UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

WASHINGTON D.C. 20549

FORM 10-Q

[X] QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d)

OF THE SECURITIES EXCHANGE ACT OF 1934

FOR THE QUARTERLY PERIOD ENDEDJUNE 30, 2016

[  ] TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d)

OF THE SECURITIES EXCHANGE ACT OF 1934

FOR THE TRANSITION PERIODFROM TO.

COMMISSION FILE NUMBER 1-13455

TETRA Technologies, Inc.

(Exact name of registrant as specified in its charter)

Delaware	74-2148293
(State of incorporation)	(I.R.S. Employer Identification No.)
24955 Interstate 45 North
The Woodlands, Texas	77380
(Address of principal executive offices)	(zip code)

(281) 367-1983

(Registrant’s telephone number, including area code)

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports) and (2) has been subject to such filing requirements for the past 90 days. Yes [ X ]  No [   ]

Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files). Yes [ X ]  No [   ]

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

Large accelerated filer [ ]	Accelerated filer [ X ]
Non-accelerated filer [   ] (Do not check if a smaller reporting company)	Smaller reporting company [   ]

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

As ofAugust 9, 2016, there were92,705,714 shares outstanding of the Company’s Common Stock, $0.01 par value per share.

PART I

FINANCIAL INFORMATION

Item 1. Financial Statements.

TETRA Technologies, Inc. and Subsidiaries

Consolidated Statements of Operations

(In Thousands, Except Per Share Amounts)

(Unaudited)

	Three Months Ended   June 30,						Six Months Ended   June 30,
	2016			2015			2016			2015
Revenues:
Product sales	$	64,446		$	149,652		$	122,143		$	234,538
Services and rentals	111,214			166,667			222,846			332,873
Total revenues	175,660			316,319			344,989			567,411
Cost of revenues:
Cost of product sales	51,011			105,084			96,270			168,663
Cost of services and rentals	74,582			102,307			149,764			205,391
Depreciation, amortization, and accretion	33,538			39,067			67,145			77,410
Impairments of long-lived assets	257			—			10,927			—
Total cost of revenues	159,388			246,458			324,106			451,464
Gross profit	16,272			69,861			20,883			115,947
General and administrative expense	27,181			37,472			60,792			72,741
Goodwill impairment	—			—			106,205			—
Interest expense, net	14,335			13,319			28,974			27,035
Other (income) expense, net	2,210			962			1,506			118
Income (loss) before taxes	(27,454		)	18,108			(176,594		)	16,053
Provision for income taxes	1,770			2,741			361			4,310
Net income (loss)	(29,224		)	15,367			(176,955		)	11,743
(Income) loss attributable to noncontrolling interest	2,650			(442		)	62,056			(1,266		)
Net income (loss) attributable to TETRA stockholders	$	(26,574	)	$	14,925		$	(114,899	)	$	10,477
Basic net income (loss) per common share:
Net income (loss) attributable to TETRA stockholders	$	(0.32	)	$	0.19		$	(1.42	)	$	0.13
Average shares outstanding	81,842			79,165			80,631			79,037
Diluted net income (loss) per common share:
Net income (loss) attributable to TETRA stockholders	$	(0.32	)	$	0.19		$	(1.42	)	$	0.13
Average diluted shares outstanding	81,842			79,915			80,631			79,506

See Notes to Consolidated Financial Statements

1

TETRA Technologies, Inc. and Subsidiaries

Consolidated Statements of Comprehensive Income (Loss)

(In Thousands)

(Unaudited)

	Three Months Ended   June 30,					Six Months Ended   June 30,
	2016			2015		2016			2015
Net income (loss)	$	(29,224	)	$	15,367	$	(176,955	)	$	11,743
Foreign currency translation adjustment	(3,367		)	2,358		(2,849		)	(7,429		)
Comprehensive income (loss)	(32,591		)	17,725		(179,804		)	4,314
Comprehensive (income) loss attributable to noncontrolling interest	2,585			602		61,539			(321		)
Comprehensive income (loss) attributable to TETRA stockholders	$	(30,006	)	$	18,327	$	(118,265	)	$	3,993

