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UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
 
FORM 10-Q 
(Mark One)
[X]
QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
For the quarterly period ended September 30, 2017
OR
[   ]
TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
For the transition period from _____ to _____
 
Commission file number: 001-16337
 
OIL STATES INTERNATIONAL, INC.
______________
(Exact name of registrant as specified in its charter)
Delaware
76-0476605
(State or other jurisdiction of
(I.R.S. Employer
incorporation or organization)
Identification No.)
 
 
Three Allen Center, 333 Clay Street, Suite 4620,
77002
Houston, Texas
(Zip Code)
(Address of principal executive offices)
 
(713) 652-0582
(Registrant’s telephone number, including area code)
 
Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.
YES [X]
NO [   ]
Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files).
YES [X]
NO [   ]
Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, 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. (Check one):
Large accelerated filer
[X]
 
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 Rule 12b-2 of the Exchange Act).
YES [   ]
NO [X]
 
As of October 23, 2017, the number of shares of common stock outstanding was 51,089,350.


OIL STATES INTERNATIONAL, INC. AND SUBSIDIARIES
 
INDEX
 
Page No.
Part I -- FINANCIAL INFORMATION
 
 
 
 
 
 
 
Item 1. Financial Statements:
 
 
 
 
 
 
 
Condensed Consolidated Financial Statements
 
 
 
Unaudited Consolidated Statements of Operations
 
 
Unaudited Consolidated Statements of Comprehensive Loss
 
 
Consolidated Balance Sheets
 
 
Unaudited Consolidated Statement of Stockholders’ Equity
 
 
Unaudited Consolidated Statements of Cash Flows
 
 
Notes to Unaudited Condensed Consolidated Financial Statements
–
 
 
 
 
Cautionary Statement Regarding Forward-Looking Statements
–
 
 
 
 
Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations
–
 
 
 
 
Item 3. Quantitative and Qualitative Disclosures About Market Risk
 
 
 
 
 
 
Item 4. Controls and Procedures
 
 
 
 
 
 
Part II -- OTHER INFORMATION
 
 
 
 
 
 
 
Item 1. Legal Proceedings
 
 
 
 
 
 
Item 1A. Risk Factors
 
 
 
 
 
 
Item 2. Unregistered Sales of Equity Securities and Use of Proceeds
 
 
 
 
 
 
Item 3. Defaults Upon Senior Securities
 
 
 
 
 
 
Item 4. Mine Safety Disclosures
 
 
 
 
 
 
Item 5. Other Information
 
 
 
 
 
 
Item 6. Exhibits
 
 
 
 
 
 
Signature Page
 
 


2

PART I – FINANCIAL INFORMATION
 
ITEM 1. Financial Statements
 
OIL STATES INTERNATIONAL, INC. AND SUBSIDIARIES
 
UNAUDITED CONSOLIDATED STATEMENTS OF OPERATIONS
(In Thousands, Except Per Share Amounts)
 
 
Three Months Ended September 30,
 
Nine Months Ended September 30,
 
2017
 
2016
 
2017
 
2016
Revenues:
 
 
 
 
 
 
 
Products
$
67,339

 
$
109,312

 
$
223,269

 
$
323,566

Service
96,709

 
69,694

 
263,648

 
200,944

 
164,048

 
179,006

 
486,917

 
524,510

 
 
 
 
 
 
 
 
Costs and expenses:
 
 
 
 
 
 
 
Product costs
50,593

 
75,345

 
160,252

 
227,855

Service costs
78,596

 
60,421

 
219,697

 
173,125

Selling, general and administrative expense
26,843

 
30,388

 
84,055

 
90,854

Depreciation and amortization expense
26,788

 
29,848

 
82,552

 
89,666

Other operating (income) expense, net
(589
)
 
(1,370
)
 
374

 
(4,098
)
 
182,231

 
194,632

 
546,930

 
577,402

Operating loss
(18,183
)
 
(15,626
)
 
(60,013
)
 
(52,892
)
 
 
 
 
 
 
 
 
Interest expense
(1,147
)
 
(1,364
)
 
(3,370
)
 
(4,124
)
Interest income
73

 
119

 
243

 
321

Other income
207

 
32

 
477

 
462

Loss from continuing operations before income taxes
(19,050
)
 
(16,839
)
 
(62,663
)
 
(56,233
)
Income tax benefit
4,019

 
6,021

 
15,708

 
20,474

Net loss from continuing operations
(15,031
)
 
(10,818
)
 
(46,955
)
 
(35,759
)
Net loss from discontinued operations, net of tax
—

 
—

 
—

 
(4
)
Net loss attributable to Oil States
$
(15,031
)
 
$
(10,818
)
 
$
(46,955
)
 
$
(35,763
)
 
 
 
 
 
 
 
 
Basic net loss per share attributable to Oil States from:
 
 
 
 
 
 
 
Continuing operations
$
(0.30
)
 
$
(0.22
)
 
$
(0.94
)
 
$
(0.71
)
Discontinued operations
—

 
—

 
—

 
—

Net loss
$
(0.30
)
 
$
(0.22
)
 
$
(0.94
)
 
$
(0.71
)
 
 
 
 
 
 
 
 
Diluted net loss per share attributable to Oil States from:
 
 
 
 
 
 
 
Continuing operations
$
(0.30
)
 
$
(0.22
)
 
$
(0.94
)
 
$
(0.71
)
Discontinued operations
—

 
—

 
—

 
—

Net loss
$
(0.30
)
 
$
(0.22
)
 
$
(0.94
)
 
$
(0.71
)
 
 
 
 
 
 
 
 
Weighted average number of common shares outstanding:
 
 
 
 
 
 
 
Basic
49,978

 
50,222

 
50,190

 
50,158

Diluted
49,978

 
50,222

 
50,190

 
50,158

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

3

OIL STATES INTERNATIONAL, INC. AND SUBSIDIARIES
 
UNAUDITED CONSOLIDATED STATEMENTS OF COMPREHENSIVE LOSS
(In Thousands)
 
 
Three Months Ended September 30,
 
Nine Months Ended September 30,
 
2017
 
2016
 
2017
 
2016
Net loss
$
(15,031
)
 
$
(10,818
)
 
$
(46,955
)
 
$
(35,763
)
 
 
 
 
 
 
 
 
Other comprehensive income (loss):
 
 
 
 
 
 
 
Currency translation adjustments
4,857

 
(5,217
)
 
13,490

 
(12,534
)
Comprehensive loss attributable to Oil States
$
(10,174
)
 
$
(16,035
)
 
$
(33,465
)
 
$
(48,297
)
 
The accompanying notes are an integral part of these financial statements.


4

OIL STATES INTERNATIONAL, INC. AND SUBSIDIARIES
 
CONSOLIDATED BALANCE SHEETS
(In Thousands, Except Share Amounts)
 
 
September 30, 2017
 
December 31, 2016
 
(Unaudited)
 
 
ASSETS 
 
 
 
 
 
 
 
Current assets:
 
 
 
Cash and cash equivalents
$
65,864

 
$
68,800

Accounts receivable, net
210,218

 
234,513

Inventories, net
173,447

 
175,490

Prepaid expenses and other current assets
26,464

 
11,174

Total current assets
475,993

 
489,977

 
 
 
 
Property, plant, and equipment, net
508,743

 
553,402

Goodwill, net
268,917

 
263,369

Other intangible assets, net
50,105

 
52,746

Other noncurrent assets
25,597

 
24,404

Total assets
$
1,329,355

 
$
1,383,898

 
 
 
 
LIABILITIES AND STOCKHOLDERS’ EQUITY
 
 
 
 
 
 
 
Current liabilities:
 
 
 
Current portion of long-term debt and capitalized leases
$
492

 
$
538

Accounts payable
44,768

 
34,207

Accrued liabilities
47,632

 
45,333

Income taxes payable
1,031

 
5,839

Deferred revenue
22,588

 
21,315

Total current liabilities
116,511

 
107,232

 
 
 
 
Long-term debt and capitalized leases
19,061

 
45,388

Deferred income taxes
4,592

 
5,036

Other noncurrent liabilities
22,914

 
21,935

Total liabilities
163,078

 
179,591

 
 
 
 
Stockholders’ equity:
 
 
 
Common stock, $.01 par value, 200,000,000 shares authorized, 62,721,256 shares and 62,295,870 shares issued, respectively
627

 
623

Additional paid-in capital
748,581

 
731,562

Retained earnings
1,086,518

 
1,133,473

Accumulated other comprehensive loss
(56,810
)
 
(70,300
)
Treasury stock, at cost, 11,631,810 and 10,921,509 shares, respectively
(612,639
)
 
(591,051
)
Total stockholders’ equity
1,166,277

 
1,204,307

Total liabilities and stockholders’ equity
$
1,329,355

 
$
1,383,898

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


5

OIL STATES INTERNATIONAL, INC. AND SUBSIDIARIES
 
UNAUDITED CONSOLIDATED STATEMENT OF STOCKHOLDERS' EQUITY
(In Thousands)
 
 
Common
Stock
 
Additional
Paid-In
Capital
 
Retained
Earnings
 
Accumulated
Other
Comprehensive
Loss
 
Treasury
Stock
 
Total
Stockholders'
Equity
Balance, December 31, 2016
$
623

 
$
731,562

 
$
1,133,473

 
$
(70,300
)
 
$
(591,051
)
 
$
1,204,307

Net loss
—

 
—

 
(46,955
)
 
—

 
—

 
(46,955
)
Currency translation adjustments (excluding intercompany advances)
—

 
—

 
—

 
12,346

 
—

 
12,346

Currency translation adjustments on intercompany advances
—

 
—

 
—

 
1,144

 
—

 
1,144

Stock-based compensation expense-
 
 
 
 
 
 
 
 
 
 
 
Restricted stock
4

 
16,043

 
—

 
—

 
—

 
16,047

Stock options
—

 
976

 
—

 
—

 
—

 
976

Stock repurchases
—

 
—

 
—

 
—

 
(16,283
)
 
(16,283
)
Surrender of stock to pay taxes on restricted stock awards
—

 
—

 
—

 
—

 
(5,305
)
 
(5,305
)
Balance, September 30, 2017
$
627

 
$
748,581

 
$
1,086,518

 
$
(56,810
)
 
$
(612,639
)
 
$
1,166,277

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


6

OIL STATES INTERNATIONAL, INC. AND SUBSIDIARIES
 
UNAUDITED CONSOLIDATED STATEMENTS OF CASH FLOWS
(In Thousands)
 
 
Nine Months Ended September 30,
 
2017
 
2016
Cash flows from operating activities:
 
 
 
Net loss
$
(46,955
)
 
$
(35,763
)
Adjustments to reconcile net loss to net cash provided by operating activities:
 
 
 
Loss from discontinued operations
—

 
4

Depreciation and amortization
82,552

 
89,666

Stock-based compensation expense
17,023

 
15,938

Deferred income tax benefit
(2,224
)
 
(28,264
)
Provision for bad debt
257

 
759

Gain on disposals of assets
(526
)
 
(445
)
Amortization of deferred financing costs
608

 
585

Other, net
62

 
689

Changes in operating assets and liabilities, net of effect from acquired businesses:
 
 
 
Accounts receivable
26,909

 
68,193

Inventories
5,912

 
15,600

Accounts payable and accrued liabilities
11,811

 
(18,588
)
Income taxes payable
(4,789
)
 
(2,987
)
Other operating assets and liabilities, net
(14,323
)
 
2,392

Net cash flows provided by continuing operating activities
76,317

 
107,779

Net cash flows used in discontinued operating activities
—

 
3

Net cash flows provided by operating activities
76,317

 
107,782

 
 
 
 
Cash flows from investing activities:
 
 
 
Capital expenditures
(20,331
)
 
(23,893
)
Acquisitions of businesses
(12,859
)
 
—

Proceeds from disposition of property, plant and equipment
1,125

 
1,026

Other, net
(631
)
 
(1,534
)
Net cash flows used in investing activities
(32,696
)
 
(24,401
)
 
 
 
 
Cash flows from financing activities:
 
 
 
Revolving credit facility borrowings (repayments), net
(26,578
)
 
(59,731
)
Debt and capital lease repayments
(403
)
 
(398
)
Purchase of treasury stock
(16,283
)
 
—

Issuance of common stock from stock-based payment arrangements
—

 
367

Shares added to treasury stock as a result of net share settlements due to vesting of restricted stock
(5,305
)
 
(3,950
)
Net cash flows used in financing activities
(48,569
)
 
(63,712
)
 
 
 
 
Effect of exchange rate changes on cash and cash equivalents
2,012

 
(1,852
)
Net change in cash and cash equivalents
(2,936
)
 
17,817

Cash and cash equivalents, beginning of period
68,800

 
35,973

 
 
 
 
Cash and cash equivalents, end of period
$
65,864

 
$
53,790

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

7
OIL STATES INTERNATIONAL, INC. AND SUBSIDIARIES
 
NOTES TO UNAUDITED CONDENSED CONSOLIDATED
FINANCIAL STATEMENTS

 
1.
Organization and Basis of Presentation
 
The accompanying unaudited condensed consolidated financial statements of Oil States International, Inc. and its subsidiaries (referred to in this report as “we” or the “Company”) have been prepared pursuant to the rules and regulations of the Securities and Exchange Commission (the “Commission”) pertaining to interim financial information. Certain information in footnote disclosures normally included in financial statements prepared in accordance with U.S. generally accepted accounting principles (“GAAP”) have been condensed or omitted pursuant to these rules and regulations. The unaudited financial statements included in this report reflect all the adjustments, consisting of normal recurring adjustments, which the Company considers necessary for a fair presentation of the results of operations for the interim periods covered and for the financial condition of the Company at the date of the interim balance sheet. Results for the interim periods are not necessarily indicative of results for the full year.
 
