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.

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).

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer or a smaller reporting company. See the definitions of "large accelerated filer", “accelerated filer” and "smaller reporting company in Rule 12b-2 of the Exchange Act.

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).

The Registrant had ~~50,805,451shares~~51,360,935 shares of common stock, par value $0.01, outstanding and ~~10,758,567~~10,918,634 shares of treasury stock as of ~~October 28, 2015.~~April 26, 2016.

													THREE MONTHS ENDED
	THREE MONTHS ENDED						NINE MONTHS ENDED						MARCH 31,
	SEPTEMBER 30,						SEPTEMBER 30,						2016			2015
	2015			2014			2015			2014
Revenues	$	258,886		$	471,032		$	865,503		$	1,335,876		$	169,655		$	337,358

Costs and expenses:
Cost of sales and services		188,590			306,497			620,976			886,777			128,815			237,722
Selling, general and administrative expenses		33,126			43,734			100,732			128,181			29,979			35,605
Depreciation and amortization expense		31,730			31,076			96,742			92,970			30,403			32,579
Other operating expense (income)		(1,206	)		(1,887	)		(2,077	)		9,524			563			(2,308	)
		252,240			379,420			816,373			1,117,452			189,760			303,598
Operating income		6,646			91,612			49,130			218,424
Operating (loss) income														(20,105	)		33,760

Interest expense		(1,541	)		(1,602	)		(4,876	)		(15,500	)		(1,445	)		(1,708	)
Interest income		153			150			428			411			92			136
Loss on extinguishment of debt		--			30			--			(100,380	)
Other income		401			235			1,221			2,571			206			466
Income from continuing operations before income taxes		5,659			90,425			45,903			105,526
Income tax provision		(3,953	)		(32,048	)		(18,646	)		(36,545	)
Net income from continuing operations		1,706			58,377			27,257			68,981
Net income (loss) from discontinued operations, net of tax		23			(1,467	)		224			51,571
Net income		1,729			56,910			27,481			120,552
Less: Net income (loss) attributable to noncontrolling interest		--			(10	)		--			8
Net income attributable to Oil States International, Inc.	$	1,729		$	56,920		$	27,481		$	120,544
(Loss) income from continuing operations before income taxes														(21,252	)		32,654
Income tax benefit (expense)														8,016			(13,252	)
Net (loss) income from continuing operations														(13,236	)		19,402
Net (loss) income from discontinued operations, net of tax														(3	)		166
Net (loss) income attributable to Oil States International, Inc.													$	(13,239	)	$	19,568


Net income (loss) attributable to Oil States International, Inc.:
Net (loss) income attributable to Oil States International, Inc.:
Continuing operations	$	1,706		$	58,387		$	27,257		$	68,973		$	(13,236	)	$	19,402
Discontinued operations		23			(1,467	)		224			51,571			(3	)		166
Net income attributable to Oil States International, Inc.	$	1,729		$	56,920		$	27,481		$	120,544
Net (loss) income attributable to Oil States International, Inc.													$	(13,239	)	$	19,568


Basic net income (loss) per share attributable to Oil States International, Inc. common stockholders from:
Basic net (loss) income per share attributable to Oil States International, Inc. common stockholders from:
Continuing operations	$	0.03		$	1.08		$	0.53		$	1.28		$	(0.26	)	$	0.38
Discontinued operations		--			(0.03	)		--			0.95			--			--
Net income	$	0.03		$	1.05		$	0.53		$	2.23
Net (loss) income													$	(0.26	)	$	0.38

Diluted net income (loss) per share attributable to Oil States International, Inc. common stockholders from:
Diluted net (loss) income per share attributable to Oil States International, Inc. common stockholders from:
Continuing operations	$	0.03		$	1.07		$	0.53		$	1.27		$	(0.26	)	$	0.38
Discontinued operations		--			(0.02	)		--			0.95			--			--
Net income	$	0.03		$	1.05		$	0.53		$	2.22
Net (loss) income													$	(0.26	)	$	0.38

Weighted average number of common shares outstanding:
Basic		50,011			52,979			50,422			53,119			50,042			50,826
Diluted		50,050			53,294			50,500			53,422			50,042			50,936

	SEPTEMBER 30,			DECEMBER 31,			MARCH 31,			DECEMBER 31,
	2015			2014			2016			2015
	(UNAUDITED)						(UNAUDITED)
ASSETS

Current assets:
Cash and cash equivalents	$	85,715		$	53,263		$	43,064		$	35,973
Accounts receivable, net		304,574			497,124			271,973			333,494
Inventories, net		226,394			232,490			215,499			212,882
Prepaid expenses and other current assets		31,325			43,789			18,911			29,124
Total current assets		648,008			826,666			549,447			611,473

Property, plant, and equipment, net		648,330			649,846			622,533			638,725
Goodwill, net		264,308			252,201			264,437			263,787
Other intangible assets, net		60,558			52,935			57,438			59,385
Other noncurrent assets		27,134			27,964			22,387			23,101
Total assets	$	1,648,338		$	1,809,612		$	1,516,242		$	1,596,471

LIABILITIES AND STOCKHOLDERS’ EQUITY

Current liabilities:
Accounts payable	$	72,345		$	108,949		$	43,199		$	59,116
Accrued liabilities		61,434			96,130			43,958			49,300
Income taxes		9,056			9,195			8,643			8,303
Current portion of long-term debt and capitalized leases		515			530			524			533
Deferred revenue		28,820			48,948			35,058			36,655
Deferred tax liabilities		12,562			7,431
Other current liabilities		213			229			292			293
Total current liabilities		184,945			271,412			131,674			154,200

Long-term debt and capitalized leases		159,611			146,835			89,158			125,887
Deferred income taxes		30,151			33,913			32,557			40,497
Other noncurrent liabilities		18,988			16,795			19,949			20,215
Total liabilities		393,695			468,955			273,338			340,799

Stockholders’ equity:
Oil States International, Inc. stockholders’ equity:
Common stock, $.01 par value, 200,000,000 shares authorized, 61,564,018 shares and 60,940,734 shares issued, respectively, and 50,805,727 shares and 53,017,359 shares outstanding, respectively		616			610
Common stock, $.01 par value, 200,000,000 shares authorized, 62,281,177 shares and 61,712,805 shares issued, respectively, and 51,362,615 shares and 50,953,149 shares outstanding, respectively								623			617
Additional paid-in capital		704,402			685,232			715,776			712,980
Retained earnings		1,178,747			1,151,266			1,166,624			1,179,863
Accumulated other comprehensive loss		(42,072	)		(22,100	)		(49,145	)		(50,698	)
Common stock held in treasury at cost, 10,758,291 and 7,923,375 shares, respectively		(587,050	)		(474,351	)
Total Oil States International, Inc. stockholders’ equity		1,254,643			1,340,657
Noncontrolling interest		--			--
Common stock held in treasury at cost, 10,918,562 and 10,759,656 shares, respectively								(590,974	)		(587,090	)
Total stockholders’ equity		1,254,643			1,340,657			1,242,904			1,255,672
Total liabilities and stockholders’ equity	$	1,648,338		$	1,809,612		$	1,516,242		$	1,596,471

							THREE MONTHS ENDED MARCH 31,
	NINE MONTHS ENDEDSEPTEMBER 30,						2016			2015
	2015			2014
Cash flows from operating activities:
Net income	$	27,481		$	120,552
Adjustments to reconcile net income to net cash provided by operating activities:
Income from discontinued operations		(224	)		(51,571	)
Net (loss) income							$	(13,239	)	$	19,568
Adjustments to reconcile net (loss) income to net cash provided by operating activities:
Loss (income) from discontinued operations								3			(166	)
Depreciation and amortization		96,742			92,970			30,403			32,579
Deferred income tax benefit		(2,862	)		(20,144	)
Tax impact of share-based payment arrangements		(550	)		(4,585	)
Deferred income tax (benefit) expense								(10,879	)		5,923
Provision for bad debt		(99	)		3,767			397			(617	)
Gain on disposals of assets		(907	)		(1,761	)		(106	)		(313	)
Non-cash compensation charge		16,245			19,284			5,105			5,660
Amortization of deferred financing costs		585			1,625			195			195
Loss on extinguishment of debt		--			100,380
Other, net		--			(182	)		57			(213	)
Changes in operating assets and liabilities, net of effect from acquired businesses:
Accounts receivable		189,882			(71,442	)		59,408			117,900
Inventories		5,207			(11,534	)		(2,836	)		(6,235	)
Accounts payable and accrued liabilities		(71,848	)		(20,257	)		(19,955	)		(65,124	)
Taxes payable		5,784			(38,990	)		8,813			2,889
Other operating assets and liabilities, net		(12,959	)		23,238			(529	)		2,345
Net cash flows provided by continuing operating activities		252,477			141,350			56,837			114,391
Net cash flows provided by discontinued operating activities		350			161,130
Net cash flows (used in) provided by discontinued operating activities								(5	)		260
Net cash flows provided by operating activities		252,827			302,480			56,832			114,651

Cash flows from investing activities:
Capital expenditures		(92,314	)		(142,549	)		(10,281	)		(38,282	)
Acquisitions of businesses, net of cash acquired		(33,427	)		193			--			(33,948	)
Proceeds from disposition of property, plant and equipment		1,911			3,069			166			437
Other, net		(491	)		(1,463	)		383			193
Net cash flows used in continuing investing activities		(124,321	)		(140,750	)		(9,732	)		(71,600	)
Net cash flows used in discontinued investing activities		--			(119,061	)
Net cash flows used in investing activities		(124,321	)		(259,811	)		(9,732	)		(71,600	)

Cash flows from financing activities:
Revolving credit borrowings, net		13,084			171,734
Repayment of 6 1/2% Senior Notes		--			(630,307	)
Repayment of 5 1/8% Senior Notes		--			(419,794	)
Distribution received from Spin-Off of Civeo		--			750,000
Revolving credit (repayments) borrowings, net								(36,800	)		59,030
Debt and capital lease repayments		(411	)		(408	)		(133	)		(131	)
Issuance of common stock from share-based payment arrangements		2,385			8,844			367			1,008
Purchase of treasury stock		(104,596	)		(162,053	)		--			(77,401	)
Tax impact of share-based payment arrangements		550			4,585
Shares added to treasury stock as a result of net share settlements due to vesting of restricted stock		(6,786	)		(5,048	)		(3,883	)		(6,084	)
Payment of financing costs		(2	)		(3,862	)
Other, net		--			1			1			(39	)
Net cash flows used in continuing financing activities		(95,776	)		(286,308	)		(40,448	)		(23,617	)
Net cash flows used in discontinued financing activities		--			(282,204	)
Net cash flows used in financing activities		(95,776	)		(568,512	)		(40,448	)		(23,617	)

Effect of exchange rate changes on cash		(278	)		(3,663	)		439			(648	)
Net change in cash and cash equivalents		32,452			(529,506	)		7,091			18,786
Cash and cash equivalents, beginning of period		53,263			599,306			35,973			53,263

Cash and cash equivalents, end of period	$	85,715		$	69,800		$	43,064		$	72,049

Common
Stock

Additional Paid-
In Capital

Retained
Earnings

Accumulated Other Comprehensive Income (Loss)

Treasury
Stock

Total
Stockholders'
Equity

Balance, December 31, 2014
$ 610 $ 685,232 $ 1,151,266 $ (22,100 ) $ (474,351 ) $ 1,340,657
Net income.
27,481 27,481
Currency translation adjustment (excluding intercompany notes)
(16,295 ) (16,295 )
Currency translation adjustment on intercompany notes
(3,837 ) (3,837 )
Unrealized gain on forward contracts, net of tax
160 160
Exercise of stock options, including tax impact
2 2,932 2,934
Amortization of restricted stock compensation
13,993 13,993
Stock option expense
2,252 2,252
Restricted stock awards granted
4 (4 ) --
Surrender of stock to pay taxes on stock option exercises and restricted stock awards
(6,786 ) (6,786 )
OIS common stock withdrawn from deferred compensation plan
(3 ) 3 --
Share repurchases
(105,916 ) (105,916 )
Balance,September 30, 2015
$ 616 $ 704,402 $ 1,178,747 $ (42,072 ) $ (587,050 ) $ 1,254,643

1.	ORGANIZATION AND BASIS OF PRESENTATION

The accompanying unaudited condensed consolidated financial statements of Oil States International, Inc. and its wholly-owned 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.

On May 30, 2014, we completed the spin-off of our accommodations business into a stand-alone, publicly traded corporation (Civeo Corporation, or Civeo) (the Spin-Off). The results of operations for our accommodations business have been classified as discontinued operations for all periods presented. Unless indicated otherwise, the information in the Notes to the Unaudited Condensed Consolidated Financial Statements relates to our continuing operations.

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 long-lived assets and related fair values of our reporting units have occurred. A longer term continuation of the current down cycle will likely result in changes in our estimates of forward cash flow timing and amounts and may result in impairment losses.

