registrant’s common stock, par value $0.01 per share, was 37,860,549.

TABLE OF CONTENTS



		Page
PART I
Item 1.	Financial Statements	3
	Balance Sheets	3
	Statements of Income	4
	Statements of Comprehensive Income	5
	Statements of Cash Flows	6
	Notes to Financial Statements	7
Item 2.	Management's Discussion and Analysis of Financial Condition and Results of Operations	18
Item 3.	Quantitative and Qualitative Disclosures About Market Risk	27
Item 4.	Controls and Procedures	28
PART II
Item 1.	Legal Proceedings	29
Item 1A.	Risk Factors	29
Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds	29
	Index to Exhibits	32
	Signatures	33

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PART I—FINANCIAL INFORMATION

Item 1. Financial Statements

DRIL-QUIP, INC.

CONDENSED CONSOLIDATED BALANCE SHEETS

(UNAUDITED)



	September 30, 2017			December 31, 2016
	(In thousands)
ASSETS
Current assets:
Cash and cash equivalents	$	473,045		$	423,497
Trade receivables, net	197,139			213,513
Inventories, net	297,217			355,413
Deferred income taxes	—			24,497
Prepaids and other current assets	25,088			39,791
Total current assets	992,489			1,056,711
Property, plant and equipment, net	286,560			323,149
Deferred income taxes	53,713			1,699
Goodwill	48,514			34,371
Intangible assets	39,019			29,594
Other assets	17,169			15,880
Total assets	$	1,437,464		$	1,461,404
LIABILITIES AND STOCKHOLDERS’ EQUITY
Current liabilities:
Accounts payable	$	23,860		$	36,108
Accrued income taxes	5,448			24,543
Customer prepayments	5,203			11,884
Accrued compensation	16,070			10,829
Other accrued liabilities	18,702			18,116
Total current liabilities	69,283			101,480
Deferred income taxes	2,188			3,500
Total liabilities	71,471			104,980
Commitments and contingencies (Note 11)
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, 37,857,549 and 37,797,317 shares issued and outstanding at September 30, 2017 and December 31, 2016	375			375
Additional paid-in capital	16,401			5,468
Retained earnings	1,471,838			1,500,988
Accumulated other comprehensive losses	(122,621		)	(150,407		)
Total stockholders’ equity	1,365,993			1,356,424
Total liabilities and stockholders’ equity	$	1,437,464		$	1,461,404

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

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DRIL-QUIP, INC.

CONDENSED CONSOLIDATED STATEMENTS OF INCOME

(UNAUDITED)



	Three months ended September 30,						Nine months ended September 30,
	2017			2016			2017			2016
	(In thousands, except per share data)
Revenues:
Products	$	75,885		$	101,277		$	269,570		$	352,519
Services	24,461			22,363			77,928			80,121
Total revenues	100,346			123,640			347,498			432,640
Cost and expenses:
Cost of sales:
Products	48,761			63,879			190,214			206,208
Services	14,289			13,754			42,825			44,402
Total cost of sales	63,050			77,633			233,039			250,610
Selling, general and administrative	27,994			12,504			84,981			31,487
Engineering and product development	10,379			10,570			32,537			33,050
Impairment and other charges (Note 7)	60,968			—			60,968			—
Total costs and expenses	162,391			100,707			411,525			315,147
Operating income (loss)	(62,045		)	22,933			(64,027		)	117,493
Interest income	957			945			2,963			1,968
Interest expense	(12		)	(1		)	(44		)	(15		)
Income (loss) before income taxes	(61,100		)	23,877			(61,108		)	119,446
Income tax provision (benefit)	(31,840		)	4,864			(31,959		)	27,527
Net income (loss)	$	(29,260	)	$	19,013		$	(29,149	)	$	91,919
Earnings (loss) per common share:
Basic	$	(0.78	)	$	0.51		$	(0.78	)	$	2.45
Diluted	$	(0.78	)	$	0.51		$	(0.78	)	$	2.44
Weighted average common shares outstanding:
Basic	37,528			37,371			37,527			37,562
Diluted	37,528			37,554			37,527			37,699

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

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DRIL-QUIP, INC.

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME

(UNAUDITED)



	Three months ended September 30,						Nine months ended September 30,
	2017			2016			2017			2016
	(In thousands)
Net income (loss)	$	(29,260	)	$	19,013		$	(29,149	)	$	91,919
Other comprehensive loss, net of tax:
Foreign currency translation adjustments	13,187			(8,852		)	27,786			(30,204		)
Total comprehensive income	$	(16,073	)	$	10,161		$	(1,363	)	$	61,715

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

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DRIL-QUIP, INC.

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(UNAUDITED)



	Nine months ended September 30,
	2017			2016
	(In thousands)
Operating activities
Net income (loss)	$	(29,149	)	$	91,919
Adjustments to reconcile net income to net cash provided by (used in) operating activities:
Depreciation and amortization	32,231			23,092
Stock-based compensation expense	10,477			9,442
Impairment and other charges (Note 7)	60,968			—
Gain on sale of equipment	(79		)	(93		)
Deferred income taxes	(31,529		)	(3,435		)
Changes in operating assets and liabilities:
Trade receivables, net	21,271			92,075
Inventories	32,596			(12,515		)
Prepaids and other assets	17,308			34,350
Excess tax benefits of stock options and awards	—			(58		)
Accounts payable and accrued expenses	(39,359		)	(13,283		)
Net cash provided by operating activities	74,735			221,494
Investing activities
Purchase of property, plant and equipment	(19,563		)	(20,289		)
Proceeds from sale of equipment	1,160			281
Acquisition of business, net of cash acquired	(21,289		)	—
Net cash used in investing activities	(39,692		)	(20,008		)
Financing activities
Repurchase of common stock	—			(24,238		)
Proceeds from exercise of stock options	455			940
Excess tax benefits of stock options and awards	—			58
Net cash provided by (used in) financing activities	455			(23,240		)
Effect of exchange rate changes on cash activities	14,050			(16,952		)
Increase (decrease) in cash and cash equivalents	49,548			161,294
Cash and cash equivalents at beginning of period	423,497			381,336
Cash and cash equivalents at end of period	$	473,045		$	542,630