See Notes to Consolidated Financial Statements

2

TETRA Technologies, Inc. and Subsidiaries

Consolidated Balance Sheets

(In Thousands)

	June 30, 2016			December 31, 2015
	(Unaudited)
ASSETS
Current assets:
Cash and cash equivalents	$	23,917		$	23,057
Restricted cash	6,688			6,721
Trade accounts receivable, net of allowances of $5,386 in 2016 and $7,847 in 2015	110,685			184,172
Inventories	124,315			117,009
Assets held for sale	729			772
Prepaid expenses and other current assets	21,336			22,298
Total current assets	287,670			354,029
Property, plant, and equipment:
Land and building	79,288			79,462
Machinery and equipment	1,351,604			1,345,969
Automobiles and trucks	38,037			43,536
Chemical plants	183,816			181,014
Construction in progress	7,725			6,505
Total property, plant, and equipment	1,660,470			1,656,486
Less accumulated depreciation	(660,301		)	(608,482		)
Net property, plant, and equipment	1,000,169			1,048,004
Other assets:
Goodwill	6,636			112,945
Patents, trademarks and other intangible assets, net of accumulated amortization of $53,760 in 2016 and $44,695 in 2015	71,314			86,375
Deferred tax assets, net	25			25
Other assets	20,609			34,824
Total other assets	98,584			234,169
Total assets	$	1,386,423		$	1,636,202

See Notes to Consolidated Financial Statements

3

TETRA Technologies, Inc. and Subsidiaries

Consolidated Balance Sheets

(In Thousands, Except Share Amounts)

	June 30, 2016			December 31, 2015
	(Unaudited)
LIABILITIES AND EQUITY
Current liabilities:
Trade accounts payable	$	46,684		$	62,114
Unearned income	21,752			27,542
Accrued liabilities	59,703			80,970
Current portion of long-term debt	—			50
Decommissioning and other asset retirement obligations	3,291			14,570
Total current liabilities	131,430			185,246
Long-term debt, net of current portion	788,222			853,228
Deferred income taxes	8,778			9,467
Decommissioning and other asset retirement obligations, net of current portion	51,732			42,879
Other liabilities	18,477			31,202
Total long-term liabilities	867,209			936,776
Commitments and contingencies
Equity:
TETRA stockholders' equity:
Common stock, par value $0.01 per share; 150,000,000 shares authorized at June 30, 2016 and 100,000,000 authorized at December 31, 2015; 95,155,510 shares issued at June 30, 2016 and 83,023,628 shares issued at December 31, 2015	952			830
Additional paid-in capital	323,892			256,184
Treasury stock, at cost; 2,825,284 shares held at June 30, 2016, and 2,766,958 shares held at December 31, 2015	(18,207		)	(16,837		)
Accumulated other comprehensive income (loss)	(45,465		)	(43,135		)
Retained earnings (deficit)	(70,723		)	44,175
Total TETRA stockholders' equity	190,449			241,217
Noncontrolling interests	197,335			272,963
Total equity	387,784			514,180
Total liabilities and equity	$	1,386,423		$	1,636,202

See Notes to Consolidated Financial Statements

4

TETRA Technologies, Inc. and Subsidiaries

Consolidated Statements of Cash Flows

(In Thousands)

(Unaudited)