The preparation of condensed consolidated financial statements in conformity with GAAP requires the use of estimates and assumptions by management in determining the reported amounts of assets and liabilities and disclosures of contingent assets and liabilities at the date of the condensed consolidated financial statements and the reported amounts of revenues and expenses during the reporting period. If the underlying estimates and assumptions, upon which the financial statements are based, change in future periods, actual amounts may differ from those included in the accompanying condensed consolidated financial statements. Our industry is cyclical and this cyclicality impacts our estimates of the period over which future cash flows will be generated, as well as the predictability of these cash flows including our determination of whether a decline in value of our deferred tax assets, long-lived assets and/or goodwill has occurred.
 
During the first quarter of 2017, we modified the name of our “Offshore Products” segment to the “Offshore/Manufactured Products” segment given the higher proportional weighting of our shorter-cycle manufactured products (much of which is driven by land-based activity) to the total revenues generated by the segment. The Company has also provided supplemental disclosure in Note 12, “Segments and Related Information,” with respect to product and service revenues generated by the Offshore/Manufactured Products segment, including project-driven products, short-cycle products, and other products and services. There have been no operational, reporting or other material changes related to the Offshore/Manufactured Products segment.
 
The financial statements included in this report should be read in conjunction with the Company’s audited financial statements and accompanying notes included in its Annual Report on Form 10-K for the year ended December 31, 2016 (the “2016 Form 10‑K”).
 
2.
Recent Accounting Pronouncements
 
From time to time, new accounting pronouncements are issued by the Financial Accounting Standards Board (the “FASB”), which are adopted by the Company as of the specified effective date. Unless otherwise discussed, management believes that the impact of recently issued standards, which are not yet effective, will not have a material impact on the Company’s consolidated financial statements upon adoption.
 
In May 2014, the FASB issued guidance on revenue from contracts with customers that will supersede most current revenue recognition guidance, including industry-specific guidance. The underlying principle is that an entity will recognize revenue to depict the transfer of goods or services to customers at an amount that the entity expects to be entitled to receive in exchange for those goods or services. The guidance permits the use of either a full retrospective or modified retrospective transition method. The Company will adopt this guidance on January 1, 2018, using the modified retrospective transition method applied to those contracts which are not completed as of that date. Upon adoption, we will recognize any cumulative effect of adopting this guidance as an adjustment to our opening balance of retained earnings. Prior periods will not be retrospectively adjusted. We have reviewed existing contracts with customers and will continue to review new contracts with certain customers (primarily those related to project-driven products) within our Offshore/Manufactured Products segment to determine the impact, if any, of the standard on such contracts and on our consolidated financial statements through the date of adoption. In accordance with the guidance, we expect to expand our revenue recognition disclosures in 2018 to address the new qualitative and quantitative requirements.
 

8
OIL STATES INTERNATIONAL, INC. AND SUBSIDIARIES
 
NOTES TO UNAUDITED CONDENSED CONSOLIDATED
FINANCIAL STATEMENTS
(Continued)


In February 2016, the FASB issued guidance on leases which introduces the recognition of lease assets and lease liabilities by lessees for all leases which are not short-term in nature. The new standard requires a modified retrospective transition for capital or operating leases existing at or entered into after the beginning of the earliest comparative period presented in the financial statements. The Company will adopt this guidance on January 1, 2019. Upon initial evaluation, we believe the key change upon adoption will be the balance sheet recognition of our operating leases when we are the lessee. The income statement recognition appears similar to our current methodology. The Company’s future obligations under operating leases as of December 31, 2016 are summarized in Note 14, “Commitments and Contingencies,” in our 2016 Form 10‑K.
 
In March 2016, the FASB issued guidance on employee share-based payment accounting which modifies existing guidance related to the accounting for forfeitures, employer tax withholding on stock-based compensation and the financial statement presentation of excess tax benefits or deficiencies. The Company adopted this guidance on January 1, 2017. Adoption of this standard had no retrospective impact on the Company’s financial statements and the impact on the Company’s income tax benefit during the first nine months of 2017 was not material.
 
In January 2017, the FASB issued guidance which simplifies the test of goodwill impairment. Under the revised standard, the Company will no longer be required to determine the implied fair value of goodwill by assigning the fair value of a reporting unit to its individual assets and liabilities as if that reporting unit had been acquired in a business combination. The revised guidance requires a prospective transition and permits early adoption for interim and annual goodwill impairment tests performed after January 1, 2017. The Company adopted this standard effective January 1, 2017.
 
In January 2017, the FASB issued guidance clarifying the definition of a business to assist entities with evaluating when a group of transferred assets and activities is a business in connection with a business combination. The revised standard provides that if substantially all of the fair value of the gross assets acquired is concentrated in a single identifiable asset or a set of similar identifiable assets, the group of transferred assets and activities is not a business. The Company adopted this standard effective January 1, 2017.
 
3.
Details of Selected Balance Sheet Accounts

Additional information regarding selected balance sheet accounts at September 30, 2017 and December 31, 2016 is presented below (in thousands):
 
 
September 30,
2017
 
December 31,
2016
Accounts receivable, net:
 
 
 
Trade
$
148,981

 
$
173,087

Unbilled revenue
63,585

 
64,564

Other
5,304

 
5,372

Total accounts receivable
217,870

 
243,023

Allowance for doubtful accounts
(7,652
)
 
(8,510
)
 
$
210,218

 
$
234,513

 
 
September 30,
2017
 
December 31,
2016
Inventories, net:
 
 
 
Finished goods and purchased products
$
86,553

 
$
87,241

Work in process
33,865

 
30,584

Raw materials
68,713

 
72,514

Total inventories
189,131

 
190,339

Allowance for excess or obsolete inventory
(15,684
)
 
(14,849
)
 
$
173,447

 
$
175,490

 

9
OIL STATES INTERNATIONAL, INC. AND SUBSIDIARIES
 
NOTES TO UNAUDITED CONDENSED CONSOLIDATED
FINANCIAL STATEMENTS
(Continued)


 
September 30,
2017
 
December 31,
2016
Prepaid expenses and other current assets:
 
 
 
Income taxes receivable (see Note 11)
$
17,695

 
$
430

Prepayments to vendors
2,826

 
877

Prepaid non-income taxes
1,857

 
1,650

Prepaid insurance
267

 
3,738

Other
3,819

 
4,479

 
$
26,464

 
$
11,174

 
 
Estimated
Useful Life (years)
 
September 30,
2017
 
December 31,
2016
Property, plant and equipment, net:
 
 
 
 
 
 
 
 
 
Land
 
 
 
 
 
 
$
36,310

 
$
31,683

Buildings and leasehold improvements
3
 
–
 
40
 
231,824

 
227,642

Machinery and equipment
2
 
–
 
28
 
466,609

 
455,873

Completion services equipment
2
 
–
 
10
 
426,726

 
429,845

Office furniture and equipment
3
 
–
 
10
 
44,401

 
42,827

Vehicles
2
 
–
 
10
 
119,336

 
121,317

Construction in progress
 
 
 
 
 
 
34,011

 
27,519

Total property, plant and equipment
 
 
 
 
 
 
1,359,217

 
1,336,706

Accumulated depreciation
 
 
 
 
 
 
(850,474
)
 
(783,304
)
 
 
 
 
 
 
 
$
508,743

 
$
553,402

 
 
September 30,
2017
 
December 31,
2016
Other noncurrent assets:
 
 
 
Deferred compensation plan
$
19,875

 
$
18,772

Deferred income taxes
418

 
120

Other
5,304

 
5,512

 
$
25,597

 
$
24,404

 
 
September 30,
2017
 
December 31,
2016
Accrued liabilities:
 
 
 
Accrued compensation
$
22,540

 
$
23,131

Insurance liabilities
7,734

 
8,099

Accrued taxes, other than income taxes
7,099

 
2,461

Accrued leasehold restoration liability
831

 
766

Accrued product warranty reserves
743

 
1,113

Accrued commissions
1,514

 
1,305

Accrued claims
1,288

 
1,578

Other
5,883

 
6,880

 
$
47,632

 
$
45,333

 

10
OIL STATES INTERNATIONAL, INC. AND SUBSIDIARIES
 
NOTES TO UNAUDITED CONDENSED CONSOLIDATED
FINANCIAL STATEMENTS
(Continued)


4.
Accumulated Other Comprehensive Loss
 
Accumulated other comprehensive loss, reported as a component of stockholders’ equity, decreased from $70.3 million at December 31, 2016 to $56.8 million at September 30, 2017, due to changes in currency exchange rates. Accumulated other comprehensive loss is primarily related to fluctuations in the currency exchange rates compared to the U.S. dollar which are used to translate certain of the international operations of our reportable segments. For the nine months ended September 30, 2017 and 2016, currency translation adjustments recognized as a component of other comprehensive income (loss) were primarily attributable to the United Kingdom and Brazil. As of September 30, 2017, the exchange rates for the British pound and the Brazilian real compared to the U.S. dollar strengthened by 8% and 3%, respectively, compared to the exchange rates at December 31, 2016, contributing to other comprehensive income of $13.5 million reported for the nine months ended September 30, 2017. During the first nine months of 2016, the exchange rates for the British pound weakened by 12% compared to the U.S. dollar, while the Brazilian real strengthened by 22% compared to the U.S. dollar during the same period, contributing to other comprehensive loss of $12.5 million.
 
5.
Net Loss Per Share
 
The table below provides a reconciliation of the numerators and denominators of basic and diluted net loss per share for the three and nine months ended September 30, 2017 and 2016 (in thousands, except per share amounts):
 
 
Three Months Ended September 30,
 
Nine Months Ended September 30,
 
2017
 
2016
 
2017
 
2016
Numerators:
 
 
 
 
 
 
 
Net loss from continuing operations
$
(15,031
)
 
$
(10,818
)
 
$
(46,955
)
 
$
(35,759
)
Less: Income attributable to unvested restricted stock awards
—

 
—

 
—

 
—

Numerator for basic net loss per share from continuing operations
(15,031
)
 
(10,818
)
 
(46,955
)
 
(35,759
)
Net loss from discontinued operations, net of tax
—

 
—

 
—

 
(4
)
Numerator for basic net loss per share attributable to Oil States
(15,031
)
 
(10,818
)
 
(46,955
)
 
(35,763
)
Effect of dilutive securities:
 
 
 
 
 
 
 
Unvested restricted stock awards
—

 
—

 
—

 
—

Numerator for diluted net loss per share attributable to Oil States
$
(15,031
)
 
$
(10,818
)
 
$
(46,955
)
 
$
(35,763
)
 
 
 
 
 
 
 
 
Denominators:
 
 
 
 
 
 
 
Weighted average number of common shares outstanding
51,089

 
51,354

 
51,310

 
51,287

Less: Weighted average number of unvested restricted stock awards outstanding
(1,111
)
 
(1,132
)
 
(1,120
)
 
(1,129
)
Denominator for basic net loss per share attributable to Oil States
49,978

 
50,222

 
50,190

 
50,158

Effect of dilutive securities:
 
 
 
 
 
 
 
Unvested restricted stock awards
—

 
—

 
—

 
—

Assumed exercise of stock options
—

 
—

 
—

 
—

 
—

 
—

 
—

 
—

Denominator for diluted net loss per share attributable to Oil States
49,978

 
50,222

 
50,190

 
50,158

 
 
 
 
 
 
 
 
Basic net loss per share attributable to Oil States from:
 
 
 
 
 
 
 
Continuing operations
$
(0.30
)
 
$
(0.22
)
 
$
(0.94
)
 
$
(0.71
)
Discontinued operations
—

 
—

 
—

 
—

Net loss
$
(0.30
)
 
$
(0.22
)
 
$
(0.94
)
 
$
(0.71
)
 
 
 
 
 
 
 
 
Diluted net loss per share attributable to Oil States from:
 
 
 
 
 
 
 
Continuing operations
$
(0.30
)
 
$
(0.22
)
 
$
(0.94
)
 
$
(0.71
)
Discontinued operations
—

 
—

 
—

 
—

Net loss
$
(0.30
)
 
$
(0.22
)
 
$
(0.94
)
 
$
(0.71
)
 

11
OIL STATES INTERNATIONAL, INC. AND SUBSIDIARIES
 
NOTES TO UNAUDITED CONDENSED CONSOLIDATED
FINANCIAL STATEMENTS
(Continued)


The calculation of diluted net loss per share for the three and nine months ended September 30, 2017 excluded 701 thousand shares and 712 thousand shares, respectively, issuable pursuant to outstanding stock options and restricted stock awards, due to their antidilutive effect. The calculation of diluted net loss per share for the three and nine months ended September 30, 2016 excluded 745 thousand shares and 755 thousand shares, respectively, issuable pursuant to outstanding stock options and restricted stock awards, due to their antidilutive effect.
 