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

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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 drilling and production equipment that is well suited primarily 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, diverters and safety valves. Dril-Quip’s products are used by major integrated, large independent and foreign national oil and gas companies and drilling contractors 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 and at TIW Corporation (TIW) in Houston, Texas. The Company maintains additional facilities for fabrication and/or reconditioning and rework in Australia, China, Denmark, Ecuador, Egypt, Ghana, Hungary, Indonesia, Mexico, Nigeria, Norway, Qatar and Venezuela. The Company’s manufacturing operations are vertically integrated, allowing it to perform substantially all of its forging, heat treating, machining, fabrication, inspection, assembly and testing at its own facilities. The Company’s major subsidiaries are Dril-Quip (Europe) Limited, located in Aberdeen with branches in Denmark, Norway and Holland; Dril-Quip Asia Pacific PTE Ltd., located in Singapore; TIW, located in Houston, Texas; Dril-Quip do Brasil LTDA, located in Macae, Brazil; and DQ Holdings Pty. Ltd., located in Perth, Australia. Other subsidiaries include Dril-Quip Oilfield Services (Tianjin) Co. Ltd., located in Tianjin, China with branches in Shenzhen and Beijing, China; Dril-Quip Egypt for Petroleum Services S.A.E., located in Alexandria, Egypt; Dril-Quip (Ghana) Ltd., located in Takoradi, Ghana; TIW Hungary LLC, located in Szolnok, Hungary; PT DQ Oilfield Services Indonesia, located in Jakarta, Indonesia; TIW de Mexico S.A. de C.V., located in Villahermosa, Mexico; Dril-Quip (Nigeria) Ltd., located in Port Harcourt, Nigeria; Dril-Quip Qatar LLC, located in Doha, Qatar; TIW (UK) Limited, located in Aberdeen, Scotland; TIW de Venezuela S.A., located in Anaco, Venezuela and with a registered branch located in Shushufindi, Ecuador; and TIW International, Inc., with a registered branch located in Singapore.

The condensed consolidated financial statements included herein are unaudited. The balance sheet at December 31, 2016 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 statement of the financial position as of September 30, 2017 and the results of operations and comprehensive income for the three and nine months ended September 30, 2017 and 2016 and cash flows for the nine-month periods ended September 30, 2017 and 2016. 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 nine-month period ended September 30, 2017 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, 2016.

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

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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 and valuation of inventories, contingent liabilities and fixed assets.

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.

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, using the efforts-expended method, calculates the percentage complete and applies the percentage to determine the revenues earned and the appropriate portion of total estimated costs to be recognized. 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 September 30, 2017 and December 31, 2016, receivables included $44.1 million and $56.8 million of unbilled receivables, respectively. For the three months ended September 30, 2017, there were seven projects representing approximately 20% of the Company's total revenues and approximately 15% of the Company's product revenues that were accounted for using percentage-of-completion accounting, compared to four projects for the three months ended September 30, 2016, which represented approximately 12% of the Company's total revenues and approximately 14% of its product revenues. For the nine months ended September 30, 2017, there were eight projects representing approximately 15% of the Company’s total revenues and approximately 19% of its product revenues that were accounted for using percentage-of-completion accounting, compared to 10 projects for the nine months ended September 30, 2016, which represented approximately 14% of the Company’s total revenues and approximately 17% 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.

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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 September 30,		Nine months ended September 30,
	2017	2016	2017	2016
	(In thousands)
Weighted average common shares outstanding—basic	37,528	37,371	37,527	37,562
Dilutive effect of common stock options and awards	—	183	—	137
Weighted average common shares outstanding—diluted	37,528	37,554	37,527	37,699

For the three and nine month period ended September 30, 2017, the Company has excluded the following common stock options and awards because their impact on the loss per share is anti-dilutive (in thousands on a weighted average basis):



	Three Months Ended September 30,		Nine months ended September 30,
	2017	2016	2017	2016
	(In thousands)
Director stock awards	15	—	13	—
Stock options	328	—	333	—
Performance share units	212	—	207	—
Restricted stock awards	315	—	293	—

3. New Accounting Standards

In September 2017, the Financial Accounting Standards Board (FASB) issued Accounting Standards Update (ASU) 2017-13, "Revenue Recognition (Topic 605), Revenue from Contracts with Customers (Topic 606), Leases (Topic 840), and Leases (Topic 842)". This update clarifies the definition of a public business entity for the application of the new revenue recognition and leasing standards. This update did not have an impact on our assessment of these standards, discussed below in connection with ASU 2014-09, and will not impact our implementation strategies. The revenue standard is effective for annual periods beginning after December 15, 2017, including interim periods within those fiscal years, and the leasing standard is effective for annual periods beginning after December 15, 2018, including interim periods within those fiscal years.

In May 2017, the FASB issued Accounting Standards Update (ASU) 2017-09, "Compensation - Stock Compensation (Topic 718): Scope of Modification Accounting." This update clarifies which changes to the terms or conditions of a share-

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based payment award require an entity to apply modification accounting in Topic 718. For public business entities, the amendments in this update are effective for fiscal years beginning after December 15, 2017, including interim periods within those fiscal years. The Company does not anticipate any modifications to its existing awards and therefore has concluded that there is no impact to its consolidated financial statements.

In January 2017, the FASB issued ASU 2017-04, “Intangibles - Goodwill and Other (Topic 350).” The standard simplifies the subsequent measurement of goodwill by removing the second step of the two-step impairment test. The amendment requires an entity to perform its annual or interim goodwill impairment test by comparing the fair value of a reporting unit with its carrying amount. An impairment charge should be recognized for the amount by which the carrying amount exceeds the reporting unit's fair value; however, the loss recognized should not exceed the total amount of goodwill allocated to that reporting unit. An entity still has the option to perform the qualitative assessment for a reporting unit to determine if the quantitative impairment test is necessary. The amendment should be applied on a prospective basis. The standard is effective for fiscal years beginning after December 15, 2019, including interim periods within those fiscal years. Early adoption is permitted for interim or annual goodwill impairment tests performed on testing dates after January 1, 2017. The Company is evaluating the impact of the new standard on its consolidated financial statements.

In January 2017, the FASB issued ASU 2017-01, “Business Combinations: Clarifying the Definition of a Business (Topic 805).” This update clarifies the definition of a business with the objective of adding guidance to assist entities with evaluating whether transactions should be accounted for as acquisitions (or disposals) of assets or businesses. For public business entities, the amendments in this update are effective for fiscal years beginning after December 15, 2017, including interim periods within those fiscal years. The Company is evaluating the impact of the new standard on its consolidated financial statements.