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, ~~2014~~2015 (the ~~2014~~2015 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 ~~September 2015,~~March 2016, the FASB issued guidance on ~~measurement-period adjustments for business combinations~~employee share-based payment accounting which require that an acquirer recognize adjustments to provisional amounts that are identified during the measurement period with a corresponding adjustment to goodwill in the reporting period in which the adjustment amounts are determined, as opposed to revising prior periods presented in financial statements as previously required. Thus, an acquirer shall record, in the same period’s financial statements, the effect on earnings of changes in depreciation, amortization, or other income effects, if any, as a result of the changemakes several modifications to the ~~provisional amounts, calculated as if~~current guidance related to the accounting ~~had been completed at~~for forfeitures, employer tax withholding on stock-based compensation and the ~~acquisition date.~~financial statement presentation of excess tax benefits or deficiencies. This guidance ~~requires an entity to present separately on~~also clarifies the ~~face~~statement of ~~the income statement or disclose in the notes the portion~~cash flows presentation for certain components of the amount recorded in current-period earnings by line item that would have been recorded in previous reporting periods if the adjustment to the provisional amounts had been recognized as of the acquisition date. For public business entities, the guidance is effective for fiscal years beginning after December 15, 2015, including interim periods within those fiscal years. This guidance should be applied prospectively to adjustments to provisional amounts that occur after the effective date of this guidance with earlier application permitted for financial statements that have not been issued. We do not expect that the adoption of thisshare-based awards. The standard ~~will have a material effect on our consolidated financial statements.~~

In July 2015, the FASB issued guidance on the measurement of inventory which simplifies the guidance on the subsequent measurement of inventory, excluding inventory measured using last-in, first out or the retail inventory method. Under this guidance, in scope inventory should be measured at the lower of cost and net realizable value. This guidance is effective for interim and annual reporting periods beginning after December 15, 2016, although early adoption is permitted. We do not expect the adoption of this standard to have a material impact on ourconsolidated financial position, results of operations and related disclosures.

In February 2016, the FASB issued guidance on leases which introduces the recognition of lease assets and lease liabilities by lessees for those leases classified as operating leases under previous guidance. The guidance will be effective for annual reporting periods beginning after December 15, 2018 and interim periods within those fiscal years with early adoption permitted. We are evaluating the impact of ~~this guidance on our consolidated financial statements and our timing for adoption but do not expect that~~ the future adoption of this ~~guidance will have a material effect on our~~standard onour consolidated financial ~~statements.~~position, results of operations and related disclosures.

OIL STATES INTERNATIONAL, INC. AND SUBSIDIARIES

NOTES TO UNAUDITED CONDENSED CONSOLIDATED

FINANCIAL STATEMENTS

(Continued)

In April 2015, the FASB issued guidance on the presentation of debt issuance costs which requires that debt issuance costs related to a recognized debt liability be presented in the balance sheet as a direct deduction from the carrying amount of that debt liability, consistent with debt discounts. In August 2015, the FASB issued additional guidance on this topic which adds comments from the Commission addressing the guidance issued in April 2015 and debt issuance costs related to line-of-credit arrangements. The Commission commented it would not object to an entity deferring and presenting debt issuance costs as an asset and subsequently amortizing the deferred debt issuance costs ratably over the term of the line-of-credit arrangement, regardless of whether there are any outstanding borrowings on the line-of-credit arrangement.The recognition and measurement guidance for debt issuance costs are not affected by this guidance. This new guidance requires retrospective application and represents a change in accounting principle. For public business entities, this guidance is effective for financial statements issued for fiscal years beginning after December 15, 2015, and interim periods within those fiscal ~~years.We do not expect that~~years. The Company adopted this new guidance during the first quarter of 2016. The adoption of this ~~standard will have~~new guidancedid not affect the Company’s results of operations or cash flows, but it resulted in the Company reclassifying its deferred financing costs associated with its revolving credit agreement from other noncurrent assets to long-term debt on a ~~material effect on our~~retrospective basis. The Company's consolidated ~~financial statements.~~balance sheets included deferred financing costs of $2.7 million as of December 31, 2015 that were reclassed from other noncurrent assets to long-term debt. See Note 7, “Debt.”

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 in exchange for those goods or services. The guidance provides a five-step analysis of transactions to determine when and how revenue is recognized. Other major provisions include capitalization of certain contract costs, consideration of time value of money in the transaction price, and allowing estimates of variable consideration to be recognized before contingencies are resolved in certain circumstances. The guidance also requires enhanced disclosures regarding the nature, amount, timing and uncertainty of revenue and cash flows arising from an entity’s contracts with customers. In August 2015, the FASB issued guidance deferring the effective date by one year to December 15, 2017 for fiscal years, and interim periods within those years, beginning after that date and permitted early adoption of the standard, but not before the original effective date of December 15, ~~2016. The~~2016.The guidance permits the use of either a retrospective or cumulative effect transition method. We have not yet selected a transition method and ~~are currently evaluating~~continue to evaluate the impact of the amended guidance on our consolidated financial position, results of operations and related disclosures.

5.	EARNINGS PER SHARE

The numerator ~~(income or loss)~~(loss/income) and denominator (shares) used for the computation of basic and diluted (loss) earnings per share were as follows (in thousands):

THREE MONTHS ENDEDSEPTEMBER 30,

2015

2014

Income (Loss)

Shares

Income (Loss)

Shares

Basic:

Net income attributable to Oil States International, Inc.
$ 1,729 $ 56,920
Less: Undistributed net income allocable to participating securities
(36 ) (1,187 )
Undistributed net income applicable to common stockholders
1,693 55,733
Less: (Income) loss from discontinued operations, net of tax
(23 ) 1,467
Add: Undistributed net income (loss) from discontinued operations allocable to participating securities
-- (31 )
Income from continuing operations applicable to Oil States International, Inc. common stockholders – Basic
$ 1,670 50,011 $ 57,169 52,979
Diluted:

Income from continuing operations applicable to Oil States International, Inc. common stockholders – Basic
$ 1,670 50,011 $ 57,169 52,979
Effect of dilutive securities:

Undistributed net income reallocated to participating securities
-- -- 7 --
Options on common stock
-- 30 -- 298
Restricted stock awards and other
-- 9 -- 17
Income from continuing operations applicable to Oil States International, Inc. common stockholders – Diluted
1,670 50,050 57,176 53,294
Income (loss) from discontinued operations, net of tax, applicable to Oil States International, Inc. common stockholders
22 (1,436 )
Net income attributable to Oil States International, Inc. common stockholders – Diluted
$ 1,692 50,050 $ 55,740 53,294

THREE MONTHS ENDED MARCH 31,

2016

2015

Income

Shares

Income

Shares

Basic:

Net (loss) income attributable to Oil States International, Inc.
$ (13,239 ) $ 19,568
Less: Undistributed net income allocable to participating securities
-- (409 )
Undistributed net (loss) income applicable to common stockholders
(13,239 ) 19,159
Less: Loss (income) from discontinued operations, net of tax
3 (166 )
Add: Undistributed net income from discontinued operations allocable to participating securities
-- 3
(Loss) income from continuing operations applicable to Oil States International, Inc. common stockholders – Basic
$ (13,236 ) 50,042 $ 18,996 50,826
Diluted:

(Loss) income from continuing operations applicable to Oil States International, Inc. common stockholders – Basic
$ (13,236 ) 50,042 $ 18,996 50,826
Effect of dilutive securities:

Undistributed net income reallocated to participating securities
-- -- 1 --
Options on common stock
-- -- -- 101
Restricted stock awards and other
-- -- -- 9
(Loss) income from continuing operations applicable to Oil States International, Inc. common stockholders – Diluted
(13,236 ) 50,042 18,997 50,936
(Loss) income from discontinued operations, net of tax, applicable to Oil States International, Inc. common stockholders
(3 ) 163
Undistributed net income reallocated to participating securities
-- --
Net (loss) income attributable to Oil States International, Inc. common stockholders – Diluted
$ (13,239 ) 50,042 $ 19,160 50,936

NINE MONTHS ENDED SEPTEMBER 30,

2015

2014

Income (Loss)

Shares

Income (Loss)

Shares

Basic:

Net income attributable to Oil States International, Inc.
$ 27,481 $ 120,544
Less: Undistributed net income allocable to participating securities
(575 ) (1,846 )
Undistributed net income applicable to common stockholders
26,906 118,698
Less: Income from discontinued operations, net of tax
(224 ) (51,571 )
Add: Undistributed net income from discontinued operations allocable to participating securities
5 790
Income from continuing operations applicable to Oil States International, Inc. common stockholders – Basic
$ 26,687 50,422 $ 67,917 53,119
Diluted:

Income from continuing operations applicable to Oil States International, Inc. common stockholders – Basic
$ 26,687 50,422 $ 67,917 53,119
Effect of dilutive securities:

Undistributed net income reallocated to participating securities
1 -- 6 --
Options on common stock
-- 70 -- 286
Restricted stock awards and other
-- 9 -- 17
Income from continuing operations applicable to Oil States International, Inc. common stockholders – Diluted
26,688 50,501 67,923 53,422
Income from discontinued operations, net of tax, applicable to Oil States International, Inc. common stockholders
219 50,781
Undistributed net income reallocated to participating securities
-- 4
Net income attributable to Oil States International, Inc. common stockholders – Diluted
$ 26,907 50,501 $ 118,708 53,422

~~OIL STATES INTERNATIONAL, INC. AND SUBSIDIARIES~~

~~NOTES TO UNAUDITED CONDENSED CONSOLIDATED~~

~~FINANCIAL STATEMENTS~~

~~(Continued)~~

Our calculation of diluted (loss) earnings per share for the three ~~and nine~~ months ended ~~September 30,~~March 31, 2016 and 2015 excluded ~~757,150~~761,760 shares and 745,514 shares, respectively, issuable pursuant to outstanding stock options and restricted stock awards, due to their antidilutive effect. Our calculation of diluted earnings per share for the three and nine months ended September 30, 2014 excluded 196,039 shares and 186,354713,187 shares, respectively, issuable pursuant to outstanding stock options and restricted stock awards, due to their antidilutive effect.

6.	BUSINESS ACQUISITIONS AND GOODWILL

On January 2, 2015, we acquired all of the equity of Montgomery Machine Company, Inc. (MMC). Headquartered in Houston, Texas, MMC combines machining and proprietary cladding technology and services to manufacture high-specification components for the offshore capital equipment industry. We believe that the acquisition of MMC ~~will strengthen~~strengthens our position in our offshore products segment as a supplier of subsea components with enhanced capabilities, proprietary technology and logistical advantages. Total transaction consideration was $33.4 million, ~~in cash,~~ net of cash ~~acquired, funded from amounts available under the Company’s credit facility.~~acquired. The operations of MMC have been included in our offshore products segment since the acquisition date.

OIL STATES INTERNATIONAL, INC. AND SUBSIDIARIES

NOTES TO UNAUDITED CONDENSED CONSOLIDATED

FINANCIAL STATEMENTS

(Continued)

Changes in the carrying amount of goodwill for the ~~nine~~three month period ended ~~September 30, 2015~~March 31, 2016 were as follows (in thousands):

	Well Site Services															Well Site Services
	Completion Services			Drilling Services			Subtotal			Offshore Products			Total			Completion Services			Drilling Services			Subtotal			Offshore Products			Total
Balance as of December 31, 2014
Balance as of December 31, 2015
Goodwill	$	200,967		$	22,767		$	223,734		$	145,762		$	369,496		$	198,903		$	22,767		$	221,670		$	159,412		$	381,082
Accumulated Impairment Losses		(94,528	)		(22,767	)		(117,295	)		--			(117,295	)		(94,528	)		(22,767	)		(117,295	)		--			(117,295	)
		106,439			--			106,439			145,762			252,201			104,375			--			104,375			159,412			263,787
Goodwill acquired		--			--			--			13,942			13,942
Foreign currency translation and other changes		(1,674	)		--			(1,674	)		(161	)		(1,835	)		772			--			772			(122	)		650
	$	104,765		$	--		$	104,765		$	159,543		$	264,308		$	105,147		$	--		$	105,147		$	159,290		$	264,437

Balance as of September 30, 2015
Balance as of March 31, 2016
Goodwill	$	199,293		$	22,767		$	222,060		$	159,543		$	381,603		$	199,675		$	22,767		$	222,442		$	159,290		$	381,732
Accumulated Impairment Losses		(94,528	)		(22,767	)		(117,295	)		--			(117,295	)		(94,528	)		(22,767	)		(117,295	)		--			(117,295	)
	$	104,765		$	--		$	104,765		$	159,543		$	264,308		$	105,147		$	--		$	105,147		$	159,290		$	264,437

7.	~~DISCONTINUED OPERATIONS~~

On May 30, 2014, we completed the Spin-Off of our accommodations business, Civeo Corporation, to the Company’s stockholders. On May 30, 2014, the stockholders of record of Oil States common stock as of the close of business on May 21, 2014 (the Record Date) received two shares of Civeo common stock for each share of Oil States common stock held as of the Record Date. Following the Spin-Off, Oil States ceased to own any shares of Civeo common stock.

