UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

(Mark One)



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

For the quarterly period ended ~~June~~September 30, 2019



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

For the transition period from _____ to _____

Commission file number: 001-16337

OIL STATES INTERNATIONAL, INC.

______________

(Exact name of registrant as specified in its charter)



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

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

(713) 652-0582

(Registrant's telephone number, including area code)

Securities registered pursuant to Section 12(b) of the Act:



Title of each class	Trading Symbol(s)	Name of each exchange on which registered
Common stock, par value $0.01 per share	OIS	New York Stock Exchange

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.



Yes	☒	No	☐

Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted 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 such files).



Yes	☒	No	☐

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company or an emerging growth company. See the definitions of "large accelerated filer," "accelerated filer," "smaller reporting company," and "emerging growth company" in Rule 12b-2 of the Exchange Act. (Check one):



Large accelerated filer	☒	Accelerated filer	☐
Non-accelerated filer	☐	Smaller reporting company	☐
		Emerging growth company	☐

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

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



Yes	☐	No	☒

As of ~~July 25,~~October 21, 2019, the number of shares of common stock outstanding was ~~60,507,750.~~60,502,803.

OIL STATES INTERNATIONAL, INC. AND SUBSIDIARIES

INDEX


	Page No.			Page No.
Part I – FINANCIAL INFORMATION

Item 1. Financial Statements:

Condensed Consolidated Financial Statements
Unaudited Consolidated Statements of Operations	Unaudited Consolidated Statements of Operations		3	Unaudited Consolidated Statements of Operations		3
Unaudited Consolidated Statements of Comprehensive Loss	Unaudited Consolidated Statements of Comprehensive Loss		4	Unaudited Consolidated Statements of Comprehensive Loss		4
Consolidated Balance Sheets	Consolidated Balance Sheets		5	Consolidated Balance Sheets		5
Unaudited Consolidated Statements of Stockholders' Equity	Unaudited Consolidated Statements of Stockholders' Equity		6	Unaudited Consolidated Statements of Stockholders' Equity		6
Unaudited Consolidated Statements of Cash Flows	Unaudited Consolidated Statements of Cash Flows		8	Unaudited Consolidated Statements of Cash Flows		8
Notes to Unaudited Condensed Consolidated Financial Statements	9	–	21	9	–	21

Cautionary Statement Regarding Forward-Looking Statements	22	–	23	23	–	24

Item 2. Management's Discussion and Analysis of Financial Condition and Results of Operations	23	–	37	24	–	38

Item 3. Quantitative and Qualitative Disclosures About Market Risk	Item 3. Quantitative and Qualitative Disclosures About Market Risk		38	Item 3. Quantitative and Qualitative Disclosures About Market Risk		39

Item 4. Controls and Procedures	Item 4. Controls and Procedures		39	Item 4. Controls and Procedures		40

Part II – OTHER INFORMATION

Item 1. Legal Proceedings	Item 1. Legal Proceedings		40	Item 1. Legal Proceedings		41

Item 1A. Risk Factors	Item 1A. Risk Factors		40	Item 1A. Risk Factors		41

Item 2. Unregistered Sales of Equity Securities and Use of Proceeds	Item 2. Unregistered Sales of Equity Securities and Use of Proceeds		40	Item 2. Unregistered Sales of Equity Securities and Use of Proceeds		41

Item 3. Defaults Upon Senior Securities	Item 3. Defaults Upon Senior Securities		40	Item 3. Defaults Upon Senior Securities		41

Item 4. Mine Safety Disclosures	Item 4. Mine Safety Disclosures		40	Item 4. Mine Safety Disclosures		41

Item 5. Other Information	Item 5. Other Information		40	Item 5. Other Information		41

Item 6. Exhibits	Item 6. Exhibits		41	Item 6. Exhibits		42

Signature Page	Signature Page		42	Signature Page		43

PART I – FINANCIAL INFORMATION

ITEM 1. Financial Statements

OIL STATES INTERNATIONAL, INC. AND SUBSIDIARIES

UNAUDITED CONSOLIDATED STATEMENTS OF OPERATIONS

(In Thousands, Except Per Share Amounts)


	Three Months Ended June 30,						Six Months Ended June 30,						Three Months Ended September 30,						Nine Months Ended September 30,
	2019			2018			2019			2018			2019			2018			2019			2018
Revenues:
Products	$	124,965		$	136,182		$	241,293		$	265,008		$	122,067		$	120,271		$	363,360		$	385,279
Services	139,720			149,663			274,003			274,413			141,630			154,323			415,633			428,736
	264,685			285,845			515,296			539,421			263,697			274,594			778,993			814,015

Costs and expenses:
Product costs	95,289			95,324			184,557			188,300			90,796			87,822			275,353			276,122
Service costs	112,823			118,079			223,433			214,993			110,294			127,836			333,727			342,829
Cost of revenues (exclusive of depreciation and amortization expense presented below)	208,112			213,403			407,990			403,293			201,090			215,658			609,080			618,951
Selling, general and administrative expense	31,484			35,919			61,592			70,114			31,935			32,285			93,527			102,399
Depreciation and amortization expense	31,883			30,922			63,434			60,112			31,366			30,586			94,800			90,698
Other operating income, net	(399		)	(3,099		)	(485		)	(1,884		)
Impairment of fixed assets													33,697			—			33,697			—
Other operating (income) expense, net													519			(213		)	34			(2,097		)
	271,080			277,145			532,531			531,635			298,607			278,316			831,138			809,951
Operating income (loss)	(6,395		)	8,700			(17,235		)	7,786			(34,910		)	(3,722		)	(52,145		)	4,064

Interest expense, net	(4,617		)	(4,790		)	(9,369		)	(9,244		)	(4,352		)	(4,843		)	(13,721		)	(14,087		)
Other income	1,009			571			1,676			1,218
Income (loss) before income taxes	(10,003		)	4,481			(24,928		)	(240		)
Income tax (provision) benefit	263			(1,739		)	540			(510		)
Net income (loss)	$	(9,740	)	$	2,742		$	(24,388	)	$	(750	)
Other income, net													1,190			709			2,866			1,927
Loss before income taxes													(38,072		)	(7,856		)	(63,000		)	(8,096		)
Income tax benefit													6,204			3,837			6,744			3,327
Net loss													$	(31,868	)	$	(4,019	)	$	(56,256	)	$	(4,769	)

Net income (loss) per share:
Net loss per share:
Basic	$	(0.16	)	$	0.05		$	(0.41	)	$	(0.01	)	$	(0.54	)	$	(0.07	)	$	(0.95	)	$	(0.08	)
Diluted	(0.16		)	0.05			(0.41		)	(0.01		)	(0.54		)	(0.07		)	(0.95		)	(0.08		)

Weighted average number of common shares outstanding:
Basic	59,406			59,005			59,332			58,396			59,423			59,026			59,362			58,606
Diluted	59,406			59,005			59,332			58,396			59,423			59,026			59,362			58,606

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

OIL STATES INTERNATIONAL, INC. AND SUBSIDIARIES

UNAUDITED CONSOLIDATED STATEMENTS OF COMPREHENSIVE LOSS

(In Thousands)


	Three Months Ended June 30,						Six Months Ended June 30,						Three Months Ended September 30,						Nine Months Ended September 30,
	2019			2018			2019			2018			2019			2018			2019			2018
Net income (loss)	$	(9,740	)	$	2,742		$	(24,388	)	$	(750	)
Net loss													$	(31,868	)	$	(4,019	)	$	(56,256	)	$	(4,769	)

Other comprehensive income (loss):
Other comprehensive loss:
Currency translation adjustments	(2,329		)	(13,733		)	137			(8,699		)	(5,672		)	(2,539		)	(5,535		)	(11,238		)
Comprehensive loss	$	(12,069	)	$	(10,991	)	$	(24,251	)	$	(9,449	)	$	(37,540	)	$	(6,558	)	$	(61,791	)	$	(16,007	)

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

OIL STATES INTERNATIONAL, INC. AND SUBSIDIARIES

CONSOLIDATED BALANCE SHEETS

(In Thousands, Except Share Amounts)


	June 30, 2019			December 31, 2018			September 30, 2019			December 31, 2018
	(Unaudited)						(Unaudited)
ASSETS

Current assets:
Cash and cash equivalents	$	12,406		$	19,316		$	14,655		$	19,316
Accounts receivable, net	263,453			283,607			256,387			283,607
Inventories, net	210,006			209,393			215,558			209,393
Prepaid expenses and other current assets	25,514			21,715			18,802			21,715
Total current assets	511,379			534,031			505,402			534,031

Property, plant, and equipment, net	520,324			540,427			470,983			540,427
Operating lease assets, net	48,235			—			45,497			—
Goodwill, net	646,984			647,018			646,744			647,018
Other intangible assets, net	242,886			255,301			236,159			255,301
Other noncurrent assets	27,893			27,044			29,179			27,044
Total assets	$	1,997,701		$	2,003,821		$	1,933,964		$	2,003,821

LIABILITIES AND STOCKHOLDERS' EQUITY

Current liabilities:
Current portion of long-term debt	$	25,583		$	25,561		$	25,591		$	25,561
Accounts payable	83,909			77,511			78,511			77,511
Accrued liabilities	53,478			60,730			59,988			60,730
Current operating lease liabilities	8,997			—			8,557			—
Income taxes payable	4,243			3,072			5,385			3,072
Deferred revenue	15,360			14,160			25,888			14,160
Total current liabilities	191,570			181,034			203,920			181,034

Long-term debt	272,784			306,177			239,596			306,177
Long-term operating lease liabilities	39,268			—			37,230			—
Deferred income taxes	50,224			53,831			41,604			53,831
Other noncurrent liabilities	24,127			23,011			25,270			23,011
Total liabilities	577,973			564,053			547,620			564,053

Stockholders' equity:
Common stock, $.01 par value, 200,000,000 shares authorized, 72,521,801 shares and 71,753,937 shares issued, respectively	726			718
Common stock, $.01 par value, 200,000,000 shares authorized, 72,548,151 shares and 71,753,937 shares issued, respectively							726			718
Additional paid-in capital	1,106,340			1,097,758			1,110,572			1,097,758
Retained earnings	1,005,130			1,029,518			973,262			1,029,518
Accumulated other comprehensive loss	(71,260		)	(71,397		)	(76,932		)	(71,397		)
Treasury stock, at cost, 12,039,547 and 11,784,242 shares, respectively	(621,208		)	(616,829		)
Treasury stock, at cost, 12,045,065 and 11,784,242 shares, respectively							(621,284		)	(616,829		)
Total stockholders' equity	1,419,728			1,439,768			1,386,344			1,439,768
Total liabilities and stockholders' equity	$	1,997,701		$	2,003,821		$	1,933,964		$	2,003,821

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

OIL STATES INTERNATIONAL, INC. AND SUBSIDIARIES

UNAUDITED CONSOLIDATED STATEMENTS OF STOCKHOLDERS' EQUITY

(In Thousands)


Three Months Ended June 30, 2019	Common Stock		Additional Paid-In Capital		Retained Earnings			Accumulated Other Comprehensive Loss			Treasury Stock			Total Stockholders' Equity
Balance, March 31, 2019	$	725	$	1,102,176	$	1,014,870		$	(68,931	)	$	(621,196	)	$	1,427,644
Three Months Ended September 30, 2019																	Common Stock		Additional Paid-In Capital		Retained Earnings			Accumulated Other Comprehensive Loss			Treasury Stock			Total Stockholders' Equity
Balance, June 30, 2019																	$	726	$	1,106,340	$	1,005,130		$	(71,260	)	$	(621,208	)	$	1,419,728
Net loss	—		—		(9,740		)	—			—			(9,740		)	—		—		(31,868		)	—			—			(31,868		)
Currency translation adjustments (excluding intercompany advances)	—		—		—			(2,946		)	—			(2,946		)	—		—		—			(4,448		)	—			(4,448		)
Currency translation adjustments on intercompany advances	—		—		—			617			—			617			—		—		—			(1,224		)	—			(1,224		)
Stock-based compensation expense:
Restricted stock	1		4,164		—			—			—			4,165			—		4,232		—			—			—			4,232
Stock options	—		—		—			—			—			—			—		—		—			—			—			—
Stock repurchases	—		—		—			—			—			—			—		—		—			—			—			—
Surrender of stock to settle taxes on restricted stock awards	—		—		—			—			(12		)	(12		)	—		—		—			—			(76		)	(76		)
Balance, June 30, 2019	$	726	$	1,106,340	$	1,005,130		$	(71,260	)	$	(621,208	)	$	1,419,728
Balance, September 30, 2019																	$	726	$	1,110,572	$	973,262		$	(76,932	)	$	(621,284	)	$	1,386,344


Six Months Ended June 30, 2019	Common Stock		Additional Paid-In Capital		Retained Earnings			Accumulated Other Comprehensive Loss			Treasury Stock			Total Stockholders' Equity
Nine Months Ended September 30, 2019																	Common Stock		Additional Paid-In Capital		Retained Earnings			Accumulated Other Comprehensive Loss			Treasury Stock			Total Stockholders' Equity
Balance, December 31, 2018	$	718	$	1,097,758	$	1,029,518		$	(71,397	)	$	(616,829	)	$	1,439,768		$	718	$	1,097,758	$	1,029,518		$	(71,397	)	$	(616,829	)	$	1,439,768
Net loss	—		—		(24,388		)	—			—			(24,388		)	—		—		(56,256		)	—			—			(56,256		)
Currency translation adjustments (excluding intercompany advances)	—		—		—			(393		)	—			(393		)	—		—		—			(4,841		)	—			(4,841		)
Currency translation adjustments on intercompany advances	—		—		—			530			—			530			—		—		—			(694		)	—			(694		)
Stock-based compensation expense:
Restricted stock	8		8,529		—			—			—			8,537			8		12,761		—			—			—			12,769
Stock options	—		53		—			—			—			53			—		53		—			—			—			53
Stock repurchases	—		—		—			—			(757		)	(757		)	—		—		—			—			(757		)	(757		)
Surrender of stock to settle taxes on restricted stock awards	—		—		—			—			(3,622		)	(3,622		)	—		—		—			—			(3,698		)	(3,698		)
Balance, June 30, 2019	$	726	$	1,106,340	$	1,005,130		$	(71,260	)	$	(621,208	)	$	1,419,728
Balance, September 30, 2019																	$	726	$	1,110,572	$	973,262		$	(76,932	)	$	(621,284	)	$	1,386,344

OIL STATES INTERNATIONAL, INC. AND SUBSIDIARIES

UNAUDITED CONSOLIDATED STATEMENTS OF STOCKHOLDERS' EQUITY

(In Thousands)


Three Months Ended June 30, 2018	Common Stock		Additional Paid-In Capital		Retained Earnings		Accumulated Other Comprehensive Loss			Treasury Stock			Total Stockholders' Equity
Balance, March 31, 2018	$	717	$	1,080,216	$	1,045,131	$	(53,459	)	$	(616,590	)	$	1,456,015
Net income	—		—		2,742		—			—			2,742
Three Months Ended September 30, 2018																Common Stock		Additional Paid-In Capital		Retained Earnings			Accumulated Other Comprehensive Loss			Treasury Stock			Total Stockholders' Equity
Balance, June 30, 2018																$	718	$	1,085,927	$	1,047,873		$	(67,192	)	$	(616,673	)	$	1,450,653
Net loss																—		—		(4,019		)	—			—			(4,019		)
Currency translation adjustments (excluding intercompany advances)	—		—		—		(11,242		)	—			(11,242		)	—		—		—			(2,915		)	—			(2,915		)
Currency translation adjustments on intercompany advances	—		—		—		(2,491		)	—			(2,491		)	—		—		—			376			—			376
Stock-based compensation expense:
Restricted stock	1		5,617		—		—			—			5,618			—		5,597		—			—			—			5,597
Stock options	—		94		—		—			—			94			—		96		—			—			—			96
Issuance of common stock in connection with GEODynamics acquisition	—		—		—		—			—			—			—		—		—			—			—			—
Issuance of 1.50% convertible senior notes, net of income taxes of $7,744	—		—		—		—			—			—			—		43		—			—			—			43
Surrender of stock to settle taxes on restricted stock awards	—		—		—		—			(83		)	(83		)	—		—		—			—			(156		)	(156		)
Balance, June 30, 2018	$	718	$	1,085,927	$	1,047,873	$	(67,192	)	$	(616,673	)	$	1,450,653
Balance, September 30, 2018																$	718	$	1,091,663	$	1,043,854		$	(69,731	)	$	(616,829	)	$	1,449,675


Six Months Ended June 30, 2018	Common Stock		Additional Paid-In Capital		Retained Earnings			Accumulated Other Comprehensive Loss			Treasury Stock			Total Stockholders' Equity
Nine Months Ended September 30, 2018																	Common Stock		Additional Paid-In Capital		Retained Earnings			Accumulated Other Comprehensive Loss			Treasury Stock			Total Stockholders' Equity
Balance, December 31, 2017	$	627	$	754,607	$	1,048,623		$	(58,493	)	$	(612,651	)	$	1,132,713		$	627	$	754,607	$	1,048,623		$	(58,493	)	$	(612,651	)	$	1,132,713
Net loss	—		—		(750		)	—			—			(750		)	—		—		(4,769		)	—			—			(4,769		)
Currency translation adjustments (excluding intercompany advances)	—		—		—			(6,138		)	—			(6,138		)	—		—		—			(9,053		)	—			(9,053		)
Currency translation adjustments on intercompany advances	—		—		—			(2,561		)	—			(2,561		)	—		—		—			(2,185		)	—			(2,185		)
Stock-based compensation expense:
Restricted stock	4		10,557		—			—			—			10,561			4		16,154		—			—			—			16,158
Stock options	—		300		—			—			—			300			—		396		—			—			—			396
Issuance of common stock in connection with GEODynamics acquisition	87		294,823		—			—			—			294,910			87		294,823		—			—			—			294,910
Issuance of 1.50% convertible senior notes, net of income taxes of $7,744	—		25,640		—			—			—			25,640			—		25,683		—			—			—			25,683
Surrender of stock to settle taxes on restricted stock awards	—		—		—			—			(4,022		)	(4,022		)	—		—		—			—			(4,178		)	(4,178		)
Balance, June 30, 2018	$	718	$	1,085,927	$	1,047,873		$	(67,192	)	$	(616,673	)	$	1,450,653
Balance, September 30, 2018																	$	718	$	1,091,663	$	1,043,854		$	(69,731	)	$	(616,829	)	$	1,449,675

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

OIL STATES INTERNATIONAL, INC. AND SUBSIDIARIES

UNAUDITED CONSOLIDATED STATEMENTS OF CASH FLOWS

(In Thousands)


	Six Months Ended June 30,						Nine Months Ended September 30,
	2019			2018			2019			2018
Cash flows from operating activities:
Net loss	$	(24,388	)	$	(750	)	$	(56,256	)	$	(4,769	)
Adjustments to reconcile net loss to net cash provided by operating activities:
Depreciation and amortization expense	63,434			60,112			94,800			90,698
Impairment of fixed assets							33,697			—
Stock-based compensation expense	8,590			10,861			12,822			16,554
Amortization of debt discount and deferred financing costs	3,894			3,613			5,903			5,504
Deferred income tax provision (benefit)	(3,495		)	481			(11,935		)	1,061
Gain on disposals of assets	(1,245		)	(927		)	(2,310		)	(5,046		)
Other, net	141			2,520			1,216			991
Changes in operating assets and liabilities, net of effect from acquired businesses:
Accounts receivable	19,884			(19,134		)	24,993			(25,454		)
Inventories	(534		)	(1,768		)	(6,867		)	(7,867		)
Accounts payable and accrued liabilities	1,200			(2,251		)	3,143			18,311
Income taxes payable	943			(31		)	1,948			524
Other operating assets and liabilities, net	(2,421		)	(5,792		)	14,740			(10,406		)
Net cash flows provided by operating activities	66,003			46,934			115,894			80,101

Cash flows from investing activities:
Capital expenditures	(31,577		)	(38,261		)	(45,832		)	(71,286		)
Acquisitions of businesses, net of cash acquired	—			(379,676		)	—			(379,676		)
Proceeds from disposition of property, plant and equipment	2,151			1,197			3,619			1,812
Proceeds from flood insurance claims							—			3,589
Other, net	(1,459		)	(985		)	(1,534		)	(1,218		)
Net cash flows used in investing activities	(30,885		)	(417,725		)	(43,747		)	(446,779		)

Cash flows from financing activities:
Issuance of 1.50% convertible senior notes	—			200,000			—			200,000
Purchase of 1.50% convertible senior notes							(858		)	—
Revolving credit facility borrowings	119,252			704,469			175,306			769,147
Revolving credit facility repayments	(156,208		)	(546,564		)	(246,450		)	(608,565		)
Other debt and finance lease repayments, net	(301		)	(266		)	(434		)	(405		)
Payment of financing costs	(8		)	(7,366		)	(18		)	(7,368		)
Purchase of treasury stock	(757		)	—			(757		)	—
Shares added to treasury stock as a result of net share settlements due to vesting of restricted stock	(3,622		)	(4,022		)	(3,698		)	(4,178		)
Net cash flows provided by (used in) financing activities	(41,644		)	346,251			(76,909		)	348,631

Effect of exchange rate changes on cash and cash equivalents	(384		)	183			101			849
Net change in cash and cash equivalents	(6,910		)	(24,357		)	(4,661		)	(17,198		)
Cash and cash equivalents, beginning of period	19,316			53,459			19,316			53,459
Cash and cash equivalents, end of period	$	12,406		$	29,102		$	14,655		$	36,261

Cash paid for:
Interest	$	5,285		$	4,033		$	8,378		$	7,730
Income taxes, net of refunds	2,002			2,978			(2,522		)	2,369

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

OIL STATES INTERNATIONAL, INC. AND SUBSIDIARIES

NOTES TO UNAUDITED CONDENSED CONSOLIDATED

FINANCIAL STATEMENTS


1.	Organization and Basis of Presentation

The accompanying unaudited condensed consolidated financial statements of Oil States International, Inc. and its subsidiaries (referred to in this report as "we" or the "Company") have been prepared pursuant to the rules and regulations of the Securities and Exchange Commission (the "Commission") pertaining to interim financial information. Certain information in footnote disclosures normally included in financial statements prepared in accordance with U.S. generally accepted accounting principles ("GAAP") have been condensed or omitted pursuant to these rules and regulations. The unaudited financial statements included in this report reflect all the adjustments, consisting of normal recurring adjustments, which the Company considers necessary for a fair statement 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. Certain prior-year amounts in the Company's unaudited condensed consolidated financial statements have been reclassified to conform to the current year presentation.