In March 2016, the FASB issued ASU 2016-09 “Improvements to Employee Share-Based Payment Accounting (Topic 718).” The standard simplifies several aspects of accounting for share-based payment transactions, including the accounting for income taxes, forfeitures and statutory withholding requirements, as well as classification in the statement of cash flows. The standard is effective for annual periods beginning after December 15, 2016, including interim periods within those fiscal years. The Company adopted this standard as of January 1, 2017. The primary impact of this standard is the income tax effects of awards recognized when the awards are vested or settled is now reflected in the statement of cash flows as part of net income from operating activities.

In February 2016, the FASB issued 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 in the process of assessing its contractual commitments and arrangements with respect to the required presentation and disclosure under the new lease standard and its impact. Remaining implementation matters include completing the gap analysis between current requirements and the new leasing standard, establishing new policies, procedures and controls and quantifying any adjustments upon adoption.

In November 2015, the FASB issued ASU 2015-17 “Income Taxes (Topic 740)." The new standard requires that deferred tax assets and liabilities be classified as noncurrent on a classified balance sheet. The Company adopted this standard in the first quarter of 2017 on a prospective basis.

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 new revenue standard permits companies to either apply the requirements retrospectively to all prior periods presented or apply the requirements in the year of adoption through a cumulative adjustment. The Company has engaged a third party expert to assist in the analysis of contracts and to perform testing of the contracts to ensure the appropriate steps are taken in its assessment of the standard. The Company has completed the scoping process and has begun selection of contracts for testing, which is expected to be completed in the fourth quarter of 2017. Remaining implementation matters include completing the gap analysis between current requirements and the new revenue standard, establishing new policies, procedures and controls, and quantifying any adjustments upon adoption. The Company has not yet determined if it will apply the full retrospective or the modified retrospective method.

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4. Business Acquisitions

On October 14, 2016, the Company entered into an agreement with Pearce Industries, Inc. to acquire all the outstanding common stock, par value $100.00 per share, of TIW for a cash purchase price of $142.7 million, which is subject to customary adjustments for cash and working capital. The acquisition closed on November 10, 2016 and is expected to strengthen the Company's liner hanger sales and increase market share. Additionally, the acquisition of TIW gives Dril-Quip a presence in the onshore oil and gas market.

Total acquisition costs since inception through September 30, 2017 in connection with the purchase of TIW were $2.5 million. These costs were expensed in general and administrative costs as of December 31, 2016.

Purchase Price Allocation

Acquired assets and liabilities were recorded at estimated fair value as of the acquisition date. The excess of the purchase price over the estimated fair value of tangible and intangible identifiable net assets resulted in the recognition of goodwill of $34.4 million, the majority of which is included in long-lived assets in the Western Hemisphere and is attributable to expected synergies from combining operations as well as intangible assets which do not qualify for separate recognition. The amount of goodwill that is deductible for income tax purposes is not significant.

The goodwill was determined on the basis of the fair values of the tangible and intangible assets and liabilities as of the acquisition date. It may be adjusted if the provisional fair values change as a result of circumstances existing at the acquisition date. Such fair value adjustments may arise in respect to intangible assets, inventories and property, plant and equipment, upon completion of the necessary valuations and physical verifications of such assets. The amount of deferred taxes may also be adjusted during the measurement period. For further information regarding goodwill, see Note 8.

The following table sets forth the preliminary purchase price allocation, which was based on fair value of assets acquired and liabilities assumed at the acquisition date, November 10, 2016:



	Valuation at November 10, 2016
	(In thousands)
Cash	$	1,829
Trade receivables	9,794
Inventories	29,896
Prepaid and other current assets	3,572
Deferred income taxes	205
Property, plant and equipment	38,058
Intangible assets ⁽¹⁾	29,808
Total assets acquired	$	113,162

Accounts payable	5,599
Customer prepayments	2,757
Other accrued liabilities	2,644
Deferred tax liabilities, non-current	2,261
Total liabilities assumed	$	13,261

Net identifiable assets acquired	$	99,901
Goodwill	34,371
Net assets acquired	$	134,272

(1) Includes $3.3 million of patents with a weighted average useful life of 10 years, $8.4 million of tradenames with an indefinite life and $18.1 million

of customer relationships with a weighted average useful life of 15 years. See Note 9 for further information regarding intangible assets.

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Summary of Unaudited Pro Forma Information

TIW's results of operations have been included in Dril-Quip's financial statements for the period subsequent to the closing of the acquisition on November 10, 2016. Business acquired from TIW contributed revenues of $36.3 million, a pre-tax operating loss of $13.9 million and a net loss of $8.7 million for the nine months ended September 30, 2017.

The following table reflects the unaudited pro forma consolidated results of operations for the three and nine months ended September 30, 2016, as though the acquisition of TIW had occurred on January 1, 2016:



	Three months ended September 30, 2016		Nine months ended September 30, 2016
	(In thousands, except per share data)
	(unaudited)
Revenues	$	133,526	$	485,505
Net income	$	14,637	$	89,290
Basic earnings per share	$	0.39	$	2.38
Diluted earnings per share	$	0.39	$	2.37

The unaudited pro forma financial information is presented for illustrative purposes only and is not indicative of the results of operations that would have been realized if the acquisition had been completed on the date indicated, nor is it indicative of future operating results. The pro forma results do not include, for example, the effects of anticipated synergies from the acquisition.

On January 6, 2017, the Company acquired The Technologies Alliance Inc. d/b/a OilPatch Technologies (OPT) for approximately $20.0 million, which was subject to customary adjustments for cash and working capital. The acquisition was accounted for as a business combination in accordance with ASC 805. The purchase price was subject to closing adjustments and was funded with cash on hand. The acquisition and purchase price allocation do not meet the significant subsidiary test outlined in Regulation S-X Rule 1-02. The acquisition does not have a material impact on the Company's Consolidated Balance Sheets. OPT's results of operations for the periods prior to this acquisition were not material to the Company's Consolidated Statements of Operations.

5. Stock-Based Compensation and Stock Awards

During the three and nine months ended September 30, 2017, the Company recognized approximately $3.7 million and $10.5 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, compared to $3.2 million and $9.4 million recorded for the three and nine months ended September 30, 2016, respectively. No stock-based compensation expense was capitalized during the three and nine months ended September 30, 2017 or 2016.