~~OIL STATES INTERNATIONAL, INC. AND SUBSIDIARIES~~

~~NOTES TO UNAUDITED CONDENSED CONSOLIDATED~~

~~FINANCIAL STATEMENTS~~

~~(Continued)~~

~~The following table provides the components of net income from discontinued operations, net of tax for each operating segment (in thousands).~~

Three Months Ended Three Months Ended Nine Months Ended Nine Months Ended
September 30, 2015 September 30, 2014 September 30, 2015 September 30, 2014
Revenues

Accommodations
$ -- $ -- $ -- $ 404,132
Tubular services
$ -- $ -- $ -- $ --

Income(loss)from Accommodations discontinued operations:

Income from discontinued operations before income taxes
$ 36 $ 512 $ 324 $ 62,436
Income tax expense
(13 ) (1,965 ) (117 ) (11,063 )
Net (loss) income from discontinued operations, net of tax
$ 23 $ (1,453 ) $ 207 $ 51,373

Income(loss)from Tubular services discontinued operations:

(Loss) Income from discontinued operations before income taxes
$ -- $ (21 ) $ 27 $ 315
Income tax (expense) benefit
-- 7 (10 ) (118 )
Net (loss) income from discontinued operations, net of tax
$ -- $ (14 ) $ 17 $ 197

~~In connection with the Spin-Off, the~~The Company ~~terminated its then existing credit facility on May 28, 2014 and entered into~~currently has a ~~new~~ $600 million senior secured revolving credit ~~facility.The Company has~~facility with an option to increase the maximum borrowings under its revolving credit facility to $750 million subject to additional lender commitments prior to its maturity on May 28, 2019. The credit facility is governed by a Credit Agreement dated as of May 28, 2014 (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 (as defined in the Credit Agreement). During the first ~~nine months~~quarter of ~~2015,~~2016, 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% for the first ~~nine months~~quarter of ~~2015.The~~2016.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 our 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 exclude goodwill impairments, ~~losses on extinguishment of debt,~~ debt discount amortization and other non-cash charges. As of ~~September 30, 2015,~~March 31, 2016, 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 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 Company's 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.

As of ~~September 30, 2015,~~March 31, 2016, we had ~~$153.8~~$86.1 million outstanding under the Credit Agreement and an additional ~~$39.5~~$38.4 million of outstanding letters of ~~credit, leaving $406.7~~credit. As of March 31, 2016, $364.6 million was available to be drawn under the credit facility. AsThe total amount available to be drawn under our revolving credit facility was less than the lender commitments as of ~~September 30, 2015, the Company had approximately $85.7 million of cash and cash equivalents.~~

~~During the first nine months of 2014, we recognized losses on the extinguishment of debt totaling $100.4 million primarily~~March 31, 2016, due to the ~~repurchase of~~maximum leverage ratio covenant in our ~~remaining 6 1/2% Notes~~credit facility which serves to limit borrowings, and ~~5 1/8% Notes (the Notes), which resulted~~such availabilityis expected to be furtherreduced as our trailing twelve months EBITDA moves lower into 2016 given that, in ~~a loss of $96.7 million consisting of the premium paid over book value for the Notes and the write-off of unamortized deferred financing costs associated~~accordance with the Notes. This repurchase was partially funded with the proceeds of the $750 million special cash dividend paid to us by Civeo in connection with the Spin-Off, along with available cash on hand. In addition, as a result of the refinancing ofCredit Agreement, total debt cannot exceed 3.25 times our existing credit facility in the second quarter of 2014, we recognized a loss on extinguishment of debt of $3.7 million (net of $1.8 million allocated to discontinued operations for the Canadian portion of the facility) from the write-off of unamortized deferred financing costs.trailing twelve months EBITDA.

~~10.~~9.

CHANGES IN COMMON STOCK OUTSTANDING

Shares of common stock outstanding – January 1, ~~2015~~2016	~~53,017,359~~50,953,149
~~Repurchase of shares – transferred to treasury~~	~~(2,674,218~~	)
Shares issued upon granting of restricted stock awards, net of forfeitures	~~448,024~~551,658
Shares issued upon exercise of stock options	~~175,260~~16,714
Shares withheld for taxes on ~~exercise of stock options and~~ vesting of restricted stock awards and transferred to treasury	(~~160,698~~158,906	)
Shares of common stock outstanding – ~~September 30, 2015~~March 31, 2016	~~50,805,727~~51,362,615

On September 6, 2013, the Company announced an increase in its Board-authorized Company share repurchase program from $200 million to $500 million providing for the repurchase of the Company’s common stock, par value $.01 per share. On July 29, 2015, the Company’s Board of Directors approved the termination of our then existing share repurchase program and authorized a new program providing for the repurchase of up to $150 million of the Company’s common stock, par value $.01 per share. The new program is set to expire on July 29, 2016. During the ~~nine months ended September 30, 2015,~~first quarter of 2016, there were no repurchases of our common stock made under our current program. As of March 31, 2016, a total of ~~$105.9~~$456.0 million of our stock ~~(2,674,218 shares) were~~(6,902,748 shares, or approximately 13% of the outstanding shares of our common stock at the initiation of our initial share repurchase authorization in August 2012) had been repurchased under these ~~programs compared to $155.4 million (1,704,127 shares) during the nine months ended September 30, 2014.~~programs. The amount remaining under our current share repurchase authorization as of ~~September 30, 2015~~March 31, 2016 was ~~approximately~~ $136.8 million. Subject to applicable securities laws, such purchases will be at such times and in such amounts as the Company deems appropriate.

~~Stock based~~Stock-based compensation pre-tax expense from continuing operations recognized in the three month periods ended ~~September 30,~~March 31, 2016 and 2015 ~~and 2014~~ totaled ~~$5.5~~$5.1 million and ~~$6.8~~$5.7 million, respectively. ~~Stock based compensation pre-tax expense from continuing operations recognized in the nine month periods ended September 30, 2015 and 2014 totaled $16.2 million and $19.3 million, respectively.~~

In February ~~2015,~~2016, the Company granted performance based stock awards totaling ~~75,900~~86,462 shares valued at a total of ~~$3.2~~approximately $2.1 million. These performance based awards may vest in February ~~2018~~2019 in an amount that will depend on the Company’s achievement of specified performance objectives. These performance based awards have a performance criteria that will be measured based upon the Company’s achievement of specified levels of ~~average after-tax annual~~relative total shareholder return ~~on invested capital~~compared toour peer group of companies for the three year period commencing January 1, ~~2015~~2016 and ending December 31, ~~2017.~~2018.

At ~~September 30, 2015, $38.3~~March 31, 2016, $42.8 million of compensation ~~cost~~costs related to unvested stock options and restricted stock awards attributable to vesting conditions had not yet been recognized.

~~12.~~11.

INCOME TAXES

Income tax expense 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, 2015~~March 31, 2016 was ~~income~~a total tax ~~expense~~benefit of ~~$4.0~~$8.0 million, ~~representing 69.9%~~or 37.7% of pretax ~~income, and $18.6 million, representing 40.6% of pretax income, respectively,~~losses, compared to income tax expense of ~~$32.0~~$13.3 million, or ~~35.4%~~40.6% of pretax income, ~~and income tax expense of $36.5 million, or 34.6% of pretax income, respectively,~~ for the three ~~and nine~~ months ended ~~September 30, 2014.~~March 31, 2015. The higher effective tax rate in the third quarter of 2015 compared to the third quarter of 2014 was primarily due to a $3.2 million tax valuation allowance recorded against certain of the Company’s deferred tax assets. The increase in the effective tax rate for the ~~nine~~three months ended ~~September 30,~~March 31, 2015 ~~compared to the same period in 2014 was largely the result of the $3.5 million tax valuation allowance recorded against certain of the Company’s deferred tax assets,~~included a $2.3 million deferred tax adjustment in the first quarter of 2015 for certain prior period non-deductible items ~~in 2015, partially offset by reduced domestic income in 2015 due~~related to ~~the impact of the industry downturn in activity and the loss incurred in 2014 from the extinguishment of debt associated with the debt refinancings completed in conjunction with the Spin-Off.~~ stock-based compensation.

~~13.~~12.

SEGMENT AND RELATED INFORMATION

In accordance with current accounting standards regarding disclosures about segments of an enterprise and related information, the Company has identified the following reportable segments: well site services and offshore 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. Most of the businesses were initially acquired as a unit, and the management at the time of the acquisition was retained. Subsequent 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.

OIL STATES INTERNATIONAL, INC. AND SUBSIDIARIES

NOTES TO UNAUDITED CONDENSED CONSOLIDATED

FINANCIAL STATEMENTS

(Continued)

Financial information by business segment for continuing operations for each of the three ~~and nine~~ months ended ~~September 30,~~March 31, 2016 and 2015 ~~and 2014~~ is summarized in the following table (in thousands):.

	Revenues from unaffiliated customers		Depreciation and amortization		Operating income (loss)			Equity in earnings of unconsolidated affiliates		Capital expenditures		Total assets		Revenues from unaffiliated customers		Depreciation and amortization		Operating(loss)income			Equity inlossesof unconsolidated affiliates			Capital expenditures		Total assets
Three months ended September 30, 2015
Three months ended March 31, 2016
Well site services –
Completion services	$	66,734	$	18,701	$	(9,991	)	$	-	$	11,343	$	545,986	$	40,949	$	17,944	$	(24,335	)	$	-		$	4,538	$	508,066
Drilling services		16,506		6,725		(4,844	)		-		1,539		109,645		2,772		6,522		(8,105	)		-			254		92,620
Total well site services		83,240		25,426		(14,835	)		-		12,882		655,631		43,721		24,466		(32,440	)		-			4,792		600,686
Offshore products		175,646		5,985		33,512			1		10,538		955,439		125,934		5,654		23,311			(22	)		5,391		890,067
Corporate and eliminations		-		319		(12,031	)		-		154		37,268		-		283		(10,976	)		-			98		25,489
Total	$	258,886	$	31,730	$	6,646		$	1	$	23,574	$	1,648,338	$	169,655	$	30,403	$	(20,105	)	$	(22	)	$	10,281	$	1,516,242

Revenues
from
unaffiliated
customers

Depreciation
and
amortization

Operating
income
(loss)

Equity in
earnings of
unconsolidated
affiliates

Capital
expenditures

Total
assets

Nine months ended September 30, 2015

Well site services –

Completion services
$ 254,265 $ 57,289 $ (8,492 ) $ - $ 46,721 $ 545,986
Drilling services
56,888 20,368 (11,725 ) - 10,209 109,645
Total well site services
311,153 77,657 (20,217 ) - 56,930 655,631
Offshore products
554,350 18,054 104,889 5 34,704 955,439
Corporate and eliminations
- 1,031 (35,542 ) - 680 37,268
Total
$ 865,503 $ 96,742 $ 49,130 $ 5 $ 92,314 $ 1,648,338

Revenues
from
unaffiliated
customers

Depreciation
and
amortization

Operating
income
(loss)

Equity in
earnings of
unconsolidated
affiliates

Capital
expenditures

Total
assets

Nine months ended September 30, 2014

Well site services –

Completion services
$ 474,106 $ 54,904 $ 106,760 $ - $ 80,523 $ 622,318
Drilling services
152,243 20,358 23,044 - 21,141 144,211
Total well site services
626,349 75,262 129,804 - 101,664 766,529
Offshore products
709,527 16,939 142,508 292 39,190 1,016,077
Corporate and eliminations
- 769 (53,888 ) (1) - 1,695 20,863
Total
$ 1,335,876 $ 92,970 $ 218,424 $ 292 $ 142,549 $ 1,803,469

~~14.~~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. During 2014 and ~~the first nine months of~~early 2015, a number of lawsuits were filed by current and former employees, in Federal Court against the Company and or one of its subsidiaries, 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 ~~seek~~are seeking recovery on their own behalf ~~and seek certification~~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 ~~is actively defending~~has settled the vast majority of these claims ~~in Federal Court while pursuing~~and is evaluating potential ~~resolution of the claims through settlement in appropriate cases. The Company recorded a liability in earlier periods~~settlements for the ~~estimated amount of any~~remaining individual plaintiffs’ claims which are not expected ~~settlement.~~to be significant.

~~In addition, we~~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.

This quarterly report on Form 10-Q contains ~~"certain forward-looking~~certain "forward-looking statements" within the meaning of Section 27A of the Securities Act of 1933 and Section 21E of the Securities Exchange Act of 1934 (the Exchange Act).ThePrivateSecuritiesLitigationReformAct of 1995 provides safe harbor provisions for forward-looking information. "“Forward-looking statements" can be identified by the use of forward-looking terminology including "may," "expect," "anticipate," "estimate," "continue," "believe," or other similar words. 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 II, Item 1A. Risk Factors” in this report and "Part I, Item 1A. Risk Factors" and the financial statement line item discussions set forth in "Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations" included in our 20145 Form 10-K filed with the Commissionon February ~~23, 2015.~~22, 2016.Should one or more of these risks or uncertainties materialize, or should the assumptions prove incorrect, actual results may differ materially from those expected, estimated or projected. Our management believes these forward-looking statements are reasonable. However, you should not place undue reliance on these forward-looking statements, which are based only on our current expectations and are not guarantees of future performance. All subsequent written and oral forward-looking statements attributable to us or to persons acting on our behalf are expressly qualified in their entirety by the foregoing. Forward-looking statements speak only as of the date they are made, and we undertake no obligation to publicly update or revise any of them in light of new information, future events or otherwise.