	Six Months Ended   June 30,
	2016			2015
Operating activities:
Net income (loss)	$	(176,955	)	$	11,743
Reconciliation of net income (loss) to cash provided by operating activities:
Depreciation, amortization, and accretion	67,145			77,410
Impairment of long-lived assets	10,927			—
Impairment of goodwill	106,205			—
Provision (benefit) for deferred income taxes	(533		)	(953		)
Equity-based compensation expense	9,001			4,197
Provision for doubtful accounts	1,333			1,354
Excess decommissioning and abandoning costs	2,793			6
Amortization of deferred financing costs	2,128			1,808
Other non-cash charges and credits	2,557			(1,917		)
Gain on sale of assets	(1,856		)	(2,306		)
Changes in operating assets and liabilities:
Accounts receivable	70,412			31,137
Inventories	(14,198		)	6,148
Prepaid expenses and other current assets	2,137			(2,092		)
Trade accounts payable and accrued expenses	(43,145		)	(43,079		)
Decommissioning liabilities	(3,443		)	(4,411		)
Other	(911		)	3,117
Net cash provided by operating activities	33,597			82,162
Investing activities:
Purchases of property, plant, and equipment	(8,996		)	(73,269		)
Proceeds on sale of property, plant, and equipment	2,279			3,943
Other investing activities	27			(323		)
Net cash used in investing activities	(6,690		)	(69,649		)
Financing activities:
Proceeds from long-term debt	281,300			203,871
Principal payments on long-term debt	(350,501		)	(203,045		)
CCLP distributions	(14,418		)	(18,723		)
Proceeds from exercise of stock options	—			101
Proceeds from issuance of common units, net of underwriters' discount	60,404			—
Other financing activities	(2,095		)	(244		)
Net cash used in financing activities	(25,310		)	(18,040		)
Effect of exchange rate changes on cash	(737		)	(916		)
Increase (decrease) in cash and cash equivalents	860			(6,443		)
Cash and cash equivalents at beginning of period	23,057			48,384
Cash and cash equivalents at end of period	$	23,917		$	41,941
Supplemental cash flow information:
Interest paid	$	28,703		$	28,418
Income taxes paid	2,662			4,814

See Notes to Consolidated Financial Statements

5

TETRA Technologies, Inc. and Subsidiaries

Notes to Consolidated Financial Statements

(Unaudited)

NOTE A – BASIS OF PRESENTATION AND SIGNIFICANT ACCOUNTING POLICIES

We are a geographically diversified oil and gas services company, focused on completion fluids and associated products and services, water management, frac flowback, production well testing, offshore rig cooling, compression services and equipment, and selected offshore services including well plugging and abandonment, decommissioning, and diving. We also have a limited domestic oil and gas production business. We were incorporated in Delaware in 1981 and are composed of five reporting segments organized into four divisions – Fluids, Production Testing, Compression, and Offshore. Unless the context requires otherwise, when we refer to “we,” “us,” and “our,” we are describing TETRA Technologies, Inc. and its consolidated subsidiaries on a consolidated basis.

Our consolidated financial statements include the accounts of our wholly owned subsidiaries. Our interests in oil and gas properties are proportionately consolidated. All intercompany accounts and transactions have been eliminated in consolidation. The information furnished reflects all normal recurring adjustments, which are, in the opinion of management, necessary to provide a fair statement of the results for the interim periods. Operating results for the period ended June 30, 2016 are not necessarily indicative of results that may be expected for the twelve months ended December 31, 2016.

We consolidate the financial statements of CSI Compressco LP and its subsidiaries ("CCLP") as part of our Compression Division, as we determined that CCLP is a variable interest entity and we are the primary beneficiary. We control the financial interests of CCLP and have the ability to direct the activities of CCLP that most significantly impact its economic performance through our ownership of its general partner. The share of CCLP net assets and earnings that is not owned by us is presented as noncontrolling interest in our consolidated financial statements. Our cash flows from our investment in CCLP are limited to the quarterly distributions we receive and the amounts collected for services we perform on behalf of CCLP, as TETRA's capital structure and CCLP's capital structure are separate, as we have no cross default provisions, cross collateralization provisions, or cross guarantees with CCLP's debt, nor does CCLP with TETRA's debt.

The accompanying unaudited consolidated financial statements have been prepared in accordance with Rule 10-01 of Regulation S-X for interim financial statements required to be filed with the Securities and Exchange Commission ("SEC") and do not include all information and footnotes required by generally accepted accounting principles for complete financial statements. These financial statements should be read in connection with the financial statements for the year ended December 31, 2015, and notes thereto included in our Annual Report on Form 10-K, whichwe filed with the SEC on March 4, 2016.

Certain previously reported financial information has been reclassified to conform to the current year period’s presentation. The impact of such reclassifications was not significant to the prior year period’s overall presentation. These reclassifications include the presentation of deferred financing costs in accordance with the adoption of Accounting Standards Update ("ASU") No. 2015-03 and ASU No. 2015-15 as further discussed below and the allocation of deferred financing costs from Other Expense, net to Interest Expense, net. See Note B - Long-Term Debt and Other Borrowings for further discussion and presentation.