6.
Business Acquisitions and Goodwill
 
In January 2017, our Offshore/Manufactured Products segment acquired the intellectual property and assets of complementary product lines to our global crane manufacturing and service operations. The acquisition included adding active heave compensation technology and knuckle-boom crane designs to our existing portfolio.
 
In April 2017, our Offshore/Manufactured Products segment acquired assets and intellectual property that are complementary to our riser testing, inspection and repair service offerings. This complimentary technology allows the segment to provide automated inspection techniques either on board an offshore vessel or on the quayside, without the requirements to transport to a facility to remove the buoyancy materials.
 
Using cash on hand, consideration paid in connection with these transactions totaled $12.9 million, which was allocated to the net assets acquired, including intangibles and goodwill. While no material adjustments are anticipated, the Company’s allocations of purchase price are preliminary and subject to change primarily based on the final determination of the fair values of intangible assets acquired.
 
Changes in the carrying amount of goodwill for the nine month period ended September 30, 2017 were as follows (in thousands):
 
 
Well Site Services
 
 
 
 
 
Completion
Services
 
Drilling
Services
 
Subtotal
 
Offshore /
Manufactured
Products
 
Total
Balance as of December 31, 2016
 
 
 
 
 
 
 
 
 
Goodwill
$
199,278

 
$
22,767

 
$
222,045

 
$
158,619

 
$
380,664

Accumulated impairment losses
(94,528
)
 
(22,767
)
 
(117,295
)
 
—

 
(117,295
)
 
104,750

 
—

 
104,750

 
158,619

 
263,369

Goodwill acquired
—

 
—

 
—

 
4,698

 
4,698

Foreign currency translation
353

 
—

 
353

 
497

 
850

Balance as of September 30, 2017
$
105,103

 
$
—

 
$
105,103

 
$
163,814

 
$
268,917

 
 
 
 
 
 
 
 
 
 
Balance as of September 30, 2017
 
 
 
 
 
 
 
 
 
Goodwill
$
199,631

 
$
22,767

 
$
222,398

 
$
163,814

 
$
386,212

Accumulated impairment losses
(94,528
)
 
(22,767
)
 
(117,295
)
 
—

 
(117,295
)
 
$
105,103

 
$
—

 
$
105,103

 
$
163,814

 
$
268,917

 

12
OIL STATES INTERNATIONAL, INC. AND SUBSIDIARIES
 
NOTES TO UNAUDITED CONDENSED CONSOLIDATED
FINANCIAL STATEMENTS
(Continued)


7.
Long-term Debt
 
As of September 30, 2017 and December 31, 2016, long-term debt consisted of the following (in thousands):
 
September 30,
2017
 
December 31,
2016
Revolving credit facility(1)
$
14,260

 
$
40,230

Capital lease obligations and other debt
5,293

 
5,696

Total debt
19,553

 
45,926

Less: Current portion
(492
)
 
(538
)
Total long-term debt and capitalized leases
$
19,061

 
$
45,388

 
(1)
Amounts presented are net of $1.4 million and $2.0 million, respectively, of unamortized debt issuance costs.

Revolving Credit Facility
 
The Company has a $600 million senior secured revolving credit facility (the “Revolving Credit Facility”) with an option to increase the maximum borrowings to $750 million subject to additional lender commitments prior to its maturity on May 28, 2019. As of September 30, 2017, we had $15.6 million outstanding under the Credit Agreement (as defined below) and an additional $21.6 million of outstanding letters of credit, leaving $146.5 million available to be drawn under the Revolving Credit Facility. As of September 30, 2017, amounts available to be drawn under the Revolving Credit Facility plus cash and cash equivalents totaled $212.4 million. The total amount available to be drawn was less than the lender commitments as of September 30, 2017, due to the maximum leverage ratio covenant in the Credit Agreement which serves to limit borrowings. We expect our availability to continue to be limited by the maximum leverage ratio covenant during the remainder of 2017 and into 2018 based upon our forecast of our trailing twelve-month EBITDA (as defined in the Credit Agreement and further discussed below).
 
The Revolving Credit Facility is governed by a Credit Agreement dated as of May 28, 2014, as amended, (the “Credit Agreement”) by and among the Company, the Lenders party thereto, Wells Fargo Bank, N.A., as administrative agent, the Swing Line Lender and an Issuing Bank, and Royal Bank of Canada, as Syndication agent, and Compass Bank, as Documentation agent. Amounts outstanding under the Revolving Credit Facility bear interest at LIBOR plus a margin of 1.50% to 2.50%, or at a base rate plus a margin of 0.50% to 1.50%, in each case based on a ratio of the Company’s total leverage to EBITDA. During the first nine months of 2017, our applicable margin over LIBOR was 1.50%. We must also pay a quarterly commitment fee, based on our leverage ratio, on the unused commitments under the Credit Agreement. The unused commitment fee was 0.375% during the first nine months of 2017. The Credit Agreement contains customary financial covenants and restrictions. Specifically, we must maintain an interest coverage ratio, defined as the ratio of consolidated EBITDA to consolidated interest expense, of at least 3.0 to 1.0 and a maximum leverage ratio, defined as the ratio of total debt to consolidated EBITDA, of no greater than 3.25 to 1.0. Each of the factors considered in the calculations of these ratios are defined in the Credit Agreement. EBITDA and consolidated interest, as defined, exclude goodwill impairments, losses on extinguishment of debt, debt discount amortization, and other non-cash charges. As of September 30, 2017, we were in compliance with our debt covenants.
 
Borrowings under the Credit Agreement are secured by a pledge of substantially all of our assets and the assets of our domestic subsidiaries. Our obligations under the Credit Agreement are guaranteed by our significant domestic subsidiaries. The Revolving Credit Facility also contains negative covenants that limit the Company's ability to borrow additional funds, encumber assets, pay dividends, sell assets and enter into other significant transactions.
 
Under the Credit Agreement, the occurrence of specified change of control events involving our Company would constitute an event of default that would permit the banks to, among other things, accelerate the maturity of the facility and cause it to become immediately due and payable in full.
 
8.
Fair Value Measurements
 
The Company’s financial instruments consist of cash and cash equivalents, investments, receivables, payables, bank debt and foreign currency forward contracts. The Company believes that the carrying values of these instruments on the accompanying consolidated balance sheets approximate their fair values.
 

13
OIL STATES INTERNATIONAL, INC. AND SUBSIDIARIES
 
NOTES TO UNAUDITED CONDENSED CONSOLIDATED
FINANCIAL STATEMENTS
(Continued)


9.
Changes in Common Stock Outstanding
 
Shares of common stock outstanding – December 31, 2016
51,374,361

Restricted stock awards, net of forfeitures
425,386

Shares withheld for taxes on vesting of restricted stock awards and transferred to treasury
(148,536
)
Purchase of treasury stock
(561,765
)
Shares of common stock outstanding – September 30, 2017
51,089,446

 
On July 29, 2015, the Company’s Board of Directors approved a new share repurchase program providing for the repurchase of up to $150.0 million of the Company’s common stock, which, following extension, was scheduled to expire on July 29, 2017. On July 26, 2017, our Board of Directors extended the share repurchase program for one year to July 29, 2018. During the first nine months of 2017, the Company repurchased 562 thousand shares of common stock under the program at a total cost of $16.3 million. The amount remaining under our share repurchase authorization as of September 30, 2017 was $120.5 million. Subject to applicable securities laws, such purchases will be at such times and in such amounts as the Company deems appropriate.
 
10.
Stock-based Compensation
 
The following table presents a summary of activity for stock options, service-based restricted stock awards and performance-based stock unit awards for the nine months ended September 30, 2017.
 
 
Stock Options
 
Service-based
Restricted Stock
 
Performance-based
Stock Units
Outstanding at December 31, 2016
715,095

 
1,140,489

 
157,925

Granted
—

 
475,432

 
74,758

Restricted stock awards vested
—

 
(466,304
)
 
—

Forfeited
(21,818
)
 
(50,046
)
 
—

Outstanding at September 30, 2017
693,277

 
1,099,571

 
232,683

Weighted average grant date fair value (2017 awards)
$
—

 
$
39.50

 
$
62.66

 
The restricted stock program consists of a combination of service-based restricted stock and performance-based stock units. The service-based restricted stock awards generally vest on a straight-line basis over their term, which is generally three to four years. The number of performance-based restricted shares ultimately issued under the program is dependent upon our achievement of a predefined specific performance measures generally measured over a three-year period. In the event the predefined targets are exceeded for any performance-based award, additional shares up to a maximum of 200% of the target award may be granted. Conversely, if actual performance falls below the predefined target, the number of shares vested is reduced. If the actual performance falls below the threshold performance level, no restricted shares will vest. The performance measure for the 2017 and 2016 awards is relative total stockholder return compared to our peer group of companies while the performance measure specified for the 2015 awards was average after-tax return on invested capital. Currently, it is unlikely that the 2015 performance measure threshold will be met which would result in a performance award forfeiture of approximately 80 thousand units in the fourth quarter of 2017.
 
Stock-based compensation pre-tax expense recognized in the three-month periods ended September 30, 2017 and 2016 totaled $6.1 million and $5.4 million, respectively. Stock-based compensation pre-tax expense recognized in the nine month periods ended September 30, 2017 and 2016 totaled $17.1 million and $15.9 million, respectively. As of September 30, 2017, there was $33.7 million of pre-tax compensation costs related to service-based and performance-based stock awards and unvested stock options, which will be recognized in future periods as vesting conditions are satisfied.
 

14
OIL STATES INTERNATIONAL, INC. AND SUBSIDIARIES
 
NOTES TO UNAUDITED CONDENSED CONSOLIDATED
FINANCIAL STATEMENTS
(Continued)


11.
Income Taxes
 
The income tax provision for interim periods is based on estimates of the effective tax rate for the entire fiscal year. The Company’s income tax provision for the three and nine months ended September 30, 2017 was an income tax benefit of $4.0 million, or 21.1% of pre-tax losses, and $15.7 million, or 25.1% of pre-tax losses, respectively. This compares to an income tax benefit of $6.0 million, or 35.8% of pre-tax losses, and $20.5 million, or 36.4% of pre-tax losses, respectively, for the three and nine months ended September 30, 2016. The lower effective tax rate benefit in the first nine months of 2017 was primarily attributable to a shift in the mix between domestic pre-tax losses and foreign pre-tax income compared to the prior-year period, additional valuation allowances provided against net operating losses in certain domestic and foreign jurisdictions, and incremental tax expense related to our decision to carryback certain U.S. net operating losses discussed below.
 
During the third quarter of 2017, the Company decided to carryback 2016 and 2017 U.S. net operating losses to prior years. The Company plans to file carryback claims against prior year U.S. federal income tax returns and has recorded related income taxes receivable totaling $16.6 million. Such amounts have been classified within prepaid expenses and other current assets as of September 30, 2017. The effect of the carryback will result in the loss of certain previously claimed tax deductions. As a result, the Company recorded a discrete tax charge of $1.0 million in the third quarter of 2017, thereby reducing the effective tax rate benefit.
 
The Company records a valuation allowance in each reporting period when management believes that it is more likely than not that any deferred tax asset will not be realized. This assessment requires analysis of available positive and negative evidence, including losses incurred in recent years, reversals of temporary differences, forecasts of future income, assessment of future business assumptions and tax planning strategies. During 2016 and the first nine months of 2017, we recorded valuation allowances with respect to net operating loss carryforwards of certain of our domestic and foreign operations. Future increases in our valuation allowances are possible if our estimates and assumptions (particularly as they relate to our forecasts) are revised such that they reduce estimates of future taxable income during the carryforward period.
 
12.
Segments and Related Information
 
The Company operates through two reportable segments: Well Site Services and Offshore/Manufactured Products. The Company’s reportable segments represent strategic business units that offer different products and services. They are managed separately because each business requires different technologies and marketing strategies. Acquisitions have been direct extensions to our business segments. Separate business lines within the Well Site Services segment have been disclosed to provide additional information for that segment.
 
Our Well Site Services segment provides a broad range of equipment and services that are used to drill for, establish and maintain the flow of oil and natural gas from a well throughout its life cycle. In this segment, our operations primarily include completion-focused equipment and services as well as land drilling services. Our Completion Services operations provide solutions to our customers using our completion tools and highly-trained personnel throughout our service offerings which include: wireline support, frac stacks, isolations tools, extended reach tools, ball launchers, well testing operations, thru tubing activity and sand control. Drilling Services provides land drilling services for shallow to medium depth wells in West Texas and the Rocky Mountain region of the United States.
 
Our Offshore/Manufactured Products segment designs, manufactures and markets capital equipment utilized on floating production systems, subsea pipeline infrastructure, and offshore drilling rigs and vessels, along with short-cycle and other products. Driven principally by longer-term customer investments for offshore oil and natural gas projects, “project-driven product” revenues include: flexible bearings, advanced connector systems, high-pressure riser systems, deepwater mooring systems, cranes, subsea pipeline products and blow-out preventer stack integration. “Short-cycle products” manufactured by the segment include: valves, elastomers and other specialty products generally used in the land-based drilling and completion markets. “Other products,” manufactured and offered by the segment, include a variety of products for use in industrial, military and other applications outside the oil and gas industry. The segment also offers a broad line of complementary, value-added services including: specialty welding, fabrication, cladding and machining services, offshore installation services, and inspection and repair services.
 