In addition, in certain places in this quarterly report, 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 in 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

You should read the following discussion and analysis 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 the ~~2014~~2015 Form 10-K.

Due to the spin-off on May 30, 2014 of our accommodations business into a stand-alone, publicly traded corporation (Civeo Corporation, or Civeo) through a tax-free distribution of the accommodations business to the Company’s shareholders (the Spin-Off), and the sale of our tubular services business on September 6, 2013, both of which are reported as discontinued operations, our management believes that income from continuing operations is more representative of the Company’s current business environment and focus. The terms “earnings” and “loss” as used in this “Management’s Discussion and Analysis of Financial Condition and Results of Operations” refer to income (loss) from continuing operations.

~~With the completion of the Spin-Off, we~~We are ~~now~~ a technology-focused, pure-play energy services company. We provide a broad range of products and services to the oil and gas industry through our offshore 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 oil and natural gas. 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 expected commodity prices, principally related to crude oil and natural gas.

In the past few years, crude oil prices have been volatile due to global economic uncertainties as well as inadequate regional well site transportation infrastructure. Significant downward crude oil price volatility began early in the fourth quarter of 2014 and ~~prices~~has continued ~~to drop precipitously throughout the remainder of 2014 and~~ into the first quarter of ~~2015, with a partial recovery during the second quarter of 2015 offset by a decline in prices again in the third quarter of 2015.~~2016. The material decrease in crude oil prices over this period can primarily be attributed to high levels of global crude oil inventories due to significant production growth in the U.S. shale plays, strengthening of the U.S. dollar throughout 2015 relative to other foreign currencies, and the Organization of Petroleum Exporting ~~Countries~~Companies (OPEC) ~~increase of~~increasing its ~~production~~production. OPEC has demonstrated through 2015 and to date in 2016 an unwillingness to cut its production, as it has done in previous years, in an effort to protect market share. These production increases have been offset somewhat by ~~increasing~~moderate increases in global oil demand. The combination of these factors caused a global supply and demand imbalance for crude oil which, along with concerns regarding the growth outlook in China and other emerging markets, and the anticipation of potential supply increases related to the lifting of sanctions against Iran (sanctions were lifted in January 2016), resulted in materially lower crude oil prices in 2015 and the first quarter of 2016. The average price of West Texas Intermediate (WTI) crude oil decreased from an average price of ~~$73~~$42 per barrel in the fourth quarter of ~~2014~~2015 to an average of ~~$46~~$33 per barrel in the ~~third~~first quarter of ~~2015.~~2016. These data points compare to an average price of ~~$100~~$48 per barrel in the first ~~nine months~~quarter of ~~2014.~~2015. The average price of Intercontinental Exchange Brent (Brent) crude decreased from an average price of ~~$76~~$44 per barrel in the fourth quarter of ~~2014~~2015 to an average of ~~$50~~$34 per barrel in the ~~third~~first quarter of ~~2015.~~2016. These data points compare to an average price of ~~$107~~$54 per barrel in the first ~~nine months~~quarter of ~~2014.~~2015. As of ~~October 28, 2015,~~April 26, 2016, WTI crude traded at approximately $43 per barrel while ~~ICE~~ Brent crude traded at approximately ~~$47~~$44 per barrel. ~~Crude oil prices decreased in~~The magnitude of the third quarter of 2015 primarily due to high levels of domestic crude oil inventories, concerns regarding the growth outlook in China, global economic uncertainties, and the anticipation of potential supply increases related to the proposed lifting of sanctions against Iran. These events havesupply/demand imbalance has created a market concern that crude oil prices ~~will~~could decline further or remain at their currently low level for the foreseeable future, with the current twelve-month forward strip price for WTI and Brent crude each averaging ~~$46~~$48 per ~~barrel and $50 per barrel, respectively.~~barrel. The current and expected price for WTI crude will continue to influence our customers’ spending in U.S. shale play developments, such as the Permian, Bakken, Niobrara, ~~Permian~~ and Eagle Ford basins. Spending in these regions will influence the overall drilling and completion activity in the area and, therefore, the activity of our well site services segment. The price for Brent crude will influence our customers’ spending related to global offshore drilling and development and, thus, the activity of our offshore products segment.

Given the historical volatility of crude prices, there remains a high degree of risk that prices could remain at depressed levels or deteriorate further due to high levels of domestic ~~and OPEC~~ crude oil production (albeit U.S. production has been declining), slowing growth rates in various global regions and/or the potential for ongoing supply/demand imbalances. Conversely, if the global supply of oil ~~and global inventory levels~~ were to decrease due to reduced capital investment by our customers (which is occurring), or government instability in a major oil-producing nation and energy demand ~~continues~~were to continue to increase in the U.S. and countries such as China and India, a recovery in WTI and Brent crude 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 ~~if they~~ decline further, demand for our products and services could continue to be weak or further decline.

Prices for natural gas in the U.S. averaged ~~$2.80~~$1.99 per mmBtu in the first ~~nine months~~quarter of ~~2015~~2016 compared to ~~$3.78~~$2.12 per mmBtu in the fourth quarter of ~~2014~~2015 and ~~$4.57~~$2.90 per mmBtu in the first ~~nine months~~quarter of ~~2014.~~2015. Natural gas prices declined during the first ~~nine months~~quarter of ~~2015~~2016 largely due to ~~increased~~a continued oversupply of natural gas ~~inventories.~~inventories and a warm 2015-2016 winter season. Natural gas prices traded at approximately ~~$2.09per~~$2.06per mmBtu as of ~~October 28, 2015.~~April 26, 2016. Strong production and a milder winter this year compared to last year resulted in significant increases in natural gas inventories in the U.S. during the first ~~nine months~~quarter of ~~2015,~~2016, from ~~11%~~12% below the 5-year average as of the end of the first ~~nine months~~quarter of ~~2014~~2015 to 4%52% above the 5-year average as of the end of the first ~~nine months~~quarter of ~~2015.~~2016. Customer spending in the natural gas shale plays has been limited due to associated gas being produced from unconventional oil wells in North America ~~specifically onshore shale production resulting from~~and the ~~broad application~~recent commissioning of ~~horizontal drilling and hydraulic fracturing techniques which continued during~~a number of new, large, LNG export facilities around the ~~first nine months of the year.~~world. As a result of natural gas production growth outpacing demand growth in the U.S., natural gas prices continue to be weak and are expected to remain below levels considered economical for new investments in numerous natural gas fields, with the current twelve-month forward strip price for natural gas averaging ~~$2.49~~$2.69 per mmBtu. If natural gas production growth continues to surpass demand growth in the U.S. and/or the supply of natural gas were to increase, whether ~~the supply comes~~ from conventional or unconventional production or associated natural gas production from oil wells, prices for natural gas could remain depressed for an extended period and result in fewer rigs drilling for natural gas.

Recent WTI crude, Brent crude and natural gas pricing trends are as follows:

Demand for the products and services of our offshore products segment is tied primarily to the long-term outlook for commodity prices. Demand for our well site services segment responds to shorter-term movements in 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 the general global economic environment and regulatory changes in the U.S. and international markets.

Our offshore products segment provides 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 drilling market. Sales of our offshore products and services depend primarily upon capital spending for offshore production systems and subsea pipelines, repairs and, to a lesser extent, upgrades of existing offshore drilling rigs and construction of new offshore drilling rigs and vessels. In this segment, we are 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. Such projects are generally undertaken by larger exploration, field development and production companies using relatively conservative crude oil and natural gas pricing assumptions. We believe some of these deepwater projects 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, ~~recent~~the continued declines in crude oil prices that have persisted since late 2014 and 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 given that, certain of these deep water projects, may become uneconomical relative to the risk ~~involved. In~~involved.In addition, shorter-cycle product sales (such as valves and elastomer products) and services for this segment have declined in ~~the first nine months of 2015.~~2015 and 2016.

Bidding and quoting activity along with receipts of purchase orders from customers for our offshore products segment continued during the first ~~nine months~~quarter of ~~2015,~~2016, albeit at a slower pace. Accordingly, backlog in our offshore products segment decreased ~~approximately 20%~~ to ~~$394~~$306 million at ~~September 30, 2015~~March 31, 2016 from ~~$490~~$340 million at December 31, ~~2014~~2015 due to project deferrals and delays in award timing resulting from the continued ~~low~~depressed commodity price environment. Backlog totaled ~~$543~~$474 million at ~~September 30, 2014.~~ March 31, 2015.

Our well site services business segment is primarily affected by drilling and completion activity in the U.S., including the Gulf of Mexico, and, to a lesser extent, Canada and the rest of the world. U.S. drilling and completion activity and, thus, our well site services segment results, are especially sensitive to near-term fluctuations in commodity prices and have, therefore, been significantly negatively affected by the material decline in crude oil prices from 2014 to the current date.

In the past few years, our industry has experienced a shift in 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. According to the most current rig count data published by Baker Hughes Incorporated, the U.S. oil rig count peaked in October 2014 at 1,609 rigs but has declined materially in recent months due to much lower crude oil prices, totaling ~~594~~343 rigs as of ~~October 23, 2015.~~April 22, 2016. The ~~October 23, 2015~~April 22, 2016 oil rig count comprised approximately ~~75%~~80% of total U.S. drilling activity. The remaining ~~25%~~20% of drilling activity is largely natural ~~gas-related.~~gas related. The U.S. natural gas-related working rig count has declined from more than 810 rigs at the beginning of 2012 to ~~193~~88 rigs as of ~~October 23, 2015,~~April 22, 2016, a more than 28 year low. Unless commodity prices improve, we expect that the rig count and demand from our customers for our well site services will remain low during 2016.

In our well site services business 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 throughout North America. Well complexity has increased with the continuing transition to multi-well pads and the drilling of longer laterals along with the increased number of frac stages completed in horizontal wells. Demand for our drilling services 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 Rocky Mountain area in the U.S., where we drill both liquids-rich and natural gas wells.

Demand for our land drilling and completion services businesses is correlated to changes in the drilling rig count in North America, as well as changes in the total number of wells expected to be drilled, total footage expected to be drilled and the number of drilled wells that are completed. The table below sets forth a summary of North American rig activity, as measured by Baker Hughes Incorporated, for the periods indicated.

The average North American rig count for the ~~nine~~three months ended ~~September 30, 2015~~March 31, 2016 decreased 965 rigs, or ~~44%~~57%, compared to the ~~nine~~three months ended ~~September 30, 2014~~March 31, 2015 in response to much lower crude oil prices from the levels experienced in 2014 and the first ~~nine months~~quarter of ~~2014.~~2015.

Exacerbating the steep declines in drilling activity, many of our exploration and production customers have been and are continuing to defer well completions. These deferred completions are referred to in the industry as drilled but uncompleted wells (or ~~“DUC’s”~~“DUCs”). Motivation on the part of our customers to defer completions is generally driven by the need to preserve cash ~~flow~~ in a weak commodity price environment and/or the desire to produce reserves at a later date with expectations that commodity prices will improve and/or completion costs will continue to decline. Given our ~~wellsite~~well site services segment’s exposure to completion activity, ~~DUC’s~~DUCs continue to have a negative impact on our results of operations.

The reduced demand for our products and services coupled with a reduction in the prices we charge our customers, particularly customers of our well site services business segment, have adversely affected our results of operations, cash flows and financial position as of and for the ~~nine-month period~~quarter ended ~~September 30, 2015.~~March 31, 2016. If the current pricing environment for oil and natural gas continues, our customers could be required to further reduce their capital expenditures, causing further declines in the demand for, and prices of, our products and ~~services. Additionally, many~~services, which would adversely affect our results of ~~our~~operations, cash flows and financial position during the remainder of 2016. Our customers have experienced a significant decline in their revenues and cash flows due to the commodity price declines and ~~some~~the fact that, due to the passage of time, many customers have less production hedged and, thus, are receiving spot prices for a greater percentage of their production. As a result, many customers have experienced a significant reduction in liquidity and access to ~~capital.~~the capital and debt markets. There have already been several exploration and production companies who have declared bankruptcy and others who are forced to sell assets in an effort to preserve liquidity. A continuation of these adverse conditions could ~~adversely~~ affect certain of our customers’ ability to pay or otherwise perform on their obligations to us. 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 or their insolvency or liquidation, may require us to incur asset impairment charges 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.

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 our business. We currently expect to spend a total of approximately ~~$125~~$45 million to ~~$130~~$50 million for capital expenditures during 2016, including approximately $19 million of carry-over from 2015, to upgrade and maintain our ~~completion services and drilling services equipment, to expand and upgrade our~~ offshore products facilities and completion services equipment and to fund various other capital spending ~~initiatives.~~projects. Whether planned expenditures will actually be spent in ~~2015~~2016 depends on industry conditions, project approvals and schedules, vendor delivery timing, ~~and~~ free cash flow ~~generation.~~generation, and careful monitoring of our levels of liquidity. We plan to fund our capital expenditures with available cash, internally generated funds and borrowings under our revolving credit facility. In our well site services ~~segment, the majority of our capital expenditures in the first nine months of 2015 were carryover from our 2014 budget. In this~~ segment, we continue to monitor industry capacity additions and will make future capital expenditure decisions based on an evaluation of both the market outlook and industry fundamentals.