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. Examples of such estimates include goodwill and long-lived asset impairment analyses, revenue and income recognized over time, valuation allowances recorded on deferred tax assets, the fair value of assets and liabilities acquired and identification of associated goodwill and intangible assets, reserves on inventory, allowances for doubtful accounts, warranty obligations and potential future adjustments related to contractual indemnification and other agreements. 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.

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, 2018 (the "2018 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 February 2016, the FASB issued guidance on leases which, as amended, introduced the recognition of lease assets and lease liabilities by lessees for all leases that are not short-term in nature. The Company adopted this guidance on January 1, 2019, using the optional transition method of recognizing any cumulative effect of adopting this guidance as an adjustment to the opening balance of retained earnings. The cumulative impact of the adoption of the new standard was not material to the Company's consolidated financial statements. Prior periods were not retrospectively adjusted. In addition, the Company elected a package of practical expedients permitted under transition guidance for the new standard which, among other things, allowed for the carryforward of historical lease classification. The Company has lease agreements with lease and non-lease components, which are generally accounted for as a single lease component. Most of the Company's leases do not provide an implicit interest rate. Therefore, the Company's incremental borrowing rate, based on available information at the lease commencement date, is used to determine the present value of lease payments.

In connection with the adoption of the new standard, the Company recorded $47.7 million of operating lease assets and liabilities as of January 1, 2019. The standard did not materially impact our consolidated statement of operations and had no impact on cash flows. As of September 30, 2019, net operating lease assets and liabilities totaled $45.5 million and $45.8 million, respectively.

OIL STATES INTERNATIONAL, INC. AND SUBSIDIARIES

NOTES TO UNAUDITED CONDENSED CONSOLIDATED

FINANCIAL STATEMENTS

(Continued)


3.	Business Acquisitions ~~Goodwill and Other Intangible Assets~~

GEODynamics Acquisition

On January 12, 2018, the Company acquired GEODynamics, Inc. ("GEODynamics"), which provides oil and gas perforation systems and downhole tools in support of completion, intervention, wireline and well abandonment operations (the "GEODynamics Acquisition"). Total recorded purchase price consideration was $615.3 million, consisting of (i) $295.4 million in cash (net of cash acquired), which was funded through borrowings under the Company's Revolving Credit Facility (as defined in Note 6, "Long-term Debt"), (ii) approximately 8.66 million shares of the Company's common stock (having a market value of approximately $295 million based on the ~~closing~~ share price of $34.05 as of the acquisition closing ~~date of the acquisition)~~date) and (iii) an unsecured $25 million promissory note that bears interest at 2.5% per annum. Under the terms of the purchase agreement, the Company is entitled to indemnification in respect of certain matters occurring prior to the acquisition and payments due under the promissory note are subject to set-off, in part or in full, ~~regarding~~in respect of such indemnified matters. See Note 14, "Commitments and Contingencies."

GEODynamics' results of operations have been included in the Company's financial statements subsequent to the closing of the acquisition on January 12, 2018. The acquired GEODynamics operations are reported as the Downhole Technologies segment. See Note 13, "Segments and Related Information" for further information with respect to the Downhole Technologies segment operations.

Falcon Acquisition

On February 28, 2018, the Company acquired Falcon Flowback Services, LLC ("Falcon"), a full service provider of flowback and well testing services for the separation and recovery of fluids, solid debris and proppant used during hydraulic fracturing operations. Falcon provides additional scale and diversity to our Completion Services well testing operations in key shale plays in the United States. The purchase price was $84.2 million (net of cash acquired). The Falcon acquisition was funded by borrowings under the Company's Revolving Credit Facility. Under the terms of the purchase agreement, the Company ~~may be~~is entitled to indemnification in respect of certain matters occurring prior to the acquisition. Falcon's results of operations have been included in the Company's financial statements and ~~has~~have been reported within the Completion Services business subsequent to the closing of the acquisition on February 28, 2018.

Transaction-Related Costs

During the first quarter of 2018, the Company expensed transaction-related costs of $2.6 million, which are included in selling, general and administrative expense and in other operating income, net for the ~~six~~nine months ended ~~June~~September 30, 2018.

Supplemental Unaudited Pro Forma Financial Information

The following supplemental unaudited pro forma results of operations data for the ~~six~~nine months ended ~~June~~September 30, 2018 gives pro forma effect to the consummation of the GEODynamics and Falcon acquisitions as if they had occurred on January 1, 2018. The supplemental unaudited pro forma financial information was prepared based on historical financial information, adjusted to give pro forma effect to fair value adjustments on depreciation and amortization expense, interest expense, and related tax effects, among others. The pro forma results for the ~~six~~nine months ended ~~June~~September 30, 2018 also reflect adjustments to exclude the after-tax impact of transaction costs totaling $2.0 million. The supplemental unaudited pro forma financial information may not reflect what the results of the combined operations would have been had the acquisitions occurred on January 1, 2018. As such, it is presented for informational purposes only (in thousands, except per share amount).


	Six Months Ended June 30, 2018		Nine Months Ended September 30, 2018
Revenue	$	566,045	$	840,639
Net income	$	1,750
Diluted net income per share	$	0.03
Net loss			$	(2,269	)
Diluted net loss per share			$	(0.04	)
Diluted weighted average common shares outstanding	58,922		59,132

OIL STATES INTERNATIONAL, INC. AND SUBSIDIARIES

NOTES TO UNAUDITED CONDENSED CONSOLIDATED

FINANCIAL STATEMENTS

(Continued)


4.	Details of Selected Balance Sheet Accounts

~~Goodwill~~

~~Changes in the carrying amount of goodwill for the six-month period ended June 30, 2019 were as follows (in thousands):~~

Well Site Services Downhole Technologies Offshore/
Manufactured Products Total
Completion Services Drilling Services Subtotal
Balance as of December 31, 2018
Goodwill $ 221,582
$ 22,767
$ 244,349
$ 357,502
$ 162,462
$ 764,313
Accumulated impairment losses (94,528 ) (22,767 ) (117,295 ) —
—
(117,295 )
127,054
—
127,054
357,502
162,462
647,018
Foreign currency translation —
—
—
—
(34 ) (34 )
Balance as of June 30, 2019 $ 127,054
$ —
$ 127,054
$ 357,502
$ 162,428
$ 646,984

~~Other Intangible Assets~~

~~The following table presents the gross carrying amount, accumulated amortization and net carrying amount for major intangible asset classes as of June~~Additional information regarding selected balance sheet accounts at September 30, 2019 and December 31, 2018 is presented below (in thousands):

June 30, 2019 December 31, 2018

Gross
Carrying
Amount

Accumulated
Amortization
Net Carrying Amount
Gross
Carrying
Amount

Accumulated
Amortization
Net Carrying Amount
Customer relationships $ 168,266
$ 38,729
$ 129,537
$ 167,811
$ 33,247
$ 134,564
Patents/Technology/Know-how 85,423
27,268
58,155
84,903
23,418
61,485
Noncompete agreements 17,100
8,418
8,682
18,705
7,544
11,161
Tradenames and other 53,708
7,196
46,512
53,708
5,617
48,091
$ 324,497
$ 81,611
$ 242,886
$ 325,127
$ 69,826
$ 255,301



	September 30, 2019			December 31, 2018
Accounts receivable, net:
Trade	$	206,574		$	227,052
Unbilled revenue	36,856			35,674
Contract assets	16,364			21,201
Other	3,564			6,381
Total accounts receivable	263,358			290,308
Allowance for doubtful accounts	(6,971		)	(6,701		)
	$	256,387		$	283,607



	September 30, 2019		December 31, 2018
Deferred revenue (contract liabilities)	$	25,888	$	14,160

For the ~~three~~nine months ended ~~June~~September 30, 2019, ~~and 2018, amortization expense~~the $4.8 million net decrease in contract assets was ~~$6.8~~primarily attributable to $19.8 million ~~and $6.4~~transferred to accounts receivable, which was partially offset by $15.2 million ~~respectively. Amortization expense~~in revenue recognized during the period. Deferred revenue (contract liabilities) increased by $11.7 million in 2019, primarily reflecting $19.0 million in new customer billings which were not recognized as revenue during the period, partially offset by the recognition of $7.2 million of revenue that was ~~$13.5 million and $12.0 million for~~deferred at the ~~six months ended June 30, 2019 and 2018, respectively.~~beginning of the period.



	September 30, 2019			December 31, 2018
Inventories, net:
Finished goods and purchased products	$	107,388		$	96,195
Work in process	23,218			20,552
Raw materials	103,922			111,197
Total inventories	234,528			227,944
Allowance for excess or obsolete inventory	(18,970		)	(18,551		)
	$	215,558		$	209,393



	Estimated Useful Life (years)			September 30, 2019			December 31, 2018
Property, plant and equipment, net:
Land				$	36,802		$	37,545
Buildings and leasehold improvements	2	–	40	261,772			259,834
Machinery and equipment	1	–	28	241,322			483,629
Completion Services equipment	2	–	10	509,340			492,183
Office furniture and equipment	3	–	10	44,665			43,654
Vehicles	2	–	10	104,053			122,982
Construction in progress				22,615			29,451
Total property, plant and equipment				1,220,569			1,469,278
Accumulated depreciation				(749,586		)	(928,851		)
				$	470,983		$	540,427

The Company's industry is highly cyclical, and this cyclicality impacts the determination of whether a decline in value of the Company's long-lived assets, including fixed assets, definite-lived ~~intangibles,~~intangible assets, and/or goodwill has occurred. The Company is required to periodically review the long-lived assets and goodwill of its reporting units for potential impairment in value if circumstances, some of which are beyond the Company's control, indicate that the carrying amounts will not be recoverable.

OIL STATES INTERNATIONAL, INC. AND SUBSIDIARIES

NOTES TO UNAUDITED CONDENSED CONSOLIDATED

FINANCIAL STATEMENTS

(Continued)

In this regard, the Company made the strategic decision to reduce the scope of its Drilling Services business unit (with plans to adjust from 34 rigs to 9 rigs) during the third quarter of 2019 due to the ongoing weakness in customer demand for vertical drilling rigs in the U.S. land market, particularly the Permian Basin. As a result of this decision, the carrying value of 25 rigs which will be decommissioned or sold was reduced to their estimated salvage value, resulting in the recognition of a $25.5 million non-cash impairment charge. Additionally, indicators of impairment were identified for the remaining rigs which the Company plans to continue operating. The Company performed a fair value assessment on the remaining drilling rigs and recognized an additional non-cash impairment charge of $8.2 million (a Level 3 fair value measurement). This fixed asset impairment charge was based in part on the estimated future cash flows that these assets are projected to generate (income approach), which included unobservable inputs that required significant judgments including projected day rates and costs, rig utilization and remaining economic useful life. The income approach was also weighted with a market approach, which included estimates of the selling price for each drilling rig, resulting in a fair value measurement of $4.9 million. These non-cash charges totaling $33.7 million are reported in the Drilling Services business and are separately presented in the consolidated statement of operations. In connection with this fixed asset impairment and as reflected in the preceding table, the cost basis of drilling rigs (included in machinery and equipment) and other fixed assets, along with related accumulated depreciation, were both reduced by a total of $257.8 million as of September 30, 2019.



	September 30, 2019		December 31, 2018
Other noncurrent assets:
Deferred compensation plan	$	22,784	$	20,468
Deferred income taxes	700		761
Other	5,695		5,815
	$	29,179	$	27,044



	September 30, 2019		December 31, 2018
Accrued liabilities:
Accrued compensation	$	28,846	$	29,867
Insurance liabilities	9,992		9,177
Accrued taxes, other than income taxes	9,148		4,530
Accrued commissions	1,448		1,484
Other	10,554		15,672
	$	59,988	$	60,730



Goodwill:	Well Site Services									Downhole Technologies		Offshore/ Manufactured Products			Total
Goodwill:	Completion Services			Drilling Services			Subtotal			Downhole Technologies		Offshore/ Manufactured Products			Total
Balance as of December 31, 2018
Goodwill	$	221,582		$	22,767		$	244,349		$	357,502	$	162,462		$	764,313
Accumulated impairment losses	(94,528		)	(22,767		)	(117,295		)	—		—			(117,295		)
	127,054			—			127,054			357,502		162,462			647,018
Foreign currency translation	—			—			—			—		(274		)	(274		)
Balance as of September 30, 2019	$	127,054		$	—		$	127,054		$	357,502	$	162,188		$	646,744

OIL STATES INTERNATIONAL, INC. AND SUBSIDIARIES

NOTES TO UNAUDITED CONDENSED CONSOLIDATED

FINANCIAL STATEMENTS

(Continued)



Other Intangible Assets:	September 30, 2019						December 31, 2018
	Gross Carrying Amount		Accumulated Amortization		Net Carrying Amount		Gross Carrying Amount		Accumulated Amortization		Net Carrying Amount
Customer relationships	$	168,257	$	41,512	$	126,745	$	167,811	$	33,247	$	134,564
Patents/Technology/Know-how	85,487		29,146		56,341		84,903		23,418		61,485
Noncompete agreements	17,082		9,724		7,358		18,705		7,544		11,161
Tradenames and other	53,708		7,993		45,715		53,708		5,617		48,091
	$	324,534	$	88,375	$	236,159	$	325,127	$	69,826	$	255,301

For the three months ended September 30, 2019 and 2018, amortization expense was $6.8 million and $6.4 million, respectively. Amortization expense was $20.3 million and $18.4 million for the nine months ended September 30, 2019 and 2018, respectively.

The Company performed a qualitative assessment of definite-lived intangible assets and goodwill at ~~June~~September 30, 2019 and concluded that no further impairment evaluation was required. As a result, no additional impairments were recorded in the ~~second~~third quarter of 2019. Should, among other events and circumstances, global economic and industry conditions deteriorate, the outlook for future operating results and cash flow for any of the Company's reporting units decline, income tax rates increase or regulations change, costs of equity or debt capital increase, valuations for comparable public companies or comparable acquisition valuations decrease, or the Company's market capitalization ~~experiences~~experience a material, sustained decline below its book value, the Company may need to recognize additional impairment losses in future periods.

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

~~NOTES TO UNAUDITED CONDENSED CONSOLIDATED~~

~~FINANCIAL STATEMENTS~~

~~(Continued)~~


4.	~~Details of Selected Balance Sheet Accounts~~

~~Additional information regarding selected balance sheet accounts at June 30, 2019 and December 31, 2018 is presented below (in thousands):~~

June 30,
2019 December 31,
2018
Accounts receivable, net:
Trade $ 208,175
$ 227,052
Unbilled revenue 37,518
35,674
Contract assets 20,113
21,201
Other 3,950
6,381
Total accounts receivable 269,756
290,308
Allowance for doubtful accounts (6,303 ) (6,701 )
$ 263,453
$ 283,607

June 30,
2019 December 31,
2018
Deferred revenue (contract liabilities) $ 15,360
$ 14,160

For the six months ended June 30, 2019, the $1.1 million net decrease in contract assets was primarily attributable to $13.1 million transferred to accounts receivable, which was partially offset by $12.1 million in revenue recognized during the period. Deferred revenue increased by $1.2 million in 2019, primarily reflecting $5.9 million in new customer billings which were not recognized as revenue during the period, partially offset by the recognition of $5.0 million of revenue that was deferred at the beginning of the period.

June 30,
2019 December 31,
2018
Inventories, net:
Finished goods and purchased products $ 105,285
$ 96,195
Work in process 21,838
20,552
Raw materials 103,139
111,197
Total inventories 230,262
227,944
Allowance for excess or obsolete inventory (20,256 ) (18,551 )
$ 210,006
$ 209,393

Estimated
Useful Life (years)
June 30,
2019 December 31,
2018
Property, plant and equipment, net:
Land $ 37,758
$ 37,545
Buildings and leasehold improvements 2 – 40 259,981
259,834
Machinery and equipment 1 – 28 493,121
483,629
Completion Services equipment 2 – 10 505,427
492,183
Office furniture and equipment 3 – 10 45,013
43,654
Vehicles 2 – 10 114,729
122,982
Construction in progress 23,337
29,451
Total property, plant and equipment 1,479,366
1,469,278
Accumulated depreciation (959,042 ) (928,851 )
$ 520,324
$ 540,427

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

~~NOTES TO UNAUDITED CONDENSED CONSOLIDATED~~

~~FINANCIAL STATEMENTS~~

~~(Continued)~~

June 30,
2019 December 31,
2018
Other noncurrent assets:
Deferred compensation plan $ 21,593
$ 20,468
Deferred income taxes 633
761
Other 5,667
5,815
$ 27,893
$ 27,044

June 30,
2019 December 31,
2018
Accrued liabilities:
Accrued compensation $ 20,722
$ 29,867
Insurance liabilities 12,080
9,177
Accrued taxes, other than income taxes 7,990
4,530
Accrued commissions 1,470
1,484
Accrued claims 258
2,983
Other 10,958
12,689
$ 53,478
$ 60,730


5.	Net ~~Income (Loss)~~Loss Per Share

The table below provides a reconciliation of the numerators and denominators of basic and diluted net ~~income (loss)~~loss per share for the three and ~~six~~nine months ended ~~June~~September 30, 2019 and 2018 (in thousands, except per share amounts):


	Three Months Ended June 30,						Six Months Ended June 30,						Three Months Ended September 30,						Nine Months Ended September 30,
	2019			2018			2019			2018			2019			2018			2019			2018
Numerators:
Net income (loss)	$	(9,740	)	$	2,742		$	(24,388	)	$	(750	)
Net loss													$	(31,868	)	$	(4,019	)	$	(56,256	)	$	(4,769	)
Less: Income attributable to unvested restricted stock awards	—			(44		)	—			—			—			—			—			—
Numerator for basic net income (loss) per share	(9,740		)	2,698			(24,388		)	(750		)
Numerator for basic net loss per share													(31,868		)	(4,019		)	(56,256		)	(4,769		)
Effect of dilutive securities:
Unvested restricted stock awards	—			—			—			—			—			—			—			—
Numerator for diluted net income (loss) per share	$	(9,740	)	$	2,698		$	(24,388	)	$	(750	)
Numerator for diluted net loss per share													$	(31,868	)	$	(4,019	)	$	(56,256	)	$	(4,769	)

Denominators:
Weighted average number of common shares outstanding	60,458			59,964			60,353			59,389			60,493			59,977			60,400			59,585
Less: Weighted average number of unvested restricted stock awards outstanding	(1,052		)	(959		)	(1,021		)	(993		)	(1,070		)	(951		)	(1,038		)	(979		)
Denominator for basic net income (loss) per share	59,406			59,005			59,332			58,396
Effect of dilutive securities:
Unvested restricted stock awards	—			—			—			—
Assumed exercise of stock options	—			—			—			—
1.50% convertible senior notes	—			—			—			—
Denominator for basic and diluted net loss per share													59,423			59,026			59,362			58,606
	—			—			—			—
Denominator for diluted net income (loss) per share	59,406			59,005			59,332			58,396

Net income (loss) per share:
Net loss per share:
Basic	$	(0.16	)	$	0.05		$	(0.41	)	$	(0.01	)	$	(0.54	)	$	(0.07	)	$	(0.95	)	$	(0.08	)
Diluted	(0.16		)	0.05			(0.41		)	(0.01		)	(0.54		)	(0.07		)	(0.95		)	(0.08		)

The calculation of diluted net loss per share for the three and ~~six~~nine months ended ~~June~~September 30, 2019 excluded ~~664~~643 thousand shares and ~~676~~665 thousand shares, respectively, issuable pursuant to outstanding stock options, due to their antidilutive effect. The calculation of diluted net ~~income (loss)~~loss per share for the three and ~~six~~nine months ended ~~June~~September 30, 2018 excluded ~~695~~694 thousand shares and ~~697~~696 thousand shares, respectively, issuable pursuant to outstanding stock options, due to their antidilutive effect. Additionally, shares issuable upon conversion of the 1.50% convertible senior notes were not convertible and therefore excluded for the three and ~~six~~nine months ended ~~June~~September 30, 2019 and 2018, due to their antidilutive effect.