6. Inventories, net

Inventories consist of the following:



	September 30, 2017			December 31, 2016
	(In thousands)
Raw materials	$	78,934		$	85,684
Work in progress	71,614			81,645
Finished goods	230,497			233,732
	381,045			401,061
Less: allowance for obsolete and excess inventory (see Note 7)	(83,828		)	(45,648		)
Net inventory	$	297,217		$	355,413

7. Impairments and Other Charges

We carry a variety of long-lived assets on our balance sheet, including property, plant and equipment, goodwill and other intangibles. We conduct impairment tests on long-lived assets if events or changes in circumstances indicate that the carrying

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amount of an asset may not be recoverable. We review the recoverability of the carrying value of our assets based upon estimated future cash flows while taking into consideration assumptions and estimates including the future use of the asset, remaining useful life of the asset and service potential of the asset. Additionally, inventories are valued at the lower of cost or market.

In connection with our preparation and review of financial statements for the quarter ended September 30, 2017, after considering current Brent Crude (Brent) consensus forecasts and expected rig counts for the foreseeable future, we determined the carrying amount of certain of our long-lived assets in the Western Hemisphere exceeded their respective fair values due to projected declines in asset utilization, and that the cost of some of our worldwide inventory exceeded its market value. As a result, we recorded corresponding impairments and other charges.

Primarily as a result of the factors described above, we recorded charges of approximately $33.6 million related to inventory and $27.4 million related to fixed assets.

8. Goodwill

The changes in the carrying amount of goodwill by reporting unit during the nine months ended September 30, 2017 were as follows:



	Carrying Value						Carrying Value
	December 31, 2016		Acquisitions⁽¹⁾		Foreign Currency Translation Adjustment		September 30, 2017
	(In thousands)
Western Hemisphere	$	26,632	$	12,788	$	696	$	40,116
Eastern Hemisphere	7,739		—		659		8,398
Asia-Pacific	—		—		—		—
Total	$	34,371	$	12,788	$	1,355	$	48,514

(1) Primarily relates to goodwill additions as a result of the OPT acquisition.

The Company performs its annual impairment tests of goodwill as of October 1 or when there is an indication an impairment may have occurred.

In connection with our preparation and review of financial statements for the quarter ended September 30, 2017, as a result of charges related to inventory and fixed assets and our updated business outlook, the Company performed a goodwill impairment test for the Western Hemisphere reporting unit as of September 30, 2017. Based on the results of this assessment, we concluded that no goodwill impairment was required.

The fair values used in the goodwill impairment assessment were determined using the net present value of the expected future cash flows for the reporting unit. During the Company’s goodwill impairment analysis, the Company determines the fair value of the reporting unit, as a whole, using a discounted cash flow analysis, which requires significant assumptions and estimates about future operations. The assumptions about future cash flows and growth rates are based on our current budget for the remainder of the current year, 2018 and for future periods, as well as our strategic plans and management’s beliefs about future exploration and development in the industry. Changes in management's forecast commodity price assumptions may cause us to reassess our goodwill for impairment, and could result in non-cash impairment charges in the future.

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9. Intangible Assets

Intangible assets, substantially all of which were acquired in the acquisition of TIW and OPT, consist of the following:



	Estimated Useful Lives	September 30, 2017							December 31, 2016
	Estimated Useful Lives	Gross Book Value		Accumulated Amortization			Net Book Value		Gross Book Value		Accumulated Amortization			Net Book Value
		(In thousands)
Trademarks	indefinite	$	8,474	$	—		$	8,474	$	8,416	$	—		$	8,416
Patents	15 - 30 years	5,955		(745		)	5,210		3,583		(294		)	3,289
Customer relationships	5 - 15 years	26,737		(1,531		)	25,206		18,057		(168		)	17,889
Noncompete Agreements	3 years	171		(42		)	129		—		—			—
		$	41,337	$	(2,318	)	$	39,019	$	30,056	$	(462	)	$	29,594

Amortization expense for the three and nine months ended September 30, 2017, was $0.6 million and $1.8 million, respectively.

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10. Geographic Areas



	Three months ended September 30,						Nine months ended September 30,
	2017			2016			2017			2016
	(In thousands)
Revenues:
Western Hemisphere
Products	$	43,344		$	61,071		$	162,931		$	202,457
Services	14,406			13,395			49,298			47,171
Intercompany	12,569			6,444			22,700			27,660
Total	$	70,319		$	80,910		$	234,929		$	277,288
Eastern Hemisphere
Products	$	17,200		$	26,133		$	53,567		$	89,207
Services	7,557			7,264			20,685			28,275
Intercompany	267			109			554			316
Total	$	25,024		$	33,506		$	74,806		$	117,798
Asia-Pacific
Products	$	15,341		$	14,073		$	53,072		$	60,855
Services	2,498			1,704			7,945			4,675
Intercompany	416			1,335			533			1,851
Total	$	18,255		$	17,112		$	61,550		$	67,381
Summary
Products	$	75,885		$	101,277		$	269,570		$	352,519
Services	24,461			22,363			$	77,928		$	80,121
Intercompany	13,252			7,888			$	23,787		$	29,827
Eliminations	(13,252		)	(7,888		)	(23,787		)	(29,827		)
Total	$	100,346		$	123,640		$	347,498		$	432,640
Impairment and Other Charges:
Western Hemisphere	$	45,439		$	—		$	45,439		$	—
Eastern Hemisphere	8,532			—			8,532			—
Asia-Pacific	6,997			—			6,997			—
Total	$	60,968		$	—		$	60,968		$	—
Depreciation and amortization:
Western Hemisphere	$	6,827		$	5,052		$	24,153		15,157
Eastern Hemisphere	1,073			1,171			$	3,228		3,856
Asia-Pacific	1,015			1,070			$	3,046		3,319
Corporate	603			299			1,804			760
Total	$	9,518		$	7,592		$	32,231		$	23,092
Income before income taxes:
Western Hemisphere	$	(40,472	)	$	22,009		$	(28,558	)	$	85,921
Eastern Hemisphere	(2,882		)	15,618			3,401			57,352
Asia-Pacific	(4,525		)	73			3,115			11,296
Corporate	(13,283		)	(12,603		)	(37,878		)	(37,524		)
Eliminations	62			(1,220		)	(1,188		)	2,401
Total	$	(61,100	)	$	23,877		$	(61,108	)	$	119,446

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	September 30, 2017			December 31, 2016
	(In thousands)
Total Long-Lived Assets:
Western Hemisphere	$	373,394		$	317,875
Eastern Hemisphere	34,248			33,338
Asia-Pacific	58,203			53,960
Eliminations	(20,870		)	(480		)
Total	$	444,975		$	404,693
Total Assets:
Western Hemisphere	$	771,401		$	775,358
Eastern Hemisphere	325,476			318,529
Asia-Pacific	365,976			370,043
Eliminations	(25,389		)	(2,526		)
Total	$	1,437,464		$	1,461,404

11. Income Taxes

Valuation Allowances

As of September 30, 2017, the Company recorded a full valuation allowance in Asia Pacific of $1.6 million related to beginning of the year deferred tax assets in the region due to the projected cumulative loss position in the most recent forecast.