Financial information by business segment for the three and nine months ended September 30, 2017 and 2016 is summarized as follows (in thousands).
 

15
OIL STATES INTERNATIONAL, INC. AND SUBSIDIARIES
 
NOTES TO UNAUDITED CONDENSED CONSOLIDATED
FINANCIAL STATEMENTS
(Continued)


 
Revenues
 
Depreciation and
amortization
 
Operating (loss) income
 
Equity in
losses of
unconsolidated
affiliates
 
Capital
expenditures
 
Total assets
Three months ended September 30, 2017
 
 
 
 
 
 
 
 
 
 
 
Well Site Services –
 
 
 
 
 
 
 
 
 
 
 
Completion Services
$
61,015

 
$
15,679

 
$
(9,933
)
 
$
—

 
$
2,447

 
$
427,207

Drilling Services
16,162

 
4,454

 
(3,235
)
 
—

 
1,693

 
74,991

Total Well Site Services
77,177

 
20,133

 
(13,168
)
 
—

 
4,140

 
502,198

Offshore/Manufactured Products
86,871

 
6,404

 
7,334

 
(33
)
 
2,846

 
782,651

Corporate
—

 
251

 
(12,349
)
 
—

 
54

 
44,506

Total
$
164,048

 
$
26,788

 
$
(18,183
)
 
$
(33
)
 
$
7,040

 
$
1,329,355

 
 
Revenues
 
Depreciation and
amortization
 
Operating (loss) income
 
Equity in
losses of
unconsolidated
affiliates
 
Capital
expenditures
 
Total assets
Three months ended September 30, 2016
 
 
 
 
 
 
 
 
 
 
 
Well Site Services –
 
 
 
 
 
 
 
 
 
 
 
Completion Services
$
38,975

 
$
17,230

 
$
(20,450
)
 
$
—

 
$
2,365

 
$
475,139

Drilling Services
7,375

 
5,629

 
(5,641
)
 
—

 
249

 
82,683

Total Well Site Services
46,350

 
22,859

 
(26,091
)
 
—

 
2,614

 
557,822

Offshore/Manufactured Products
132,656

 
6,712

 
22,867

 
(77
)
 
2,502

 
851,819

Corporate
—

 
277

 
(12,402
)
 
—

 
379

 
25,486

Total
$
179,006

 
$
29,848

 
$
(15,626
)
 
$
(77
)
 
$
5,495

 
$
1,435,127

 
 
Revenues
 
Depreciation and
amortization
 
Operating (loss) income
 
Equity in
losses of
unconsolidated
affiliates
 
Capital
expenditures
 
Total assets
Nine months ended September 30, 2017
 
 
 
 
 
 
 
 
 
 
 
Well Site Services –
 
 
 
 
 
 
 
 
 
 
 
Completion Services
$
167,577

 
$
48,400

 
$
(38,960
)
 
$
—

 
$
8,560

 
$
427,207

Drilling Services
39,120

 
14,283

 
(11,239
)
 
—

 
2,800

 
74,991

Total Well Site Services
206,697

 
62,683

 
(50,199
)
 
—

 
11,360

 
502,198

Offshore/Manufactured Products
280,220

 
19,091

 
27,460

 
(62
)
 
8,775

 
782,651

Corporate
—

 
778

 
(37,274
)
 
—

 
196

 
44,506

Total
$
486,917

 
$
82,552

 
$
(60,013
)
 
$
(62
)
 
$
20,331

 
$
1,329,355

 
 
Revenues
 
Depreciation and
amortization
 
Operating (loss) income
 
Equity in
losses of
unconsolidated
affiliates
 
Capital
expenditures
 
Total assets
Nine months ended September 30, 2016
 
 
 
 
 
 
 
 
 
 
 
Well Site Services –
 
 
 
 
 
 
 
 
 
 
 
Completion Services
$
116,748

 
$
52,789

 
$
(66,251
)
 
$
—

 
$
9,032

 
$
475,139

Drilling Services
14,016

 
18,053

 
(19,697
)
 
—

 
748

 
82,683

Total Well Site Services
130,764

 
70,842

 
(85,948
)
 
—

 
9,780

 
557,822

Offshore/Manufactured Products
393,746

 
17,977

 
67,854

 
(196
)
 
13,476

 
851,819

Corporate
—

 
847

 
(34,798
)
 
—

 
637

 
25,486

Total
$
524,510

 
$
89,666

 
$
(52,892
)
 
$
(196
)
 
$
23,893

 
$
1,435,127

 

16
OIL STATES INTERNATIONAL, INC. AND SUBSIDIARIES
 
NOTES TO UNAUDITED CONDENSED CONSOLIDATED
FINANCIAL STATEMENTS
(Continued)


The Company has one customer whose revenue individually represented 16% and 15% of the Company’s consolidated product and service revenue for the three and nine months ended September 30, 2017, respectively, and whose receivables individually represented 12% of the Company’s consolidated total accounts receivable as of September 30, 2017.
 
The following table provides supplemental revenue information for the Offshore/Manufactured Products segment for the three and nine months ended September 30, 2017 and 2016 (in thousands):
 
 
Three Months Ended September 30,
 
Nine Months Ended September 30,
 
2017
 
2016
 
2017
 
2016
Project-driven products
$
22,698

 
$
76,541

 
$
89,615

 
$
234,440

Short-cycle products
37,781

 
23,766

 
110,872

 
63,033

Other products and services
26,392

 
32,349

 
79,733

 
96,273

 
$
86,871

 
$
132,656

 
$
280,220

 
$
393,746

 
13.
Commitments and Contingencies
 
In the ordinary course of conducting our business, we become involved in litigation and other claims from private party actions, as well as judicial and administrative proceedings involving governmental authorities at the federal, state and local levels. Over recent years, a number of lawsuits were filed in Federal Court, against the Company and or one of its subsidiaries, by current and former employees alleging violations of the Fair Labor Standards Act (“FLSA”). The plaintiffs seek damages and penalties for the Company’s alleged failure to: properly classify its field service employees as “non-exempt” under the FLSA; and pay them on an hourly basis (including overtime). The plaintiffs are seeking recovery on their own behalf as well as on behalf of a class of similarly situated employees. Settlement of the class action against the Company was approved, and a judgment was entered November 19, 2015. The Company has settled the vast majority of these claims and is evaluating potential settlements for the remaining individual plaintiffs’ claims which are not expected to be significant.
 
We are a party to various pending or threatened claims, lawsuits and administrative proceedings seeking damages or other remedies concerning our commercial operations, products, employees and other matters, including occasional claims by individuals alleging exposure to hazardous materials as a result of our products or operations. Some of these claims relate to matters occurring prior to our acquisition of businesses, and some relate to businesses we have sold. In certain cases, we are entitled to indemnification from the sellers of businesses and, in other cases, we have indemnified the buyers of businesses from us. Although we can give no assurance about the outcome of pending legal and administrative proceedings and the effect such outcomes may have on us, we believe that any ultimate liability resulting from the outcome of such proceedings, to the extent not otherwise provided for or covered by indemnity or insurance, will not have a material adverse effect on our consolidated financial position, results of operations or liquidity.


17

Cautionary Statement Regarding Forward-Looking Statements
 
This Quarterly Report on Form 10-Q and other statements we make contain certain “forward-looking statements” within the meaning of Section 27A of the Securities Act of 1933 (the “Securities Act”) and Section 21E of the Securities Exchange Act of 1934 (the “Exchange Act”). Actual results could differ materially from those projected in the forward-looking statements as a result of a number of important factors. For a discussion of known material factors that could affect our results, please refer to “Part I, Item 1. Business,” “Part I, Item 1A. Risk Factors,” “Part II, Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations” and “Part II, Item 7A. Quantitative and Qualitative Disclosures about Market Risk” included in our 2016 Form 10-K filed with the Securities and Exchange Commission on February 17, 2017 as well as “Part II, Item 1A, Rick Factors” included in this Quarterly Report on Form 10-Q.
 
You can typically identify “forward-looking statements” by the use of forward-looking words such as “may,” “will,” “could,” “project,” “believe,” “anticipate,” “expect,” “estimate,” “potential,” “plan,” “forecast,” “proposed,” “should,” “seek,” and other similar words. Such statements may relate to our future financial position, budgets, capital expenditures, projected costs, plans and objectives of management for future operations and possible future strategic transactions. Where any such forward-looking statement includes a statement of the assumptions or bases underlying such forward-looking statement, we caution that assumed facts or bases almost always vary from actual results. The differences between assumed facts or bases and actual results can be material, depending upon the circumstances.
 
In any forward-looking statement where we express an expectation or belief as to future results, such expectation or belief is expressed in good faith and believed to have a reasonable basis. However, there can be no assurance that the statement of expectation or belief will result or be achieved or accomplished. The following are important factors that could cause actual results to differ materially from those expressed in any forward-looking statement made by, or on behalf of, our Company:
 
•
the level of supply of and demand for oil and natural gas;
•
fluctuations in the current and future prices of oil and natural gas;
•
the cyclical nature of the oil and gas industry;
•
the level of exploration, drilling and completion activity;
•
the financial health of our customers;
•
the availability of attractive oil and natural gas field prospects, which may be affected by governmental actions or actions of other parties which may restrict drilling;
•
the level of offshore oil and natural gas developmental activities;
•
general global economic conditions;
•
the ability of the Organization of Petroleum Exporting Countries to set and maintain production levels and pricing;
•
global weather conditions and natural disasters;
•
changes in tax laws and regulations;
•
impact of environmental matters, including future environmental regulations;
•
our ability to find and retain skilled personnel;
•
negative outcome of litigation, threatened litigation or government proceeding;
•
fluctuations in currency exchange rates;
•
the availability and cost of capital; and
•
the other factors identified in “Part I, Item 1A. Risk Factors” in our 2016 Form 10-K.
 

18

Should one or more of these risks or uncertainties materialize, or should the assumptions on which our forward-looking statements are based prove incorrect, actual results may differ materially from those expected, estimated or projected. In addition, the factors identified above may not necessarily be all of the important factors that could cause actual results to differ materially from those expressed in any forward-looking statement made by us, or on our behalf. Readers are cautioned not to place undue reliance on forward-looking statements, which speak only as of the date hereof. We undertake no responsibility to publicly release the result of any revision of our forward-looking statements after the date they are made.
 
In addition, in certain places in this Quarterly Report on Form 10-Q, we refer to reports published by third parties that purport to describe trends or developments in the energy industry. The Company does so for the convenience of our stockholders and in an effort to provide information available in the market that will assist the Company’s investors to have a better understanding of the market environment in which the Company operates. However, the Company specifically disclaims any responsibility for the accuracy and completeness of such information and undertakes no obligation to update such information.
 
ITEM 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations
 
The following discussion and analysis should be read together with our condensed consolidated financial statements and the notes to those statements included elsewhere in this Quarterly Report on Form 10-Q and our consolidated financial statements and notes to those statements included in our 2016 Form 10-K.
 
During the first quarter of 2017, we modified the name of our “Offshore Products” segment to the “Offshore/Manufactured Products” segment given the higher proportional weighting of our shorter-cycle manufactured products (much of which is driven by land-based activity) to the total revenues generated by the segment. The Company has also provided supplemental disclosure below, and in Note 12, “Segments and Related Information,” with respect to product and service revenues generated by the Offshore/Manufactured Products segment, including project-driven products, short-cycle products, and other products and services. There have been no operational, reporting or other material changes related to the Offshore/Manufactured Products segment.
 
Macroeconomic Environment
 
We provide a broad range of products and services to the oil and gas industry through our Offshore/Manufactured Products and Well Site Services business segments. Demand for our products and services is cyclical and substantially dependent upon activity levels in the oil and gas industry, particularly our customers’ willingness to invest capital in the exploration for and development of crude oil and natural gas reserves. Our customers’ capital spending programs are generally based on their cash flows and their outlook for near-term and long-term commodity prices, economic growth, commodity demand and estimates of resource production. As a result, demand for our products and services is largely sensitive to future expectations with respect to crude oil and natural gas prices.
 
Our consolidated results of operations reflect current industry trends and customer spending activities which are focused on growth in the U.S. shale play regions with weaker U.S. Gulf of Mexico and international activity. In addition, investments in deepwater markets globally have slowed since the start of the recent industry downturn in 2014.
 