6.	~~Long-term Debt~~

~~As of June 30, 2019 and December 31, 2018, long-term debt consisted of the following (in thousands):~~

June 30,
2019 December 31,
2018
Revolving credit facility⁽¹⁾
$ 97,465
$ 134,096
1.50% convertible senior notes⁽²⁾
170,663
167,102
Promissory note 25,000
25,000
Other debt and finance lease obligations 5,239
5,540
Total debt 298,367
331,738
Less: Current portion (25,583 ) (25,561 )
Total long-term debt $ 272,784
$ 306,177

~~____________________~~


~~(1)~~	~~Presented net of $1.7 million and $2.0 million of unamortized debt issuance costs as of June 30, 2019 and December 31, 2018, respectively.~~


~~(2)~~	~~The principal amount of the 1.50% convertible senior notes is $200.0 million. See "1.50% Convertible Senior Notes" below.~~

OIL STATES INTERNATIONAL, INC. AND SUBSIDIARIES

NOTES TO UNAUDITED CONDENSED CONSOLIDATED

FINANCIAL STATEMENTS

(Continued)


6.	Long-term Debt

As of September 30, 2019 and December 31, 2018, long-term debt consisted of the following (in thousands):



	September 30, 2019			December 31, 2018
Revolving credit facility⁽¹⁾	$	63,436		$	134,096
1.50% convertible senior notes⁽²⁾	171,645			167,102
Promissory note	25,000			25,000
Other debt and finance lease obligations	5,106			5,540
Total debt	265,187			331,738
Less: Current portion	(25,591		)	(25,561		)
Total long-term debt	$	239,596		$	306,177

____________________


(1)	Presented net of $1.6 million and $2.0 million of unamortized debt issuance costs as of September 30, 2019 and December 31, 2018, respectively.


(2)	The outstanding principal amount of the 1.50% convertible senior notes was $199.0 million and $200.0 million as of September 30, 2019 and December 31, 2018, respectively.

Revolving Credit Facility

The Company's senior secured revolving credit facility, as amended (the "Revolving Credit Facility") is governed by a credit agreement with Wells Fargo Bank, N.A., as administrative agent for the lenders party thereto and collateral agent for the secured parties thereunder, and the lenders and other financial institutions from time to time party thereto, dated as of January 30, 2018, as amended and restated (the "Credit Agreement"), and matures on January 30, 2022. The ~~Credit Agreement governs our Revolving Credit Facility. The~~ Revolving Credit Facility provides for $350 million in lender commitments with an option to increase the maximum borrowings to $500 million subject to additional lender commitments prior to its maturity on January 30, 2022. Under the Revolving Credit Facility, $50 million is available for the issuance of letters of credit.

As of ~~June~~September 30, 2019, the Company had ~~$99.2~~$65.0 million of borrowings outstanding under the Credit Agreement and ~~$16.1~~$22.6 million of outstanding letters of credit, leaving ~~$96.0~~$139.1 million available to be drawn. The total amount available to be drawn under our Revolving Credit Facility was less than the lender commitments as of ~~June~~September 30, 2019, due to limits imposed by maintenance covenants in the Credit Agreement.

Amounts outstanding under the Revolving Credit Facility bear interest at LIBOR plus a margin of 1.75% to 3.00%, or at a base rate plus a margin of 0.75% to 2.00%, in each case based on a ratio of the Company's total net funded debt to consolidated EBITDA (as defined in the Credit Agreement). The Company must also pay a quarterly commitment fee of 0.25% to 0.50%, based on the Company's ratio of total net funded debt to consolidated EBITDA, on the unused commitments under the Credit Agreement.

The Credit Agreement contains customary financial covenants and restrictions. Specifically, the Company must maintain an interest coverage ratio, defined as the ratio of consolidated EBITDA to consolidated interest expense, of at least 3.00 to 1.0, a maximum senior secured leverage ratio, defined as the ratio of senior secured debt to consolidated EBITDA, of no greater than 2.25 to 1.0 and a total net leverage ratio, defined as the ratio of total net funded debt to consolidated EBITDA, of no greater than 3.75 to 1.0. The financial covenants give pro forma effect to acquired businesses and the annualization of EBITDA for acquired businesses.

Each of the factors considered in the calculation of these ratios are defined in the Credit Agreement. Consolidated EBITDA and consolidated interest, as defined, exclude goodwill and fixed asset impairments, losses on extinguishment of debt, debt discount amortization, stock-based compensation expense and other non-cash charges.

Borrowings under the Credit Agreement are secured by a pledge of substantially all of the Company's assets and the assets of its domestic subsidiaries. The Company's obligations under the Credit Agreement are guaranteed by its significant domestic subsidiaries. The Credit Agreement also contains negative covenants that limit the Company's ability to borrow additional funds, encumber assets, pay dividends, sell assets and enter into other significant transactions.

Under the Credit Agreement, the occurrence of specified change of control events involving the 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.

OIL STATES INTERNATIONAL, INC. AND SUBSIDIARIES

NOTES TO UNAUDITED CONDENSED CONSOLIDATED

FINANCIAL STATEMENTS

(Continued)

As of ~~June~~September 30, 2019, the Company was in compliance with its debt covenants.

1.50% Convertible Senior Notes

On January 30, 2018, the Company issued $200 million aggregate principal amount of its 1.50% convertible senior notes due 2023 (the "Notes") pursuant to an indenture, dated as of January 30, 2018 (the "Indenture"), between the Company and Wells Fargo Bank, National Association, as trustee. Net proceeds from the Notes, after deducting issuance costs, were approximately $194 million, which ~~was~~were used by the Company to repay a portion of the outstanding borrowings under the Revolving Credit Facility during the first quarter of 2018.

During the third quarter of 2019, the Company repurchased $1.0 million in principal amount of the outstanding Notes for $0.9 million, which approximated the net carrying amount of the related liability.

The initial carrying amount of the Notes recorded in the consolidated balance sheet was less than the $200 million in principal amount of the Notes, in accordance with applicable accounting principles, reflective of the estimated fair value of a similar debt instrument that does not have a conversion feature. The Company recorded the value of the conversion feature as a debt discount, which is amortized as interest expense over the term of the Notes, with a similar amount allocated to additional paid-in capital. As a result of this amortization, the interest expense the Company recognizes related to the Notes for accounting purposes is based on an effective interest rate of approximately 6.0%, which is greater than the cash interest payments the Company is obligated to pay on the Notes. ~~Interest~~Recorded interest expense associated with the Notes for the three and ~~six~~nine months ended ~~June~~September 30, 2019 was ~~$2.5~~$2.6 million and

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

~~NOTES TO UNAUDITED CONDENSED CONSOLIDATED~~

~~FINANCIAL STATEMENTS~~

~~(Continued)~~

~~$5.1~~ $7.7 million, respectively, while the related contractual cash interest expense totaled $0.8 million and ~~$1.5~~$2.3 million, respectively. ~~Interest~~Recorded interest expense associated with the Notes for the three and ~~six~~nine months ended ~~June~~September 30, 2018 was ~~$2.4~~$2.5 million and ~~$4.1~~$6.6 million, respectively, while the related contractual cash interest expense totaled $0.8 million and ~~$1.3~~$2.0 million, respectively.

The following table presents the carrying amount of the Notes in the consolidated balance sheets (in thousands):


	June 30, 2019		December 31, 2018		September 30, 2019		December 31, 2018
Principal amount of the liability component	$	200,000	$	200,000	$	199,000	$	200,000
Less: Unamortized discount	25,669		28,825		23,919		28,825
Less: Unamortized issuance costs	3,668		4,073		3,436		4,073
Net carrying amount of the liability	$	170,663	$	167,102	$	171,645	$	167,102

The Notes bear interest at a rate of 1.50% per year until maturity. Interest is payable semi-annually in arrears on February 15 and August 15 of each year, beginning on August 15, 2018. In addition, additional interest and special interest may accrue on the Notes under certain circumstances as described in the Indenture. The Notes will mature on February 15, 2023, unless earlier repurchased, redeemed or converted. The initial conversion rate is 22.2748 shares of the Company's common stock per $1,000 principal amount of Notes (equivalent to an initial conversion price of approximately $44.89 per share of common stock). The conversion rate, and thus the conversion price, may be adjusted under certain circumstances as described in the Indenture. The Company's intent is to repay the principal amount of the Notes in cash and the conversion feature, if payable, in shares of the Company's common stock.

Noteholders may convert their Notes, at their option, only in the following circumstances: (1) if the last reported sale price per share of the Company's common stock exceeds 130% of the conversion price for each of at least 20 trading days during the 30 consecutive trading days ending on, and including, the last trading day of the immediately preceding calendar quarter; (2) during the ~~five~~5 consecutive business days immediately after any five consecutive trading day period (such ~~five~~5 consecutive trading day period, the "measurement period") in which the trading price per $1,000 principal amount of the Notes for each trading day of the measurement period was less than 98% of the product of the last reported sale price per share of the Company's common stock on such trading day and the conversion rate on such trading day; (3) upon the occurrence of certain corporate events or distributions on the Company's common stock, as described in the Indenture; or (4) if the Company calls the Notes for redemption, or at any time from, and including, November 15, 2022 until the close of business on the second scheduled trading day immediately before the maturity date. The Company will settle conversions by paying or delivering, as applicable, cash, shares of common stock or a combination of cash and shares of common stock, at the Company's election, based on the applicable conversion rate(s). If the Company elects to deliver cash or a combination of cash and shares of common stock, then the consideration due upon conversion will be based on a defined observation period.

OIL STATES INTERNATIONAL, INC. AND SUBSIDIARIES

NOTES TO UNAUDITED CONDENSED CONSOLIDATED

FINANCIAL STATEMENTS

(Continued)

The Notes will be redeemable, in whole or in part, at the Company's option at any time, and from time to time, on or after February 15, 2021, at a cash redemption price equal to the principal amount of the Notes to be redeemed, plus accrued and unpaid interest, if any, to, but excluding, the redemption date, but only if the last reported sale price per share of common stock exceeds 130% of the conversion price on each of at least 20 trading days during the 30 consecutive trading days ending on, and including, the trading day immediately before the date the Company sends the related redemption notice.

If specified change in control events involving the Company as defined in the Indenture occur, then noteholders may require the Company to repurchase their Notes at a cash repurchase price equal to the principal amount of the Notes to be repurchased, plus accrued and unpaid interest. Additionally, the Notes contain certain events of default as set forth in the Indenture. As of ~~June~~September 30, 2019, none of the conditions allowing holders of the Notes to convert, or requiring usthe Company to repurchase the Notes, had been met.

Promissory Note

In connection with the GEODynamics Acquisition, the Company issued a $25.0 million promissory note that bears interest at 2.50% per annum and was scheduled to mature on July 12, 2019. Payments due under the promissory note are subject to set off, in part or in full, against certain ~~indemnifications~~indemnification claims related to matters occurring prior to the Company's acquisition of GEODynamics. As more fully described in Note 14, "Commitments and Contingencies," the Company has provided notice to and asserted an indemnification claim against the seller of GEODynamics. As a result, the maturity date of the note is extended until the resolution of the indemnity claim. The Company expects that the amount ultimately paid in respect of such note may be reduced as a result of this indemnification claim.

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

~~NOTES TO UNAUDITED CONDENSED CONSOLIDATED~~

~~FINANCIAL STATEMENTS~~

~~(Continued)~~


7.	Fair Value Measurements

The Company's financial instruments consist of cash and cash equivalents, investments, receivables, payables and debt instruments. The Company believes that the carrying values of these instruments, other than the Notes, on the accompanying consolidated balance sheets approximate their fair values. The estimated fair value of the Notes as of ~~June~~September 30, 2019 and December 31, 2018 was approximately ~~$178~~$170 million and $166 million, respectively, based on quoted market prices (a Level 1 fair value measurement), which compares to the ~~$200~~$199 million in principal amount of the Notes.


8.	Leases

The Company leases a portion of its facilities, office space, equipment and vehicles. Leases with an initial term of 12 months or less are not recorded in the consolidated balance sheet as of ~~June~~September 30, 2019. Substantially all of the Company's future lease obligations are related to operating leases. Consistent with the Company's historical practice, finance (capital) lease obligations, which totaled ~~$0.7~~$0.6 million as of ~~June~~September 30, 2019, are classified within long-term debt while related assets are included within property, plant and equipment.

Most of the Company's operating leases include one or more options to renew, with renewal terms that can extend the lease term from one to 20 years. The exercise of lease renewal options is at the Company's sole discretion. The depreciable life of lease-related assets and leasehold improvements are limited by the expected lease term. Certain operating lease agreements include rental payments adjusted periodically for inflation. The Company's operating lease agreements do not contain any material residual value guarantees or material restrictive covenants. While the Company rents or subleases certain real estate to third parties, such amounts are not material. Cash outflows related to operating leases are presented within cash flows from operations.

~~The following tables summarize the financial statement information regarding of the Company's operating leases for the three and six months ended June 30, 2019 (in thousands):~~

Three Months Ended
June 30, 2019 Six Months Ended
June 30, 2019
Operating lease expense components:
Leases with initial term of greater than 12 months $ 2,897
$ 5,858
Leases with initial term of 12 months or less 1,413
2,766
$ 4,310
$ 8,624

Operating lease assets obtained in exchange for operating lease liabilities:
Upon adoption of standard (January 1, 2019) $ 47,721
Subsequent to adoption 5,332
Non-cash operating lease amounts $ 53,053

~~The following table provides the maturities of operating lease liabilities as of June 30, 2019 (in thousands):~~

Operating Leases
2019 (less six months ended June 30) $ 5,654
2020 10,125
2021 8,282
2022 6,176
2023 5,192
After 2023 22,861
Total lease payments 58,290
Less: Imputed interest (10,025 )
Present value of operating lease liabilities 48,265
Less: Current portion (8,997 )
Total long-term operating lease liabilities $ 39,268
Weighted-average remaining lease term (years) 7.7
Weighted-average discount rate 5.0 %

OIL STATES INTERNATIONAL, INC. AND SUBSIDIARIES

NOTES TO UNAUDITED CONDENSED CONSOLIDATED

FINANCIAL STATEMENTS

(Continued)

The following tables summarize the financial statement information regarding of the Company's operating leases for the three and nine months ended September 30, 2019 (in thousands):



	Three Months Ended September 30, 2019		Nine Months Ended September 30, 2019
Operating lease expense components:
Leases with initial term of greater than 12 months	$	3,032	$	9,006
Leases with initial term of 12 months or less	1,576		4,228
	$	4,608	$	13,234

Operating lease assets obtained in exchange for operating lease liabilities:
Upon adoption of standard (January 1, 2019)			$	47,721
Subsequent to adoption of standard			5,865
Non-cash operating lease additions			$	53,586

The following table provides the maturities of operating lease liabilities as of September 30, 2019 (in thousands):



	Operating Leases
2019 (less nine months ended September 30)	$	2,819
2020	10,060
2021	8,295
2022	6,177
2023	5,182
After 2023	22,621
Total lease payments	55,154
Less: Imputed interest	(9,367		)
Present value of operating lease liabilities	45,787
Less: Current portion	(8,557		)
Total long-term operating lease liabilities	$	37,230
Weighted-average remaining lease term (years)	7.5
Weighted-average discount rate	5.0		%


9.	Stockholders' Equity

The following table provides details with respect to the changes to the number of shares of common stock, $0.01 par value, outstanding during the first ~~six~~nine months of 2019:



Shares of common stock outstanding – December 31, 2018	59,969,695
Restricted stock awards, net of forfeitures	~~767,864~~794,214
Shares withheld for taxes on vesting of restricted stock awards and transferred to treasury	(~~204,505~~210,023	)
Purchase of treasury stock	(50,800	)
Shares of common stock outstanding – ~~June~~September 30, 2019	~~60,482,254~~60,503,086

As of ~~June~~September 30, 2019 and December 31, 2018, the Company had 25,000,000 shares of preferred stock, $0.01 par value, authorized, with no0 shares issued or outstanding.

On July 29, 2015, the Company's Board of Directors approved a share repurchase program providing for the repurchase of up to $150.0 million of the Company's common stock, which, following extensions, was scheduled to expire on July 29, 2019. On July 24, 2019, ~~our~~the Company's Board of Directors extended the share repurchase program for one year to July 29, 2020. During the first ~~six~~nine months of 2019, the Company repurchased approximately 51 thousand shares of common stock under the program. The amount remaining under the Company's share repurchase authorization as of ~~June~~September 30, 2019 was $119.8 million. Subject to applicable securities laws, such purchases will be at such times and in such amounts as the Company deems appropriate.

OIL STATES INTERNATIONAL, INC. AND SUBSIDIARIES

NOTES TO UNAUDITED CONDENSED CONSOLIDATED

FINANCIAL STATEMENTS

(Continued)


10.	Accumulated Other Comprehensive Loss

Accumulated other comprehensive loss, reported as a component of stockholders' equity, ~~decreased slightly during the first half of 2019~~increased from $71.4 million at December 31, 2018 to ~~$71.3~~$76.9 million at ~~June~~September 30, 2019, due to changes in currency exchange rates. Accumulated other comprehensive loss is primarily related to fluctuations in the currency exchange rates compared to the U.S. dollar which are used to translate certain of the international operations of our reportable segments. For the ~~six~~nine months ended ~~June~~September 30, 2019 and 2018, currency translation adjustments recognized as a component of other comprehensive loss were primarily attributable to the United Kingdom and ~~Brazil, due~~Brazil. As of September 30, 2019, the exchange rate for the British pound and the Brazilian real compared to the U.S. dollar weakened by 4% and 7%, respectively, compared to the exchange rate at December 31, 2018, contributing to other comprehensive loss of $5.5 million reported for the nine months ended September 30, 2019. During the first nine months of 2018, the exchange rates for the British pound and the Brazilian real ~~weakening~~weakened by 2%4% and ~~14%~~17%, respectively, compared to the U.S. dollar, ~~and~~ contributing to other comprehensive loss of ~~$8.7~~$11.2 million.


11.	Long-Term Incentive Compensation

The following table presents a summary of activity for stock options, service-based restricted stock awards and performance-based stock unit awards for the ~~six~~nine months ended ~~June~~September 30, 2019.