Throughout 2015 and continuing into 2016, low oil and natural gas commodity prices lowered the capital expenditure and operating plans of many of our customers, creating uncertainty regarding the expected demand for many of our products and services and the resulting cash flows from operating activities for the foreseeable future. In addition, the availability of new borrowings in current capital markets is more limited and costly. Accordingly, we and CCLP have implemented and continue to implement measures designed to lower our respective cost structures, improve our respective operating cash flows, and improve liquidity and strengthen our respective balance sheets. These measures include headcount reductions and wage reductions. We and CCLP also continue to negotiate with our suppliers and service providers to reduce costs. We and CCLP continue to critically review all capital expenditure activities and are deferring a significant portion of our respective growth and maintenance capital expenditure plans until they may be justified in the future by expected activity levels. We and CCLP believe the steps taken have enhanced our respective capital structures and operating cash flows and additional steps may be taken to enhance our respective operating cash flows in the future.

6

During the three month period ended June 30, 2016, and pursuant to tender offers (the “Tender Offers”) to purchase for cash any and all of the outstanding Series 2010-A Senior Notes, Series 2010-B Senior Notes, and Series 2013 Senior Notes (together the "Tender Offer Senior Notes"), we purchased Tender Offer Senior Notes in an aggregate principal amount of $100.0 million representing the total outstanding principal amount of the Tender Offer Senior Notes. In June 2016, upon the closing of our previously announced offering for the issuance of shares of our common stock, we issued 11.5 million shares of our common stock and used the proceeds to repay the remaining balance outstanding under our Senior Secured Notes. (For further discussion of this common stock offering, see Note F - Equity.) In addition, in July 2016, we amended certain provisions of the agreement governing our bank revolving credit facility (as amended, the "Credit Agreement") as well as certain provisions of our 11% Senior Notes due November 5, 2022 (the "11% Senior Notes") whereby, among other modifications, certain financial covenants under the Credit Agreement and 11% Senior Notes were amended. (For further discussion of the Tender Offers and the amendments to these debt agreements, see Note B - Long-Term Debt and Other Borrowings.) As a result of these steps taken, and financial forecasts based on current market conditions as of August 9, 2016, we believe that despite the current industry environment and activity levels, we will have adequate liquidity to fund our operations and debt obligations and maintain compliance with our amended debt covenants through June 30, 2017.

In May 2016, CCLP amended certain provisions of the agreement governing its bank revolving credit facility (as amended, the "CCLP Credit Agreement") by, among other things, favorably amending certain financial covenants. In August 2016, CCLP received $49.8 million of net proceeds, after deducting certain offering expenses, from the private placement (the "Private Placement") of its Series A Convertible Preferred Units (the "CCLP Preferred Units") and the net proceeds will be used to pay additional offering expenses and reduce outstanding indebtedness of CCLP under the CCLP Credit Agreement or the CCLP 7.25% Senior Notes. We purchased a portion of the CCLP Preferred Units for $10.0 million. (For further discussion of the issuance of CCLP Preferred Units, see Note C - CCLP Series A Convertible Preferred Units.) As a result of these steps taken, and financial forecasts based on current market conditions as of August 9, 2016, CCLP believes that despite the current industry environment and activity levels, it will have adequate liquidity to fund its operations and debt obligations and maintain compliance with its amended debt covenants through June 30, 2017.

Use of Estimates

The preparation of financial statements in conformity with U.S. generally accepted accounting principles ("GAAP") requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclose contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues, expenses, and impairments during the reporting period. Actual results could differ from those estimates, and such differences could bematerial.

Cash Equivalents

We consider all highly liquid cash investments with a maturity of three months or less when purchased to be cash equivalents.

Restricted Cash

Restricted cash is classified as a current asset when it is expected to be repaid or settled in the next twelve month period. Restricted cash reported on our balance sheet as of June 30, 2016 consists primarily of escrowed cash associated with our July 2011 purchase of a heavy lift derrick barge. The escrowed cash is expected to be released to the sellers in early 2017.