A severe industry downturn started in the second half of 2014 and continued into 2017, driven by global economic uncertainties and high levels of global oil production. As shown in the table that follows, significant downward crude oil price volatility began in late 2014 with Intercontinental Exchange Brent (“Brent”) crude oil declining from an average of $102 per barrel in the third quarter of 2014 to an average of $34 per barrel in the first quarter of 2016 (a level last seen in 2004). The sustained material decrease in crude oil prices relative to 2014 is primarily attributable to high levels of global crude oil inventories resulting from significant production growth in the U.S. shale plays, the strengthening of the U.S. dollar relative to other currencies, and increased production by the Organization of Petroleum Exporting Countries (“OPEC”). OPEC demonstrated, throughout 2015 and through November of 2016 an unwillingness to modify production levels, as it had done in previous years, in an effort to protect its market share. These production increases were partially offset by growth in global crude oil demand. The combination of these factors caused a global supply and demand imbalance for crude oil which, along with concerns regarding the potential effects on energy demand stemming from the diminished growth outlook in China and other emerging markets, and supply increases related to the lifting of sanctions against Iran, resulted in materially lower crude oil prices. Non-OPEC production, particularly in the United States, began to decline in 2015 due to substantially reduced investment in drilling and completion activity triggered by lower crude oil prices leading to some recovery in crude oil prices in late 2016 and early 2017 relative to the crude oil price lows experienced in early 2016. On November 30, 2016, OPEC agreed to production cuts which should, over time, if the cuts are adhered to, result in further reductions in global crude oil inventories and a more favorable commodity price environment. In May 2017, OPEC agreed to extend these production cuts to March 2018. Brent crude oil prices averaged $52 per barrel in the third quarter of 2017, which is 14% above the third quarter 2016 average of $46 per barrel and up 5% from the average in the second quarter of 2017. Similarly, the average price

19

of West Texas Intermediate (“WTI”) was $48 per barrel in the third quarter of 2017, up 7% from the third quarter 2016 average of $45 per barrel but unchanged on a sequential quarter basis. The year-over-year improvement in oil prices was driven by the belief that OPEC and Russia, its key ally in the effort to stabilize the global crude oil market, would be successful in cutting their production. However, improvements in crude oil prices rapidly translated into increased drilling activity in U.S. shale play developments in areas such as the Permian Basin, which is leading to higher domestic production. This increased shale driven activity has pressured crude oil prices again with the average WTI price per barrel over the second and third quarters of 2017 declining 7% from the first quarter 2017 average. Further, WTI crude oil is currently trading at an approximate $6 per barrel discount to Brent crude oil, as shown below. Spending in these regions, which began to improve in the second half of 2016 in response to higher crude oil prices, has positively influenced the overall drilling and completion activity in these regions and, therefore, the activity of our Well Site Services segment as well as for short-cycle products within our Offshore/Manufactured Products segment in 2017. Expectations with respect to the longer-term price for Brent crude oil will continue to influence our customers’ spending related to global offshore drilling and development and, thus, a significant portion of the activity of our Offshore/Manufactured Products segment.
 
Given the historical volatility of crude oil prices, there remains a degree of risk that prices could remain at their current levels or deteriorate further due to relatively high levels of global inventories, increasing domestic crude oil production, slowing growth rates in various global regions, use of alternatives, a more sustained movement to electric vehicles and/or the potential for ongoing supply/demand imbalances. Conversely, if the global supply of crude oil were to decrease due to a prolonged reduction in capital investment by our customers or if government instability in a major oil-producing nation develops, and energy demand were to continue to increase in the United States, India and China, a sustained recovery in WTI and Brent crude oil prices could occur. In any event, crude oil price improvements will depend upon a rebalancing of global supply and demand, with a corresponding reduction in global inventories, the timing of which is difficult to predict. If commodity prices do not improve, or decline further, demand for our products and services could continue to be weak or could decline further.
 
Natural gas prices improved slightly over the past year from an average of $2.88 per mmBtu in the third quarter of 2016 to an average of $2.95 per mmBtu during the third quarter of 2017. Customer spending in the natural gas shale plays has been limited due to associated natural gas being produced from unconventional oil wells in North America. If natural gas production growth surpasses demand growth in the United States, and/or if the supply of natural gas were to increase, whether from conventional or unconventional production or associated natural gas production from oil wells, prices for natural gas could remain depressed for an extended period of time and could result in fewer rigs drilling for natural gas.
 
Recent WTI crude oil, Brent crude and natural gas pricing trends are as follows:
 
 
Average Price(1) for quarter ended
Year
 
March 31
 
June 30
 
September 30
 
December 31
WTI Crude (per bbl)
 
 
 
 
 
 
2017
 
$
51.62

 
$
48.14

 
$
48.18

 
 
2016
 
$
33.35

 
$
45.46

 
$
44.85

 
$
49.14

2015
 
$
48.49

 
$
57.85

 
$
46.49

 
$
41.94

2014
 
$
98.68

 
$
103.35

 
$
97.87

 
$
73.21

Brent Crude (per bbl)
 
 
 
 
 
 
2017
 
$
53.59

 
$
49.59

 
$
52.10

 
 
2016
 
$
33.84

 
$
45.57

 
$
45.80

 
$
49.11

2015
 
$
53.98

 
$
61.65

 
$
50.44

 
$
43.56

2014
 
$
108.14

 
$
109.69

 
$
101.90

 
$
76.43

Henry Hub Natural Gas (per mmBtu)
 
 
 
 
2017
 
$
3.02

 
$
3.08

 
$
2.95

 
 
2016
 
$
1.99

 
$
2.15

 
$
2.88

 
$
3.04

2015
 
$
2.90

 
$
2.75

 
$
2.76

 
$
2.12

2014
 
$
5.18

 
$
4.61

 
$
3.96

 
$
3.78

 
(1)
Source: U.S. Energy Information Administration (“EIA”). As of October 23, 2017, WTI crude oil, Brent crude oil and natural gas traded at approximately $51.91 per barrel, $57.69 per barrel and $2.95 per mmBtu, respectively.
 

20

Overview
 
Demand for the products and services of our Offshore/Manufactured Products segment is driven by the longer-term outlook for commodity prices and changes in drilling and completion activity, both offshore and onshore. Demand for the equipment and services of our Well Site Services segment responds to shorter-term movements in crude oil and natural gas prices and, specifically, changes in North American drilling and completion activity given the spot contract nature of our operations coupled with shorter cycles between drilling a well and bringing it on production. Other factors that can affect our business and financial results include, but are not limited to, the general global economic environment, competitive pricing pressures and regulatory changes in the United States and international markets.
 
Our Offshore/Manufactured Products segment provides technology-driven, highly-engineered products and services for offshore oil and natural gas production systems and facilities, as well as certain products and services to the offshore and land-based drilling and completion markets. Approximately 60% of Offshore/Manufactured Products sales in 2016 were driven by our customers’ capital spending for offshore production systems and subsea pipeline infrastructure, repairs and, to a lesser extent, upgrades of existing offshore drilling rigs and construction of new offshore drilling rigs and vessels (referred to herein as “project-driven product revenue”). As a result, this segment has historically been particularly influenced by global deepwater drilling and production spending, which are driven largely by our customers’ longer-term outlook for crude oil and natural gas prices. Deepwater oil and gas development projects typically involve significant capital investments and multi-year development plans. As a result, such projects are generally undertaken by larger exploration, field development and production companies (primarily international oil companies (“IOCs”) and state-run national oil companies (“NOCs”)) using relatively conservative crude oil and natural gas pricing assumptions. We believe some of these deepwater projects once approved for development are, therefore, less susceptible to short-term fluctuations in the price of crude oil and natural gas given longer lead times associated with field development. However, the decline in crude oil prices that began in 2014 and continued into 2017, coupled with the relatively uncertain outlook around shorter-term and possibly longer-term pricing improvements have caused exploration and production companies to reevaluate their future capital expenditures in regards to these deepwater projects since they are expensive to drill and complete, have long lead times to first production and may be considered uneconomical relative to the risk involved. However, a few development projects have been sanctioned in the first nine months of 2017 due to re-engineering of the projects and lower development costs, which led to an improvement in final investment decisions (“FIDs”) on these projects from the previous two years. Our bookings have declined, leading to substantially reduced backlog in 2017 relative to recent years. As a result, this segment’s project-driven revenue declined 62% from the first nine months of 2016 and accounted for only 32% of the segment’s total revenue in the first nine months of 2017. Shorter-cycle manufactured products sold primarily to the land-based completions market are impacted by near-term fluctuations in commodity prices. For the nine months ended September 30, 2017, sales of these shorter-cycle products (such as valves and elastomer products) for this segment increased 76% over the level reported in the same period last year due to the significant increase in U.S. land-based drilling and completion activity.
 
Our Offshore/Manufactured Products segment revenues and operating income declined at a slower pace during 2015 and 2016 than our Well Site Services segment given the high levels of backlog that existed at the beginning of 2014. Bidding and quoting activity, along with orders from customers, for our Offshore/Manufactured Products segment continued after 2014, albeit at a much slower pace. Reflecting the impact of customer (both IOCs and NOCs) delays and deferrals in approving major, capital intensive projects in light of the prolonged low commodity price environment, backlog in our Offshore/Manufactured Products segment decreased from $599 million at June 30, 2014 to $199 million at December 31, 2016. With a book-to-bill ratio of 1.0x for the first nine months of 2017, our backlog totaled $198 million at September 30, 2017. The following table sets forth backlog for our Offshore/Manufactured Products segment as of the dates indicated (in millions).
 
 
 
Backlog as of
Year
 
March 31
 
June 30
 
September 30
 
December 31
 
Year Average(1)
2017
 
$
204

 
$
202

 
$
198

 
 

 
$
202

2016
 
$
306

 
$
268

 
$
203

 
$
199

 
$
269

2015
 
$
474

 
$
409

 
$
394

 
$
340

 
$
435

2014
 
$
578

 
$
599

 
$
543

 
$
490

 
$
564

 
(1)
Average is computed based on month end backlog amounts for the respective nine-month and twelve-month periods.
 

21

In our Well Site Services segment, we predominantly provide completion services and, to a lesser extent, land drilling services. Our Completion Services business provides equipment and service personnel utilized in the completion and initial production of new and recompleted wells. Activity for the Completion Services business is dependent primarily upon the level and complexity of drilling, completion, and workover activity in the United States, including the Gulf of Mexico, and, to a lesser extent, Canada and the rest of the world. Well complexity has increased with the continuing transition to multi-well pads and the drilling of longer lateral wells along with the increased number of frac stages completed in horizontal wells. Demand for our Drilling Services operations is driven by land drilling activity in our primary drilling markets of the Permian Basin in West Texas, where we primarily drill oil wells, and the U.S. Rocky Mountain area, where we drill both liquids-rich and natural gas wells.
 
Demand for our Completion Services and Drilling Services businesses is correlated to changes in the drilling rig count in North America, as well as changes in the total number of wells drilled, total footage, and the number of drilled wells that are completed. The following table sets forth a summary of the average North American drilling rig count, as measured by Baker Hughes (a GE company), for the periods indicated.
 
 
Three Months Ended September 30,
 
Nine Months Ended September 30,
 
2017
 
2016
 
2017
 
2016
U.S. Land – Oil
742
 
375
 
671
 
370
U.S. Land – Natural gas and other
182
 
87
 
167
 
90
U.S. Offshore
22
 
18
 
23
 
23
Total United States
946
 
480
 
861
 
483
Canada
208
 
121
 
207
 
112
Total North America
1,154
 
601
 
1,068
 
595
 
The average North American rig count for the nine months ended September 30, 2017 increased 473 rigs, or 79%, compared to the nine months ended September 30, 2016, in response to the increase in crude oil prices discussed above.
 
Over recent years, our industry experienced a shift in customer spending from natural gas exploration and development to crude oil and liquids-rich exploration and development in the North American shale plays utilizing horizontal drilling and completion techniques. The U.S. natural gas-related working rig count declined from approximately 810 rigs at the beginning of 2012 to 81 rigs in August of 2016, a more than 29 year low. According to rig count data published by Baker Hughes (a GE company), the U.S. oil rig count peaked in October 2014 at 1,609 rigs but has declined materially since late 2014 due to much lower crude oil prices, totaling 750 rigs as of September 30, 2017 (with the U.S. oil rig count having troughed at 316 rigs in May 2016, which was the lowest oil rig count during this current cyclical downturn). As of September 30, 2017, oil-directed drilling accounted for 80% of the total U.S. rig count – with the balance natural gas related. The total U.S. rig count has increased 536 rigs, or 133%, since troughing in May of 2016, largely due to improved crude oil prices, decreased service costs and improved technologies applied in the shale play regions of the United States.
 
Exacerbating the steep declines in drilling activity experienced in 2015 and 2016, many of our exploration and production customers deferred well completions. These deferred completions are referred to in the industry as drilled but uncompleted wells (or “DUCs”). Given our Well Site Services segment’s exposure to the level of completion activity, an increase in the number of DUCs will have a short-term negative impact on our results of operations relative to the rig count trends but over the longer-term should have a positive impact on the segment’s results as the wells are completed.
 
Reduced demand for our products and services, coupled with a reduction in the prices we charge our customers for our services has adversely affected our results of operations, cash flows and financial position since the second half of 2014. If the current pricing environment for crude oil and natural gas does not improve, or declines further, our customers may be required to further reduce their capital expenditures, causing additional declines in the demand for, and prices of, our products and services, which would adversely affect our results of operations, cash flows and financial position. Our customers have experienced a significant decline in their revenues and cash flows due to the commodity price declines, with many experiencing a significant reduction in liquidity. Several exploration and production companies declared bankruptcy during 2015 and 2016, or had to exchange equity for the forgiveness of debt, and others were forced to sell assets in an effort to preserve liquidity. However, over the past twelve months, access to capital and debt markets have improved for certain of these customers.
 