	Stock Options			Service-based Restricted Stock			Performance-based Stock Units			Stock Options			Service-based Restricted Stock			Performance-based Stock Units
Outstanding – December 31, 2018	681,894			929,554			227,124			681,894			929,554			227,124
Granted	—			674,923			76,793			—			701,671			76,793
Vested/Exercised	—			(534,661		)	(105,988		)	—			(551,296		)	(105,988		)
Forfeited	(45,624		)	(13,047		)	—			(46,381		)	(13,445		)	—
Outstanding – June 30, 2019	636,270			1,056,769			197,929
Outstanding – September 30, 2019										635,513			1,066,484			197,929
Weighted average grant date fair value (2019 awards)	$	—		$	17.65		$	17.58		$	—		$	17.64		$	17.58

The restricted stock program consists of a combination of service-based restricted stock and performance-based stock units. Service-based restricted stock awards generally vest on a straight-line basis over their term, which is generally three years. Performance-based restricted stock awards generally vest at the end of a three-year period, with the number of shares ultimately issued under the program dependent upon achievement of predefined specific performance measures.

In the event the predefined targets are exceeded for any performance-based award, additional shares up to a maximum of 200% of the target award may be granted. Conversely, if actual performance falls below the predefined target, the number of shares vested is reduced. If the actual performance falls below the threshold performance level, no restricted shares will vest. The performance measure for awards issued in 2017 is relative total stockholder return compared to a peer group of companies. The performance measures for performance-based stock units granted during 2018 and 2019 are based on the Company's EBITDA growth rate over a three-year period.

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

~~NOTES TO UNAUDITED CONDENSED CONSOLIDATED~~

~~FINANCIAL STATEMENTS~~

~~(Continued)~~

During the first quarters of 2019 and 2018, the Company issued conditional long-term cash incentive awards ("Cash Awards") of approximately $1.3 million each year, with the ultimate dollar amount to be awarded ranging from ~~zero~~0 to a maximum of $2.7 million ~~each.~~for each Cash Award. The performance measure for these Cash Awards is relative total stockholder return compared to a peer group of companies measured over a three-year period. The ultimate dollar amount to be awarded for the 2019 Cash Awards is limited to their targeted award value ($1.3 million) if the Company's total stockholder return is negative over the performance period. The obligation related to the Cash Awards is classified as a liability and recognized over the vesting period.

Stock-based compensation pre-tax expense recognized in the three and ~~six~~nine months ended ~~June~~September 30, 2019 totaled $4.2 million and ~~$8.6~~$12.8 million, respectively. Stock-based compensation pre-tax expense recognized in the three and ~~six~~nine months ended ~~June~~September 30, 2018 totaled ~~$6.0~~$5.7 million and ~~$11.2~~$16.6 million, respectively. As of ~~June~~September 30, 2019, there was ~~$22.4~~$18.6 million of pre-tax compensation costs related to service-based and performance-based stock awards, which will be recognized in future periods as vesting conditions are satisfied.

OIL STATES INTERNATIONAL, INC. AND SUBSIDIARIES

NOTES TO UNAUDITED CONDENSED CONSOLIDATED

FINANCIAL STATEMENTS

(Continued)


12.	Income Taxes

The income tax benefit for the three and ~~six~~nine month periods ended ~~June~~September 30, 2019 was calculated using a discrete approach. This methodology was used because minor changes in the Company's results of operations and non-deductible expenses can materially impact the estimated annual effective tax rate. For the three months ended ~~June~~September 30, 2019, the Company's income tax benefit was ~~$0.3~~$6.2 million, or ~~2.6%~~16.3% of pre-tax losses. For the ~~six~~nine months ended ~~June~~September 30, 2019, the Company's income tax benefit was ~~$0.5~~$6.7 million, or ~~2.2%~~10.7% of pre-tax losses. This compares to an income tax ~~provision~~benefit of ~~$1.7~~$3.8 million, or ~~38.8%~~48.8% of pre-tax ~~income,~~losses, and an income tax ~~provision~~benefit of ~~$0.5~~$3.3 million, or ~~212.5%~~41.1% of pre-tax losses, for the three and ~~six~~nine months ended ~~June~~September 30, 2018, respectively. The ~~relatively low~~ effective tax rate benefit for the three and ~~six~~nine months ended ~~June~~September 30, 2019 was below the U.S. statutory rate primarily ~~attributable~~due to certain non-deductible expenses.


13.	Segments and Related Information

The Company operates through ~~three~~3 reportable segments: Well Site Services, Downhole Technologies and Offshore/Manufactured Products. The Company's reportable segments represent strategic business units that generally offer different products and services. They are managed separately because each business often requires different technologies and marketing strategies. Recent acquisitions, except for the acquisition of GEODynamics in 2018, have been direct extensions to our business segments.

Financial information by business segment for the three and ~~six~~nine months ended ~~June~~September 30, 2019 and 2018 is summarized in the following tables (in thousands).


	Revenues		Depreciation and amortization		Operating income (loss)			Capital expenditures		Total assets		Revenues		Depreciation and amortization		Operating income (loss)			Capital expenditures		Total assets
Three months ended June 30, 2019
Three months ended September 30, 2019
Well Site Services –
Completion Services	$	103,320	$	17,248	$	(507	)	$	7,201	$	507,028	$	103,966	$	17,024	$	1,719		$	6,088	$	496,684
Drilling Services(1)	12,646		3,224		(2,601		)	965		59,322		12,034		3,164		(36,495		)	538		21,464
Total Well Site Services	115,966		20,472		(3,108		)	8,166		566,350		116,000		20,188		(34,776		)	6,626		518,148
Downhole Technologies	46,740		5,256		(1,462		)	3,460		707,878		42,882		5,309		659			4,045		700,789
Offshore/Manufactured Products	101,979		5,973		9,809			1,720		677,644		104,815		5,680		11,139			3,147		673,947
Corporate	—		182		(11,634		)	309		45,829		—		189		(11,932		)	437		41,080
Total	$	264,685	$	31,883	$	(6,395	)	$	13,655	$	1,997,701	$	263,697	$	31,366	$	(34,910	)	$	14,255	$	1,933,964



	Revenues		Depreciation and amortization		Operating income (loss)			Capital expenditures		Total assets
Three months ended September 30, 2018
Well Site Services –
Completion Services	$	111,669	$	16,884	$	(3,271	)	$	17,915	$	540,203
Drilling Services	16,920		3,479		(2,206		)	2,711		68,444
Total Well Site Services	128,589		20,363		(5,477		)	20,626		608,647
Downhole Technologies	56,571		4,582		6,485			8,727		691,974
Offshore/Manufactured Products	89,434		5,426		7,069			3,475		703,203
Corporate	—		215		(11,799		)	197		40,972
Total	$	274,594	$	30,586	$	(3,722	)	$	33,025	$	2,044,796

OIL STATES INTERNATIONAL, INC. AND SUBSIDIARIES

NOTES TO UNAUDITED CONDENSED CONSOLIDATED

FINANCIAL STATEMENTS

(Continued)


	Revenues		Depreciation and amortization		Operating income (loss)			Capital expenditures		Total assets		Revenues		Depreciation and amortization		Operating income (loss)			Capital expenditures		Total assets
Three months ended June 30, 2018
Nine months ended September 30, 2019
Well Site Services –
Completion Services	$	108,368	$	16,816	$	1,204		$	14,590	$	526,551	$	307,928	$	51,558	$	(2,282	)	$	24,971	$	496,684
Drilling Services(1)	16,756		3,551		(2,957		)	1,801		69,256		32,430		9,729		(43,655		)	2,452		21,464
Total Well Site Services	125,124		20,367		(1,753		)	16,391		595,807		340,358		61,287		(45,937		)	27,423		518,148
Downhole Technologies	59,274		4,532		11,600			3,168		677,367		143,912		15,631		3,251			11,121		700,789
Offshore/Manufactured Products	101,447		5,786		12,664			4,108		710,125		294,723		17,240		26,207			6,413		673,947
Corporate	—		237		(13,811		)	356		41,827		—		642		(35,666		)	875		41,080
Total	$	285,845	$	30,922	$	8,700		$	24,023	$	2,025,126	$	778,993	$	94,800	$	(52,145	)	$	45,832	$	1,933,964

Revenues Depreciation and
amortization Operating income (loss) Capital
expenditures Total assets
Six months ended June 30, 2019
Well Site Services –
Completion Services $ 203,962
$ 34,534
$ (4,001 ) $ 18,883
$ 507,028
Drilling Services 20,396
6,565
(7,160 ) 1,914
59,322
Total Well Site Services 224,358
41,099
(11,161 ) 20,797
566,350
Downhole Technologies 101,030
10,322
2,592
7,076
707,878
Offshore/Manufactured Products 189,908
11,560
15,068
3,266
677,644
Corporate —
453
(23,734 ) 438
45,829
Total $ 515,296
$ 63,434
$ (17,235 ) $ 31,577
$ 1,997,701


	Revenues		Depreciation and amortization		Operating income (loss)			Capital expenditures		Total assets		Revenues		Depreciation and amortization		Operating income (loss)			Capital expenditures		Total assets
Six months ended June 30, 2018
Nine months ended September 30, 2018
Well Site Services –
Completion Services	$	191,208	$	32,198	$	(3,267	)	$	22,515	$	526,551	$	302,877	$	49,082	$	(6,538	)	$	40,430	$	540,203
Drilling Services	34,315		7,419		(5,268		)	3,026		69,256		51,235		10,898		(7,474		)	5,737		68,444
Total Well Site Services	225,523		39,617		(8,535		)	25,541		595,807		354,112		59,980		(14,012		)	46,167		608,647
Downhole Technologies	105,055		8,416		19,654			5,066		677,367		161,626		12,998		26,139			13,793		691,974
Offshore/Manufactured Products	208,843		11,600		25,116			7,131		710,125		298,277		17,026		32,185			10,606		703,203
Corporate	—		479		(28,449		)	523		41,827		—		694		(40,248		)	720		40,972
Total	$	539,421	$	60,112	$	7,786		$	38,261	$	2,025,126	$	814,015	$	90,698	$	4,064		$	71,286	$	2,044,796

________________


(1)	Operating loss for the Drilling Services business includes a non-cash fixed asset impairment charge of $33.7 million. See Note 4, “Details of Selected Balance Sheet Accounts,” for further discussion.

No customer individually accounted for 10% of the Company's consolidated product and service revenue for the nine months ended September 30, 2019 or individually represented 10% of the Company's consolidated total accounts receivable as of September 30, 2019. One customer individually accounted for 10% of the Company's consolidated product and service revenue for the ~~six~~nine months ended ~~June~~September 30, 2018 and individually represented 11% of the Company's consolidated total accounts receivable as of December 31, 2018.

The following table provides supplemental disaggregated revenue from contracts with customers by business segment for the three and nine months ended September 30, 2019 and 2018 (in thousands):



	Well Site Services				Downhole Technologies				Offshore/Manufactured Products				Total
	2019		2018		2019		2018		2019		2018		2019		2018
Three months ended September 30
Major revenue categories -
Project-driven products	$	—	$	—	$	—	$	—	$	39,474	$	22,277	$	39,474	$	22,277
Short-cycle:
Completion products and services	103,966		111,669		42,882		56,571		26,710		27,463		173,558		195,703
Drilling services	12,034		16,920		—		—		—		—		12,034		16,920
Other products	—		—		—		—		7,988		6,707		7,988		6,707
Total short-cycle	116,000		128,589		42,882		56,571		34,698		34,170		193,580		219,330
Other products and services	—		—		—		—		30,643		32,987		30,643		32,987
	$	116,000	$	128,589	$	42,882	$	56,571	$	104,815	$	89,434	$	263,697	$	274,594



Percentage of total revenue by type -
Products	—	%	—	%	98	%	98	%	77	%	73	%	46	%	44	%
Services	100	%	100	%	2	%	2	%	23	%	27	%	54	%	56	%

OIL STATES INTERNATIONAL, INC. AND SUBSIDIARIES

NOTES TO UNAUDITED CONDENSED CONSOLIDATED

FINANCIAL STATEMENTS

(Continued)

~~The following table provides supplemental disaggregated revenue from contracts with customers by business segment for the three and six months ended June 30, 2019 and 2018 (in thousands):~~


	Well Site Services				Downhole Technologies				Offshore/Manufactured Products				Total				Well Site Services				Downhole Technologies				Offshore/Manufactured Products				Total
	2019		2018		2019		2018		2019		2018		2019		2018		2019		2018		2019		2018		2019		2018		2019		2018
Three months ended June 30
Nine months ended September 30
Major revenue categories -
Project-driven products	$	—	$	—	$	—	$	—	$	38,517	$	35,225	$	38,517	$	35,225	$	—	$	—	$	—	$	—	$	105,236	$	98,301	$	105,236	$	98,301
Short-cycle:
Completion products and services	103,320		108,368		46,740		59,274		29,265		29,783		179,325		197,425		307,928		302,877		143,912		161,626		80,250		90,218		532,090		554,721
Drilling services	12,646		16,756		—		—		—		—		12,646		16,756		32,430		51,235		—		—		—		—		32,430		51,235
Other products	—		—		—		—		5,746		7,565		5,746		7,565		—		—		—		—		21,472		21,718		21,472		21,718
Total short-cycle	115,966		125,124		46,740		59,274		35,011		37,348		197,717		221,746		340,358		354,112		143,912		161,626		101,722		111,936		585,992		627,674
Other products and services	—		—		—		—		28,451		28,874		28,451		28,874		—		—		—		—		87,765		88,040		87,765		88,040
	$	115,966	$	125,124	$	46,740	$	59,274	$	101,979	$	101,447	$	264,685	$	285,845	$	340,358	$	354,112	$	143,912	$	161,626	$	294,723	$	298,277	$	778,993	$	814,015

Percentage of total revenue by type -
Products — % — % 98 % 98 % 78 % 77 % 47 % 48 %
Services 100 % 100 % 2 % 2 % 22 % 23 % 53 % 52 %

Well Site Services Downhole Technologies Offshore/Manufactured Products Total
2019 2018 2019 2018 2019 2018 2019 2018
Six months ended June 30
Major revenue categories -
Project-driven products $ —
$ —
$ —
$ —
$ 65,762
$ 76,024
$ 65,762
$ 76,024
Short-cycle:
Completion products and services 203,962
191,208
101,030
105,055
53,540
62,755
358,532
359,018
Drilling services 20,396
34,315
—
—
—
—
20,396
34,315
Other products —
—
—
—
13,484
15,011
13,484
15,011
Total short-cycle 224,358
225,523
101,030
105,055
67,024
77,766
392,412
408,344
Other products and services —
—
—
—
57,122
55,053
57,122
55,053
$ 224,358
$ 225,523
$ 101,030
$ 105,055
$ 189,908
$ 208,843
$ 515,296
$ 539,421


Percentage of total revenue by type -
Products	—	%	—	%	97	%	98	%	75	%	78	%	47	%	49	%	—	%	—	%	97	%	98	%	76	%	76	%	47	%	47	%
Services	100	%	100	%	3	%	2	%	25	%	22	%	53	%	51	%	100	%	100	%	3	%	2	%	24	%	24	%	53	%	53	%

Revenues from products and services transferred to customers over time accounted for approximately 67% and ~~68%~~69% of consolidated revenues for the ~~six~~nine months ended ~~June~~September 30, 2019 and 2018, respectively. The balance of revenues for the respective periods relates to products and services transferred to customers at a point in time. As of ~~June~~September 30, 2019, the Company had ~~$142~~$174 million of remaining backlog related to contracts with an original expected duration of greater than one year. Approximately ~~26%~~13% of this remaining backlog is expected to be recognized as revenue over the remaining ~~six~~three months of 2019, with an additional ~~64%~~55% in 2020 and the balance thereafter.

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

~~NOTES TO UNAUDITED CONDENSED CONSOLIDATED~~

~~FINANCIAL STATEMENTS~~

~~(Continued)~~


14.	Commitments and Contingencies

Following the Company's acquisition of GEODynamics in January 2018, the Company determined that certain steel products historically imported by GEODynamics from China for use in its manufacturing process may potentially be subject to anti-dumping and countervailing duties based on ~~recent~~ clarifications/decisions rendered by the U.S. Department of Commerce and the U.S. Court of International ~~Trade.~~Trade in March 2018. Following these findings, the Company commenced an internal review of this matter and ceased further purchases of these potentially affected Chinese products. As part of the Company's internal review, the Company engaged trade counsel and decided to voluntarily disclose this matter to U.S. Customs and Border Protection in September 2018. In connection with the GEODynamics Acquisition, the seller agreed to indemnify and hold the Company harmless against certain claims related to matters such as this, and the Company has provided notice to and asserted an indemnification claim against the seller. Additionally, the Company is able to set-off payments due under the $25.0 million promissory note (see Note 6, "Long-term Debt") issued to the seller of GEODynamics in respect of indemnification claims. Such note was scheduled to mature on July 12, 2019, but, because the Company has provided notice to and asserted an indemnification claim, the maturity date of the note is extended until the resolution of such claim. The Company expects that the amount ultimately paid in respect of such note may be reduced as a result of this indemnification claim.

Additionally, in the ordinary course of conducting its business, the Company becomes 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.

~~The Company is a~~may become party to various pending or threatened claims, lawsuits and administrative proceedings seeking damages or other remedies concerning its commercial operations, products, employees and other matters, including occasional claims by individuals alleging exposure to hazardous materials as a result of the Company's products or operations. Some of these claims relate to matters occurring prior to the acquisition of businesses (including GEODynamics and Falcon), and some relate to businesses the Company has sold. In certain cases, the Company is entitled to indemnification from the sellers of businesses and, in other cases, the Company has indemnified the buyers of businesses. Although the Company can give no assurance about the outcome of pending legal and administrative proceedings and the effect such outcomes may have on the Company, management believes 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 the Company's consolidated financial position, results of operations or liquidity.


15.	Related Party Transactions

GEODynamics historically leased certain land and facilities from an equity holder and employee of GEODynamics. In connection with the acquisition of GEODynamics, the Company assumed these leases. The Company exercised its option to purchase the most significant facilities and associated land for approximately $5.4 million in September 2018. Rent expense related to leases with this employee for the three and ~~six~~nine months ended ~~June~~September 30, 2019 totaled $44 thousand and ~~$69~~$113 thousand, respectively. Rent expense related to leases with this employee for the three months ended ~~June~~September 30, 2018 and the period from January 12, 2018 through ~~June~~September 30, 2018 totaled ~~$142~~$96 thousand and ~~$220~~$316 thousand, respectively.

Additionally, in 2019 GEODynamics purchased products from and sold products to a company in which this employee is an investor. Purchases from this company were $0.4 million and ~~$0.8~~$1.2 million for the three and ~~six~~nine months ended ~~June~~September 30, 2019, respectively. Sales to this company by GEODynamics were ~~$0.6~~$0.4 million and $1.0 million for ~~both~~ the three and ~~six~~nine months ended ~~June~~September 30, ~~2019.~~2019, respectively.

Cautionary Statement Regarding Forward-Looking Statements

This Quarterly Report on Form 10-Q and other statements we make contain certain "forward-looking statements" within the meaning of Section 27A of the Securities Act of 1933 and Section 21E of the Securities Exchange Act of 1934 (the "Exchange Act"). Actual results could differ materially from those projected in the forward-looking statements as a result of a number of important factors. For a discussion of known material factors that could affect our results, please refer to "Part I, Item 1. Business," "Part I, Item 1A. Risk Factors," "Part II, Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations" and "Part II, Item 7A. Quantitative and Qualitative Disclosures about Market Risk" included in our 2018 Form 10-K filed with the Securities and Exchange Commission (the "Commission") on February 19, 2019 as well as "Part II, Item 1A. Risk Factors" included in this Quarterly Report on Form 10-Q.

You can typically identify "forward-looking statements" by the use of forward-looking words such as "may," "will," "could," "project," "believe," "anticipate," "expect," "estimate," "potential," "plan," "forecast," "proposed," "should," "seek," and other similar words. Such statements may relate to our future financial position, budgets, capital expenditures, projected costs, plans and objectives of management for future operations and possible future strategic transactions. Where any such forward-looking statement includes a statement of the assumptions or bases underlying such forward-looking statement, we caution that assumed facts or bases almost always vary from actual results. The differences between assumed facts or bases and actual results can be material, depending upon the circumstances.