The Company has evaluated the need for a valuation allowance in the remaining jurisdictions based on the most recent forecast, cumulative loss position, reversing taxable temporary differences and allowable carrybacks and determined that no additional valuation allowances are required. The Company will continue to monitor the need for a further valuation adjustment as the year progresses.

Uncertain Tax Positions (UTPs)

As of September 30, 2017, the Company has accrued liabilities for tax exposures of $2.2 million related to tax on service revenue in Saudi Arabia, an increase of $168,000 from year end recorded as a discrete period tax in the quarter ended September 30, 2017. The Company recognized deductions related to the UK patent box. This resulted in the Company recording a discrete tax benefit in the amount of $8.2 million.

The Company has reviewed its various tax positions around the world including the impact of any tax authority audits or inquiry and determined that no additional UTPs were required.

12. 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.

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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 a 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 filed a similar appeal in the judicial system with regard to the January 2011 assessment and was required to deposit with the court approximately $5.7 million in December 2016. 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, property damage 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.

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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, 2016.

Overview

Oil and Gas Prices

The market for 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. Oil and gas prices and the level of drilling and production 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:



	Three months ended September 30,				Nine months ended September 30,
Brent Crude Oil Price per Barrel	2017		2016		2017		2016
Low	$	46.47	$	40.00	$	43.98	$	26.01
High	59.77		49.66		59.77		50.73
Average	52.10		45.80		51.75		41.86
Closing	57.02		48.24		57.02		48.24

According to the September 2017 release of the Short-Term Energy Outlook published by the EIA, Brent Crude oil prices are expected to average approximately $51 per barrel in 2017 and $52 per barrel in 2018. In its September 2017 Oil Market Report, the International Energy Agency projected the 2017 global oil demand will grow to 97.7 million barrels per day, a 1.6 million barrels per day increase over 2016.

Offshore 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 nine months ended September 30, 2017 and 2016. 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.



	Nine months ended September 30,
	2017		2016
	Floating Rigs	Jack-up Rigs	Floating Rigs	Jack-up Rigs
Western Hemisphere	63	42	87	43
Eastern Hemisphere	56	58	65	67
Asia-Pacific	31	217	31	223
TOTAL	150	317	183	333

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Source: IHS—Petrodata RigBase – September 30, 2017 and 2016

According to IHS-Petrodata RigBase, as of September 30, 2017, there were 464 contracted rigs for the Company’s geographic regions (148 floating rigs and 316 jack-up rigs), which represents an 3.5% decline from the rig count of 481 rigs (163 floating rigs and 318 jack-up rigs) as of September 30, 2016.

The Company believes that the number of rigs (semi-submersibles, drillships and jack-up rigs) under construction impacts its backlog and resulting 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, as of September 30, 2017 and 2016, there were 143 and 171 rigs, respectively, under construction, which represents an approximate 16.4% decline in rigs under construction. The expected delivery dates for the rigs under construction at September 30, 2017 are as follows:



	Floating	Jack-Up
	Rigs	Rigs	Total
2017	8	11	19
2018	19	60	79
2019	11	20	31
2020	6	7	13
After 2020 or unspecified delivery date	1	—	1
	45	98	143

However, given the sustained low level of oil and gas prices and oversupply of offshore drilling rigs, the Company believes it is 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 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 pressure in both crude oil and natural gas prices, as well as in the level of drilling and production related activities, particularly as they relate to offshore 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. The sustained lower crude oil and natural gas prices, along with lower drilling and production activity, had a negative impact on the Company’s results for the nine months ended September 30, 2017 and is expected to persist through 2018. A prolonged delay in the recovery of hydrocarbon prices could also lead to further material impairment charges to tangible or intangible assets or otherwise result in a material adverse effect on the Company's results of operations.

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To some extent, the Company believes that its backlog should help mitigate the impact of negative market conditions. However, continued low commodity prices or an extended downturn in the global economy or future restrictions or declines in oil and gas exploration and production could have a negative impact on the Company and its backlog. The Company’s product backlog at September 30, 2017 was approximately $217 million, compared to approximately $235 million as at June 30, 2017, $296 million at March 31, 2017 and $318 million at December 31, 2016.

The following table represents the change in backlog for the three months ended September 30, 2017, March 31, 2017 and December 31, 2016:



	Three months ended
	September 30, 2017	June 30, 2017		March 31, 2017		December 31, 2016
	(in thousands)
Beginning Backlog	$234,859	$295,534		$317,579		$378,447
Bookings:
Product	56,329	45,804		71,054		62,743
Service	24,461	25,831		27,636		25,598
Cancellation/Revision	95	(2,758	)	(3,500	)	(36,784	)
Translation	1,173	(1,630	)	1,993		(6,334	)
Total Bookings	82,058	67,247		97,183		45,223
Revenues:
Product	75,885	102,092		91,592		80,493
Service	24,461	25,830		27,636		25,598
Total Revenue	100,346	127,922		119,228		106,091
Ending Backlog	$216,571	$234,859		$295,534		$317,579

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 $418 million based on the September 30, 2017 exchange rate of 3.17 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 $148 million have been recognized on this contract through September 30, 2017. As of September 30, 2017, the Company’s backlog included $15 million of purchase orders under this Petrobras contract. The Company has not yet recognized revenue of approximately $3 million as of September 30, 2017 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. Following an interim amendment to extend the term of the contract pending the resolution of discussions, the Company entered into an amendment on October 17, 2016 to extend the duration of the contract until July 2020. As part of the amendment to the contract, Petrobras agreed to issue purchase orders totaling a minimum of approximately $31 million (based on current exchange rates) before 2019. The Company cannot provide assurances that Petrobras will order all of the equipment under the contract.

As of September 30, 2016, the total number of the Company's employees was 1,980, of which 1,102 were located in the United States. The total number of the Company’s employees as of December 31, 2016 was 2,355, which included the addition of 406 employees of TIW during the fourth quarter of 2016. Of those 2,355, 1,193 were located in the United States. As a result of additional worldwide reductions in workforce and natural attrition, the total number of employees as of September 30, 2017 was reduced to 2,067, a 12.2% reduction from December 31, 2016. Of these 2,067 employees, 1,099 are located in the United States. The Company's ongoing efforts to control costs and reduce its workforce resulted in $3.0 million in severance costs being recognized in the nine months ended September 30, 2017. In addition, reductions in pay, estimated at approximately $10.0 million on an annualized basis, were instituted globally at the end of the first quarter of 2017.