We continue to monitor the global economy, the prices of and demand for crude oil and natural gas, and the resultant impact on the capital spending plans and operations of our customers in order to plan and manage our business.
 

22

Consolidated Results of Operations
 
We manage and measure our business performance in two distinct operating segments: Well Site Services and Offshore/Manufactured Products. Selected financial information by business segment for the three and nine months ended September 30, 2017 and 2016 is summarized below (dollars in thousands):
 
Three Months Ended September 30,
 
Nine Months Ended September 30,
 
 
 
 
 
Variance
 
 
 
 
 
Variance
 
2017
 
2016
 
$
 
%
 
2017
 
2016
 
$
 
%
Revenues
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Well Site Services -
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Completion Services
$
61,015

 
$
38,975

 
$
22,040

 
57
 %
 
$
167,577

 
$
116,748

 
$
50,829

 
44
 %
Drilling Services
16,162

 
7,375

 
8,787

 
119
 %
 
39,120

 
14,016

 
25,104

 
179
 %
Total Well Site Services
77,177

 
46,350

 
30,827

 
67
 %
 
206,697

 
130,764

 
75,933

 
58
 %
Offshore/Manufactured Products -
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Project-driven products
22,698

 
76,541

 
(53,843
)
 
(70
)%
 
89,615

 
234,440

 
(144,825
)
 
(62
)%
Short-cycle products
37,781

 
23,766

 
14,015

 
59
 %
 
110,872

 
63,033

 
47,839

 
76
 %
Other products and services
26,392

 
32,349

 
(5,957
)
 
(18
)%
 
79,733

 
96,273

 
(16,540
)
 
(17
)%
Total Offshore/Manufactured Products
86,871

 
132,656

 
(45,785
)
 
(35
)%
 
280,220

 
393,746

 
(113,526
)
 
(29
)%
Total
$
164,048

 
$
179,006

 
$
(14,958
)
 
(8
)%
 
$
486,917

 
$
524,510

 
$
(37,593
)
 
(7
)%
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Product and service costs
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Well Site Services -
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Completion Services
$
51,584

 
$
36,871

 
$
14,713

 
40
 %
 
$
146,833

 
$
111,701

 
$
35,132

 
31
 %
Drilling Services
14,521

 
6,992

 
7,529

 
108
 %
 
34,755

 
14,368

 
20,387

 
142
 %
Total Well Site Services
66,105

 
43,863

 
22,242

 
51
 %
 
181,588

 
126,069

 
55,519

 
44
 %
Offshore/Manufactured Products
63,084

 
91,903

 
(28,819
)
 
(31
)%
 
198,361

 
274,912

 
(76,551
)
 
(28
)%
Total
$
129,189

 
$
135,766

 
$
(6,577
)
 
(5
)%
 
$
379,949

 
$
400,981

 
$
(21,032
)
 
(5
)%
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Gross profit (loss)(1)
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Well Site Services -
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Completion Services
$
9,432

 
$
2,104

 
$
7,328

 
348
 %
 
$
20,744

 
$
5,047

 
$
15,697

 
311
 %
Drilling Services
1,640

 
383

 
1,257

 
328
 %
 
4,365

 
(352
)
 
4,717

 
n.m.

Total Well Site Services
11,072

 
2,487

 
8,585

 
345
 %
 
25,109

 
4,695

 
20,414

 
435
 %
Offshore/Manufactured Products
23,787

 
40,754

 
(16,967
)
 
(42
)%
 
81,859

 
118,835

 
(36,976
)
 
(31
)%
Total
$
34,859

 
$
43,241

 
$
(8,382
)
 
(19
)%
 
$
106,968

 
$
123,530

 
$
(16,562
)
 
(13
)%
Gross profit (loss) as a percentage of revenues(1)
 
 
 
 
 
 
 
 
 
 
 
 
Well Site Services -
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Completion Services
15
%
 
5
%
 
 
 
 
 
12
%
 
4
 %
 
 
 
 
Drilling Services
10
%
 
5
%
 
 
 
 
 
11
%
 
(3
)%
 
 
 
 
Total Well Site Services
14
%
 
5
%
 
 
 
 
 
12
%
 
4
 %
 
 
 
 
Offshore/Manufactured Products
27
%
 
31
%
 
 
 
 
 
29
%
 
30
 %
 
 
 
 
Total
21
%
 
24
%
 
 
 
 
 
22
%
 
24
 %
 
 
 
 
 
(1)
Gross profit (loss) is computed by deducting product and service costs from revenues, and excludes depreciation expense. Gross profit (loss) as a percentage of revenues is also referred to herein as gross margin.
 

23

Three Months Ended September 30, 2017 Compared to Three Months Ended September 30, 2016
 
We reported a net loss for the three months ended September 30, 2017 of $15.0 million, or $0.30 per diluted share, which included $0.4 million ($0.3 million after-tax, or $0.01 per diluted share) of severance and other downsizing charges and $1.0 million ($0.02 per diluted share) of additional tax expense related to the decision to carryback net operating losses incurred in 2016 against taxable income reported in 2014. Excluding these third quarter 2017 charges, the net loss would have been $13.7 million, or $0.27 per diluted share. These results compare to a net loss for the three months ended September 30, 2016 of $10.8 million, or $0.22 per diluted share, which included $2.0 million ($1.3 million after-tax, or $0.03 per diluted share) of severance and other downsizing charges. Excluding these third quarter 2016 charges, the net loss from continuing operations would have been $9.5 million, or $0.19 per diluted share.
 
The Company’s third quarter 2017 consolidated results of operations were adversely affected by Hurricane Harvey which caused widespread damage and logistical challenges in Houston and the surrounding region where we operate five manufacturing facilities and employ about 500 individuals. The Company was impacted by lower revenues and under-absorption of manufacturing facility costs primarily in its Offshore/Manufactured Products segment but also suffered some field-level downtime due to employee dislocations resulting from the storm. One of the Company's Houston facilities experienced significant flooding and is not yet operational but was fully insured. Project work in that facility has been shifted to other manufacturing locations to meet customer delivery requirements.
 
Our consolidated results of operations also reflect current industry trends and customer spending activities which are focused on growth in the U.S. shale play regions with weaker U.S. Gulf of Mexico and international activity. In addition, investments in deepwater markets globally have slowed since the start of the recent industry downturn in 2014.
 
Revenues. Consolidated revenues in the third quarter of 2017 decreased $15.0 million, or 8%, from the third quarter of 2016 due to declines in our Offshore/Manufactured Products segment, which were partially offset by improvements in our Well Site Services segment. In the third quarter of 2017, over 55% of consolidated revenues were driven by U.S. shale play activity.
 
Our Well Site Services segment revenues increased $30.8 million, or 67%, in the third quarter of 2017 from the prior-year quarter due to growth of both Completion Services and Drilling Services revenues. Our Completion Services revenues increased $22.0 million, or 57%, in the third quarter of 2017 compared to the third quarter of 2016, with the impact of a higher commodity price environment and lower overall service costs driving increased U.S. land-based activity, partially offset by the timing of customer activity in certain international markets. The number of Completion Services job tickets in the third quarter of 2017 increased 31% over the prior-year period and revenue per Completion Services job increased 20% year-over-year as a result of increased completions activity and a more favorable job mix. Our Drilling Services revenues increased $8.8 million, or 119%, to $16.2 million in the third quarter of 2017 from the third quarter of 2016 primarily as a result of increased utilization of our land drilling rigs from an average of 15% during the third quarter of 2016 to an average of 34% in the third quarter of 2017 coupled with increased dayrates.
 
Our Offshore/Manufactured Products segment revenues decreased $45.8 million, or 35%, in the third quarter of 2017 compared to the third quarter of 2016 primarily as a result of a decline in demand for deepwater project-driven products (including subsea pipeline infrastructure, offshore production and drilling products), lower levels of service activities and a backlog position that has trended lower since mid-2014. These deepwater project-driven revenue declines were partially offset by increases in sales of our short-cycle products, which increased 59% year-over-year. Shorter-cycle products, such as elastomers and valves, have benefited from increased land-based drilling and completion activity in the United States. Bidding and quoting activity, along with orders from customers, for our Offshore/Manufactured Products segment continued, albeit at a much slower pace. Reflecting the impact of customer delays and deferrals in approving major, capital intensive projects in light of the prolonged low commodity price environment, backlog in our Offshore/Manufactured Products segment decreased from $340 million at December 31, 2015 to $199 million at December 31, 2016. With a book to bill ratio of 1.0x in the first nine months of 2017, our backlog remained relatively flat at $198 million as of September 30, 2017.
 
Cost of Sales and Services. Our consolidated cost of sales and services decreased $6.6 million, or 5%, in the third quarter of 2017 compared to the third quarter of 2016 as a result of decreased cost of sales and services at our Offshore/Manufactured Products segment of $28.8 million, or 31%, which was partially offset by a $22.2 million, or 51%, increase in cost of services at our Well Site Services segment. Consolidated gross profit as a percentage of revenues decreased from 24% in the third quarter of 2016 to 21% in the third quarter of 2017, with gross margin expansion within our Well Site Services segment offset by the impact of a significant reduction in sales of project-driven products in our Offshore/Manufactured Products segment.
 

24

Our Well Site Services segment cost of services increased $22.2 million, or 51%, in the third quarter of 2017 compared to the third quarter of 2016 as a result of a $14.7 million, or 40%, increase in Completion Services cost of services and a $7.5 million, or 108%, increase in costs in our Drilling Services business. These increases in cost of services, which are strongly correlated to the revenue increases in these businesses, reflect the increase in land-based activity in the United States. Costs increases included higher personnel costs from increased employee overtime and costs associated with headcount additions made during the current year. Our Well Site Services segment gross profit as a percentage of revenues improved from 5% in the third quarter of 2016 to 14% in the third quarter of 2017. Our Completion Services gross profit as a percentage of revenues increased from 5% in the third quarter of 2016 to 15% in the third quarter of 2017 primarily due to the significant increase in revenue levels. Our Drilling Services gross profit as a percentage of revenues improved from 5% in the third quarter of 2016 to 10% in the third quarter of 2017, primarily due to increased rig utilization and cost absorption.
 
Our Offshore/Manufactured Products segment cost of sales decreased $28.8 million, or 31%, in the third quarter of 2017 compared to the third quarter of 2016 reflecting the decrease in project-driven activity. Gross profit as a percentage of revenues decreased from 31% in the third quarter of 2016 to 27% in the third quarter of 2017 driven primarily by the reported 70% decline in sales of project-driven products.
 
Selling, General and Administrative Expenses. Selling, general and administrative expenses decreased $3.5 million, or 12%, in the third quarter of 2017 from the prior-year quarter reflecting the impact of 2016 cost reduction measures, lower incentive compensation accruals and reduced employee severance-related charges in the third quarter of 2017.
 
Depreciation and Amortization. Depreciation and amortization expense decreased $3.1 million, or 10%, in the third quarter of 2017 compared to the third quarter of 2016 primarily due to certain assets becoming fully depreciated and overall lower levels of capital expenditures.
 
Other Operating (Income) Expense, Net. Other operating income declined from $1.4 million in the third quarter of 2016 to $0.6 million in the third quarter of 2017, primarily due to the impact of lower foreign currency exchange gains recognized in the current-year period.
 
Operating Loss. Our consolidated operating loss increased from $15.6 million in the third quarter of 2016 to $18.2 million in the third quarter of 2017 primarily as a result of a decrease in operating income from our Offshore/Manufactured Products segment of $15.5 million due to a continued decline in offshore-related activity, offset by a decrease in operating loss of $12.9 million from our Well Site Services segment. Corporate expenses were $12.3 million in the third quarter of 2017, flat with the prior-year period.
 
Interest Expense and Interest Income. Net interest expense decreased $0.2 million, or 14%, in the third quarter of 2017 compared to the third quarter of 2016 primarily due to a reduction in amounts outstanding under the Revolving Credit Facility (defined below) partially offset by higher unused commitment fees paid to our lenders. Interest expense as a percentage of total debt outstanding increased from 5.6% in the third quarter of 2016 to 14.0% in the third quarter of 2017 due to an increased proportion of interest expense associated with unused commitment fees, lower average borrowings outstanding under the Revolving Credit Facility and non-cash amortization of debt issuance costs.
 
Income Tax Benefit. The income tax provision for interim periods is based on estimates of the effective tax rate for the entire fiscal year. The Company’s income tax provision for the three months ended September 30, 2017 was an income tax benefit of $4.0 million, or 21% of pre-tax losses, compared to an income tax benefit of $6.0 million, or 36% of pre-tax losses for the three months ended September 30, 2016. The lower effective tax rate benefit in the third quarter of 2017 was primarily attributable to a shift in the mix between domestic pre-tax losses and foreign pre-tax income compared to the prior-year period, additional valuation allowances provided against net operating losses in certain domestic and foreign jurisdictions and incremental tax expense related to the decision to carryback 2016 net operating losses.
 