In any forward-looking statement where we express an expectation or belief as to future results, such expectation or belief is expressed in good faith and believed to have a reasonable basis. However, there can be no assurance that the statement of expectation or belief will result or be achieved or accomplished. The following are important factors that could cause actual results to differ materially from those expressed in any forward-looking statement made by, or on behalf of, our Company:

the level of supply of and demand for oil and natural gas;

fluctuations in the current and future prices of oil and natural gas;

the cyclical nature of the oil and natural gas industry;

the level of exploration, drilling and completion activity;

the financial health of our customers;

the impact on certain major U.S. areas in which we operate of pipeline take away capacity constraints;

the availability of and access to attractive oil and natural gas field prospects by our customers, which may be affected by governmental actions or actions of other parties which may restrict drilling and completion activities;

the level of offshore oil and natural gas developmental activities;

general global economic conditions;

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

global weather conditions and natural disasters;

changes in tax laws and regulations;

the impact of tariffs and duties on imported raw materials and exported finished goods;

impact of environmental matters, including future environmental or climate change regulations which may result in increased operating costs or reduced commodity demand globally;

our ability to find and retain skilled personnel;

negative outcome of litigation, threatened litigation or government proceedings;

fluctuations in currency exchange rates;

physical, digital, cyber, internal and external security breaches;

the availability and cost of capital;

our ability to protect our intellectual property rights;

our ability to complete the integration of acquired businesses and achieve the expected accretion in earnings; and

the other factors identified in "Part I, Item 1A. Risk Factors" in our 2018 Form 10-K and "Part II, Item 1A. Risk Factors" included in this Quarterly Report on Form 10-Q.

Should one or more of these risks or uncertainties materialize, or should the assumptions on which our forward-looking statements are based prove incorrect, actual results may differ materially from those expected, estimated or projected. In addition, the factors identified above may not necessarily be all of the important factors that could cause actual results to differ materially from those expressed in any forward-looking statement made by us, or on our behalf. Readers are cautioned not to place undue reliance on forward-looking statements, which speak only as of the date hereof. We undertake no responsibility to publicly release the result of any revision of our forward-looking statements after the date they are made.

In addition, in certain places in this Quarterly Report on Form 10-Q, we refer to reports published by third parties that purport to describe trends or developments in the energy industry. The Company does so for the convenience of our stockholders and in an effort to provide information available in the market that will assist the Company's investors to have a better understanding of the market environment in which the Company operates. However, the Company specifically disclaims any responsibility for the accuracy and completeness of such information and undertakes no obligation to update such information.

ITEM 2. Management's Discussion and Analysis of Financial Condition and Results of Operations

The following discussion and analysis should be read together with our condensed consolidated financial statements and the notes to those statements included elsewhere in this Quarterly Report on Form 10‑Q and our consolidated financial statements and notes to those statements included in our 2018 Form 10‑K in order to understand factors, such as business acquisitions and financing transactions, which may impact comparability.

We provide a broad range of products and services to the oil and gas industry through our Well Site Services, Downhole Technologies and Offshore/Manufactured Products business segments. Demand for our products and services is cyclical and substantially dependent upon activity levels in the oil and gas industry, particularly our customers' willingness to invest capital in the exploration for and development of crude oil and natural gas reserves. Our customers' capital spending programs are generally based on their cash flows and their outlook for near-term and long-term commodity prices, economic growth, commodity demand and estimates of resource production. As a result, demand for our products and services is sensitive to future expectations with respect to crude oil and natural gas prices.

Our consolidated results of operations include contributions from the GEODynamics and Falcon acquisitions completed in the first quarter of 2018 (discussed below). Our reported results of operations reflect the impact of current industry trends and customer spending activities with investments ~~recently~~ weighted toward U.S. shale play regions. However, in 2019, we are beginning to see a general improvement in the level of planned investments in deepwater markets globally.

Recent Developments

In addition to capital spending, we have invested in acquisitions of businesses complementary to our growth strategy. Our acquisition strategy has allowed us to leverage our existing and acquired products and services into new geographic locations and has expanded the breadth of our technology and product offerings while allowing us to leverage our cost structure. We have made strategic and complementary acquisitions in each of our business segments in recent years.

On December 12, 2017 we entered into an agreement to acquire GEODynamics, Inc. ("GEODynamics"), which provides oil and gas perforation systems and downhole tools in support of completion, intervention, wireline and well abandonment operations. On January 12, 2018, we closed the acquisition of GEODynamics for total consideration of $615 million (the "GEODynamics Acquisition"), consisting of (i) $295 million in cash (net of cash acquired), (ii) 8.66 million shares of our common stock and (iii) an unsecured $25 million promissory note.

In connection with the GEODynamics Acquisition, we completed several financing transactions to extend the maturity of our debt while providing us with the flexibility to repay outstanding borrowings under our revolving credit facility (the "Revolving Credit Facility") with anticipated future cash flows from operations.

On January 30, 2018, we sold $200.0 million aggregate principal amount of our 1.50% convertible senior notes due 2023 (the "Notes") through a private placement to qualified institutional buyers. We received net proceeds from the offering of the Notes of approximately $194 million, after deducting issuance costs. We used the net proceeds from the sale of the Notes to repay a portion of the borrowings outstanding under our Revolving Credit Facility, substantially all of which were drawn to fund the cash portion of the purchase price paid for GEODynamics.

Concurrently with the Notes offering, we amended our Revolving Credit Facility, to extend the maturity date to January 2022, permit the issuance of the Notes and provide for up to $350.0 million in borrowing capacity.

On February 28, 2018, we acquired Falcon Flowback Services, LLC ("Falcon"), a full service provider of flowback and well testing services for the separation and recovery of fluids, solid debris and proppant used during hydraulic fracturing operations. Falcon provides additional scale and diversity to our Completion Services well testing operations in key shale plays in the United States. The acquisition price was $84.2 million, net of cash acquired. The Falcon acquisition was funded with borrowings under our Revolving Credit Facility.

During the third quarter of 2019, we made the strategic decision to reduce the scope of our Drilling Services business (with plans to adjust from 34 rigs to 9 rigs) due to the ongoing weakness in customer demand for vertical drilling rigs in the U.S. land market. As a result of this decision, our Drilling Services business recorded a non-cash impairment charge of $33.7 million to decrease the carrying value of the business' fixed assets to their estimated fair value.

See Note 3, "Business Acquisitions, ~~Goodwill and Other Intangible Assets"~~" Note 4, "Details of Selected Balance Sheet Accounts," and Note 6, "Long-term Debt" to the unaudited condensed consolidated financial statements included in this Quarterly Report on Form 10‑Q for further discussion of these recent developments.

Macroeconomic Environment

The macroeconomic environment for the energy sector has been ~~volatile in recent years.~~and continues to be extremely volatile. Significant downward crude oil price volatility began early in the fourth quarter of 2014 and continued into 2016. In response to weakening crude oil prices, the Organization of Petroleum Exporting Countries ("OPEC"), along with Russia, agreed to reduce crude oil production in late 2016 in an effort to re-balance supply and demand. Crude oil prices began to improve in the second half of 2017, which carried into 2018. During 2018, crude oil prices rose to their highest levels since the beginning of the downturn, improving our customers' cash flow and potentially driving them to invest additional capital to increase their production. Additionally, advancements in technologies and improved operating efficiencies have allowed the U.S. exploration and production industry to lower the breakeven price of oil and gas production. During 2017 and 2018, rising crude oil prices rapidly translated into increased U.S. land oriented drilling and completion activity in areas of concentration such as the Permian Basin, which led to record high domestic production. The U.S. Energy Information Administration estimates that U.S. crude oil production averaged 11.0 million barrels per day in 2018, up approximately 17% from the 2017 average, reaching its highest level, ~~and~~ experiencing the largest volume growth on ~~record.~~record and accounting for approximately 60% of global demand growth over the period. However, during the fourth quarter of 2018, crude oil prices declined approximately 40%, due in part to higher than expected supply growth from the United States, Russia and Saudi Arabia, as well as ~~concerns over the possible~~ slowing of global demand growth. In response to the precipitous decline in crude oil prices, OPEC and Russia agreed to reduce production and the Canadian government mandated a production shut‑in in December of 2018. In July 2019, OPEC and Russia agreed to extend these production cuts through March 2020.

After declining materially in the fourth quarter of 2018, Brent and West Texas Intermediate ("WTI") crude oil prices closed at $51 and $45 per barrel, respectively, on December 31, 2018. Subsequent to year-end 2018, Brent and WTI crude oil prices increased to ~~$68~~$61 and ~~$58~~$54 per barrel, respectively, as of ~~June~~September 30, 2019. Additionally, during the first quarter of 2019, the pricing differential for WTI crude oil between Cushing, Oklahoma and Midland, Texas was effectively eliminated due to improvements in pipeline takeaway capacity from the Permian Basin, providing operators in the region with increased cash flows. While the commodity price environment has improved in 2019 relative to ~~late~~December of 2018, the crude oil price outlook and associated volatility continues to have a moderating impact on our customers' operating results and capital spending plans, particularly those operating in the U.S. shale play regions. The ~~average~~ U.S. rig count ~~for~~at September 30, 2019 of 860 rigs has fallen 21% since the ~~second quarter~~most recent peak of ~~2019 decreased 8% compared to the fourth quarter 2018 average.~~1,083 rigs in December 2018.

Current and expected future pricing for WTI crude will continue to influence our customers' spending in U.S. shale play developments as our customers strive for financial discipline and spending levels that are within their capital budgets and generated cash flow ranges. Expectations for the longer-term price for Brent crude oil will continue to influence our customers' spending related to global offshore drilling and development and, thus, a significant portion of the activity of our Offshore/Manufactured Products segment.

There remains a degree of risk that crude oil prices could remain highly volatile due to increases in global inventory levels, increasing domestic or international crude oil production, trade tensions with China, ~~and Mexico,~~ sanctions ~~or potential waivers~~ on Iranian production and tensions with Iran, civil unrest in Libya and Venezuela, increasing price differentials between markets, slowing growth rates in China and other global regions, use of alternative fuels, improved vehicle fuel efficiency, a more sustained movement to electric vehicles and/or the potential for ongoing supply/demand imbalances. Conversely, if the global supply of crude oil were to decrease due to a prolonged reduction in capital investment by our customers or if government instability in a major oil-producing nation develops, and energy demand were to continue to increase, a sustained recovery in WTI and Brent crude oil prices could occur. In any event, crude oil price improvements will depend upon the balance of global supply and demand, with a corresponding continued reduction in global inventories.

Customer spending in the natural gas shale plays has been limited due to natural gas production from prolific basins in the Northeastern United States and from associated gas produced from the drilling and completion of unconventional oil wells in North America.

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


		Average Price⁽¹⁾ for quarter ended								Average Price⁽¹⁾ for year ended December 31			Average Price⁽¹⁾ for quarter ended								Average Price⁽¹⁾ for year ended December 31
Year		March 31		June 30		September 30		December 31		Average Price⁽¹⁾ for year ended December 31			March 31		June 30		September 30		December 31		Average Price⁽¹⁾ for year ended December 31
WTI Crude (per bbl)	WTI Crude (per bbl)											WTI Crude (per bbl)
2019		$	54.82	$	59.88								$	54.82	$	59.88	$	56.34
2018	⁽²⁾	$	62.91	$	68.07	$	69.70	$	59.97	$	65.25	⁽²⁾	$	62.91	$	68.07	$	69.70	$	59.97	$	65.25
2017		$	51.62	$	48.13	$	48.18	$	55.27	$	50.80		$	51.62	$	48.13	$	48.18	$	55.27	$	50.80
Brent Crude (per bbl)	Brent Crude (per bbl)											Brent Crude (per bbl)
2019		$	63.10	$	69.01								$	63.10	$	69.01	$	61.95
2018	⁽²⁾	$	66.86	$	74.53	$	75.08	$	68.76	$	71.32	⁽²⁾	$	66.86	$	74.53	$	75.08	$	68.76	$	71.32
2017		$	53.59	$	49.55	$	52.10	$	61.40	$	54.12		$	53.59	$	49.55	$	52.10	$	61.40	$	54.12
Henry Hub Natural Gas (per mmBtu)	Henry Hub Natural Gas (per mmBtu)											Henry Hub Natural Gas (per mmBtu)
2019		$	2.92	$	2.57								$	2.92	$	2.57	$	2.38
2018		$	3.08	$	2.85	$	2.93	$	3.77	$	3.15		$	3.08	$	2.85	$	2.93	$	3.77	$	3.15
2017		$	3.02	$	3.08	$	2.95	$	2.90	$	2.99		$	3.02	$	3.08	$	2.95	$	2.90	$	2.99


(1)	Source: U.S. Energy Information Administration. As of ~~July 22,~~October 24, 2019, WTI crude oil, Brent crude oil and natural gas traded at approximately ~~$55.87~~$56.11 per barrel, ~~$61.96~~$61.71 per barrel and $2.33 per mmBtu, respectively.

(2)

Reflecting the impact of pipeline takeaway capacity constraints from the Permian Basin, the average price per barrel for WTI (Midland, Texas) crude oil for the first, second, third and fourth quarters of 2018 was approximately 1%, 12%, 21% and 11%, respectively, below the average WTI crude oil quarterly benchmark prices referenced, which are based on the spot price of WTI at Cushing, Oklahoma. Brent crude oil average quarterly prices for the first, second, third and fourth quarters of 2018 were 7%, 24%, 36% and 28%, respectively above the corresponding WTI (Midland, Texas) crude oil quarterly average prices. During the first quarter of 2019, the differential between WTI crude oil pricing and WTI (Midland, Texas) crude oil pricing was effectively eliminated due to reductions in pipeline takeaway capacity constraints from the Permian Basin.

Overview

Our Well Site Services segment provides completion services in the United States (including the Gulf of Mexico) and the rest of the world and, to a much lesser extent, land drilling services in the United States. U.S. drilling and completion activity and, in turn, our Well Site Services results, are sensitive to near-term fluctuations in commodity prices, particularly WTI crude oil prices, given the short-term, call-out nature of its operations.

Within this segment, our Completion Services business (which includes the Falcon operations we acquired in February 2018) supplies equipment and service personnel utilized in the completion and initial production of new and recompleted wells. Activity for the Completion Services business is dependent primarily upon the level and complexity of drilling, completion, and workover activity in the areas of operations mentioned above. Well intensity and complexity has increased with the continuing transition to multi-well pads, the drilling of longer lateral wells and increased downhole pressures, along with the increased number of frac stages completed in horizontal wells. Similarly, demand for our Drilling Services operations ishas historically been driven by activity in our primary land drilling markets of the Permian Basin in West Texas and the U.S. Rocky Mountain area. During the third quarter of 2019, we made the strategic decision to reduce the scope of our Drilling Services business (with plans to adjust from 34 rigs to 9 rigs) due to the ongoing weakness in customer demand for vertical drilling rigs in the U.S. land market. Prospectively, the operations will primarily focus on serving operators in the Rocky Mountain region. See Note 4, "Details of Selected Balance Sheet Accounts."

Our Downhole Technologies segment is comprised of the GEODynamics business we acquired in January 2018. GEODynamics was founded in 2004 as a researcher, developer and manufacturer of consumable engineered products used in completion applications. This segment provides oil and gas perforation systems, downhole tools and services in support of completion, intervention, wireline and well abandonment operations. This segment designs, manufactures and markets its consumable engineered products to oilfield service as well as exploration and production companies. Product and service offerings for this segment include innovations in perforation technology through patented and proprietary systems combined with advanced modeling and analysis tools. This expertise has led to the optimization of perforation hole size, depth, and quality of tunnels, which are key factors for maximizing the effectiveness of hydraulic fracturing. Additional offerings include proprietary toe valve and frac plug products, which are focused on zonal isolation for hydraulic fracturing of horizontal wells, and a broad range of consumable products, such as setting tools and bridge plugs, that are used in completion, intervention and decommissioning applications. Demand drivers for the Downhole Technologies segment include continued trends toward longer lateral lengths, increased frac stages and more perforation clusters to target increased unconventional well productivity.

Demand for our Well Site Services and Downhole Technologies segments' businesses is correlated to changes in the total number of wells drilled in the United States, total footage drilled, the number of drilled wells that are completed and, to a lesser degree, changes in the drilling rig count. The following table sets forth a summary of the average U.S. drilling rig count, as measured by Baker Hughes, for the periods indicated.


	Three Months Ended June 30,		Six Months Ended June 30,		Three Months Ended September 30,		Nine Months Ended September 30,
	2019	2018	2019	2018	2019	2018	2019	2018
Average U.S. drilling rig count
Land – Oil	783	827	807	797	733	848	782	814
Land – Natural gas and other	180	191	185	189	160	181	177	184
Offshore	27	21	24	17	27	22	25	21
Total	989	1,039	1,016	1,003	920	1,051	984	1,019

Over recent years, our industry experienced increased customer spending in crude oil and liquids-rich exploration and development in U.S. shale plays utilizing horizontal drilling and completion techniques. As of ~~June~~September 30, 2019, oil-directed drilling accounted for ~~82%~~83% of the total U.S. rig count – with the balance largely natural gas related. The average U.S. rig count for the three months ended ~~June~~September 30, 2019 decreased by 50131 rigs, or 5%12%, compared to the average for the three months ended ~~June~~September 30, 2018.

Many of our exploration and production customers defer well completions due to a number of factors, including normal operational delays, cost management, current crude oil and national gas prices, and problem wells. These deferred completions are referred to in the industry as drilled but uncompleted wells (or "DUCs"). Given our Well Site Services and Downhole Technologies segments' exposure to the level of completion activity, an increase in the number of DUCs will have a short-term negative impact on our results of operations relative to the rig count trends but over the longer-term should have a positive impact on the segments' results as the wells are completed.

Our Offshore/Manufactured Products segment provides technology-driven, highly-engineered products and services for offshore oil and natural gas production systems and facilities, as well as certain products and services to the offshore and land-based drilling and completion markets. Approximately 60% of Offshore/Manufactured Products sales in 2016 were driven by our customers' capital spending for offshore production systems and subsea pipelines, repairs and, to a lesser extent, upgrades of existing offshore drilling rigs and construction of new offshore drilling rigs and vessels (referred to herein as "project-driven products"). For the first ~~half~~nine months of 2019, these activities only represent approximately ~~35%~~36% of the segment's revenue. This segment is particularly influenced by global

deepwater drilling and production spending, which are driven largely by our customers' longer-term commodity demand forecasts and 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 (primarily international oil companies ("IOCs") and state-run national oil companies ("NOCs")) using relatively conservative crude oil and natural gas pricing assumptions. Given the longer lead times associated with field development, we believe some of these deepwater projects, once approved for development, are therefore less susceptible to short-term fluctuations in the price of crude oil and natural gas. However, the decline in crude oil prices that began in 2014 and continued into 2016, coupled with the relatively uncertain outlook around shorter-term and possibly longer-term pricing improvements, caused exploration and production companies to reduce their capital expenditures in regards to these deepwater projects since they are expensive to drill and complete, have long lead times to first production and may be considered uneconomical relative to the risk involved. Customers have focused on improving the economics of major deepwater projects at lower commodity breakeven prices by re-bidding projects, identifying advancements in technology, and reducing overall project costs through equipment standardization. As a result, our bookings declined over this period, leading to substantially reduced backlog in 2018, and lower levels of project-driven revenue in 2018 ~~and the first half of 2019~~ relative to prior years. During 2019, we have experienced higher bidding and quoting activity in this segment, leading to an improved outlook.

Our Offshore/Manufactured Products segment revenues and operating income declined at a slower pace during 2015 and 2016 than our Well Site Services segment given the high levels of backlog that existed at the beginning of 2015. Bidding and quoting activity, along with orders from customers, for our Offshore/Manufactured Products segment continued after 2014, albeit at a substantially slower pace. Reflecting the impact of customer (both IOCs and NOCs) delays and deferrals in approving major, capital intensive projects in light of the prolonged low commodity price environment, backlog in our Offshore/Manufactured Products segment decreased from $599 million at June 30, 2014 to $179 million at December 31, 2018. However, deepwater project award potential appears to be improving despite ~~the recent~~ commodity price volatility. During the first ~~six~~nine months of 2019, backlog increased ~~$104~~$114 million, totaling ~~$283~~$293 million at ~~June~~September 30, 2019 – the highest level recorded since the ~~second~~first quarter of 2016. The segment received ~~three~~four notable orders during the first ~~six~~nine months of 2019 for production facility content destined for South America and Southeast Asia, as well as connector products destined for the Middle ~~East.~~East and military products for the United States. The following table sets forth reported backlog for our Offshore/Manufactured Products segment as of the dates indicated (in millions).