We manage and measure our business performance in two distinct operating segments: well site services and offshore products. Selected financial information by business segment for the three ~~and nine~~ months ended ~~September 30,~~March 31, 2016 and 2015 ~~and 2014~~ is summarized below (in millions, except % amounts):

THREE MONTHS ENDED ~~SEPTEMBER 30, 2015~~MARCH 31, 2016 COMPARED TO THREE MONTHS ENDED ~~SEPTEMBER 30, 2014~~MARCH 31, 2015

We reported a net ~~income~~loss from continuing operations attributable to the Company for the quarter ended ~~September 30, 2015~~March 31, 2016 of ~~$1.7~~$13.2 million, or ~~$0.03~~$0.26 per diluted share, ~~including a higher effective tax rate driven primarily by a $3.2~~which included $1.6 million ~~or $0.06 per diluted share, tax valuation allowance recorded against the Company’s Brazilian~~

~~and Mexican deferred tax assets related to tax loss carryforwards and $0.7 million (pre-tax), or $0.01 per diluted share after-tax,~~ of severance ~~related costs.~~and other downsizing charges. Excluding these first quarter of 2016 charges, the ~~higher effective tax rate and severance costs,~~ net ~~income~~loss from continuing operations ~~for the third quarter of 2015~~ would have been ~~$5.6~~$12.2 million, or ~~$0.11~~$0.24 per diluted ~~share.These~~share. These results compare to net income from continuing operations attributable to the Company of $19.4 million, or $0.38 per diluted share, reported for the quarter ended ~~September 30, 2014~~March 31, 2015, including $2.1 million of ~~$58.4~~severance and other downsizing initiatives, and a higher effective tax rate driven primarily by a $2.3 million deferred tax adjustment for certain prior period non-deductible items related to stock-based compensation. Excluding the first quarter 2015 significant charges and higher effective tax rate, net income from continuing operations would have been $23.1 million, or ~~$1.07~~$0.45 per diluted share.

Revenues.Consolidated revenues decreased ~~$212.1~~$167.7 million, or ~~45%~~50%, in the ~~third~~first quarter of ~~2015~~2016 compared to the ~~third~~first quarter of ~~2014.~~2015.

Our well site services segment revenues decreased ~~$141.2~~$98.0 million, or ~~63%~~69%, in the ~~third~~first quarter of ~~2015~~2016 compared to the ~~third~~first quarter of ~~2014~~2015 due to decreases in both completion services and drilling services revenues. Our completion services revenues decreased ~~$105.3~~$77.1 million, or ~~61%~~65%, in the ~~third~~first quarter of ~~2015~~2016 compared to the ~~third~~first quarter of ~~2014,~~2015, primarily due to a ~~48%~~66% decrease in the number of service tickets completed as a result of ~~decreased~~continued depressed activity levels in the U.S. shale ~~basins and a 26% decrease in our revenue per completion services job due to pricing pressure from our customers and competitors.~~basins. Our drilling services revenues decreased ~~$35.9~~$20.9 million, or ~~69%~~88%, in the ~~third~~first quarter of ~~2015~~2016 compared to the ~~third~~first quarter of ~~2014~~2015 primarily as a result of significantly decreased utilization of our drilling rigs from an average of ~~90%~~44% during the ~~third~~first quarter of ~~2014~~2015 to an average of ~~33%~~6% in the ~~third~~first quarter of ~~2015~~2016 primarily due to the weak commodity price environment.

Our offshore products segment revenues decreased ~~$70.9~~$69.7 million, or ~~29%~~36%, in the ~~third~~first quarter of ~~2015~~2016 compared to the ~~third~~first quarter of ~~2014.~~2015. This decrease was primarily the result of lower contributions across ~~all~~most of the ~~Company’s~~segment’s product lines, ~~primarily~~especially drilling products and ~~shorter cycle businesses such~~service activities, weaker demand for shorter-cycle products (such as valves and elastomer ~~products, coupled with reduced service activities~~products) and a backlog position that has trended lower ~~during 2015.~~since mid-2014, partially offset by improved subsea product revenues.

Cost of Sales and Service.Our consolidated cost of sales and services decreased ~~$117.9~~$108.9 million, or ~~38%~~46%, in the ~~third~~first quarter of ~~2015~~2016 compared to the ~~third~~first quarter of ~~2014~~2015 as a result of decreased cost of sales and services at our well site services and offshore products segments of ~~$72.2~~$55.3 million, or ~~52%~~56%, and ~~$45.7~~$53.6 million, or ~~27%~~39%, respectively. With cost of sales and ~~services~~service decreasing at a slower rate than our revenues, ~~our~~ consolidated gross margin as a percentage of revenues decreased from ~~35%~~30% in the ~~third~~first quarter of ~~2014~~2015 to ~~27%~~24% in the ~~third~~first quarter of ~~2015~~2016 primarily due to lower margins realized in our ~~wellsite~~well site services segment in the ~~third~~first quarter of ~~2015.~~2016.

Our well site services segment cost of ~~sales~~services decreased ~~$72.2~~$55.3 million, or ~~52%~~56%, in the ~~third~~first quarter of ~~2015~~2016 compared to the ~~third~~first quarter of ~~2014~~2015 as a result of a ~~$49.8~~$40.3 million, or ~~49%~~50%, decrease in completion services cost of ~~sales~~services and a ~~$22.4~~$15.0 million, or ~~62%~~79%, decrease in drilling services cost of ~~sales.~~services. These decreases in cost of sales, which are strongly correlated to the revenue decreases in these businesses, reflect cost reduction measures implemented in response to the material decrease in revenues caused by continuing industry activity declines. Our well site services segment gross margin as a percentage of revenues decreased from ~~38%~~30% in the ~~third~~first quarter of ~~2014~~2015 to ~~20%~~(1)% in the ~~third~~first quarter of ~~2015.~~2016. Our completion services gross margin as a percentage of revenues decreased from ~~41%~~32% in the ~~third~~first quarter of ~~2014~~2015 to ~~21%~~1% in the ~~third~~first quarter of ~~2015~~2016 primarily due to the decline in revenues. Our drilling services gross margin as a percentage of revenues decreased from ~~31%~~20% in the ~~third~~first quarter of ~~2014~~2015 to ~~15%~~(39)% in the ~~third~~first quarter of ~~2015~~2016 primarily due to decreased rig utilization and cost absorption.

Our offshore products segment cost of sales decreased ~~$45.7~~$53.6 million, or ~~27%~~39%, in the ~~third~~first quarter of ~~2015~~2016 compared to the ~~third~~first quarter of ~~2014~~2015 in correlation with the decrease in revenues. Gross margin as a percentage of revenues ~~remained generally constant (32%~~increased from 29% in the ~~third~~first quarter of ~~2014 compared~~2015 to ~~31%~~33% in the ~~third~~first quarter of ~~2015).~~2016 due to strong project execution on several jobs nearing completion during the first quarter of 2016 combined with a lower overall cost structure.

Selling, General and AdministrativeExpenses.~~SG&A expenses~~Selling, general and administrative (SG&A) expense decreased ~~$10.6~~$5.6 million, or ~~24%~~16%, in the ~~third~~first quarter of ~~2015~~2016 compared to the ~~third~~first quarter of ~~2014~~2015 largely due to decreased compensation including ~~bonuses,~~ wages and benefits, short-term incentive compensation and stock compensation expense coupled with a decrease in ~~commissions.~~travel and entertainment expenses, commissions and professional fees. These decreases in SG&A expense were partially offset by an increase in our allowance for bad debts reserve.

Depreciation andAmortization.Depreciation and amortization expense ~~increased $0.7~~decreased $2.2 million, or 2%7%, in the third quarter of 2015 compared to the third quarter of 2014 primarily due to capital expenditures made during the previous twelve months across all segments of the Company along with increased depreciation and amortization expense related to the Montgomery Machine Company, Inc. (MMC) acquisition which closed at the beginning of the first quarter of ~~2015.~~2016 compared to the first quarter of 2015 primarily due to certain assets becoming fully depreciated since March 31, 2015 that, due to the downturn, have not been replaced.

Other Operating Expense (Income).Other operating expense (income) moved from other operating income ~~decreased $0.7~~of $2.3 million ~~or 36%,~~ in the ~~third~~first quarter of 2015 ~~compared~~ to other operating expense of $0.6 million in the ~~third~~first quarter of ~~2014~~2016 primarily due to ~~a decrease in offshore products royalty income and a net decrease~~increases in foreign currency exchange ~~gains.~~losses.

Operating(Loss) Income.Consolidated operating (loss) income ~~decreased $85.0~~moved from operating income of $33.8 million ~~or 93%,~~ in the ~~third~~first quarter of 2015 ~~compared~~ to an operating loss of $20.1 million in the ~~third~~first quarter of ~~2014~~2016 primarily as a result of decreases in operating income from our ~~wellsite~~well site services segment of ~~$66.6~~$42.4 million ~~due to~~resulting from decreased revenues caused by industry activity declines, and a ~~$21.4~~$13.2 million decrease in offshore products operating income.

Interest Expense and InterestIncome.Net interest expense decreased ~~$0.1~~$0.2 million, or 4%14%, in the ~~third~~first quarter of ~~2015~~2016 compared to the ~~third~~first quarter of ~~2014~~2015 primarily due to decreased amounts outstanding under our bank credit facility partially offset by ~~increased letters of credit and~~ unused commitment fees paid to our lenders. The weighted average interest rate on the Company’s total outstanding debt increased from ~~3.4%~~3.3% in the ~~third quarter of 2014 to 3.9% in the third~~first quarter of 2015 ~~primarily~~to 5.0% in the first quarter of 2016 due to an increased proportion of interest expense ~~from~~associated with unused commitment fees ~~which are calculated at a rate of 0.375%.~~coupled with lower average outstanding borrowings under our revolving credit facility.

Income Tax Expense.The Company’s income tax ~~expense~~provision for the ~~third quarter~~three months ended March 31, 2016 was a total tax benefit of ~~2015 was $4.0~~$8.0 million, ~~representing 69.9%~~or 37.7% of pretax ~~income,~~losses, compared to ~~$32.0~~income tax expense of $13.3 million, ~~representing 35.4%~~or 40.6% of pretax income, for the ~~third quarter of 2014.~~three months ended March 31, 2015. The ~~higher~~ effective tax rate for the three months ended March 31, 2015 included a $2.3 million deferred tax adjustment in the ~~third~~first quarter of 2015 ~~compared~~for certain prior period non-deductible items related to ~~the third quarter of 2014 was primarily due to a $3.2 million tax valuation allowance recorded against certain of the Company’s deferred tax assets.~~stock-based compensation.

~~Discontinued Operations.~~Other Comprehensive Income (Loss).~~Net~~Other comprehensive income (loss) increased from ~~discontinued operations for~~a loss of $14.5 million in the ~~third~~first quarter of 2015 ~~was less than $0.1 million compared~~ to ~~a net loss~~income of $1.5 million for the third quarter of 2014. Operating income included within discontinued operations was less than $0.1 million for the third quarter of 2015 and $0.5 million for the third quarter 2014. The increase in net income and the decrease in operating income year-over-year primarily relate to an income tax expense adjustment and an insurance premium refund related to discontinued operations in the third quarter of 2014.

~~Other Comprehensive~~~~Loss~~.~~Other comprehensive loss increased $2.2~~$1.6 million in the ~~third~~first quarter of ~~2015 compared to the third quarter of 2014~~2016 primarily as a result of fluctuations in the foreign currency exchange rates compared to the U.S. dollar for the foreign operations of our reportable segments (primarily in the United Kingdom, Canada, Brazil, and ~~Canada.)~~Argentina). The ~~average~~exchange rates of the Canadian dollar and the Brazilian real compared to the U.S. dollar strengthened by 6% and 8%, respectively, in the first quarter of 2016 compared to the exchange rates at December 31, 2015, while the exchange rates of the British pound ~~Brazilian real,~~ and ~~Canadian dollar~~the Argentine peso compared to the U.S. dollar weakened by ~~7%, 36%,~~3% and ~~17%~~11%, respectively, ~~for the three months ended September 30, 2015 compared to the three months ended September 30, 2014.~~

~~NINE MONTHS ENDED SEPTEMBER 30, 2015 COMPARED TO NINE MONTHS ENDED SEPTEMBER 30, 2014~~

We reported net income from continuing operations attributable to the Company for the nine months ended September 30, 2015 of $27.3 million, or $0.53 per diluted share, which included $4.5 million of severance and other downsizing charges and a higher effective tax rate driven primarily by a $3.5 million tax valuation allowance recorded against the Company’s Brazilian and Mexican deferred tax assets related to tax loss carryforwards and a $2.3 million deferred tax adjustment for certain prior period non-deductible items. Excluding these significant charges in the first nine months of 2015, net income from continuing operations would have been $36.4 million, or $0.71 per diluted share. These results compare to net income from continuing operations attributable to the Company for the nine months ended September 30, 2014 of $69.0 million, or $1.27 per diluted share, which included a loss on extinguishment of debt of $100.4 million, or $1.22 per diluted share after-tax, and $11.0 million, or $0.12 per diluted share after-tax, of transaction costs included in “Other operating expense” and SG&A expenses primarily related to the Spin-Off. Excluding these significant charges in the first nine months of 2014, net income from continuing operations would have been $141.8 million, or $2.61 per diluted share.