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

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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 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 September 30, 2017 and 2016, the Company derived 76% and 82%, respectively, of its revenue from the sale of its products and 24% and 18%, respectively, of its revenues from services. For the nine months ended September 30, 2017 and 2016, the Company derived 78% and 81%, respectively, of its revenues from the sales of its products and 22% and 19%, 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 and rental of running tools during installation. The Company has substantial international operations, with approximately 56% and 58% of its revenues derived from foreign sales for the nine months ended September 30, 2017 and 2016, respectively. The majority of the Company’s domestic revenue relates to operations in the U.S. Gulf of Mexico. Domestic revenue approximated 44% and 42% of the Company’s total revenues for the nine months ended September 30, 2017 and 2016, 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 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 three months ended September 30, 2017, there were seven projects representing approximately 20% of the Company’s total revenues and approximately 15% of its product revenues that were accounted for using percentage-of-completion accounting, compared to four projects for the three months ended September 30, 2016, which represented approximately 12% of the Company’s total revenues and approximately 14% of its product revenues. For the nine months ended September 30, 2017, there were eight projects representing approximately 15% of the Company’s total revenues and approximately 19% of its product revenues, compared to 10 projects for the nine months ended September 30, 2016, which represented approximately 14% of the Company’s total revenues and approximately 17% 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 to be recognized. Accordingly, price and cost estimates are reviewed periodically as the work progresses, and adjustments proportionate to the percentage 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, over/under manufacturing overhead absorption, pricing 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. The Company’s U.K. subsidiary, whose functional currency is the British pound sterling, conducts a portion of its operations in U.S. dollars. As a result, this subsidiary holds significant monetary assets denominated in U.S. dollars. These monetary assets are subject to changes in exchange rates between the U.S. dollar and the British pound sterling, which may result in pre-tax non-cash foreign currency gains or losses.

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.

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Impairment and Other Charges. Impairment and other charges consist of certain fixed asset and inventory write-downs of $27.4 million and $33.6 million, respectively, which occurred in connection with our preparation and review of financial statements for the quarter ended September 30, 2017. See Note 7 for more detail.

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 statement of operations data expressed as a percentage of revenues:



	Three months ended September 30,				Nine months ended September 30,
	2017		2016		2017		2016
Revenues:
Products	75.6	%	81.9	%	77.6	%	81.5	%
Services	24.4		18.1		22.4		18.5
Total revenues	100.0		100.0		100.0		100.0
Cost of sales:
Products	48.6		51.7		54.7		47.7
Services	14.2		11.1		12.3		9.9
Total cost of sales	62.8		62.8		67.1		57.9
Selling, general and administrative	27.9		10.2		24.5		7.4
Engineering and product development	10.3		8.5		9.4		7.6
Impairment and other charges	60.8		—		17.5		—
Operating income	(61.8	)	18.5		(18.4	)	27.1
Interest income	1.0		0.8		0.9		0.5
Income before income taxes	(60.9	)	19.3		(17.6	)	27.6
Income tax provision	(31.7	)	3.9		(9.2	)	6.4
Net income	(29.2	)%	15.4	%	(8.4	)%	21.2	%

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



	Three months ended September 30,				Nine months ended September 30,
	2017		2016		2017		2016
	(In millions)
Revenues:
Products
Subsea equipment	$	64.8	$	89.8	$	224.9	$	309.3
Downhole tools	5.6		0.2		23.1		2.6
Offshore rig equipment	2.4		6.7		10.1		26.1
Surface equipment	3.0		4.6		11.5		14.5
Total products	75.8		101.3		269.6		352.5
Services	24.5		22.3		77.9		80.1
Total revenues	$	100.3	$	123.6	$	347.5	$	432.6

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

Revenues. Revenues decreased by $23.3 million, or approximately 18.9%, to $100.3 million in the three months ended September 30, 2017 from $123.6 million in the three months ended September 30, 2016, primarily due to a decrease in demand for exploration and production equipment. Product revenues decreased by approximately $25.5 million for the three months ended September 30, 2017 compared to the same period in 2016 as a result of decreased revenues of $25.0 million in subsea equipment, $4.3 million in offshore rig equipment and $1.6 million in surface equipment, offset by an increase of $5.4 million in downhole tools, primarily due to the acquisition of TIW. Product revenues decreased in the Western and Eastern Hemispheres by $17.7 million and $8.9 million, respectively, largely due to low oil and gas prices resulting in decreases in the demand for exploration and production equipment, especially subsea equipment. 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 $2.1 million resulting from increased service revenues in the Western Hemisphere of $1.0 million, Asia-Pacific of $0.8 million, and Eastern Hemisphere of $0.3 million. The majority of the increases in service revenues related to increased Rental Tools business and completion of certain milestones on a project with Shell.

Cost of Sales. Cost of sales decreased by $14.5 million, or approximately 18.7%, to $63.1 million for the three months ended September 30, 2017 from $77.6 million for the same period in 2016. The cost of sales as a percentage of revenue remained the same at 62.8% for the three months ended September 30, 2017 as compared to the same period in 2016.

Selling, General and Administrative Expenses. For the three months ended September 30, 2017, selling, general and administrative expenses increased by approximately $15.5 million to $28.0 million from $12.5 million for the same period in 2016. The Company experienced a non-cash pre-tax foreign currency transaction loss of $0.4 million in the third quarter of 2017 compared to a gain of $5.5 million in the third quarter of 2016. In addition, the Company recognized recurring TIW expenses of $7.7 million in the third quarter of 2017. Severance costs totaled $1.1 million for the three months ended September 30, 2017, compared to no severance costs for the same period of 2016. Corporate expenses totaled $9.1 million and $8.0 million for the three months ended September 30, 2017 and 2016, respectively. Selling, general and administrative expenses as a percentage of revenues increased to 27.9% in the third quarter of 2017 from 10.2% in the third quarter of 2016.

Engineering and Product Development Expenses. For the three months ended September 30, 2017, engineering and product development expenses totaled $10.4 million compared to $10.6 million for the same period in 2016, a decrease of $0.2 million, or 1.9%. The majority of the decrease was due to a reduction in personnel and related costs associated with lower headcount during the third quarter of 2017, offset by the inclusion of recurring TIW expenses of $0.7 million. Corporate expenses totaled $4.8 million and $4.6 million for the three months ended September 30, 2017 and 2016, respectively. Engineering and product development expenses as a percentage of revenues increased to 10.3% for the three months ended September 30, 2017 compared to 8.5% for the three months ended September 30, 2016.