Inventories

Inventories are stated at the lower of cost or market value. Except for work in progress inventory discussed below, cost is determined using the weighted average method. Components of inventories as of June 30, 2016, and December 31, 2015, are as follows: 

7

	June 30, 2016		December 31, 2015
	(In Thousands)
Finished goods	$	63,696	$	54,587
Raw materials	3,118		1,731
Parts and supplies	37,830		37,379
Work in progress	19,671		23,312
Total inventories	$	124,315	$	117,009

Finished goods inventories include newly manufactured clear brine fluids as well as used brines that are repurchased from certain customers for recycling. Recycled brines are recorded at cost, using the weighted average method. Work in progress inventory consists primarily of new compressor packages located in the CCLP fabrication facility in Midland, Texas. The cost of work in process is determined using the specific identification method. During the six month period ended June 30, 2016, $11.2 million of CCLP work in progress inventory was transferred to Property, Plant and Equipment. We write down the value of inventory by an amount equal to the difference between its cost and its market value.

Goodwill

Goodwill represents the excess of cost over the fair value of the net assets of businesses acquired in purchase transactions. We perform a goodwill impairment test on an annual basis or whenever indicators of impairment are present. We perform the annual test of goodwill impairment following the fourth quarter of each year.The assessment for goodwill impairment begins with a qualitative assessment of whether it is “more likely than not” that the fair value of each reporting unit is less than its carrying value. This qualitative assessment requires the evaluation, based on the weight of evidence, of the significance of all identified events and circumstances for each reporting unit. During 2015, and continuing into 2016, global oil and natural gas commodity prices, particularly crude oil, were significantly reduced. These low commodity prices have had, and are expected to continue to have, a negative impact on industry drilling and capital expenditure activity, which affects the demand for a portion of our products and services. Due to the decrease in the price of our common stock and the price per common unit of CCLP during the first three months of 2016, our and CCLP's market capitalizations as of March 31, 2016, were below their respective recorded net book values, including goodwill. In addition, the continuing low oil and natural gas commodity price environment resulted in a further negative impact on demand for the products and services for each of our reporting units. As a result of these factors, we determined that it was “more likely than not” that the fair values of certain of our reporting units were less than their respective carrying values as of March 31, 2016.

When the qualitative analysis indicates that it is “more likely than not” that a reporting unit’s fair value is less than its carrying value, the resulting goodwill impairment test consists of a two-step accounting test performed on a reporting unit basis.The first step of the impairment test is to compare the estimated fair value with the recorded net book value (including goodwill) of our business. If the estimated fair value of the reporting unit is higher than the recorded net book value, no impairment is deemed to exist and no further testing is required. If, however, the estimated fair value of the reporting unit is below the recorded net book value, then a second step must be performed to determine the goodwill impairment required, if any. In this second step, the estimated fair value from the first step is used as the purchase price in a hypothetical acquisition of the reporting unit. Business combination accounting rules are followed to determine a hypothetical purchase price allocation to the reporting unit’s assets and liabilities. The residual amount of goodwill that results from this hypothetical purchase price allocation is compared to the recorded amount of goodwill for the reporting unit, and the recorded amount is written down to the hypothetical amount, if lower. The application of this second step under goodwill impairment testing may also result in impairments of other long-lived assets, including identified intangible assets. See Impairment of Long-Lived Assets section below for a discussion of other asset impairments that were identified as part of the testing of goodwill as of March 31, 2016.

Because quoted market prices for our reporting units other than Compression are not available, our management must apply judgment in determining the estimated fair value of these reporting units for purposes of performing the goodwill impairment test. Management uses all available information to make these fair value determinations, including the present value of expected future cash flows using discount rates commensurate with the risks involved in the assets. The resultant fair values calculated for the reporting units are then compared to observable metrics for other companies in our industry or to mergers and acquisitions in our industry to determine whether those valuations, in our judgment, appear reasonable.