	Backlog as of								Backlog as of
Year	March 31		June 30		September 30		December 31		March 31		June 30		September 30		December 31
2019	$	234	$	283					$	234	$	283	$	293
2018	$	157	$	165	$	175	$	179	$	157	$	165	$	175	$	179
2017	$	204	$	202	$	198	$	168	$	204	$	202	$	198	$	168
2016	$	306	$	268	$	203	$	199	$	306	$	268	$	203	$	199

Reduced demand for our products and services, coupled with a reduction in the prices we charge our customers for our services, has adversely affected our results of operations, cash flows and financial position since the second half of 2014. If the current pricing environment for crude oil does not continue to improve, or declines ~~again,~~further, our customers may be required to further reduce their capital expenditures, causing additional declines in the demand for, and prices of, our products and services, which would adversely affect our results of operations, cash flows and financial position.

We use a variety of domestically produced and imported raw materials and component products, including steel, in manufacturing our products. The United States recently imposed tariffs on a variety of imported products, including steel and aluminum. In response to the U.S. tariffs on steel and aluminum, the European Union and several other countries, including Canada and China, have threatened and/or imposed retaliatory tariffs. The effect of these new tariffs and the application and interpretation of existing trade agreements and customs, anti-dumping and countervailing duty regulations continue to evolve, and we continue to monitor these matters. If we encounter difficulty in procuring these raw materials and component products, or if the prices we have to pay for these products increase as a result of customs, anti-dumping and countervailing duty regulations or otherwise, and we are unable to pass corresponding cost increases on to our customers, our financial position and results of operations could be adversely affected. Furthermore, uncertainty with respect to potential costs in the drilling and completion of oil and gas wells, or regarding the expected impact of such tariffs on the demand for and the price of crude oil, could cause our customers to delay or cancel planned projects which, if this occurred, would adversely affect our financial position and results of operations. See Note 14, "Commitments and Contingencies."

Other factors that can affect our business and financial results include but are not limited to the general global economic environment, competitive pricing pressures, regulatory changes and changes in tax laws in the United States and international markets. We continue to monitor the global economy, the prices of and demand for crude oil and natural gas, and the resultant impact on the capital spending plans and operations of our customers in order to plan and manage our business.

Selected Financial Data

Unaudited Consolidated Results of Operations Data

The following summarizes our unaudited consolidated results of operations for the three and ~~six~~nine months ended ~~June~~September 30, 2019 and 2018 (in thousands, except per share amounts):


	Three Months Ended June 30,									Six Months Ended June 30,									Three Months Ended September 30,									Nine Months Ended September 30,
	2019			2018			Variance			2019			2018			Variance			2019			2018			Variance			2019			2018			Variance
Revenues
Products	$	124,965		$	136,182		$	(11,217	)	$	241,293		$	265,008		$	(23,715	)	$	122,067		$	120,271		$	1,796		$	363,360		$	385,279		$	(21,919	)
Services	139,720			149,663			(9,943		)	274,003			274,413			(410		)	141,630			154,323			(12,693		)	415,633			428,736			(13,103		)
	264,685			285,845			(21,160		)	515,296			539,421			(24,125		)	263,697			274,594			(10,897		)	778,993			814,015			(35,022		)
Costs and expenses:
Product costs	95,289			95,324			(35		)	184,557			188,300			(3,743		)	90,796			87,822			2,974			275,353			276,122			(769		)
Service costs	112,823			118,079			(5,256		)	223,433			214,993			8,440			110,294			127,836			(17,542		)	333,727			342,829			(9,102		)
Cost of revenues (exclusive of depreciation and amortization expense presented below)	208,112			213,403			(5,291		)	407,990			403,293			4,697			201,090			215,658			(14,568		)	609,080			618,951			(9,871		)
Selling, general and administrative expenses	31,484			35,919			(4,435		)	61,592			70,114			(8,522		)	31,935			32,285			(350		)	93,527			102,399			(8,872		)
Depreciation and amortization expense	31,883			30,922			961			63,434			60,112			3,322			31,366			30,586			780			94,800			90,698			4,102
Other operating income, net	(399		)	(3,099		)	2,700			(485		)	(1,884		)	1,399
Impairment of fixed assets⁽¹⁾																			33,697			—			33,697			33,697			—			33,697
Other operating (income) expense, net																			519			(213		)	732			34			(2,097		)	2,131
	271,080			277,145			(6,065		)	532,531			531,635			896			298,607			278,316			20,291			831,138			809,951			21,187
Operating income (loss)	(6,395		)	8,700			(15,095		)	(17,235		)	7,786			(25,021		)	(34,910		)	(3,722		)	(31,188		)	(52,145		)	4,064			(56,209		)
Interest expense	(4,658		)	(4,913		)	255			(9,455		)	(9,446		)	(9		)
Interest income	41			123			(82		)	86			202			(116		)
Interest expense, net																			(4,352		)	(4,843		)	491			(13,721		)	(14,087		)	366
Other income	1,009			571			438			1,676			1,218			458			1,190			709			481			2,866			1,927			939
Income (loss) before income taxes	(10,003		)	4,481			(14,484		)	(24,928		)	(240		)	(24,688		)
Income tax benefit (provision)	263			(1,739		)	2,002			540			(510		)	1,050
Net income (loss)	$	(9,740	)	$	2,742		$	(12,482	)	$	(24,388	)	$	(750	)	$	(23,638	)
Loss before income taxes																			(38,072		)	(7,856		)	(30,216		)	(63,000		)	(8,096		)	(54,904		)
Income tax benefit																			6,204			3,837			2,367			6,744			3,327			3,417
Net loss																			$	(31,868	)	$	(4,019	)	$	(27,849	)	$	(56,256	)	$	(4,769	)	$	(51,487	)

Net income (loss) per share:
Net loss per share:																			Net loss per share:
Basic	$	(0.16	)	$	0.05					$	(0.41	)	$	(0.01	)				$	(0.54	)	$	(0.07	)				$	(0.95	)	$	(0.08	)
Diluted	(0.16		)	0.05						(0.41		)	(0.01		)				(0.54		)	(0.07		)				(0.95		)	(0.08		)

Weighted average number of common shares outstanding:
Basic	59,406			59,005						59,332			58,396						59,423			59,026						59,362			58,606
Diluted	59,406			59,005						59,332			58,396						59,423			59,026						59,362			58,606

_____________


(1)	Operating loss for the Drilling Services business includes a non-cash fixed asset impairment charge of $33.7 million for the three and nine months ended September 30, 2019. See Note 4, "Details of Selected Balance Sheet Accounts," to the condensed consolidated financial statements for further discussion.

Unaudited Operating Segment Financial Data

We manage and measure our business performance in three distinct operating segments: Well Site Services, Downhole Technologies and Offshore/Manufactured Products. Supplemental unaudited financial information by business segment for the three and ~~six~~nine months ended ~~June~~September 30, 2019 and 2018 is summarized below (dollars in thousands):


	Three Months Ended June 30,									Six Months Ended June 30,									Three Months Ended September 30,									Nine Months Ended September 30,
	2019			2018			Variance			2019			2018			Variance			2019			2018			Variance			2019			2018			Variance
Revenues
Well Site Services -
Completion Services	$	103,320		$	108,368		$	(5,048	)	$	203,962		$	191,208		$	12,754		$	103,966		$	111,669		$	(7,703	)	$	307,928		$	302,877		$	5,051
Drilling Services	12,646			16,756			(4,110		)	20,396			34,315			(13,919		)	12,034			16,920			(4,886		)	32,430			51,235			(18,805		)
Total Well Site Services	115,966			125,124			(9,158		)	224,358			225,523			(1,165		)	116,000			128,589			(12,589		)	340,358			354,112			(13,754		)
Downhole Technologies	46,740			59,274			(12,534		)	101,030			105,055			(4,025		)	42,882			56,571			(13,689		)	143,912			161,626			(17,714		)
Offshore/Manufactured Products	101,979			101,447			532			189,908			208,843			(18,935		)	104,815			89,434			15,381			294,723			298,277			(3,554		)
Total	$	264,685		$	285,845		$	(21,160	)	$	515,296		$	539,421		$	(24,125	)	$	263,697		$	274,594		$	(10,897	)	$	778,993		$	814,015		$	(35,022	)

Operating income (loss)
Well Site Services -
Completion Services	$	(507	)	$	1,204		$	(1,711	)	$	(4,001	)	$	(3,267	)	$	(734	)	$	1,719		$	(3,271	)	$	4,990		$	(2,282	)	$	(6,538	)	$	4,256
Drilling Services(1)	(2,601		)	(2,957		)	356			(7,160		)	(5,268		)	(1,892		)	(36,495		)	(2,206		)	(34,289		)	(43,655		)	(7,474		)	(36,181		)
Total Well Site Services	(3,108		)	(1,753		)	(1,355		)	(11,161		)	(8,535		)	(2,626		)	(34,776		)	(5,477		)	(29,299		)	(45,937		)	(14,012		)	(31,925		)
Downhole Technologies	(1,462		)	11,600			(13,062		)	2,592			19,654			(17,062		)	659			6,485			(5,826		)	3,251			26,139			(22,888		)
Offshore/Manufactured Products	9,809			12,664			(2,855		)	15,068			25,116			(10,048		)	11,139			7,069			4,070			26,207			32,185			(5,978		)
Corporate	(11,634		)	(13,811		)	2,177			(23,734		)	(28,449		)	4,715			(11,932		)	(11,799		)	(133		)	(35,666		)	(40,248		)	4,582
Total	$	(6,395	)	$	8,700		$	(15,095	)	$	(17,235	)	$	7,786		$	(25,021	)	$	(34,910	)	$	(3,722	)	$	(31,188	)	$	(52,145	)	$	4,064		$	(56,209	)

																	Operating income (loss) as a percentage of revenues⁽¹⁾⁽²⁾
Well Site Services -
Completion Services	—	%	1	%	(2	)%	(2	)%	2	%	(3	)%	(1	)%	(2	)%
Drilling Services	(21	)%	(18	)%	(35	)%	(15	)%	(303	)%	(13	)%	(135	)%	(15	)%
Total Well Site Services	(3	)%	(1	)%	(5	)%	(4	)%	(30	)%	(4	)%	(13	)%	(4	)%
Downhole Technologies	(3	)%	20	%	3	%	19	%	2	%	11	%	2	%	16	%
Offshore/Manufactured Products	10	%	12	%	8	%	12	%	11	%	8	%	9	%	11	%
Total	(2	)%	3	%	(3	)%	1	%	(13	)%	(1	)%	(7	)%	—	%

~~(1) Operating margin is defined as operating income (loss) divided by revenues.~~_____________


(1)	Operating loss for the Drilling Services business includes a non-cash fixed asset impairment charge of $33.7 million for the three and nine months ended September 30, 2019. See Note 4, "Details of Selected Balance Sheet Accounts," to the condensed consolidated financial statements for further discussion.


(2)	Operating margin is defined as operating income (loss) divided by revenues.

Three Months Ended ~~June~~September 30, 2019 Compared to Three Months Ended ~~June~~September 30, 2018

Consolidated Operating Results

We reported a net loss for the three months ended ~~June~~September 30, 2019 of ~~$9.7~~$31.9 million, or ~~$0.16~~$0.54 per diluted share, which included ~~$1.3~~a non-cash fixed asset impairment charge of $33.7 million ($~~1.0~~26.6 million after-tax, or ~~$0.02~~$0.45 per diluted share) and $0.7 million ($0.5 million after-tax, or $0.01 per diluted share) of severance and downsizing costs. These results compare to a net ~~income~~loss for the three months ended ~~June~~September 30, 2018 of ~~$2.7~~$4.0 million, or $0.07 per diluted share, which included $3.5 million ($2.8 million after-tax, or $0.05 per diluted ~~share.~~share) of charges related to legal fees incurred for patent defense and a $2.6 million provision ($2.1 million after-tax, or $0.03 per diluted share) for prior years' Fair Labor Standards Act ("FLSA") claim settlements. Additionally, in the prior-year quarter the Company recognized a $5.8 million ($0.10 per diluted share) income tax benefit related to a change in its provisional estimates with respect to U.S. tax reform legislation.

Our consolidated results of operations include the GEODynamics (Downhole Technologies segment) and Falcon acquisitions completed in the first quarter of 2018. Our reported results of operations reflect the impact of current industry trends and customer spending activities with investments recently weighted toward U.S. shale play regions. However, in 2019, we are beginning to see a general improvement in the level of planned investments in deepwater markets globally.

Revenues. Consolidated total revenues in the ~~second~~third quarter of 2019 decreased ~~$21.2~~$10.9 million, or 7%4%, from the ~~second~~third quarter of 2018. Consolidated product revenues in the ~~second~~third quarter of 2019 ~~decreased $11.2~~increased $1.8 million, or 8%1%, from the ~~second~~third quarter of 2018, ~~driven primarily~~with the impact of higher project-driven product demand in our Offshore/Manufactured Products segment partially offset by lower U.S. land-based customer activity as well as the impact of competitive pricing pressures for conventional perforating products in our Downhole Technologies segment. Consolidated service revenues in the ~~second~~third quarter of 2019 decreased ~~$9.9~~$12.7 million, or 7%8%, from the ~~second~~third quarter of 2018 due primarily to reduced customer spending in the U.S. shale play regions. As can be derived from the following table, ~~75%~~73% of our consolidated revenues in the ~~second~~third quarter of 2019 were derived from sales of our short-cycle product and service offerings, which compares to ~~78%~~80% in the same period last year.

The following table provides supplemental disaggregated revenue from contracts with customers by operating segment for the three months ended ~~June~~September 30, 2019 and 2018 (in thousands):


	Well Site Services				Downhole Technologies				Offshore/ Manufactured Products				Total				Well Site Services				Downhole Technologies				Offshore/ Manufactured Products				Total
Three months ended June 30	2019		2018		2019		2018		2019		2018		2019		2018
Three months ended September 30																	2019		2018		2019		2018		2019		2018		2019		2018
Major revenue categories -
Project-driven products	$	—	$	—	$	—	$	—	$	38,517	$	35,225	$	38,517	$	35,225	$	—	$	—	$	—	$	—	$	39,474	$	22,277	$	39,474	$	22,277
Short-cycle:
Completion products and services	103,320		108,368		46,740		59,274		29,265		29,783		179,325		197,425		103,966		111,669		42,882		56,571		26,710		27,463		173,558		195,703
Drilling services	12,646		16,756		—		—		—		—		12,646		16,756		12,034		16,920		—		—		—		—		12,034		16,920
Other products	—		—		—		—		5,746		7,565		5,746		7,565		—		—		—		—		7,988		6,707		7,988		6,707
Total short-cycle	115,966		125,124		46,740		59,274		35,011		37,348		197,717		221,746		116,000		128,589		42,882		56,571		34,698		34,170		193,580		219,330
Other products and services	—		—		—		—		28,451		28,874		28,451		28,874		—		—		—		—		30,643		32,987		30,643		32,987
	$	115,966	$	125,124	$	46,740	$	59,274	$	101,979	$	101,447	$	264,685	$	285,845	$	116,000	$	128,589	$	42,882	$	56,571	$	104,815	$	89,434	$	263,697	$	274,594


Percentage of total revenue by type -
Products	—	%	—	%	98	%	98	%	78	%	77	%	47	%	48	%	—	%	—	%	98	%	98	%	77	%	73	%	46	%	44	%
Services	100	%	100	%	2	%	2	%	22	%	23	%	53	%	52	%	100	%	100	%	2	%	2	%	23	%	27	%	54	%	56	%

Cost of Revenues (exclusive of Depreciation and Amortization Expense). Our consolidated total cost of revenues (exclusive of depreciation and amortization expense) decreased ~~$5.3~~$14.6 million, or 2%7%, in the ~~second~~third quarter of 2019 compared to the ~~second~~third quarter of 2018. Consolidated product costs in the ~~second~~third quarter of 2019 ~~were consistent with~~increased $3.0 million, or 3%, from the ~~level reported for the second~~third quarter of 2018 while consolidated product revenues ~~decreased 8%~~increased 1% from the prior-year period. The ~~year over-over-year~~year-over-year increase in product costs was driven by the increase in activity levels in the Offshore/Manufactured Products segment, partially offset by the activity-related decrease ~~was influenced by our~~in product costs in the Downhole Technologies segment ~~which experienced an unfavorable shift in product mix, incurred higher product costs and recorded $1.4 million of inventory write-offs due to product design changes~~ during the three months ended ~~June~~September 30, 2019. Consolidated service costs in the ~~second~~third quarter of 2019 decreased ~~$5.3~~$17.5 million, or 4%14%, from the ~~second~~third quarter of 2018, ~~with~~which included the impact of $2.6 million in expense related to the settlement of FLSA claims arising in prior years which was reported within the Well Site Services segment. The balance of the decline in consolidated service costs is due primarily to the impact of lower activity levels in U.S. shale play regions, partially offset by incremental costs in our Downhole Technologies segment associated with an expansion of field support operations.

Selling, General and Administrative Expense. Selling, general and administrative expense, ~~decreased $4.4 million, or 12%,~~ in the ~~second~~third quarter of 2019 ~~from~~was consistent with expense in the ~~second~~third quarter of ~~2018, due primarily to lower stock-based and~~2018. Higher annual incentive plan compensation and bad debt expense reported in the ~~second~~third quarter of 2019 ~~and $1.5~~was offset by the non-recurrence of $3.5 million of ~~nonrecurring~~ patent defense costs recorded during the ~~second~~third quarter of 2018.

Depreciation and Amortization Expense. Depreciation and amortization expense increased ~~$1.0~~$0.8 million, or 3%, in the ~~second~~third quarter of 2019 compared to the prior-year quarter driven primarily by investments in property and equipment over the past twelve months. Note 13, "Segments and Related Information," presents depreciation and amortization expense by segment.

Impairment of Fixed Assets. During the third quarter of 2019, we made the strategic decision to reduce the scope of our Drilling Services business (with plans to adjust from 34 rigs to 9 rigs) due to the ongoing weakness in customer demand for vertical drilling rigs in the U.S. land market. As a result of this decision, our Drilling Services business recorded a non-cash impairment charge of $33.7 million to decrease the carrying value of the unit’s fixed assets. See Note 4, “Details of Selected Balance Sheet Accounts,” to the unaudited condensed consolidated financial statements included in this Quarterly Report on Form 10‑Q, for further discussion.

Other Operating (Income) Expense, Net. Other operating ~~income~~(income) expense was ~~$0.4~~relatively consistent between periods, with expense of $0.5 million in the ~~second~~third quarter of ~~2019. This compares to other operating~~2019 and income of ~~$3.1~~$0.2 million in the ~~second~~third quarter of ~~2018, which included a $3.6 million gain recognized upon settlement of a Hurricane Harvey flood insurance claim within our Offshore/Manufactured Products segment.~~2018.

Operating Income (Loss). Our consolidated operating loss was ~~$6.4~~$34.9 million in the ~~second~~third quarter of 2019, which ~~included $1.3~~includes the impact of the $33.7 million fixed asset impairment charge discussed above and $0.7 million of severance and downsizing charges. This compares to a consolidated operating ~~income~~loss of ~~$8.7~~$3.7 million in the ~~second~~third quarter of 2018, which included ~~the $3.6~~$6.1 million ~~insurance settlement gain and $1.5 million of~~in costs associated with patent defense ~~costs~~and settlement of FLSA claims as discussed previously.

Interest Expense, Net. Net interest expense was ~~$4.6~~$4.4 million in the ~~second~~third quarter of 2019, which ~~is comparable~~compares to net interest expense of $4.8 million in the same period of 2018. Interest expense, which includes amortization of debt discount and deferred financing costs, as a percentage of total debt outstanding was approximately 6% in both the ~~second~~third quarter of 2019 and 2018. Our contractual cash interest expense as a percentage of total debt outstanding was substantially lower – averaging approximately 3% in both the three months ended September 30, 2019 and 2018.