Impairment and Other Charges. In connection with our preparation and review of financial statements for the quarter ended September 30, 2017, after considering current Brent Crude (Brent) consensus forecasts and expected rig counts for the foreseeable future, we determined the carrying amount of certain of our long-lived assets in the Western Hemisphere exceeded their respective fair values due to projected declines in asset utilization, and that the cost of some of our worldwide inventory exceeded its market value. As a result, we recorded corresponding impairments and other charges. Primarily as a result of the factors described above, we recorded charges of approximately $33.6 million related to inventory and $27.4 million related to fixed assets.

Income Tax Provision. Income tax benefit for the three months ended September 30, 2017 was $31.8 million on a loss before taxes of $61.1 million resulting in a 52.1% effective tax rate. Income tax expense for the three months ended September 30, 2016 was $4.9 million on income before taxes of $23.9 million, resulting in an effective income tax rate of approximately 20.4%. Historically, the change 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. In addition, during the three months ended September 30, 2017, we recognized an $8.2 million benefit as a result of the recognition of the patent box deduction in the Eastern Hemisphere, which was partially offset by our recognition of a valuation allowance of $1.6 million related to beginning of the year deferred tax assets in Asia Pacific due to a cumulative loss position.

Net Income (Loss). Net loss was approximately $29.3 million for the three months ended September 30, 2017 and net income was $19.0 million for the same period in 2016 for the reasons set forth above.

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

Revenues. Revenues decreased by $85.1 million, or approximately 19.7%, to $347.5 million in the nine months ended September 30, 2017 from $432.6 million in the nine months ended September 30, 2016, primarily due to a decrease in demand for exploration and production equipment. Product revenues decreased by approximately $82.9 million for the nine months

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ended September 30, 2017 compared to the same period in 2016 as a result of decreased revenues of $84.4 million in subsea equipment, $16.0 million in offshore rig equipment and $3.0 million in surface equipment, offset by an increase of $20.5 million in downhole tools, primarily due to the acquisition of TIW. Product revenues decreased in the Western, Eastern and Asia Pacific Hemispheres by $39.5 million, $35.6 million and $7.8 million, respectively, largely due to low oil and gas prices resulting in decreases in the demand for exploration and production equipment, especially subsea equipment, and projects nearing completion with no new projects to maintain revenue. 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 $2.2 million resulting from decreased service revenues in the Eastern Hemisphere of $7.6 million, partially offset by an increase in Asia-Pacific of $3.3 million and in the Western Hemisphere of $2.1 million. The majority of the decreases in service revenues related to decreased demand for reconditioning of customer-owned property and technical advisory assistance, largely due to low oil and gas prices leading to decreased exploration and production activities.

Cost of Sales. Cost of sales decreased by $17.6 million, or approximately 7.0%, to $233.0 million for the nine months ended September 30, 2017 from $250.6 million for the same period in 2016 partially due to lower revenues. The cost of sales as a percentage of revenue increased to 67.1% from 57.9% in the nine months ended September 30, 2017 as compared to the same period in 2016, primarily as a result of unabsorbed manufacturing costs, product mix and pricing concessions.

Selling, General and Administrative Expenses. For the nine months ended September 30, 2017, selling, general and administrative expenses increased by approximately $53.5 million, or 169.8%, to $85.0 million from $31.5 million for the same period in 2016. The Company experienced a non-cash pre-tax foreign currency transaction loss of $4.0 million for the nine months ended September 30, 2017, compared to a gain of $28.1 million for the same period in 2016. In addition, the Company recognized recurring TIW expenses of $20.0 million for the nine months of 2017. Severance costs totaled $3.0 million for the nine months ended September 30, 2017, compared to $2.0 million severance costs for the same period of 2016. Corporate expenses totaled $26.8 million and $24.5 million for the nine months ended September 30, 2017 and 2016, respectively. Selling, general and administrative expenses as a percentage of revenues increased to 24.5% in the third quarter of 2017 from 7.4% in the third quarter of 2016.

Engineering and Product Development Expenses. For the nine months ended September 30, 2017, engineering and product development expenses totaled $32.5 million compared to $33.1 million for the same period in 2016, a decrease of $0.6 million, or 1.8%. The majority of the decrease was due to a reduction in personnel and related costs associated with lower headcount during the nine months ended September 30, 2017, offset by the inclusion of recurring TIW expenses of $3.0 million. Corporate expenses totaled $12.9 million and $13.0 million for the nine months ended September 30, 2017 and 2016, respectively. Engineering and product development expenses as a percentage of revenues increased to 9.4% for the nine months ended September 30, 2017 from 7.6% for the same period in 2016.

Income Tax Provision. Income tax benefit for the nine months ended September 30, 2017 was $32.0 million on a loss before taxes of $61.1 million. Income tax expense for the nine months ended September 30, 2016 was $27.5 million on income before taxes of $119.4 million, resulting in an effective income tax rate of approximately 23.0%. Historically, the change 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. In addition, during the three months ended ended September 30, 2017, we recognized an $8.2 million benefit as a result of the recognition of the patent box deduction in the Eastern Hemisphere, which was partially offset by our recognition of a valuation allowance of $1.6 million related to beginning of the year deferred tax assets in Asia Pacific due to a cumulative loss position

Net Income (Loss). Net loss was approximately $29.1 million for the nine months ended September 30, 2017, compared to net income of $91.9 million for the same period in 2016 for the reasons set forth above.

Non-GAAP Financial Measures

We have performed a detailed analysis of the non-GAAP measures that are relevant to our business and its operations and determined that the appropriate unit of measure to analyze our performance is Adjusted EBITDA (earnings before interest, taxes, depreciation and amortization, as well as other significant non-cash items and other adjustments for certain charges and credits). The Company believes that the exclusion of these charges and credits from these financial measures enables it to

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evaluate more effectively the Company's operations period over period and to identify operating trends that could otherwise be masked by excluded items. It is our determination that Adjusted EBITDA is a more relevant measure of how the Company reviews its ability to meet commitments and pursue capital projects.