~~Revenues.~~~~Consolidated revenues decreased $470.4 million, or 35%, in the first nine months of 2015 compared to the first nine months of 2014.~~

Our well site services segment revenues decreased $315.1 million, or 50%, in the first nine months of 2015 compared to the first nine months of 2014 due to decreases in both completion services and drilling services revenues. Our completion services revenues decreased $219.8 million, or 46%, in the first nine months of 2015 compared to the first nine months of 2014, primarily due to a 32% decrease in the number of service tickets completed as a result of decreased activity in the active shale basins and a 22% decrease in our revenue per completion services job due to pricing pressure from our customers and competitors. Our drilling services revenues decreased $95.3 million, or 63%, in the first nine months of 2015 compared to the first nine months of 2014 primarily as a result of significantly decreased utilization of our drilling rigs from an average of 87% during the ~~first nine months of 2014 to an average of 37% in the first nine months of 2015 primarily due to the weak commodity price environment.~~

Our offshore products segment revenues decreased $155.3 million, or 22%, in the first nine months of 2015 compared to the first nine months of 2014. This decrease was primarily the result of lower contributions from drilling and subsea products and shorter cycle businesses such as elastomer products, coupled with reduced service activities and a backlog that has trended lower during 2015.

~~Cost of Sales and Service.~~Our consolidated cost of sales and services decreased $265.8 million, or 30%, in the first nine months of 2015 compared to the first nine months of 2014 as a result of decreased cost of sales at our well site services and offshore products segments of $160.2 million, or 40%, and $105.6 million, or 22%, respectively. With cost of sales and services decreasing at a slower rate than our revenues, consolidated gross margin as a percentage of revenues decreased from 34% in the first nine months of 2014 to 28% in the first nine months of 2015 primarily due to lower margins realized in our wellsite services segment in the first nine months of 2015.

Our well site services segment cost of sales decreased $160.2 million, or 40%, in the first nine months of 2015 compared to the first nine months of 2014 as a result of a $100.1 million, or 35%, decrease in completion services cost of sales and a $60.1 million, or 56%, decrease in drilling services cost of sales. These decreases in cost of sales, which are strongly correlated to the revenue decreases in these businesses, reflect cost reduction measures implemented in response to the material decrease in revenues caused by industry activity declines. Our well site services segment gross margin as a percentage of revenues decreased from 37% in the first nine months of 2014 to 24% in the first nine months of 2015. Our completion services gross margin as a percentage of revenues decreased from 39% in the first nine months of 2014 to 25% in the first nine months of 2015 primarily due to the decline in revenues. Our drilling services gross margin as a percentage of revenues decreased from 30% in the first nine months of 2014 to 18% in the first nine months of 2015 primarily due to decreased rig utilization and cost absorption.

Our offshore products segment cost of sales decreased $105.6 million, or 22%, in the first nine months of 2015 compared to the first nine months of 2014 in correlation with the decrease in revenues. Gross margin as a percentage of revenues remained constant at 31% in the first nine months of 2014 and 2015.

~~Selling, General and Administrative Expenses.~~SG&A expense decreased $27.4 million, or 21%, in the first nine months of 2015 compared to the first nine months of 2014 largely due to decreased compensation including bonuses, wages and benefits and stock compensation expense coupled with a decrease in commissions and bad debt expense.

~~Depreciation and Amortization.~~Depreciation and amortization expense increased $3.8 million, or 4%, in the first nine months of 2015 compared to the first nine months of 2014 primarily due to capital expenditures made during the previous twelve months across all segments of the Company along with increased depreciation and amortization expense related to the MMC acquisition which closed at the beginning of the first quarter of 2015.

~~Other Operating Expense (Income).~~Other operating expense (income) moved from other operating expense of $9.5 million in the first nine months of 2014 to other operating income of $2.1 million in the first nine months of 2015 primarily due to transaction costs incurred in 2014 in connection with the Spin-Off totaling $11.0 million.

~~Operating Income.~~Consolidated operating income decreased $169.3 million, or 78%, in the first nine months of 2015 compared to the first nine months of 2014 primarily as a result of decreases in operating income from our wellsite services segment of $150.0 million, resulting from decreased revenues caused by industry activity declines, and a $37.6 million decrease in offshore products operating income.

~~Interest Expense and Interest Income.~~Net interest expense decreased $10.6 million, or 71%, in the first nine months of 2015 compared to the first nine months of 2014 primarily due to the Company’s repurchase of the remaining $966.0 million aggregate principal amount of our 6 1/2% and 5 1/8% Notes in the second quarter of 2014, partially offset by increased amounts outstanding under our bank credit facility coupled with unused commitment fees paid to our lenders. The weighted average interest rate on the Company’s total outstanding debt decreased from 6.3% in the first nine months of 2014 to 3.5% in the first nine months of 2015 primarily due to the repurchase of the 6 1/2% and 5 1/8% Notes in the second quarter of 2014.

~~Loss on Extinguishment of Debt.~~During the first nine months of 2014, we recognized losses on the extinguishment of debt totaling $100.4 million primarily due to the repurchase of our remaining 6 1/2% Notes and 5 1/8% Notes, resulting in a loss of $96.7 million consisting of the premium paid over book value for the Notes and the write-off of unamortized deferred financing costs associated with the Notes. In addition, as a result of the refinancing of our bank debt in the second quarter of 2014, we recognized a loss of $3.7 million (net of $1.8 million allocated to discontinued operations for the Canadian portion of the facility) from the write-off of unamortized deferred financing costs on our existing credit facility.

~~Income Tax Expense.~~The Company’s income tax provision for the first nine months of 2015 was $18.6 million, representing 40.6% of pretax income, compared to $36.5 million, representing 34.6% of pretax income, for the first nine months of 2014. The increase in the effective tax rate from the prior year was largely the result of the $3.5 million tax valuation allowance recorded against certain of the Company’s deferred tax assets, a $2.3 million deferred tax adjustment for certain prior period non-deductible items in 2015, partially offset by reduced domestic income in 2015 due to the impact of the industry downturn in activity and the loss incurred in 2014 from the extinguishment of debt associated with the debt refinancings completed in conjunction with the Spin-Off.

~~Discontinued Operations.~~Net income from discontinued operations for the first nine months of 2015 was $0.2 million compared to net income of $51.6 million for the first nine months of 2014. There were no revenues reported within discontinued operations during the first nine months of 2015 compared to $404.2 million for the first nine months of 2014 due to the Spin-Off on May 30, 2014. Operating income included within discontinued operations was $0.4 million and $79.9 million for the first nine months of 2015 and 2014, respectively. The decreases in revenue and operating income year-over-year primarily relate to the absence of accommodations operations for the first nine months of 2015 compared to five months of operations in the first nine months of 2014.

~~Other Comprehensive Income (Loss).~~Other comprehensive income (loss) decreased from income of $10.3 million in the first nine months of 2014 to a loss of $20.0 million in the first nine months of 2015 primarily as a result of fluctuations in the foreign currency exchange rates compared to the U.S. dollar for the foreign operations of our reportable segments (primarily in Brazil, Canada and the United Kingdom). The average exchange rates of the British pound, Brazilian real, and Canadian dollar compared to the U.S. dollar weakened by 8%, 27%, and 13%, respectively, for the nine months ended September 30, 2015 compared to the nine months ended September 30, 2014.same period.

Our primary liquidity needs are to fund operating and capital expenditures, which in the past have included expanding and upgrading our offshore 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 our credit facilities and capital markets transactions.

Despite the weak market conditions, cash totaling ~~$252.5~~$56.8 million was provided by continuing operations during the first ~~nine months~~quarter of ~~2015~~2016 compared to ~~$141.4~~$114.4 million provided by continuing operations during the first ~~nine months~~quarter of ~~2014.~~2015. During the first ~~nine months~~quarter of ~~2015, $116.1~~2016, $44.9 million was provided from net working capital reductions, primarily due to decreases in ~~receivables partially offset by decreases in accounts payable and accrued liabilities.~~receivables. During the first ~~nine months~~quarter of ~~2014, $119.0~~2015, $51.8 million was ~~used to fund~~provided from net working capital reductions, primarily due to ~~a build~~decreases in ~~accounts receivable in addition to income tax and interest payments.~~receivables.

Cash was used in investing activities during the ~~first nine~~three months ~~of 2015~~ended March 31, 2016 in the amount of ~~$124.3~~$9.7 million compared to ~~$140.8~~$71.6 million used in ~~continuing operations~~investing activities during the ~~first nine~~three months ~~of 2014.~~ended March 31, 2015. Capital expenditures for continuing operations totaled ~~$92.3~~$10.3 million and ~~$142.6~~$38.3 million during the ~~first nine~~three months ofended March 31, 2016 and 2015, ~~and 2014,~~ respectively. Capital expenditures in both years consisted principally of purchases of completion ~~services equipment, upgrading and maintenance of our drilling~~ services equipment, expansion and upgrading of our offshore products segment facilities and various other capital spending initiatives.

On January 2, 2015, we acquired all of the equity of MMC. ~~Subject to customary post-closing adjustments, total~~Total transaction consideration was $33.4 million, ~~in cash,~~ net of cash acquired, funded from amounts available under the Company’s credit facility.

We currently expect to spend a total of approximately ~~$125~~$45 million to ~~$130~~$50 million for capital expenditures during 2016 including approximately $19 million of carry-over from 2015, to upgrade and maintain our ~~completion services and drilling services equipment, to expand and upgrade our~~ offshore products facilities and completion services equipment, and to fund various other capital spending initiatives. Whether planned expenditures will actually be spent in ~~2015~~2016 depends on industry conditions, project approvals and schedules, vendor delivery timing, ~~and~~ free flow cash ~~generation.~~generation and careful monitoring of our levels of liquidity. We plan to fund these capital expenditures with available cash, internally generated funds and borrowings under our 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, 2015,~~March 31, 2016, we had cash totaling ~~$84.4~~$41.9 million held by foreign subsidiaries, primarily in Singapore, ~~and~~ the United ~~Kingdom.~~Kingdom and Canada. Our intent is to utilize at least a portion of these cash balances for future investment outside the United States. Approximately ~~$42~~$37 million of cash held by our foreign subsidiaries can be repatriated without triggering any incremental tax consequences.

Net cash of ~~$95.8~~$40.4 million was used in financing activities during the ~~first nine~~three months ended March 31, 2016, primarily as a result of ~~2015, primarily associated with repurchases~~repayments of outstanding debt under our ~~common stock totaling $104.6 million.~~revolving credit facility. Net cash of ~~$286.3~~$23.6 million was used in financing activities during the ~~first nine~~three months ~~of 2014,~~ended March 31, 2015, primarily as a result of ~~the repayment of our 6 1/2% and 5 1/8% Notes and~~ repurchases of our common stock totaling $77.4 million partially offset by ~~net cash received from the Spin-Off (the $750 million special cash dividend received from Civeo) and~~ borrowings under our revolving credit facility.

We believe that cash on hand, cash flow from operations and available borrowings under our 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, suchadditional 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 the issuance of additional equity securities could result in significant dilution to stockholders.

Share Repurchase Program.On September 6, 2013, the Company announced an increase in its Board-authorized Company share repurchase program from $200 million to $500 million providing for the repurchase of the Company’s common stock, par value $.01 per share. On July 29, 2015, the Company’s Board of Directors approved the termination of our then existing share repurchase program and authorized a new program providing for the repurchase of up to $150 million of the Company’s common stock, par value $.01 per share. The new program is set to expire on July 29, 2016. During the ~~nine months ended September 30, 2015, a total~~first quarter of ~~$105.9 million~~2016, there were no repurchases of our common stock ~~(2,674,218 shares) were repurchased~~made under ~~these programs compared to $155.4 million (1,704,127 shares) during the nine months ended September 30, 2014.~~our current program. As of ~~September 30, 2015,~~March 31, 2016, a total of $456.0 million of our stock (6,902,748 shares, or approximately 13% of the outstanding shares of our common stock at the initiation of our initial share repurchase authorization in August 2012) had been repurchased under these programs. The amount remaining available under our current share repurchase authorization as of ~~September 30, 2015~~March 31, 2016 was ~~approximately~~ $136.8 million. Subject to applicable securities laws, such purchases will be at such times and in such amounts as the Company deems appropriate.

Credit ~~Facilities~~Facilities..~~In connection with the Spin-Off, the~~The Company ~~terminated its then existing bank credit facility on May 28, 2014 and entered into~~has a ~~new~~ $600 million senior secured revolving credit facility (the revolving credit facility). with~~The Company has~~ an option to increase the maximum borrowings under the new facility to $750 million contingent upon additional lender commitments prior to its ~~maturity. The facility matures~~maturity on May 28, 2019. The credit facility is governed by a Credit Agreement dated as of May 28, 2014 (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~~Bank; Royal Bank of Canada, as Syndication ~~agent,~~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 (as defined in the Credit Agreement). During the first ~~nine months~~quarter of ~~2015,~~2016, our applicable margin over LIBOR was 1.50%.The weighted average interest rate on the Company’s total outstanding debt ~~decreased~~increased from ~~6.3%~~3.3% in the first ~~nine months~~quarter of ~~2014~~2015 to ~~3.5%~~5.0% in the first ~~nine months~~quarter of ~~2015 primarily due to the repurchase of the 6 1/2% and 5 1/8% Notes~~2016. The increase in the ~~second quarter~~weighted average interest rate was attributable to an increased proportion of ~~2014.~~interest expense associated with unused commitment fees coupled with lower average outstanding borrowings under our revolving credit facility. 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~~quarter of ~~2015.~~ 2016.