Income Tax. The income tax benefit for the three months ended ~~June~~September 30, 2019 was calculated using a discrete approach. This methodology was used because minor changes in our results of operations and non-deductible expenses can materially impact the estimated annual effective tax rate. For the three months ended ~~June~~September 30, 2019, our income tax benefit was ~~$0.3~~$6.2 million, or ~~2.6%~~16.3% of pre-tax losses. This compares to an income tax ~~provision~~benefit of ~~$1.7~~$3.8 million, or ~~38.8%~~48.8% of pre-tax ~~income,~~losses, for the three months ended ~~June~~September 30, 2018. The ~~change in~~ effective tax rate benefit for the ~~second quarter of~~three months ended September 30, 2019 was below the U.S. statutory rate primarily ~~attributable~~due to certain non-deductible expenses.

Other Comprehensive ~~Income (Loss).~~Loss. Reported comprehensive loss is the sum of reported net ~~income (loss)~~loss and other comprehensive ~~income (loss).~~loss. Other comprehensive loss was ~~$2.3~~$5.7 million in the ~~second~~third quarter of 2019 compared to ~~other comprehensive loss of $13.7~~$2.5 million in the ~~second~~third quarter of 2018 due to fluctuations in foreign currency exchange rates compared to the U.S. dollar for certain of the international operations of our reportable segments. For the three months ended ~~June~~September 30, 2019 and 2018, currency translation adjustments recognized as a component of other comprehensive ~~income (loss)~~loss were primarily attributable to the United Kingdom and Brazil. During the ~~second quarter~~third quarters of both 2019 and 2018, the exchange ~~rate for the British pound weakened while the Brazilian real strengthened compared to the U.S. dollar. This compares to the second quarter of 2018, when the exchange rate~~rates for both the British pound and the Brazilian real weakened compared to the U.S. dollar.

Segment Operating Results

Well Site Services

Revenues. Our Well Site Services segment revenues decreased ~~$9.2~~$12.6 million, or 7%10%, in the ~~second~~third quarter of 2019 compared to the prior-year quarter. Completion Services revenue decreased ~~$5.0~~$7.7 million, or 5%7%, ~~reflecting~~due to the impact of a decline in U.S. land-based customer completion and production activity following the material decline in commodity prices in the fourth quarter of 2018. Our Drilling Services revenues decreased ~~$4.1~~$4.9 million, or ~~25%~~29%, in the ~~second~~third quarter of 2019 from the ~~second~~third quarter of 2018 due to lower rig utilization.

Operating Loss. Our Well Site Services segment operating loss increased ~~$1.4~~$29.3 million in the ~~second~~third quarter of 2019 from the prior-year period. Reported results for the Well Site Services segment for the third quarter of 2019 included the impact within Drilling Services of the $33.7 million non-cash fixed asset impairment charge discussed previously as well as $0.6 million of incremental reserves for uncollectible accounts receivable due to ~~a significant reduction in demand for Drilling Services.~~uncertainties with respect to future collection. Well Site Services segment revenues and cost of services for the ~~second~~third quarter of 2019 decreased 7%10% and 8%17%, respectively, from the prior-year quarter, with other costs and expenses remaining relatively ~~flat.~~consistent. Our Completion Services operating ~~loss~~income in the ~~second~~third quarter of 2019 was ~~$0.5~~$1.7 million, compared to an operating ~~income~~loss of ~~$1.2~~$3.3 million in the ~~prior year~~prior-year quarter, reflecting the impact of lower ~~service activity.~~revenues

partially offset by reduced equipment repair, maintenance and rental expense. Additionally, results in the third quarter of 2018 included a $2.6 million charge associated with the additional reserves established for previous FLSA claims. Our Drilling Services operating loss ~~decreased $0.4~~increased $34.3 million in the ~~second~~third quarter of 2019 from the ~~second~~third quarter of 2018 due primarily to ~~lower depreciation expense resulting from certain assets becoming fully depreciated over~~ the ~~past twelve months.~~$33.7 million non-cash fixed asset impairment charge discussed previously and a decline in customer activity levels.

Downhole Technologies

Revenues. Our Downhole Technologies segment revenues decreased ~~$12.5~~$13.7 million, or ~~21%~~24%, in the ~~second~~third quarter of 2019 from the prior-year ~~quarter reflecting~~period due to a decline in U.S. land-based customer completion activity, a shift in sales mix and competitive pricing pressures for certain of its conventional perforating products.

Operating Income. Our Downhole Technologies segment operating income declined ~~$13.1~~$5.8 million ~~or 113%,~~ in the ~~second~~third quarter of 2019 from the prior-year period due primarily to the decline in revenues coupled with higher product and engineering costs and an expansion of field support ~~operations and $1.4 million of inventory write-offs due to product design changes.~~operations. Prior-year results included ~~$1.5~~$3.5 million in patent defense costs incurred in the ~~second~~third quarter of 2018.

Offshore/Manufactured Products

Revenues. Our Offshore/Manufactured Products segment revenues increased ~~$0.5~~$15.4 million, or 1%17%, in the ~~second~~third quarter of 2019 compared to the ~~second~~third quarter of 2018 ~~with the impact of~~driven primarily by higher project-driven product ~~demand partially offset by lower customer demand for short-cycle products and reduced service activity.~~demand.

Operating Income. Our Offshore/Manufactured Products segment operating income ~~decreased $2.9~~increased $4.1 million, or ~~23%~~58%, in the ~~second~~third quarter of 2019 compared to the ~~second~~third quarter of 2018 due to the ~~2018 quarter including a non-recurring gain of $3.6 million for a Hurricane Harvey flood insurance claim. Excluding this prior-year gain, operating income increased $0.7 million, or 8%.~~increase in revenues.

Backlog. Bidding and quoting activity, along with orders from customers, for our Offshore/Manufactured Products segment continued to improve during the ~~second~~third quarter of 2019 with deepwater project awards increasing after several years of reduced award activity. Backlog in our Offshore/Manufactured Products segment increased ~~$49~~$10 million from ~~$234~~$283 million at ~~March 31,~~June 30, 2019 to total ~~$283~~$293 million as of ~~June~~September 30, 2019 – the highest level recorded since the ~~second~~first quarter of 2016. Orders totaled ~~$163~~$123 million in the ~~second~~third quarter of 2019 resulting in a ~~book to bill~~book-to-bill ratio of ~~1.6x.~~1.2x.

Corporate

Expenses ~~decreased $2.2~~increased $0.1 million, or ~~16%~~1%, in the ~~second~~third quarter of 2019 from the prior-year ~~period due primarily to lower stock-based and annual incentive plan compensation expenses.~~period.

~~Six~~Nine Months Ended ~~June~~September 30, 2019 Compared to ~~Six~~Nine Months Ended ~~June~~September 30, 2018

Consolidated Operating Results

We reported a net loss for the ~~six~~nine months ended ~~June~~September 30, 2019 of ~~$24.4~~$56.3 million, or ~~$0.41~~$0.95 per diluted share, which included ~~$2.3~~a non-cash fixed asset impairment charge of $33.7 million ($~~1.8~~26.6 million after-tax, or ~~$0.03~~$0.45 per diluted share) and $2.9 million ($2.3 million after-tax, or $0.04 per diluted share) of severance and downsizing costs. These results compare to a net loss for the ~~six~~nine months ended ~~June~~September 30, 2018 of ~~$0.8~~$4.8 million, or ~~$0.01~~$0.08 per diluted share, which included ~~$2.6~~$5.9 million ($~~2.0 million after, tax, or $0.03 per diluted share) of transaction-related expense, $2.4 million ($1.9~~4.7 million after-tax, or ~~$0.03~~$0.08 per diluted share) of charges related to legal fees incurred for patent defense and $3.3 million ($2.6 million after-tax, or $0.04 per diluted share) in provisions for prior years' FLSA claim settlements, $2.6 million ($2.0 million after-tax, or $0.03 per diluted share) of transaction-related expense and $0.8 million ($0.6 million after-tax, or $0.01 per diluted share) of ~~severance and downsizing expense and $0.7~~severance. Additionally, during the nine months ended September 30, 2018 the Company recognized a $5.8 million ~~in reserves~~ ($~~0.6 million after-tax, or $0.01~~0.10 per diluted share) ~~for prior years' Fair Labor Standards Act ("FLSA") claim settlements.~~income tax benefit related to a change in its December 2017 provisional estimates with respect to U.S. tax reform legislation.

Our consolidated results of operations include the GEODynamics (Downhole Technologies segment) and Falcon acquisitions completed in the first quarter of 2018. Our reported results of operations reflect the impact of current industry trends and customer spending activities with investments ~~recently~~ weighted toward U.S. shale play regions. However, in 2019, we are beginning to see a general improvement in the level of planned investments in deepwater markets globally.

Revenues. Consolidated total revenues in the first ~~six~~nine months of 2019 decreased ~~$24.1~~$35.0 million, or 4%, from the first ~~six~~nine months of 2018. Consolidated product revenues in the first ~~six~~nine months of 2019 decreased ~~$23.7~~$21.9 million, or 9%6%, from the first ~~six~~nine months of 2018, due primarily to lower U.S. land-based customer activity ~~reduced project-driven sales within our Offshore/Manufactured Products segment~~ and the impact of competitive pricing pressures for conventional perforating products in our Downhole Technologies segment, partially offset by higher project-driven sales within our Offshore/Manufactured Products segment. Consolidated service revenues in the first ~~six~~nine months of 2019 ~~was comparable to~~decreased $13.1 million, or 3%, from the first ~~six~~nine months of 2018, with the impact of lower customer spending in the U.S. shale play regions in the Well Site Services segment partially offset by the impact of two additional months of revenue generated by the Falcon operations (acquired February 28, 2018) in the 2019 ~~period, substantially offset by the impact of lower customer spending in the U.S. shale play regions in the Well Site Services segment.~~period. As can be derived from the following table, ~~76%~~75% of our consolidated revenues in the first ~~six~~nine months of 2019 were derived from sales of our short-cycle product and service offerings, which compares to ~~76%~~77% in the same period in 2018.

The following table provides supplemental disaggregated revenue from contracts with customers by operating segment for the ~~six~~nine months ended ~~June~~September 30, 2019 and 2018 (in thousands):


	Well Site Services				Downhole Technologies				Offshore/ Manufactured Products				Total				Well Site Services				Downhole Technologies				Offshore/ Manufactured Products				Total
Six months ended June 30	2019		2018		2019		2018		2019		2018		2019		2018
Nine months ended September 30																	2019		2018		2019		2018		2019		2018		2019		2018
Major revenue categories -
Project-driven products	$	—	$	—	$	—	$	—	$	65,762	$	76,024	$	65,762	$	76,024	$	—	$	—	$	—	$	—	$	105,236	$	98,301	$	105,236	$	98,301
Short-cycle:
Completion products and services	203,962		191,208		101,030		105,055		53,540		62,755		358,532		359,018		307,928		302,877		143,912		161,626		80,250		90,218		532,090		554,721
Drilling services	20,396		34,315		—		—		—		—		20,396		34,315		32,430		51,235		—		—		—		—		32,430		51,235
Other products	—		—		—		—		13,484		15,011		13,484		15,011		—		—		—		—		21,472		21,718		21,472		21,718
Total short-cycle	224,358		225,523		101,030		105,055		67,024		77,766		392,412		408,344		340,358		354,112		143,912		161,626		101,722		111,936		585,992		627,674
Other products and services	—		—		—		—		57,122		55,053		57,122		55,053		—		—		—		—		87,765		88,040		87,765		88,040
	$	224,358	$	225,523	$	101,030	$	105,055	$	189,908	$	208,843	$	515,296	$	539,421	$	340,358	$	354,112	$	143,912	$	161,626	$	294,723	$	298,277	$	778,993	$	814,015


Percentage of total revenue by type -
Products	—	%	—	%	97	%	98	%	75	%	78	%	47	%	49	%	—	%	—	%	97	%	98	%	76	%	76	%	47	%	47	%
Services	100	%	100	%	3	%	2	%	25	%	22	%	53	%	51	%	100	%	100	%	3	%	2	%	24	%	24	%	53	%	53	%

Cost of Revenues (exclusive of Depreciation and Amortization Expense). Our consolidated total cost of revenues (exclusive of depreciation and amortization expense) ~~increased $4.7~~decreased $9.9 million, or 1%2%, in the first ~~six~~nine months of 2019 compared to the first ~~six~~nine months of 2018. Consolidated product costs in the first ~~six~~nine months of 2019 ~~decreased $3.7 million, or 2%, from~~were comparable to the level reported in the first ~~six~~nine months of 2018 despite a 6% decrease in product revenue as a result of ~~a decline in product sales, partially offset by~~ higher costs within the Downhole Technologies segment. The Downhole Technologies segment experienced an unfavorable shift in product mix, incurred higher product costs and recorded $1.4 million of inventory write-offs due to product design changes during the ~~six~~nine months ended ~~June~~September 30, 2019. Consolidated service costs in the first ~~six~~nine months of 2019 ~~increased $8.4~~decreased $9.1 million, or 4%3%, from the first ~~six~~nine months of 2018, which included the impact of $3.3 million in costs associated with the settlement of prior-year FLSA claims. The balance of the decrease in service costs

from the 2018 period is due primarily to the ~~inclusion of~~activity-driven revenue decline within the ~~Falcon operations for a full quarter in 2019 versus a single month in the prior-year period and~~Well Site Services segment, partially offset by incremental costs in our Downhole Technologies segment associated with an expansion of field support ~~operations, partially offset by a reduction in variable costs in our Drilling Services business.~~

operations.

Selling, General and Administrative Expense. Selling, general and administrative expense decreased ~~$8.5~~$8.9 million, or ~~12%~~9%, in the first ~~six~~nine months of 2019 from the first ~~six~~nine months of 2018. The first ~~six~~nine months of 2018 included ~~$2.4~~$5.9 million of patent defense costs ~~a $1.8 million provision for bad debt related to a customer bankruptcy filing~~ and $0.9 million of transaction-related costs. Excluding these items from the first ~~six~~nine months of 2018, selling, general and administrative expense declined ~~$3.4~~$2.1 million, or 5%2%, due primarily to a year-over-year reduction in stock-based ~~and annual incentive plan~~ compensation expense.

Depreciation and Amortization Expense. Depreciation and amortization expense increased ~~$3.3~~$4.1 million, or 6%5%, in the first ~~six~~nine months of 2019 compared to the prior-year period reflecting the impact of the GEODynamics and Falcon operations acquired in the first quarter of 2018, which was partially offset by the effect of certain assets becoming fully depreciated. Note 13, "Segments and Related Information," presents depreciation and amortization expense by segment.

Impairment of Fixed Assets. During the third quarter of 2019, our Drilling Services business recorded a non-cash impairment charge of $33.7 million to decrease the carrying value of the unit’s fixed assets as discussed previously. See Note 4, “Details of Selected Balance Sheet Accounts,” to the unaudited condensed consolidated financial statements included in this Quarterly Report on Form 10‑Q, for further discussion.

Other Operating (Income) Expense, Net. Other operating income ~~was $0.5~~of $2.1 million in the first ~~six~~nine months of ~~2019. This compares to other operating income of $1.9 million in the first six months of~~ 2018 ~~which~~ included a $3.6 million gain recognized upon settlement of a Hurricane Harvey flood insurance claim, partially offset by $1.7 million in transaction-related expenses.

Operating Income (Loss). Our consolidated operating loss was ~~$17.2~~$52.1 million in the first ~~six~~nine months of 2019, which included ~~$2.3~~the impact of the $33.7 million fixed asset impairment charge discussed previously and $2.9 million of severance and downsizing charges. This compares to a consolidated operating income of ~~$7.8~~$4.1 million in the first ~~six~~nine months of 2018, which included the $3.6 million insurance settlement gain discussed previously, offset by ~~$3.1~~$9.2 million of costs associated with patent defense and settlement of FLSA claims and $3.4 million of transaction-related, severance and downsizing charges.

Interest Expense, Net. Net interest expense was ~~$9.4~~$13.7 million in the first ~~six~~nine months of 2019, which is comparable to net interest expense of ~~$9.2~~$14.1 million in the same period of 2018. Interest expense, which includes amortization of debt discount and deferred financing costs, as a percentage of total debt outstanding was approximately 6% in both the first ~~six~~nine months of 2019 and 2018. Our contractual cash interest expense as a percentage of total debt outstanding was substantially lower – averaging approximately 3% in both the nine months ended September 30, 2019 and 2018.

Income Tax. The income tax benefit for the ~~six~~nine months ended ~~June~~September 30, 2019 was calculated using a discrete approach. This methodology was used because minor changes in our results of operations and non-deductible expenses can materially impact the estimated annual effective tax rate. For the ~~six~~nine months ended ~~June~~September 30, 2019, our income tax benefit was ~~$0.5~~$6.7 million, or ~~2.2%~~10.7% of pre-tax losses. This compares to an income tax ~~provision~~benefit of ~~$0.5~~$3.3 million, or ~~213%~~41.1% of pre-tax losses, for the ~~six~~nine months ended ~~June~~September 30, 2018. The ~~change in~~ effective tax rate benefit for the ~~first half of~~nine months ended September 30, 2019 was below the U.S. statutory rate primarily ~~attributable~~due to certain non-deductible expenses.

Other Comprehensive ~~Income (Loss).~~Loss. Reported comprehensive loss is the sum of reported net ~~income (loss)~~loss and other comprehensive ~~income (loss).~~loss. Other comprehensive ~~income~~loss was ~~$0.1~~$5.5 million in the first ~~six~~nine months of 2019 compared to ~~other comprehensive loss of $8.7~~$11.2 million in the first ~~six~~nine months of 2018 due to fluctuations in foreign currency exchange rates compared to the U.S. dollar for certain of the international operations of our reportable segments. For the ~~six~~nine months ended ~~June~~September 30, 2019 and 2018, currency translation adjustments recognized as a component of other comprehensive ~~income (loss)~~loss were primarily attributable to the United Kingdom and Brazil. During ~~the first six months of 2018,~~both periods, the exchange rate for the British pound and the Brazilian real compared to the U.S. dollar weakened.

Segment Operating Results

Well Site Services

Revenues. Our Well Site Services segment revenues decreased ~~$1.2~~$13.8 million, or 1%4%, in the first ~~six~~nine months of 2019 compared to the prior-year period. Completion Services revenue increased ~~$12.8~~$5.1 million, or 7%2%, reflecting two additional months of revenue generated by the acquired Falcon operations (acquired February 28, 2018) in the 2019 period, partially offset by the impact of a decline in U.S. land-based customer completion and production activity following the ~~material~~ decline in commodity prices in the fourth quarter of 2018. Our Drilling Services revenues decreased ~~$13.9~~$18.8 million, or ~~41%~~37%, to ~~$20.4~~$32.4 million in the first ~~half~~nine months of 2019 from the same period in 2018 due to ~~customers temporarily suspending their~~a reduction in customer vertical drilling operations ~~in response to~~following the material decline in commodity prices in the fourth quarter of 2018.

Operating Loss. Our Well Site Services segment operating loss increased ~~$2.6~~$31.9 million in the first ~~six~~nine months of 2019 from the prior-year period due primarily to ~~a reduction in demand for~~the impact within Drilling ~~Services.~~Services of the $33.7 million non-cash fixed asset impairment charge discussed above. Well Site Services segment cost of services for the first ~~half~~nine months of 2019 ~~increased 1%~~decreased 6% from the prior-year period, with other costs and expenses remaining relatively flat. Our Completion Services operating loss in the first ~~half~~nine months of 2019 ~~increased $0.7~~decreased $4.3 million, or ~~22%~~65%, from the prior-year period, ~~with the impact of higher revenues offset by an unfavorable shift in service offering mix. Results in the first half of 2018~~which included ~~a $1.8 million provision for bad debt related to a customer bankruptcy filing and $0.7~~$3.3 million in charges associated with additional reserves established for prior-year FLSA claims. Our Drilling Services operating loss increased ~~$1.9~~$36.2 million in the first ~~half~~nine months of 2019 from the same period in 2018 due to the $33.7 million non-cash fixed asset impairment charge discussed previously and, to a lesser extent, the impact of a ~~47%~~46% reduction in rig utilization.