Other Comprehensive Income (Loss). Other comprehensive income was $4.9 million in the third quarter of 2017 compared to a loss of $5.2 million in the third quarter of 2016 due to fluctuations in foreign currency exchange rates compared to the U.S. dollar for certain of the international operations of our reportable segments. For the three months ended September 30, 2017 and 2016, currency translation adjustments recognized as a component of other comprehensive income (loss) were primarily attributable to the United Kingdom and Brazil. During the third quarter of 2017, the exchange rates for the British pound and the Brazilian real strengthened compared to the U.S. dollar. This compares to the third quarter of 2016, when the exchange rates for the British pound weakened compared to the U.S. dollar, while the Brazilian real strengthened compared to the U.S. dollar. The British pound was impacted by the United Kingdom’s vote to exit the European Union in late June 2016.
 

25

Nine Months Ended September 30, 2017 Compared to Nine Months Ended September 30, 2016
 
We reported a net loss for the nine months ended September 30, 2017 of $47.0 million, or $0.94 per diluted share, which included $2.0 million ($1.5 million after-tax, or $0.03 per diluted share) of severance and other downsizing charges and $1.0 million ($0.02 per diluted share) of additional tax expense related to the decision to carryback net operating losses incurred in 2016 against taxable income reported in 2014. Excluding these charges in the first nine months of 2017, the net loss would have been $44.5 million, or $0.89 per diluted share. These results compare to a net loss of $35.8 million, or $0.71 per diluted share for the nine months ended September 30, 2016, which included $4.6 million ($3.0 million after-tax, or $0.06 per diluted share) of severance and other downsizing charges. Excluding these charges in the first nine months of 2016, the net loss would have been $32.8 million, or $0.65 per diluted share.
 
During the third quarter of 2017, the Company’s consolidated results of operations were adversely affected by Hurricane Harvey which caused widespread damage and logistical challenges in Houston and the surrounding region where we operate five manufacturing facilities and employ about 500 individuals. The Company was impacted by lower revenues and under-absorption of manufacturing facility costs primarily in its Offshore/Manufactured Products segment but also suffered some field-level downtime due to employee dislocations resulting from the storm. One of the Company's Houston facilities experienced significant flooding and is not yet operational but was fully insured. Project work in that facility has been shifted to other manufacturing locations to meet customer delivery requirements.
 
Our consolidated results of operations also reflect current industry trends and customer spending activities which are focused on growth in the U.S. shale play regions with weaker U.S. Gulf of Mexico and international activity. In addition, investments in deepwater markets globally have slowed since the start of the recent industry downturn in 2014.
 
Revenues. Consolidated revenues in the first nine months of 2017 decreased $37.6 million, or 7%, from the first nine months of 2016 due to declines in our Offshore/Manufactured Products segment, partially offset by improvements in our Well Site Services segment. In the first nine months of 2017, over 50% of consolidated revenues were driven by U.S. shale play activity.
 
Our Well Site Services segment revenues increased $75.9 million, or 58%, in the first nine months of 2017 compared to the prior-year period due to growth of both Completion Services and Drilling Services revenues. Our Completion Services revenues increased $50.8 million, or 44%, in the first nine months of 2017 compared to the first nine months of 2016, with the impact of a higher commodity price environment and lower service costs driving increased U.S. land-based activity, partially offset by the timing of customer activity in certain international markets. The number of Completion Services job tickets in the first nine months of 2017 increased 23% over the prior-year period and revenue per Completion Services job increased 17% year-over-year as a result of increased completions activity, a more favorable job mix and improved pricing. Our Drilling Services revenues increased $25.1 million, or 179%, to $39.1 million in the first nine months of 2017 from the first nine months of 2016 due to higher utilization of our land drilling rigs, which increased from an average of 10% during the first nine months of 2016 to an average of 28% in the first nine months of 2017.
 
Our Offshore/Manufactured Products segment revenues decreased $113.5 million, or 29%, in the first nine months of 2017 compared to the first nine months of 2016 primarily as a result of a decline in demand for deepwater project-driven products (primarily subsea pipeline infrastructure, offshore production and drilling products), lower levels of service activities and a backlog position that has trended lower since mid-2014. These deepwater project-driven revenue declines were partially offset by a 76% increase in sales of our short-cycle products. Shorter-cycle products, such as elastomers and valves, have benefited from increased land-based drilling and completion activity in the United States. Bidding and quoting activity, along with orders from customers, for our Offshore/Manufactured Products segment continued, albeit at a much slower pace. Reflecting the impact of customer delays and deferrals in approving major, capital intensive projects in light of the prolonged low commodity price environment, backlog in our Offshore/Manufactured Products segment decreased from $340 million at December 31, 2015 to $199 million at December 31, 2016. With a book-to-bill ratio of 1.0x in the first nine months of 2017, our backlog remained relatively flat at $198 million as of September 30, 2017.
 
Cost of Sales and Services. Our consolidated cost of sales and services decreased $21.0 million, or 5%, in the first nine months of 2017 compared to the first nine months of 2016 as a result of decreased cost of sales and services at our Offshore/Manufactured Products segment of $76.6 million, or 28%, which was partially offset by a $55.5 million, or 44%, increase in cost of services at our Well Site Services segment. Consolidated gross profit as a percentage of revenues decreased from 24% in the first nine months of 2016 to 22% in the first nine months of 2017 with gross margin expansion within our Well Site Services segment offset by the impact of a significant reduction in sales of project-driven products in our Offshore/Manufactured Products segment.
 

26

Our Well Site Services segment cost of services increased $55.5 million, or 44%, in the first nine months of 2017 compared to the first nine months of 2016 as a result of a $35.1 million, or 31%, increase in Completion Services cost of services and a $20.4 million, or 142%, increase in service costs in our Drilling Services business. These increases in cost of services, which are strongly correlated to the revenue increases in these businesses, reflect the increase in land-based activity in the United States. Costs increases included higher personnel costs from increased employee overtime and costs associated with headcount additions made during the nine months of 2017. Our Well Site Services segment gross profit as a percentage of revenues increased from 4% in the first nine months of 2016 to 12% in the first nine months of 2017. Our Completion Services gross profit as a percentage of revenues increased from 4% in the first nine months of 2016 to 12% in the first nine months of 2017 primarily due to the increase in revenues. Our Drilling Services gross profit as a percentage of revenues improved from (3)% in the first nine months of 2016 to 11% in the first nine months of 2017 primarily due to increased rig utilization and cost absorption.
 
Our Offshore/Manufactured Products segment cost of sales decreased $76.6 million, or 28%, in the first nine months of 2017 compared to the first nine months of 2016 reflecting the decrease in project-driven revenues. Gross profit as a percentage of revenues decreased from 30% in the first nine months of 2016 to 29% in the first nine months of 2017, due primarily to the reported 62% decline in sales of project-driven products, which was partially offset by a 76% increase in sales of short-cycle products.
 
Selling, General and Administrative Expenses. Selling, general and administrative expenses decreased $6.8 million, or 7%, in the first nine months of 2017 from the prior-year period primarily due to the impact of 2016 cost reduction initiatives and lower employee severance-related charges in the first nine months of 2017, partially offset by higher incentive compensation accruals.

Depreciation and Amortization. Depreciation and amortization expense decreased $7.1 million, or 8%, in the first nine months of 2017 compared to the first nine months of 2016 primarily due to certain assets becoming fully depreciated coupled with overall lower levels of capital expenditures.
 
Other Operating (Income) Expense, Net. Other operating (income) expense, net moved from other operating income of $4.1 million in the first nine months of 2016 to other operating expense of $0.4 million in the first nine months of 2017, reflecting primarily the impact of foreign currency exchange gains or losses recognized in the respective periods.
 
Operating Loss. Our consolidated operating loss increased from $52.9 million in the first nine months of 2016 to $60.0 million in the first nine months of 2017 primarily as a result of a decrease in operating income from our Offshore/Manufactured Products segment of $40.4 million due to a continued decline in offshore-related activity, partially offset by a decreased operating loss of $35.7 million from our Well Site Services segment. Corporate expenses were $37.3 million in the first nine months of 2017, an increase of $2.5 million from the prior-year period due primarily to higher incentive compensation accruals and increased stock-based compensation expense.
 
Interest Expense and Interest Income. Net interest expense decreased $0.7 million, or 18%, in the first nine months of 2017 compared to the first nine months of 2016 primarily due to a reduction in amounts outstanding under the Revolving Credit Facility partially offset by higher unused commitment fees paid to our lenders. Interest expense as a percentage of total debt outstanding increased from 5.6% in the first nine months of 2016 to 14.5% in the first nine months of 2017 due to an increased proportion of interest expense associated with unused commitment fees, lower average borrowings outstanding under the Revolving Credit Facility and non-cash amortization of debt issuance costs.
 
Income Tax Benefit. The income tax provision for interim periods is based on estimates of the effective tax rate for the entire fiscal year. The Company’s income tax provision for the nine months ended September 30, 2017 was an income tax benefit of $15.7 million, or 25% of pre-tax losses, compared to an income tax benefit of $20.5 million, or 36% of pre-tax losses for the nine months ended September 30, 2016. The lower effective tax rate benefit in the first nine months of 2017 was primarily attributable to a shift in the mix between domestic pre-tax losses and foreign pre-tax income compared to the prior-year period, additional valuation allowances provided against net operating losses in certain domestic and foreign jurisdictions, and incremental tax expense related to the decision to carryback 2016 U.S. net operating losses against 2014 taxable income.
 
Other Comprehensive Income (Loss). Other comprehensive income was $13.5 million in the first nine months of 2017 compared to a loss of $12.5 million in the first nine months of 2016 due to fluctuations in foreign currency exchange rates compared to the U.S. dollar for certain of the international operations of our reportable segments. For the nine months ended September 30, 2017 and 2016, currency translation adjustments recognized as a component of other comprehensive income (loss) were primarily attributable to the United Kingdom and Brazil. During the first nine months of 2017, the exchange rates for the British pound and the Brazilian real strengthened compared to the U.S. dollar. This compares to the first nine months of 2016, when exchange rates for the British pound weakened compared to the U.S. dollar, while the Brazilian real strengthened compared to the U.S. dollar. The British pound was impacted by the United Kingdom’s vote to exit the European Union in late June 2016.

27

Liquidity, Capital Resources and Other Matters
 
Our primary liquidity needs are to fund operating and capital expenditures which, in the past, have included expanding and upgrading our Offshore/Manufactured Products manufacturing facilities and equipment, replacing and increasing Completion Services assets, funding new product development, and general working capital needs. In addition, capital has been used to repay debt, fund our share repurchase program, and fund strategic business acquisitions. Our primary sources of funds have been cash flow from operations, proceeds from borrowings under the Revolving Credit Facility, and capital markets transactions.
 
The crude oil and natural gas industry is highly cyclical which may result in declines in the demand for, and prices of, our products and services or the inability or failure of our customers to meet their obligations to us. These adverse market conditions could require us to incur asset impairment charges, deferred tax valuation allowances and/or write down the value of our goodwill, and may otherwise adversely impact our results of operations and our cash flows and financial position.
 
Operating Activities
 
Despite generally weak market conditions, cash flows totaling $76.3 million were provided by continuing operations during the first nine months of 2017 compared to $107.8 million provided by continuing operations during the same period of 2016. During the first nine months of 2017, $25.5 million was provided from net working capital reductions with decreases in accounts receivable and inventories partially offset by the impact of a $17.3 million increase in income taxes receivable. During the first nine months of 2016, $64.6 million was provided from net working capital reductions primarily due to decreases in accounts receivable and inventories.
 
Investing Activities
 
Cash used in investing activities during the first nine months of 2017 was $32.7 million compared to $24.4 million used in investing activities during the first nine months of 2016. Capital expenditures totaled $20.3 million and $23.9 million during the first nine months of 2017 and 2016, respectively. During the first nine months of 2017, we also invested $12.9 million within our Offshore/Manufactured Products segment to acquire complementary intellectual property and assets to expand our global crane manufacturing and service operations as well as our riser testing, inspection and repair service offerings.
 
After considering the $20.3 million invested during the first nine months of 2017, we expect to spend between $30 million and $35 million in total capital expenditures during 2017, which compares to $30 million spent in 2016. Whether planned expenditures will actually be spent in 2017 depends on industry conditions, project approvals and schedules, vendor delivery timing, and careful monitoring of our levels of liquidity. We plan to fund these capital expenditures with available cash, internally generated funds, and borrowings under the Revolving Credit Facility. The foregoing capital expenditure forecast does not include any funds for strategic acquisitions, which the Company could pursue depending on the economic environment in our industry and the availability of transactions at prices deemed to be attractive to the Company.
 
At September 30, 2017, substantially all of our cash was held by our international subsidiaries. Our intent is to utilize at least a portion of these cash balances for future investment outside of the United States. Approximately $37 million of cash held by our international subsidiaries can be repatriated by us without triggering any incremental tax consequences.
 
Financing Activities
 
During the nine months ended September 30, 2017, net cash of $48.6 million was used in financing activities, primarily as a result of repayment of $26.6 million of borrowings under the Revolving Credit Facility and repurchases of our common stock totaling $16.3 million in the second quarter of 2017. This compares to $63.7 million of cash used in financing activities during the nine months ended September 30, 2016, primarily as a result of repaying outstanding debt under the Revolving Credit Facility.
 