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, 2015,~~March 31, 2016, we were in compliance with our debt covenants and expect to continue to be in compliance during the remainder of ~~2015.~~2016. 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.

As of ~~September 30, 2015,~~March 31, 2016, we had ~~$153.8~~$86.1 million in borrowings outstanding under the Credit Agreement and ~~$39.5~~$38.4 million of outstanding letters of ~~credit, leaving $406.7~~credit. As of March 31, 2016, $364.6 million was available to be drawn under the credit facility. The total amount available to be drawn under our revolving credit ~~facility.~~facility was less than the lender commitments as of March 31, 2016, due to the maximum leverage ratio covenant in our credit facility which serves to limit borrowings, and such availability is expected to be further reduced as our trailing twelve months EBITDA moves lower into 2016 given that, in accordance with the Credit Agreement, total debt cannot exceed 3.25 times our trailing twelve months EBITDA.

Our total debt represented ~~11.3%~~6.9% of our combined total debt and stockholders’ equity at ~~September 30, 2015~~March 31, 2016 compared to ~~9.9%~~9.3% at December 31, ~~2014~~2015 and ~~11.8%~~14.0% at ~~September 30, 2014.~~March 31, 2015.

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 ~~2014~~2015 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, please see Note 2, “Recent Accounting Pronouncements.”

As of ~~September 30, 2015,~~March 31, 2016, we had no off-balance sheet arrangements as defined in Item 303(a)(4)(ii) of Regulation S-K.

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.

We have credit facilities that are subject to the risk of higher interest charges associated with increases in interest rates. As of ~~September 30, 2015,~~March 31, 2016, we had floating-rate obligations totaling ~~approximately $153.8~~$86.1 million drawn under our 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, 2015~~March 31, 2016 levels, our consolidated interest expense would increase by a total of approximately ~~$1.5~~$0.9 million annually.

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 exchange rate risks in areas outside the U.S. (primarily in our offshore 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~~three months ended ~~September 30, 2015,~~March 31, 2016, our reported foreign exchange ~~gains~~losses were ~~$1.3~~$0.8 million and are included in “Other operating expense (income) ~~expense”~~” in the ~~Condensed~~ Consolidated Statements of ~~Income.~~Operations. In order to reduce our exposure to fluctuations in currency exchange rates, we may enter into foreign exchange agreements with financial institutions. As of ~~September 30, 2015~~March 31, 2016 and December 31, ~~2014,~~2015, we had outstanding foreign currency forward purchase contracts with notional amounts of $4.6 million and $5.4 million, respectively, related to expected cash flows denominated in Euros. AsWe recorded no other comprehensive losses as a result of these contracts ~~we recorded other comprehensive income of $0.3~~for the three months ended March 31, 2016 and less than $0.1 million for the ~~nine~~three months ended ~~September 30,~~March 31, 2015.

Our accumulated other comprehensive loss, reported as a component of stockholders’ equity, decreased from $50.7 million at December 31, 2015 to $49.1 million at March 31, 2016, primarily as a result of foreign currency exchange rate differences. Our accumulated other comprehensive loss is primarily related to fluctuations in the foreign currency exchange rates compared to the U.S. dollar which are used to remeasure the foreign operations of our reportable segments (primarily in the United Kingdom, Canada, Brazil, and Argentina). The exchange rates of the Canadian dollar and the Brazilian real compared to the U.S. dollar strengthened by 6% and 8%, respectively, in the first quarter of 2016 compared to the exchange rates at December 31, 2015, while the exchange rates of the British pound and the Argentine peso compared to the U.S. dollar weakened by 3% and 11%, respectively, during the same period.

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, 2015~~March 31, 2016 at the reasonable assurance level.

In January 2016, we completed the implementation of a new financial and inventory accounting system in our completion services business. We believe the new software will enhance our internal controls over financial reporting, and we believe that we have taken the necessary steps to maintain appropriate internal control over financial reporting during this period of system change. We plan to monitor controls through and around the system to provide reasonable assurance that controls are effective.

During the ~~nine~~three months ended ~~September 30, 2015~~March 31, 2016 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), ~~or in~~ other ~~factors,~~than described above, which have materially affected our internal control over financial reporting, or are reasonably likely to materially affect our internal control over financial reporting.

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. During 2014 and early 2015, a number of lawsuits were filed by current and former employees, in Federal Court against the Company and or one of its subsidiaries, 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 ~~seek~~are seeking recovery on their own behalf ~~and seek certification~~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 ~~is actively defending~~has settled the vast majority of these claims ~~in Federal Court while pursuing~~and is evaluating potential ~~resolution of the claims through settlement in appropriate cases. The Company recorded a liability in earlier periods~~settlements for the ~~estimated amount of any~~remaining individual plaintiffs’ claims which are not expected ~~settlement.~~ to be significant.

~~For additional information regarding legal proceedings, see “Part I, Item 1. Legal Proceedings” in our 2014 Form 10-K.~~

“Item 1A. Risk Factors” of our ~~2014~~2015 Form 10-K includes a detailed discussion of our risk factors. The risks described in this Quarterly Report on Form 10-Q and our ~~2014~~2015 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 ~~2014~~2015 Form 10-K.

Delaware	76-0476605
(State or other jurisdiction of	~~(I.R.S. Employer~~
incorporation or organization)	(I.R.S. Employer Identification No.)

Three Allen Center, 333 Clay Street, Suite 4620,	77002
Houston, Texas	(Zip Code)
(Address of principal executive offices)

Large Accelerated Filer [X]	Accelerated Filer [ ]

Non-Accelerated Filer [ ] (Do not check if a smaller reporting company)	Smaller Reporting Company [ ]

	Page No.
Part I -- FINANCIAL INFORMATION

Item 1. Financial Statements:

Condensed Consolidated Financial Statements
Unaudited Condensed Consolidated Statements of ~~Income~~Operations	3
Unaudited Condensed Consolidated Statements of Comprehensive Income (Loss)	4
Consolidated Balance Sheets	5
Unaudited Condensed Consolidated Statements of Cash Flows	6
Unaudited Condensed Consolidated Statement of Stockholders’ Equity	7
Notes to Unaudited Condensed Consolidated Financial Statements	8 – 1715

Cautionary Statement Regarding Forward-Looking Statements	1816

Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations	1816 – 2824

Item 3. Quantitative and Qualitative Disclosures About Market Risk	~~28 – 29~~25

Item 4. Controls and Procedures	2925 – 26


Part II -- OTHER INFORMATION

Item 1. Legal Proceedings	~~29 – 30~~26

Item 1A. Risk Factors	3026

Item ~~2. Unregistered~~2.Unregistered Sales of Equity Securities and Use of Proceeds	3027

Item 6. Exhibits	31

~~(a) Index of Exhibits~~	3127

Signature Page	3228

	THREE MONTHS ENDED						NINE MONTHS ENDED
	SEPTEMBER 30,						SEPTEMBER 30,
	2015			2014			2015			2014
Net income	$	1,729		$	56,910		$	27,481		$	120,552

Other comprehensive income (loss):
Foreign currency translation adjustment		(15,415	)		(13,144	)		(20,132	)		10,301
Unrealized gain on forward contracts, net of tax		88			3			160			4
Total other comprehensive income (loss)		(15,327	)		(13,141	)		(19,972	)		10,305

Comprehensive income (loss)		(13,598	)		43,769			7,509			130,857
Less: Comprehensive loss attributable to noncontrolling interest		--			(10	)		--			(16	)
Comprehensive income (loss) attributable to Oil States International, Inc.	$	(13,598	)	$	43,779		$	7,509		$	130,873

	THREE MONTHS ENDED
	MARCH 31,
	2016			2015

Net (loss) income	$	(13,239	)	$	19,568

Other comprehensive income (loss):
Foreign currency translation adjustment		1,553			(14,490	)
Unrealized loss on forward contracts, net of tax		--			(52	)
Total other comprehensive income (loss)		1,553			(14,542	)

Comprehensive (loss) income attributable to Oil States International, Inc.	$	(11,686	)	$	5,026

	[X]	QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
		For the quarterly period ended ~~September 30, 2015~~March 31, 2016

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

		For the transition period from _________________________ to

	Common Stock		Additional Paid-In Capital			Retained Earnings			Accumulated Other Comprehensive Income (Loss)			Treasury Stock			Total Stockholders' Equity
Balance, December 31, 2015	$	617	$	712,980		$	1,179,863		$	(50,698	)	$	(587,090	)	$	1,255,672
Net loss							(13,239	)								(13,239	)
Currency translation adjustment (excluding intercompany notes)										1,783						1,783
Currency translation adjustment on intercompany notes										(230	)					(230	)
Exercise of stock options, including tax impact				(2,278	)											(2,278	)
Amortization of restricted stock compensation				4,168												4,168
Stock option expense				912												912
Restricted stock awards granted		6		(6	)											--
Surrender of stock to pay taxes on restricted stock awards													(3,883	)		(3,883	)
Other													(1	)		(1	)
Balance,March 31, 2016	$	623	$	715,776		$	1,166,624		$	(49,145	)	$	(590,974	)	$	1,242,904

	Common Stock		Additional Paid- In Capital			Retained Earnings		Accumulated Other Comprehensive Income (Loss)			Treasury Stock			Total Stockholders' Equity
Balance, December 31, 2014	$	610	$	685,232		$	1,151,266	$	(22,100	)	$	(474,351	)	$	1,340,657
Net income.							27,481								27,481
Currency translation adjustment (excluding intercompany notes)									(16,295	)					(16,295	)
Currency translation adjustment on intercompany notes									(3,837	)					(3,837	)
Unrealized gain on forward contracts, net of tax									160						160
Exercise of stock options, including tax impact		2		2,932											2,934
Amortization of restricted stock compensation				13,993											13,993
Stock option expense				2,252											2,252
Restricted stock awards granted		4		(4	)										--
Surrender of stock to pay taxes on stock option exercises and restricted stock awards												(6,786	)		(6,786	)
OIS common stock withdrawn from deferred compensation plan				(3	)							3			--
Share repurchases												(105,916	)		(105,916	)
Balance,September 30, 2015	$	616	$	704,402		$	1,178,747	$	(42,072	)	$	(587,050	)	$	1,254,643

	Estimated	SEPTEMBER 30,			DECEMBER 31,			Estimated				MARCH 31,			DECEMBER 31,
	Useful Life (years)	2015			2014			Useful Life				2016			2015
Property, plant and equipment, net:
Land	Land	$	26,375		$	29,850						$	27,239		$	26,334
Buildings and leasehold improvements	3-40		181,854			175,421		3	-	40	years		185,623			185,274
Machinery and equipment	2-28		459,858			438,980		2	-	28	years		449,321			462,054
Completion services equipment	2-10		419,761			387,165		2	-	10	years		438,453			421,386
Office furniture and equipment	1-10		32,024			30,647		3	-	10	years		40,552			32,200
Vehicles	1-10		127,307			129,922		2	-	10	years		124,322			125,211
Construction in progress	Construction in progress		82,450			74,088							88,398			92,800
Total property, plant and equipment	Total property, plant and equipment		1,329,629			1,266,073							1,353,908			1,345,259
Accumulated depreciation	Accumulated depreciation		(681,299	)		(616,227	)						(731,375	)		(706,534	)
		$	648,330		$	649,846						$	622,533		$	638,725

	THREE MONTHS ENDEDSEPTEMBER 30,
	2015					2014
	Income (Loss)			Shares		Income (Loss)			Shares
Basic:
Net income attributable to Oil States International, Inc.	$	1,729				$	56,920
Less: Undistributed net income allocable to participating securities		(36	)				(1,187	)
Undistributed net income applicable to common stockholders		1,693					55,733
Less: (Income) loss from discontinued operations, net of tax		(23	)				1,467
Add: Undistributed net income (loss) from discontinued operations allocable to participating securities		--					(31	)
Income from continuing operations applicable to Oil States International, Inc. common stockholders – Basic	$	1,670			50,011	$	57,169			52,979
Diluted:
Income from continuing operations applicable to Oil States International, Inc. common stockholders – Basic	$	1,670			50,011	$	57,169			52,979
Effect of dilutive securities:
Undistributed net income reallocated to participating securities		--			--		7			--
Options on common stock		--			30		--			298
Restricted stock awards and other		--			9		--			17
Income from continuing operations applicable to Oil States International, Inc. common stockholders – Diluted		1,670			50,050		57,176			53,294
Income (loss) from discontinued operations, net of tax, applicable to Oil States International, Inc. common stockholders		22					(1,436	)
Net income attributable to Oil States International, Inc. common stockholders – Diluted	$	1,692			50,050	$	55,740			53,294