Adjusted EBITDA

We calculate Adjusted EBITDA as one of the indicators to evaluate and compare the results of our operations from period to period by removing the effect of our capital structure from our operating structure. This measurement is used in concert with net income and cash flows from operations, which measures actual cash generated in the period. In addition, we believe that Adjusted EBITDA is a supplemental measurement tool used by analysts and investors to help evaluate overall operating performance, ability to pursue and service possible debt opportunities and analyze possible future capital expenditures. Adjusted EBITDA does not represent funds available for our discretionary use and is not intended to represent or to be used as a substitute for net income, as measured under U.S. generally accepted accounting principles. The items excluded from Adjusted EBITDA, but included in the calculation of reported net income, are significant components of the consolidated statements of income and must be considered in performing a comprehensive assessment of overall financial performance. Our calculation of Adjusted EBITDA may not be consistent with calculations of Adjusted EBITDA used by other companies.

The following table reconciles our reported net income to Adjusted EBITDA for each of the respective periods:



		Three months ended September 30,						Nine months ended September 30,
		2017			2016			2017			2016
		(In thousands)
Net Income (Loss)		$	(29,260	)	$	19,013		$	(29,149	)	$	91,919
Add:
	Interest (income) expense	(945		)	(944		)	(2,919		)	(1,953		)
	Income tax expense (benefit)	(31,840		)	4,864			(31,959		)	27,527
	Depreciation and amortization expense	9,518			7,592			32,231			23,092
	Impairment and other charges	60,968			—			60,968			—
	Foreign currency loss (gain)	380			(5,478		)	3,965			(28,140		)
	Severance costs	1,163			—			3,040			—
	Stock compensation expense	3,694			3,188			10,477			9,442
Adjusted EBITDA ⁽¹⁾		$	13,678		$	28,235		$	46,654		$	121,887

^{(1) The Adjusted EBITDA for the three and nine months ended September 30, 2017 includes negative Adjusted EBITDA of approximately $1.0 million and $2.8 million, respectively, related to TIW. These decreases in Adjusted EBITDA were related to lower international orders for the three and nine months ended September 30, 2017.}

Adjusted EBITDA does not measure financial performance under GAAP and, accordingly, should not be considered as an alternative to net income as an indicator of operating performance.

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Liquidity and Capital Resources

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



	Nine months ended September 30,
	2017			2016
	(In thousands)
Operating activities	$	74,735		$	221,494
Investing activities	(39,692		)	(20,008		)
Financing activities	455			(23,240		)
	35,498			178,246
Effect of exchange rate changes on cash activities	14,050			(16,952		)
Increase (decrease) in cash and cash equivalents	$	49,548		$	161,294

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 for the nine months ended September 30, 2017 was $74.7 million as compared to $221.5 million for the nine months ended September 30, 2016. The decrease is primarily due to lower net income of $121.1 million, net increases to deferred income taxes of $28.1 million, and net decreases in operating assets and liabilities of $68.8 million, partially offset by the impairment and other charges recorded in the third quarter of 2017 of $61.0 million and increased depreciation and amortization costs of $9.1 million.

The change in operating assets and liabilities for the nine months ended September 30, 2017 resulted in a $31.8 million increase in cash. Trade receivables decreased $21.3 million primarily due to lower revenues during the period. Inventory decreased by $32.6 million from reductions in customer orders and efforts to utilize existing inventory. Prepaids and other assets decreased by $17.3 million due to decreases in vendor prepayments. Accounts payable and accrued expenses decreased by approximately $39.4 million primarily due to a reduction in income tax payable of $20.7 million, which is comprised of the $8.2 million impact from the patent box benefit and lower income before taxes, decreases in accounts payable of $11.7 million and customer prepayments of $6.7 million.

The decrease in operating assets and liabilities for the nine months ended September 30, 2016 was due to a $64.2 million decrease in trade receivables primarily related to increased collection efforts and a decline in revenues. Prepaids and other assets decreased by $20.7 million due to decreases in vendor prepayments and the amortization of miscellaneous prepaid expenses. Accounts payable and accrued expenses decreased by approximately $13.5 million due to a reduction in customer prepayments of $10.0 million and a decrease in accrued compensation of $5.2 million.

Capital expenditures by the Company were $19.6 million and $20.4 million for the nine months ended September 30, 2017 and 2016, respectively. The capital expenditures for the nine months ended September 30, 2017 were $10.9 million for facilities, $4.4 million for rental tools, $3.9 million for machinery and equipment and $0.4 million for other capital expenditures. The capital expenditures for the nine months ended September 30, 2016 were $10.7 million for machinery and equipment, $8.6 million for facilities and other expenditures of $1.0 million.

The Company acquired The Technologies Alliance Inc. d/b/a OilPatch Technologies (OPT) for approximately $19.9 million, net of cash and working capital adjustments, during the first quarter of 2017.

The exercise of stock options generated cash to the Company of $455,000 for the nine months ended September 30, 2017 as compared to $940,000 in the same period of 2016.

On July 26, 2016, the Board of Directors authorized a stock repurchase plan under which the Company can repurchase up to $100 million of its common stock. The repurchase plan has no set expiration date and any repurchased shares are expected to be cancelled. No repurchases have been made pursuant to this plan as of September 30, 2017.

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As of September 30, 2017, 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; however, the Company is continuously reviewing sources for additional cash funding, as needed.

Off-Balance Sheet Arrangements

The Company currently 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, 2016 for a discussion of our critical accounting policies. During the nine months ended September 30, 2017, 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 since December 31, 2016.

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 $0.4 million and $4.0 million, respectively, during the three and nine-month periods ended September 30, 2017 and a pre-tax gain of $5.5 million and $28.1 million, respectively, in the same periods of 2016. These non-cash gains and losses were primarily due to the exchange rate fluctuations between the U.S. dollar and the British pound sterling.

Currently, 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.

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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 September 30, 2017 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 control over financial reporting that occurred during the quarter ended September 30, 2017 that has materially affected, or is reasonably likely to materially affect, the Company’s internal control 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 11 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, 2016.

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, 2016 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, South America, 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, including those attributable to the Brexit;


•	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


•	changes to, and differing interpretations of, tax laws with respect to our operations and 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 Jeffrey J. Bird.

32.1	—	Section 1350 Certification of Blake T. DeBerry.

32.2	—	Section 1350 Certification of Jeffrey J. Bird.

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: October 27, 2017	BY:	/s/ Jeffrey J. Bird
		Jeffrey J. Bird,
		Vice President and Chief Financial Officer
		(Principal Accounting Officer and
		Duly Authorized Signatory)

Innovex International - 10-Q quarterly report FY2017 Q3

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