8

The accounting principles regarding goodwill acknowledge that the observed market prices of individual trades of a company’s stock (and thus its computed market capitalization) may not be representative of the fair value of the company as a whole. Substantial value may arise from the ability to take advantage of synergies and other benefits that flow from control over another entity. Consequently, measuring the fair value of a collection of assets and liabilities that operate together in a controlled entity is different from measuring the fair value of a single share of that entity’s common stock. Therefore, once the fair value of the reporting units was determined, we also added a control premium to the calculations. This control premium is judgmental and is based on observed mergers and acquisitions in our industry.

Goodwill Impairment as of March 31, 2016. As part of our internal annual business outlook for each of our reporting units that we performed during the fourth quarter of 2015, we considered changes in the global economic environment that affected our stock price and market capitalization. As part of the first step of goodwill impairment testing as of March 31, 2016, we updated our annual assessment of the future cash flows for each of our reporting units, applying expected long-term growth rates, discount rates, and terminal values that we consider reasonable for each reporting unit. We calculated a present value of the respective cash flows for each of the reporting units to arrive at an estimate of fair value under the income approach, and then used the market approach to corroborate these values.

During the first three months of 2016, low oil and natural gas commodity prices resulted in decreased demand for many of the products and services of each of our reporting units. However, based on updated assumptions as of March 31, 2016, we determined that the fair value of our Fluids Division was significantly in excess of its carrying value, which includes $6.6 million of goodwill. Our Offshore Services and Maritech Divisions had no remaining goodwill as of March 31, 2016. With regard to our Compression Division, demand for low-horsepower wellhead compression services and for sales of compressor equipment decreased significantly and is expected to continue to be decreased for the foreseeable future. In addition, the price per common unit of CCLP as of March 31, 2016 decreased compared to December 31, 2015. Accordingly, the fair value, including the market capitalization for CCLP, for the Compression reporting unit was less than its carrying value as of March 31, 2016, despite impairments recorded as of December 31, 2015. For our Production Testing Division, demand for production testing services decreased in each of the market areas in which we operate, resulting in decreased estimated future cash flows. As a result, the fair value of the Production Testing reporting unit was also less than its carrying value as of March 31, 2016, despite impairments recorded as of December 31, 2015. After making the hypothetical purchase price adjustments as part of the second step of the goodwill impairment test, there was $0.0 million residual purchase price to be allocated to the goodwill of both the Compression and Production Testing reporting units. Based on this analysis, we concluded that full impairments of the $92.4 million of recorded goodwill for Compression and $13.9 millionof recorded goodwill for Production Testing were required. Accordingly, during the three month period ended March 31, 2016, $106.2 million was charged to Goodwill Impairment expense in the accompanying consolidated statement of operations.

As of June 30, 2016, we determined that there was no additional impairment of goodwill, as the fair value of our Fluids Division remains in excess of its carrying value. The carrying amounts of goodwill for the Fluids, Production Testing, Compression, and Offshore Services reporting units are net of $23.8 million, $111.8 million, $231.8 million, and $27.2 million, respectively, of accumulated impairment losses.The changes in the carrying amount of goodwill are as follows:

	Fluids		Production Testing			Compression			Offshore Services		Maritech		Total
	(In Thousands)
Balance as of December 31, 2014	6,636		53,682			233,548			—		—		293,866
Goodwill adjustments	—		(39,775		)	(141,146		)	—		—		(180,921		)
Balance as of December 31, 2015	6,636		13,907			92,402			—		—		112,945
Goodwill adjustments	—		(13,907		)	(92,402		)	—		—		(106,309		)
Balance as of June 30, 2016	$	6,636	$	—		$	—		$	—	$	—	$	6,636

9

Impairments of Long-Lived Assets

Impairments of long-lived assets, including identified intangible assets, are determined periodically when indicators of impairment are present. If such indicators are present, the determination of the amount of impairment is based on our judgments as to the future undiscounted operating cash flows to be generated from these assets throughout theirremainingestimated useful lives. If these undiscounted cash flows are less than the carrying amount of the related asset, an impairment is recognized for the excess of the carrying value over its fair value. Fair value of intangible assets is generally determined using the discounted present value of future cash flows. Assets held for sale are recorded at the lower of carrying value or estimated fair value less estimated selling costs.