We believe that cash on hand, cash flow from operations, and available borrowings under the Revolving Credit Facility will be sufficient to meet our liquidity needs in the coming twelve months. If our plans or assumptions change, or are inaccurate, or if we make further acquisitions, we may need to raise additional capital. Acquisitions have been, and our management believes acquisitions will continue to be, a key element of our business strategy. The timing, size or success of any acquisition effort and the associated potential capital commitments are unpredictable and uncertain. We may seek to fund all or part of any such efforts with proceeds from debt and/or equity issuances. Our ability to obtain capital for additional projects to implement our growth strategy over the longer term will depend upon our future operating performance, financial condition and, more broadly, on the availability of equity and debt financing. Capital availability will be affected by prevailing conditions in our industry, the global economy, the global financial markets and other factors, many of which are beyond our control. In addition, such additional debt service requirements could be based on higher interest rates and shorter maturities and could impose a significant burden on our results of operations and financial condition, and any issuance of additional equity securities could result in significant dilution to stockholders.
 

28

Share Repurchase Program. On July 29, 2015, the Company’s Board of Directors approved a new share repurchase program providing for the repurchase of up to $150.0 million of the Company’s common stock, which, following extension, was scheduled to expire on July 29, 2017. On July 26, 2017, our Board of Directors extended the share repurchase program for one year to July 29, 2018. During the first nine months of 2017, the Company repurchased 562 thousand shares of common stock under the program at a total cost of $16.3 million. The amount remaining under our share repurchase authorization as of September 30, 2017 was $120.5 million. Subject to applicable securities laws, such purchases will be at such times and in such amounts as the Company deems appropriate.
 
Credit Facility. The Company has a $600 million senior secured revolving credit facility (the “Revolving Credit Facility”) with an option to increase the maximum borrowings to $750 million subject to additional lender commitments prior to its maturity on May 28, 2019. As of September 30, 2017, we had $15.6 million in borrowings outstanding under the Credit Agreement (as defined below) and an additional $21.6 million of outstanding letters of credit, leaving $146.5 million available to be drawn under the Revolving Credit Facility. As of September 30, 2017, amounts available to be drawn under the Revolving Credit Facility plus cash and cash equivalents totaled $212.4 million. The total amount available to be drawn was less than the lender commitments as of September 30, 2017, due to the maximum leverage ratio covenant in the Credit Agreement which serves to limit borrowings. We expect our availability to continue to be limited by the maximum leverage ratio covenant during the remainder of 2017 and into 2018 based upon our forecast of our trailing twelve-month EBITDA (as defined in the Credit Agreement and further discussed below).
 
The Revolving Credit Facility is governed by a Credit Agreement dated as of May 28, 2014, as amended, (the “Credit Agreement”) by and among the Company, the Lenders party thereto, Wells Fargo Bank, N.A., as administrative agent, the Swing Line Lender and an Issuing Bank; Royal Bank of Canada, as Syndication agent; and Compass Bank, as Documentation agent. Amounts outstanding under the Revolving Credit Facility bear interest at LIBOR plus a margin of 1.50% to 2.50%, or at a base rate plus a margin of 0.50% to 1.50%, in each case based on a ratio of the Company’s total leverage to EBITDA. During the first nine months of 2017, our applicable margin over LIBOR was 1.50%. We must also pay a quarterly commitment fee, based on our leverage ratio, on the unused commitments under the Credit Agreement. The unused commitment fee was 0.375% during the first nine months of 2017. Interest expense as a percentage of total debt outstanding increased from 5.6% in the first nine months of 2016 to 14.5% in the first nine months of 2017. The increase in the weighted average interest rate was attributable to an increased proportion of interest expense associated with unused commitment fees, lower average borrowings outstanding under the Revolving Credit Facility and non-cash amortization of debt issuance costs.
 
The Credit Agreement contains customary financial covenants and restrictions. Specifically, we must maintain an interest coverage ratio, defined as the ratio of consolidated EBITDA to consolidated interest expense, of at least 3.0 to 1.0 and a maximum leverage ratio, defined as the ratio of total debt to consolidated EBITDA, of no greater than 3.25 to 1.0. Each of the factors considered in the calculations of these ratios are defined in the Credit Agreement. EBITDA and consolidated interest, as defined, exclude goodwill impairments, losses on extinguishment of debt, debt discount amortization, and other non-cash charges. As of September 30, 2017, we were in compliance with our debt covenants and expect to continue to be in compliance during the remainder of 2017. Borrowings under the Credit Agreement are secured by a pledge of substantially all of our assets and the assets of our domestic subsidiaries. Our obligations under the Credit Agreement are guaranteed by our significant domestic subsidiaries.
 
Under the Credit Agreement, the occurrence of specified change of control events involving our Company would constitute an event of default that would permit the banks to, among other things, accelerate the maturity of the facility and cause it to become immediately due and payable in full.
 
Our total debt represented 1.6% of our combined total debt and stockholders’ equity at September 30, 2017 compared to 3.7% at December 31, 2016.
 
Critical Accounting Policies
 
For a discussion of the critical accounting policies and estimates that we use in the preparation of our condensed consolidated financial statements, see “Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations” in our 2016 Form 10-K. These estimates require significant judgments, assumptions and estimates. We have discussed the development, selection, and disclosure of these critical accounting policies and estimates with the audit committee of our Board of Directors. There have been no material changes to the judgments, assumptions, and estimates upon which our critical accounting estimates are based. For a discussion of recent accounting pronouncements, see Note 2, “Recent Accounting Pronouncements.”
 
Off-Balance Sheet Arrangements
 
As of September 30, 2017, we had no off-balance sheet arrangements as defined in Item 303(a)(4)(ii) of Regulation S-K.

29

ITEM 3. Quantitative and Qualitative Disclosures about Market Risk
 
Market risk refers to the potential losses arising from changes in interest rates, foreign currency fluctuations and exchange rates, equity prices, and commodity prices, including the correlation among these factors and their volatility.
 
Our principal market risks are our exposure to changes in interest rates and foreign currency exchange rates. We enter into derivative instruments only to the extent considered necessary to meet risk management objectives and do not use derivative contracts for speculative purposes.
 
Interest Rate Risk
 
We have a revolving credit facility that is subject to the risk of higher interest charges associated with increases in interest rates. As of September 30, 2017, we had floating-rate obligations totaling $15.6 million drawn under the Revolving Credit Facility. These floating-rate obligations expose us to the risk of increased interest expense in the event of increases in short-term interest rates. If the floating interest rates increased by 1% from September 30, 2017 levels, our consolidated interest expense would increase by a total of approximately $0.2 million annually.
 
Foreign Currency Exchange Rate Risk
 
Our operations are conducted in various countries around the world and we receive revenue from these operations in a number of different currencies. As such, our earnings are subject to movements in foreign currency exchange rates when transactions are denominated in (i) currencies other than the U.S. dollar, which is our functional currency, or (ii) the functional currency of our subsidiaries, which is not necessarily the U.S. dollar. In order to mitigate the effects of foreign currency exchange rate risks in areas outside of the United States (primarily in our Offshore/Manufactured Products segment), we generally pay a portion of our expenses in local currencies and a substantial portion of our contracts provide for collections from customers in U.S. dollars. During the nine months ended September 30, 2017, our reported foreign currency exchange losses were $0.6 million and are included in “Other operating (income) expense, net” in the Consolidated Statements of Operations. In order to reduce our exposure to fluctuations in foreign currency exchange rates, we may enter into foreign currency exchange agreements with financial institutions. As of September 30, 2017 and December 31, 2016, we had outstanding foreign currency forward purchase contracts with notional amounts of $2.4 million related to expected cash flows denominated in Euros.
 
Our accumulated other comprehensive loss, reported as a component of stockholders’ equity, decreased from $70.3 million at December 31, 2016 to $56.8 million at September 30, 2017, due to changes in currency exchange rates. Accumulated other comprehensive loss is primarily related to fluctuations in the currency exchange rates compared to the U.S. dollar which are used to translate certain of the international operations of our reportable segments. For the nine months ended September 30, 2017, currency translation adjustments recognized as a component of other comprehensive income were primarily attributable to the United Kingdom and Brazil. As of September 30, 2017, the exchange rates for the British pound and the Brazilian real compared to the U.S. dollar strengthened by 8% and 3%, respectively, compared to the exchange rates at December 31, 2016, contributing to other comprehensive income of $13.5 million reported for the nine months ended September 30, 2017.
 

30

ITEM 4. Controls and Procedures
 
Evaluation of Disclosure Controls and Procedures
 
As of the end of the period covered by this Quarterly Report on Form 10-Q, we carried out an evaluation, under the supervision and with the participation of our management, including our Chief Executive Officer and Chief Financial Officer, of the effectiveness of the design and operation of our disclosure controls and procedures (as defined in Rules 13a-15(e) and 15d-15(e)) of the Exchange Act. Our disclosure controls and procedures are designed to provide reasonable assurance that the information required to be disclosed by us in reports that we file under the Exchange Act is accumulated and communicated to our management, including our Chief Executive Officer and Chief Financial Officer, as appropriate, to allow timely decisions regarding required disclosure and is recorded, processed, summarized and reported within the time periods specified in the rules and forms of the Commission. Based upon that evaluation, our Chief Executive Officer and Chief Financial Officer concluded that our disclosure controls and procedures were effective as of September 30, 2017 at the reasonable assurance level.
 
Changes in Internal Control Over Financial Reporting
 
During the nine months ended September 30, 2017, there were no changes in our internal control over financial reporting (as defined in Rules 13a-15(f) and 15d-15(f) of the Exchange Act), which have materially affected our internal control over financial reporting, or are reasonably likely to materially affect our internal control over financial reporting.


31

PART II -- OTHER INFORMATION
 
ITEM 1. Legal Proceedings
 
The information with respect to this Item 1 is set forth under Note 13, “Commitments and Contingencies.”
 
ITEM 1A. Risk Factors
 
“Part I, Item 1A. Risk Factors” of our 2016 Form 10-K includes a detailed discussion of our risk factors. The risks described in this Quarterly Report on Form 10-Q and our 2016 Form 10-K are not the only risks we face. Additional risks and uncertainties not currently known to us, or that we currently deem to be immaterial, also may materially adversely affect our business, financial condition or future results. There have been no material changes to our risk factors as set forth in our 2016 Form 10-K.
 
ITEM 2. Unregistered Sales of Equity Securities and Use of Proceeds
 
None.
 
Purchases of Equity Securities by the Issuer and Affiliated Purchasers
 
Period
 
Total Number of Shares Purchased(1)
 
Average Price Paid per Share(1)
 
Total Number of Shares Purchased as Part of Publicly Announced Plans or Programs
 
Approximate Dollar Value of Shares That May Yet Be Purchased Under the Plans or Programs(2)
July 1 through July 31, 2017
 
57

 
$
26.55

 
—

 
$
120,544,560

August 1 through August 31, 2017
 
4,354

 
21.52

 
—

 
120,544,560

September 1 through September 30, 2017
 
420

 
24.45

 
—

 
120,544,560

Total
 
4,831

 
$
21.83

 
—

 
 

 
(1)
All of the 4,831 shares purchased during the three-month period ended September 30, 2017 were acquired from employees in connection with the settlement of income tax and related benefit withholding obligations arising from vesting in restricted stock grants. These shares were not part of a publicly announced program to purchase common stock.
(2)
On July 29, 2015, the Company’s Board of Directors approved a new share repurchase program providing for the repurchase of up to $150 million of the Company’s common stock, which, following extension, was scheduled to expire on July 29, 2017. On July 26, 2017, our Board of Directors extended the share repurchase program for one year to July 29, 2018.

ITEM 3. Defaults Upon Senior Securities
 
None.
 
ITEM 4. Mine Safety Disclosures.
 
Not applicable.
 
ITEM 5. Other Information
 
None.
 
ITEM 6. Exhibits
 
The exhibits required to be filed by Item 6. are set forth in the Exhibit Index accompanying this Quarterly Report on Form 10‑Q.
 


32

SIGNATURES
 
Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.
 
OIL STATES INTERNATIONAL, INC.
 
 
 
 
 
 
 
Date:
October 27, 2017
 
By
/s/  LLOYD A. HAJDIK
 
 
 
 
 
Lloyd A. Hajdik
 
 
 
 
 
Executive Vice President, Chief Financial Officer and
 
 
 
 
 
Treasurer (Duly Authorized Officer and Principal Financial Officer)
 

33

Exhibit Index
 
Exhibit No.
 
Description
 
 
 
—
 
 
 
—
 
 
 
—
 
 
 
—
 
 
 
—
 
 
 
—
 
 
 
—
 
 
 
—
 
 
 
—
 
 
 
101.INS*
—
XBRL Instance Document
 
 
 
101.SCH*
—
XBRL Taxonomy Extension Schema Document
 
 
 
101.CAL*
—
XBRL Taxonomy Extension Calculation Linkbase Document
 
 
 
101.DEF*
—
XBRL Taxonomy Extension Definition Linkbase Document.
 
 
 
101.LAB*
—
XBRL Taxonomy Extension Label Linkbase Document
 
 
 
101.PRE*
—
XBRL Taxonomy Extension Presentation Linkbase Document
---------
*        Filed herewith.
**      Furnished herewith.


34