	THREE MONTHS ENDED MARCH 31,
	2016					2015
	Income			Shares		Income			Shares
Basic:
Net (loss) income attributable to Oil States International, Inc.	$	(13,239	)			$	19,568
Less: Undistributed net income allocable to participating securities		--					(409	)
Undistributed net (loss) income applicable to common stockholders		(13,239	)				19,159
Less: Loss (income) from discontinued operations, net of tax		3					(166	)
Add: Undistributed net income from discontinued operations allocable to participating securities		--					3
(Loss) income from continuing operations applicable to Oil States International, Inc. common stockholders – Basic	$	(13,236	)		50,042	$	18,996			50,826
Diluted:
(Loss) income from continuing operations applicable to Oil States International, Inc. common stockholders – Basic	$	(13,236	)		50,042	$	18,996			50,826
Effect of dilutive securities:
Undistributed net income reallocated to participating securities		--			--		1			--
Options on common stock		--			--		--			101
Restricted stock awards and other		--			--		--			9
(Loss) income from continuing operations applicable to Oil States International, Inc. common stockholders – Diluted		(13,236	)		50,042		18,997			50,936
(Loss) income from discontinued operations, net of tax, applicable to Oil States International, Inc. common stockholders		(3	)				163
Undistributed net income reallocated to participating securities		--					--
Net (loss) income attributable to Oil States International, Inc. common stockholders – Diluted	$	(13,239	)		50,042	$	19,160			50,936

	NINE MONTHS ENDED SEPTEMBER 30,
	2015					2014
	Income (Loss)			Shares		Income (Loss)			Shares
Basic:
Net income attributable to Oil States International, Inc.	$	27,481				$	120,544
Less: Undistributed net income allocable to participating securities		(575	)				(1,846	)
Undistributed net income applicable to common stockholders		26,906					118,698
Less: Income from discontinued operations, net of tax		(224	)				(51,571	)
Add: Undistributed net income from discontinued operations allocable to participating securities		5					790
Income from continuing operations applicable to Oil States International, Inc. common stockholders – Basic	$	26,687			50,422	$	67,917			53,119
Diluted:
Income from continuing operations applicable to Oil States International, Inc. common stockholders – Basic	$	26,687			50,422	$	67,917			53,119
Effect of dilutive securities:
Undistributed net income reallocated to participating securities		1			--		6			--
Options on common stock		--			70		--			286
Restricted stock awards and other		--			9		--			17
Income from continuing operations applicable to Oil States International, Inc. common stockholders – Diluted		26,688			50,501		67,923			53,422
Income from discontinued operations, net of tax, applicable to Oil States International, Inc. common stockholders		219					50,781
Undistributed net income reallocated to participating securities		--					4
Net income attributable to Oil States International, Inc. common stockholders – Diluted	$	26,907			50,501	$	118,708			53,422

	Three Months Ended			Three Months Ended			Nine Months Ended			Nine Months Ended
	September 30, 2015			September 30, 2014			September 30, 2015			September 30, 2014
Revenues
Accommodations	$	--		$	--		$	--		$	404,132
Tubular services	$	--		$	--		$	--		$	--

Income(loss)from Accommodations discontinued operations:
Income from discontinued operations before income taxes	$	36		$	512		$	324		$	62,436
Income tax expense		(13	)		(1,965	)		(117	)		(11,063	)
Net (loss) income from discontinued operations, net of tax	$	23		$	(1,453	)	$	207		$	51,373

Income(loss)from Tubular services discontinued operations:
(Loss) Income from discontinued operations before income taxes	$	--		$	(21	)	$	27		$	315
Income tax (expense) benefit		--			7			(10	)		(118	)
Net (loss) income from discontinued operations, net of tax	$	--		$	(14	)	$	17		$	197

	September 30,		December 31,		March 31, 2016		December 31, 2015
	2015		2014
Revolving credit facility, which matures May 28, 2019, with available commitments up to $600 million and with a weighted average interest rate of 3.5% for the nine month period ended September 30, 2015	$	153,767	$	140,684
Revolving credit facility, which matures May 28, 2019, with lending commitments up to $600 million ⁽¹⁾					$	83,586	$	120,191
Capital lease obligations and other debt		6,359		6,681		6,096		6,229
Total debt		160,126		147,365		89,682		126,420
Less: Current portion		515		530		524		533
Total long-term debt and capitalized leases	$	159,611	$	146,835	$	89,158	$	125,887

	SEPTEMBER 30,			DECEMBER 31,			MARCH 31,			DECEMBER 31,
	2015			2014			2016			2015
Inventories, net:
Finished goods and purchased products	$	101,213		$	94,955		$	102,273		$	97,362
Work in process		48,331			49,631			45,355			42,182
Raw materials		89,060			97,780			80,549			86,236
Total inventories		238,604			242,366			228,177			225,780
Allowance for excess, damaged, or obsolete inventory		(12,210	)		(9,876	)		(12,678	)		(12,898	)
	$	226,394		$	232,490		$	215,499		$	212,882

	Stock Options			Restricted Stock Awards			Stock Options			Restricted Stock Awards
	Number of Shares						Number of Shares
Outstanding at January 1, 2015		1,007,686			1,106,670
Outstanding at January 1, 2016								770,181			1,171,884
Granted		119,370			558,748			--			563,402
Options Exercised/Stock Vested		(175,260	)		(440,599	)		(16,714	)		(443,697	)
Cancelled		(18,996	)		(34,824	)		(2,744	)		(11,744	)
Outstanding at September 30, 2015		932,800			1,189,995
Outstanding at March 31, 2016								750,723			1,279,845

		Average Price⁽¹⁾						Average Price⁽¹⁾
		WTI		Brent		Henry Hub		WTI		Brent		Henry Hub
Quarter	Quarter	Crude		Crude		Natural Gas		Crude		Crude		Natural Gas
Ended	Ended	(per bbl)		(per bbl)		(per mmBtu)		(per bbl)		(per bbl)		(permmBtu)
3/31/2016								$	33.35	$	33.84	$	1.99
12/31/2015									41.94		43.56		2.12
9/30/2015		$	46.49	$	50.44	$	2.76		46.49		50.44		2.76
6/30/2015			57.85		61.65		2.75		57.85		61.65		2.75
3/31/2015			48.49		53.98		2.90		48.49		53.98		2.90
12/31/2014			73.21		76.43		3.78
12/31/2014⁽²⁾									73.21		76.43		3.78
9/30/2014			97.87		101.90		3.96		97.87		101.90		3.96
6/30/2014			103.35		109.69		4.61		103.35		109.69		4.61
3/31/2014			98.68		108.14		5.18		98.68		108.14		5.18
12/31/2013			97.50		109.23		3.85		97.50		109.23		3.85
9/30/2013			105.83		110.23		3.55

											Average Drilling Rig Count for
	Average Drilling Rig Count for								As Of		Three Months Ended
	Three Months Ended				Nine Months Ended				April 22,		March 31,
	September 30, 2015		September 30, 2014		September 30, 2015		September 30, 2014		2016		2016		2015
U.S. Land – Oil		635		1,533		783		1,472		323		420		1,052
U.S. Land – Natural gas and other		198		309		230		315		82		104		279
U.S. Offshore		32		61		38		58		26		27		49
Total U.S.		865		1,903		1,051		1,845		431		551		1,380
Canada		191		385		200		371		40		173		309
Total North America		1,056		2,288		1,251		2,216		471		724		1,689

Period	Total Number of Shares Purchased	Average Price Paid per Share		Total Number of Shares Purchased as Part of Publicly Announced Program	Approximate Dollar Value of Shares That May Yet Be Purchased Under the Program⁽¹⁾
July 1, 2015 –July 31, 2015	1,032⁽²⁾		$35.53⁽³⁾	--	$ 150,000,000
August 1, 2015 –August 31, 2015	349,488		$27.41⁽⁴⁾	349,488	$ 140,422,090
September 1, 2015 -September 30, 2015	133,076		$27.01⁽⁴⁾	133,076	$ 136,827,937
Total	483,596		$27.31	482,564	$ 136,827,937

Period	Total Number of Shares Purchased	Average Price Paid per Share	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 orPrograms⁽¹⁾
January 1, 2016 – January 31, 2016	488⁽²⁾	$27.25⁽³⁾	--	$ 136,827,937
February 1, 2016 – February 29, 2016	158,236⁽⁴⁾	$24.42⁽⁵⁾	--	$ 136,827,937
March 1, 2016 - March 31, 2016	182⁽⁶⁾	$30.47⁽⁷⁾	--	$ 136,827,937
Total	158,906	$24.44	--	$ 136,827,937

	⁽³⁾	~~The price paid per share was based on the closing price of the Company’s common stock on July 2, 2015 and July 28, 2015 which represents the dates the restrictions lapsed on such shares.~~
	~~(4)~~	^{The price paid per share was based on the weighted average closing price of theour Company’s common stock on January 1, 2016 which represents the date the restrictions lapsed on such shares.}

Date:	April 28, 2016	By	/s/ LLOYD A. HAJDIK
			Lloyd A. Hajdik
			Senior Vice President, Chief Financial Officer and Treasurer (Duly Authorized Officer and Principal Financial Officer)


Date:	April 28, 2016	By	/s/ SARAH A. MUNSON
			Sarah A. Munson
			Vice President, Controller and Chief Accounting Officer (Duly Authorized Officer and Chief Accounting Officer)

~~Exhibit No.~~		~~Description~~

3.1	—	Amended and Restated Certificate of Incorporation (incorporated by reference to Exhibit 3.1 to the Company’s Annual Report on Form 10-K for the year ended December 31, 2000, as filed with the Commission on March 30, 2001 (File No. 001-16337)).

~~3.2~~	—
3.2	—	Third Amended and Restated Bylaws (incorporated by reference to Exhibit 3.1 to the Company’s Current Report on Form 8-K, as filed with the Commission on March 13, 2009 (File No. 001-16337)).

~~3.3~~	—
3.3	—	Certificate of Designations of Special Preferred Voting Stock of Oil States International, Inc. (incorporated by reference to Exhibit 3.3 to the Company’s Annual Report on Form 10-K for the year ended December 31, 2000, as filed with the Commission on March 30, 2001 (File No. 001-16337)).




31.1*	—	Certification of Chief Executive Officer of Oil States International, Inc. pursuant to Rules 13a-14(a) or 15d-14(a) under the Securities Exchange Act of 1934.

31.2*	—	Certification of Chief Financial Officer of Oil States International, Inc. pursuant to Rules 13a-14(a) or 15d-14(a) under the Securities Exchange Act of 1934.

32.1**	—	Certification of Chief Executive Officer of Oil States International, Inc. pursuant to Rules 13a-14(b) or 15d-14(b) under the Securities Exchange Act of 1934.

32.2**	—	Certification of Chief Financial Officer of Oil States International, Inc. pursuant to Rules 13a-14(b) or 15d-14(b) under the Securities Exchange Act of 1934.


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~~Document.

101.LAB*	—	XBRL Taxonomy Extension Label Linkbase Document

101.PRE*	—	XBRL Taxonomy Extension Presentation Linkbase Document

~~Date:~~ ~~October 30, 2015~~	By	~~/s/ LLOYD A. HAJDIK~~
		~~Lloyd A. Hajdik~~
		~~Senior Vice President, Chief Financial Officer and~~
		~~Treasurer (Duly Authorized Officer and Principal Financial Officer)~~



~~Date:~~ ~~October 30, 2015~~	By	~~/s/ SARAH A. MUNSON~~
		~~Sarah A. Munson~~
		~~Vice President, Controller and~~
		~~Chief Accounting Officer (Duly Authorized Officer and Chief Accounting Officer)~~

~~Exhibit No.~~		~~Description~~

~~3.1~~	—	Amended and Restated Certificate of Incorporation (incorporated by reference to Exhibit 3.1 to the Company’s Annual Report on Form 10-K for the year ended December 31, 2000, as filed with the Commission on March 30, 2001 (File No. 001-16337)).

~~3.2~~	—	~~Third Amended and Restated Bylaws (incorporated by reference to Exhibit 3.1 to the Company’s Current Report on Form 8-K, as filed with the Commission on March 13, 2009 (File No. 001-16337)).~~

~~3.3~~	—	Certificate of Designations of Special Preferred Voting Stock of Oil States International, Inc. (incorporated by reference to Exhibit 3.3 to the Company’s Annual Report on Form 10-K for the year ended December 31, 2000, as filed with the Commission on March 30, 2001 (File No. 001-16337)).

31.1*	—	~~Certification of Chief Executive Officer of Oil States International, Inc. pursuant to Rules 13a-14(a) or 15d-14(a) under the Securities Exchange Act of 1934.~~

31.2*	—	~~Certification of Chief Financial Officer of Oil States International, Inc. pursuant to Rules 13a-14(a) or 15d-14(a) under the Securities Exchange Act of 1934.~~

32.1**	—	~~Certification of Chief Executive Officer of Oil States International, Inc. pursuant to Rules 13a-14(b) or 15d-14(b) under the Securities Exchange Act of 1934.~~

32.2**	—	~~Certification of Chief Financial Officer of Oil States International, Inc. pursuant to Rules 13a-14(b) or 15d-14(b) under the Securities Exchange Act of 1934.~~


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~~