Downhole Technologies

Revenues. Our Downhole Technologies segment revenues decreased ~~$4.0~~$17.7 million, or 4%11%, in the first ~~six~~nine months of 2019 from the prior-year period due primarily to a decline in U.S. land-based customer completion activity, a shift in sales mix and competitive pricing pressures for certain of its conventional perforating products.

Operating Income. Our Downhole Technologies segment operating income declined ~~$17.1~~$22.9 million, or ~~87%~~88%, in the first ~~six~~nine months of 2019 from the prior-year period due primarily to the decline in revenues coupled with an expansion of field support operations, higher product and engineering costs and $1.4 million of inventory write-offs due to product design changes. Prior-year results included ~~$2.4~~$5.9 million in patent defense costs incurred after our acquisition of GEODynamics.

Offshore/Manufactured Products

Revenues. Our Offshore/Manufactured Products segment revenues declined ~~$18.9~~$3.6 million, or 9%1%, in the first ~~six~~nine months of 2019 compared to the prior-year period, ~~due to decreased~~with a decrease in sales of short-cycle products substantially offset by higher sales of project-driven ~~and short-cycle~~ products.

Operating Income. Our Offshore/Manufactured Products segment operating income decreased ~~$10.0~~$6.0 million, or ~~40%~~19%, in the first ~~six~~nine months of 2019 compared to the same period in 2018, due to the 2018 period including a non-recurring gain of $3.6 million from an insurance settlement discussed above. Excluding this gain in the prior-year period, operating income decreased ~~$6.5~~$2.4 million, or ~~30%~~7%, due to ~~the significant decline~~a shift in ~~revenue.~~product and service mix.

Backlog. Bidding and quoting activity, along with orders from customers, for our Offshore/Manufactured Products segment improved during the first ~~six~~nine months of 2019 with deepwater project awards increasing after several years of reduced award activity. Backlog in our Offshore/Manufactured Products segment increased ~~$104~~$114 million from $179 million at December 31, 2018 to total ~~$283~~$293 million as of ~~June~~September 30, 2019 – the highest level recorded since the ~~second~~first quarter of 2016. Orders totaled ~~$297~~$430 million in the first ~~half~~nine months of 2019 resulting in a ~~book to bill~~book-to-bill ratio of ~~1.6x.~~1.5x.

Corporate

Expenses decreased ~~$4.7~~$4.6 million, or ~~17%~~11%, in the first ~~six~~nine months of 2019 from the prior-year period, which included transaction related expenses of ~~$2.3~~$2.4 million. The balance of the year-over-year decrease is attributable to lower stock-based ~~and annual incentive plan~~ compensation expenses.

Liquidity, Capital Resources and Other Matters

Our primary liquidity needs are to fund operating and capital expenditures which, in the past, have included expanding and upgrading our Offshore/Manufactured Products and Downhole Technologies 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 strategic business acquisitions and fund our share repurchase program. Our primary sources of funds have been cash flow from operations, proceeds from borrowings under our credit facilities and capital markets transactions.

The crude oil and natural gas industry is highly cyclical which may result in declines in the demand for, and prices of, our products and services, the inability or failure of our customers to meet their obligations to us or a sustained decline in our market capitalization. These and other potentially adverse market conditions could require us to incur additional asset impairment charges, record additional deferred tax valuation allowances and/or write down the value of our goodwill and other intangible assets, and may otherwise adversely impact our results of operations, our cash flows and our financial position. See Note ~~3, "Business Acquisitions, Goodwill and Other Intangible Assets,~~4, "Details of Selected Balance Sheet Accounts," for further information.

Operating Activities

Cash flows from operations totaling ~~$66.0~~$115.9 million were generated during the first ~~six~~nine months of 2019 compared to ~~$46.9~~$80.1 million generated during the same period of 2018. During the first ~~half~~nine months of 2019, ~~$19.1~~$38.0 million was provided by net working capital decreases, primarily due to a reduction in accounts ~~receivable and an increase in accounts payable.~~receivable. These working capital benefits were partially offset by ~~a reduction in accrued liabilities and~~ an increase in ~~prepaid expenses.~~inventories. During the first ~~six~~nine months of 2018, ~~$29.0~~$24.9 million was used to fund net working capital increases, driven primarily by increases in accounts receivable, income taxes receivable and ~~reductions~~inventories, partially offset by increases in accounts payable and accrued liabilities.

Investing Activities

Cash used in investing activities during the first ~~half~~nine months of 2019 totaled ~~$30.9~~$43.7 million, compared to ~~$417.7~~$446.8 million used in investing activities during the first ~~half~~nine months of 2018, when we invested net cash of $379.7 million for the acquisitions of GEODynamics and Falcon.

On January 12, 2018, we acquired GEODynamics for a purchase price consisting of (i) $295.4 million in cash (net of cash acquired), which we funded from borrowings under our Revolving Credit Facility, (ii) 8.66 million shares of our common stock and (iii) an unsecured $25 million promissory note.

On February 28, 2018, we acquired Falcon for cash consideration of $84.2 million (net of cash acquired), which we funded from borrowings under our Revolving Credit Facility.

Capital expenditures totaled ~~$31.6~~$45.8 million and ~~$38.3~~$71.3 million during the first ~~half~~nine months of 2019 and 2018, respectively.

We expect to spend a total of $60 million to ~~$65~~$62 million in capital expenditures during 2019 to replace and upgrade our Completion Services equipment, to expand and maintain Downhole Technologies' facilities and equipment, to upgrade and maintain our Offshore/Manufactured Products facilities and equipment, and to fund various other capital spending projects. Whether planned expenditures will actually be spent in 2019 depends on industry conditions, project approvals and schedules, vendor delivery timing, free cash flow 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 expectations do not include any funds that might be spent on future strategic acquisitions, which the Company could pursue depending on the economic environment in our industry and the availability of transactions at prices deemed attractive to the Company.

Financing Activities

During the ~~six~~nine months ended ~~June~~September 30, 2019, net cash of ~~$41.6~~$76.9 million was used in financing activities, including ~~$37.0~~$71.1 million of net repayments under our Revolving Credit Facility. This compares to ~~$346.3~~$348.6 million of cash provided by financing activities during the ~~six~~nine months ended ~~June~~September 30, 2018, primarily as a result of our issuance of $200.0 million in 1.50% convertible senior notes and ~~$157.9~~$160.6 million in net borrowings under our Revolving Credit Facility used to fund acquisitions.

At ~~June~~September 30, 2019, we had cash totaling ~~$12.4~~$14.7 million, the majority of which was held by our international subsidiaries.

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, such additional debt service requirements could be based on higher interest rates and shorter maturities and could impose a significant burden on our results of operations and financial condition, and any issuance of additional equity securities could result in significant dilution to stockholders.

Revolving Credit Facility. Our Revolving Credit Facility is governed by a credit agreement dated as of January 30, 2018, as amended, (the "Credit Agreement") by and among the Company, the Lenders party thereto, Wells Fargo Bank, N.A., as administrative agent for the lenders party thereto and collateral agent for the secured parties thereunder, and the lenders and other financial institutions from time to time party thereto. Our Revolving Credit Facility provides for up to $350 million in lender commitments with an option to increase the maximum borrowings to $500 million subject to additional lender commitments and matures on January 30, 2022.

Under our Revolving Credit Facility, $50 million is available for the issuance of letters of credit. See Note 6, "Long-term Debt," for further information regarding the terms of the Credit Agreement.

As of ~~June~~September 30, 2019, we had ~~$99.2~~$65.0 million of borrowings outstanding under the Credit Agreement and ~~$16.1~~$22.6 million of outstanding letters of credit, leaving ~~$96.0~~$139.1 million available to be drawn. The total amount available to be drawn was less than the lender commitments as of ~~June~~September 30, 2019, due to limits imposed by maintenance covenants in the Credit Agreement. As of ~~June~~September 30, 2019, we were in compliance with our debt covenants and expect to continue to be in compliance over the next twelve months.

1.50% Convertible Senior Notes. On January 30, 2018, we issued $200 million aggregate principal amount of the Notes pursuant to an indenture, dated as of January 30, 2018 (the "Indenture"), between the Company and Wells Fargo Bank, National Association, as trustee. Net proceeds from the Notes, after deducting issuance costs, were approximately $194.0 million, which we used to repay a portion of the outstanding borrowings under our Revolving Credit Facility.

During the third quarter of 2019, we repurchased $1.0 million in principal amount of the outstanding Notes for $0.9 million, which approximated the net carrying value.

The initial carrying amount of the Notes recorded in the consolidated balance sheet ~~as of January 30, 2018~~ was less than the $200 million in principal amount of the Notes, in accordance with applicable accounting principles, reflective of the estimated fair value of a similar debt instrument that does not have a conversion feature. We recorded the value of the conversion feature as a debt discount, which is amortized as interest expense over the term of the Notes, with a similar amount allocated to additional paid-in capital. As a result of this amortization, the interest expense we recognize related to the Notes for accounting purposes is based on an effective interest rate of approximately 6%6.0%, which is greater than the cash interest payments we are obligated to pay on the Notes. ~~Interest~~Recorded interest expense associated with the Notes for the three and ~~six~~nine months ended ~~June~~September 30, 2019 ~~and 2018~~ was ~~$5.1~~$2.6 million and ~~$4.1~~$7.7 million, respectively, while the related contractual cash interest expense totaled ~~$1.5~~$0.8 million and ~~$1.3~~$2.3 million, respectively. Recorded interest expense associated with the Notes for the three and nine months ended September 30, 2018 was $2.5 million and $6.6 million, respectively, while the related contractual cash interest expense totaled $0.8 million and $2.0 million, respectively. See Note 6, "Long-term Debt," for further information regarding the Notes. As of ~~June~~September 30, 2019, none of the conditions allowing holders of the Notes to convert, or requiring us to repurchase the Notes, had been met.

Promissory Note. In connection with the GEODynamics Acquisition, we issued a $25.0 million promissory note that bears interest at 2.5% per annum and was scheduled to mature on July 12, 2019. Payments due under the promissory note are subject to set-off, in full or in part, against certain indemnification claims related to matters occurring prior to our acquisition of GEODynamics. As more fully described in Note 14, "Commitments and Contingencies," the Company has provided notice to and asserted an indemnification claim against the seller of GEODynamics. As a result, the maturity date of the note is extended until the resolution of the indemnity claim. The Company expects that the amount ultimately paid in respect of such note may be reduced as a result of this indemnification claim.

Our total debt represented ~~17.3%~~16.1% of our combined total debt and stockholders' equity at ~~June~~September 30, 2019 compared to 18.7% at December 31, 2018.

Stock Repurchase Program. We maintain a share repurchase program which was extended to July 29, 2020 by our Board of Directors. During the first ~~six~~nine months of 2019, we repurchased approximately 51 thousand shares of our common stock under the program at a total cost of $757 thousand. The amount remaining under our share repurchase authorization as of ~~June~~September 30, 2019 was $119.8 million. Subject to applicable securities laws, any purchases will be at such times and in such amounts as the Company deems appropriate.

Critical Accounting Policies

For a discussion of the critical accounting policies and estimates that we use in the preparation of our condensed consolidated financial statements, see "Part II Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations" in our 2018 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. See Note 2, "Recent Accounting Pronouncements," for a discussion of recent accounting pronouncements, including our adoption of the new lease accounting standard effective January 1, 2019.

Off-Balance Sheet Arrangements

As of ~~June~~September 30, 2019, we had no off-balance sheet arrangements as defined in Item 303(a)(4)(ii) of Regulation S-K.

ITEM 3. Quantitative and Qualitative Disclosures about Market Risk

Market risk refers to the potential losses arising from changes in interest rates, foreign currency fluctuations and exchange rates, equity prices, and commodity prices, including the correlation among these factors and their volatility.

Our principal market risks are our exposure to changes in interest rates and foreign currency exchange rates. We enter into derivative instruments only to the extent considered necessary to meet risk management objectives and do not use derivative contracts for speculative purposes.

Interest Rate Risk

We have a revolving credit facility that is subject to the risk of higher interest charges associated with increases in interest rates. As of ~~June~~September 30, 2019, we had floating-rate obligations totaling ~~$99.2~~$65.0 million drawn under our Revolving Credit Facility. These floating-rate obligations expose us to the risk of increased interest expense in the event of increases in short-term interest rates. If the floating interest rates increased by 1% from ~~June~~September 30, 2019 levels, our consolidated interest expense would increase by a total of approximately ~~$1.0~~$0.7 million annually.

Foreign Currency Exchange Rate Risk

Our operations are conducted in various countries around the world and we receive revenue from these operations in a number of different currencies. As such, our earnings are subject to movements in foreign currency exchange rates when transactions are denominated in (i) currencies other than the U.S. dollar, which is our functional currency, or (ii) the functional currency of our subsidiaries, which is not necessarily the U.S. dollar. In order to mitigate the effects of foreign currency exchange rate risks in areas outside of the United States (primarily in our Offshore/Manufactured Products segment), we generally pay a portion of our expenses in local currencies and a substantial portion of our contracts provide for collections from customers in U.S. dollars. During the ~~six~~nine months ended ~~June~~September 30, 2019, our reported foreign currency exchange ~~gains~~losses were ~~$0.3~~$0.2 million and are included in "Other operating expense, net" in the condensed consolidated statements of operations.

Our accumulated other comprehensive loss, reported as a component of stockholders' equity, ~~decreased slightly~~increased $5.5 million from $71.4 million at December 31, 2018 to ~~$71.3~~$76.9 million at ~~June~~September 30, 2019, due to changes in currency exchange rates. Accumulated other comprehensive loss is primarily related to fluctuations in the currency exchange rates compared to the U.S. dollar which are used to translate certain of the international operations of our reportable segments.

ITEM 4. Controls and Procedures

Evaluation of Disclosure Controls and Procedures

As of the end of the period covered by this Quarterly Report on Form 10-Q, we carried out an evaluation, under the supervision and with the participation of our management, including our Chief Executive Officer and Chief Financial Officer, of the effectiveness of the design and operation of our disclosure controls and procedures (as defined in Rules 13a-15(e) and 15d-15(e)) of the Exchange Act. Our disclosure controls and procedures are designed to provide reasonable assurance that the information required to be disclosed by us in reports that we file under the Exchange Act is accumulated and communicated to our management, including our Chief Executive Officer and Chief Financial Officer, as appropriate, to allow timely decisions regarding required disclosure and is recorded, processed, summarized and reported within the time periods specified in the rules and forms of the Commission. Based upon that evaluation, our Chief Executive Officer and Chief Financial Officer concluded that our disclosure controls and procedures were effective as of ~~June~~September 30, 2019 at the reasonable assurance level.

Changes in Internal Control Over Financial Reporting

There have been no changes in the Company's internal control over financial reporting (as that term is defined in Rules 13a-15(f) and 15d-15(f) under the Exchange Act) that occurred during the three months ended ~~June~~September 30, 2019, that has materially affected, or is reasonably likely to materially affect, our internal control over financial reporting.

PART II -- OTHER INFORMATION

ITEM 1. Legal Proceedings

The information with respect to this Item 1 is set forth under Note 14, "Commitments and Contingencies."

ITEM 1A. Risk Factors

"Part I, Item 1A. Risk Factors" of our 2018 Form 10‑K includes a detailed discussion of our risk factors. The risks described in this Quarterly Report on Form 10‑Q and our 2018 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, may materially adversely affect our business, financial conditions or future results. There have been no material changes to our risk factors as set forth in our 2018 Form 10‑K.

ITEM 2. Unregistered Sales of Equity Securities and Use of Proceeds

None.

Purchases of Equity Securities by the Issuer and Affiliated Purchasers

Period
Total Number of Shares Purchased⁽¹⁾

Average Price Paid per Share⁽¹⁾
Total Number of Shares Purchased as Part of Publicly Announced Plans or Programs
Approximate Dollar Value of Shares That May Yet Be Purchased Under the Plans or Programs⁽²⁾
April 1 through April 30, 2019 383
$ 17.72
—
$ 119,788,435
May 1 through May 31, 2019 233
17.45
—
119,788,435
June 1 through June 30, 2019 72
16.40
—
119,788,435
Total 688
$ 17.49
—



Period	Total Number of Shares Purchased⁽¹⁾	Average Price Paid per Share⁽¹⁾		Total Number of Shares Purchased as Part of Publicly Announced Plans or Programs	Approximate Dollar Value of Shares That May Yet Be Purchased Under the Plans or Programs⁽²⁾
July 1 through July 31, 2019	627	$	14.87	—	$	119,788,435
August 1 through August 31, 2019	4,199	13.27		—	119,788,435
September 1 through September 30, 2019	692	15.52		—	119,788,435
Total	5,518	$	13.73	—


(1)	All ~~of the 688~~ shares purchased during the three-month period ended ~~June~~September 30, 2019 were acquired from employees in connection with the settlement of income tax and related benefit withholding obligations arising from vesting in restricted stock grants. These shares were not part of a publicly announced program to purchase common stock.


(2)	~~On July 29, 2015, the Company's Board of Directors approved~~We maintain a ~~new~~ share repurchase program providing for the repurchase of up to $150 million of the Company's common stock, which, following extensions, was scheduled to expire on July 29, 2019. On July 24, 2019, our Board of Directors extended the share repurchase program for one year to July 29, 2020.

ITEM 3. Defaults Upon Senior Securities

None.

ITEM 4. Mine Safety Disclosures

Not applicable.

ITEM 5. Other Information

None.

ITEM 6. Exhibits



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	—	Fourth 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 May 8, 2019 (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)).

10.1*	—	~~Form of Non-Employee Director Restricted Stock Agreement under the Company's 2018 Equity Participation Plan.~~

10.2*	—	~~Form of Performance Award Agreement under the Company's 2018 Equity Participation Plan.~~

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, as amended.

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, as amended.

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, as amended.

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, as amended.

101.INS*	—	XBRL Instance Document

101.SCH*	—	XBRL Taxonomy Extension Schema Document

101.CAL*	—	XBRL Taxonomy Extension Calculation Linkbase Document

101.DEF*	—	XBRL Taxonomy Extension Definition Linkbase Document

101.LAB*	—	XBRL Taxonomy Extension Label Linkbase Document

101.PRE*	—	XBRL Taxonomy Extension Presentation Linkbase Document

---------

* Filed herewith.

** Furnished herewith.

SIGNATURES

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



			OIL STATES INTERNATIONAL, INC.


Date:	~~July 29,~~October 28, 2019	By	/s/ LLOYD A. HAJDIK
			Lloyd A. Hajdik
			Executive Vice President, Chief Financial Officer and
			Treasurer (Duly Authorized Officer and Principal Financial Officer)

4243



	June 30, 2019						December 31, 2018
	Gross Carrying Amount		Accumulated Amortization		Net Carrying Amount		Gross Carrying Amount		Accumulated Amortization		Net Carrying Amount
Customer relationships	$	168,266	$	38,729	$	129,537	$	167,811	$	33,247	$	134,564
Patents/Technology/Know-how	85,423		27,268		58,155		84,903		23,418		61,485
Noncompete agreements	17,100		8,418		8,682		18,705		7,544		11,161
Tradenames and other	53,708		7,196		46,512		53,708		5,617		48,091
	$	324,497	$	81,611	$	242,886	$	325,127	$	69,826	$	255,301



	Three Months Ended June 30, 2019		Six Months Ended June 30, 2019
Operating lease expense components:
Leases with initial term of greater than 12 months	$	2,897	$	5,858
Leases with initial term of 12 months or less	1,413		2,766
	$	4,310	$	8,624

Operating lease assets obtained in exchange for operating lease liabilities:
Upon adoption of standard (January 1, 2019)			$	47,721
Subsequent to adoption			5,332
Non-cash operating lease amounts			$	53,053



	Operating Leases
2019 (less six months ended June 30)	$	5,654
2020	10,125
2021	8,282
2022	6,176
2023	5,192
After 2023	22,861
Total lease payments	58,290
Less: Imputed interest	(10,025		)
Present value of operating lease liabilities	48,265
Less: Current portion	(8,997		)
Total long-term operating lease liabilities	$	39,268
Weighted-average remaining lease term (years)	7.7
Weighted-average discount rate	5.0		%