During the first six months of 2016, primarily as a result of continuing decreased demand due to current market conditions, our Compression, Production Testing, and Fluids segments recorded $7.9 million, $2.8 million, and $0.3 million, respectively, of impairments associated with certain identified intangible assets. These amounts were charged to Impairments of Long-Lived Assets expense in the accompanying consolidated statement of operations.

Net Income (Loss) per Share

The following is a reconciliation of the weighted average number of common shares outstanding with the number of shares used in the computations of net income (loss) per common and common equivalent share:

	Three Months Ended   June 30,		Six Months Ended   June 30,
	2016	2015	2016	2015
	(In Thousands)
Number of weighted average common shares outstanding	81,842	79,165	80,631	79,037
Assumed exercise of stock awards	—	750	—	469
Average diluted shares outstanding	81,842	79,915	80,631	79,506

For thethree and six month periods ended June 30, 2016, the average diluted shares outstanding excludes the impact of all outstanding stock awards, as the inclusion of these shares would have been antidilutive due to the net losses recorded during the periods. For the three and six month periods ended June 30, 2015, the average diluted shares outstanding excludes the impact of 3,618,107 and 3,494,752, respectively, of average outstanding stock awards that have exercise prices in excess of the average market price, as the inclusion of these shares would have been antidilutive.

Services and Rentals Revenues and Costs

A portion of our services and rentals revenues consist of income pursuant to operating lease arrangements for compressor packages and other equipment assets. For the three and six month periods ended June 30, 2016 and 2015, the following operating lease revenues and associated costs were included in services and rentals revenues and cost of services and rentals, respectively, in the accompanying consolidated statements of operations.

	Three Months Ended   June 30,				Six Months Ended   June 30,
	2016		2015		2016		2015
	(In Thousands)
Rental revenue	$	11,865	$	42,475	$	25,966	$	91,998
Cost of rental revenue	$	10,620	$	17,914	$	22,866	$	42,436

Foreign Currency Translation

We have designated the euro, the British pound, the Norwegian krone, the Canadian dollar, theBrazilian real, the Argentine peso, and theMexican peso, respectively, as the functional currency for our operations in Finland and Sweden, the United Kingdom, Norway, Canada, Brazil, Argentina,and certain of our operations in Mexico. The U.S. dollar is the designated functional currency for all of our other foreign operations. The cumulative

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translation effects of translating the applicable accounts from the functional currencies into the U.S. dollar at current exchange rates are included as a separate component ofequity. Foreign currency exchange gains and (losses) are included in Other Expense and totaled $0.4 million and $0.7 million during the three and six month periods ended June 30, 2016 and $(0.7) million and $(1.4) million during the three and six month periods endedJune 30, 2015, respectively.

Income Taxes

Our consolidated provision for income taxes during the first six months of 2015 and 2016 is primarily attributable to taxes in certain foreign jurisdictions and Texas gross margin taxes. Our consolidated effective tax rates for the three and six month periods ended June 30, 2016 of negative 6.4% and negative 0.2%, respectively, were primarily the result of losses generated in entities for which no related tax benefit has been recorded. The losses generated by these entities do not result in tax benefits due to offsetting valuation allowances being recorded against the related net deferred tax assets. We establish a valuation allowance to reduce the deferred tax assets when it is more likely than not that some portion or all of the deferred tax assets will not be realized. Included in our deferred tax assets are net operating loss carryforwards and tax credits that are available to offset future income tax liabilities in the U.S. as well as in certain foreign jurisdictions. Further, the effective tax rate is negatively impacted by the nondeductible portion of our goodwill impairments recorded during the three month period ended March 31, 2016.

Fair Value Measurements

Fair value is defined as “the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date” within an entity’s principal market, if any. The principal market is the market in which the reporting entity would sell the asset or transfer the liability with the greatest volume and level of activity, regardless of whether it is the market in which the entity will ultimately transact for a particular asset or liability or if a different market is potentially more advantageous. Accordingly, this exit price concept may result in a fair value that may differ from the transaction price or market price of the asset or liability.

Under U.S. generally accepted accounting principles ("GAAP"), the fair value hierarchy prioritizes inputs to valuation techniques used to measure fair value. Fair value measurements should maximize the use of observable inputs and minimize the use of unobservable inputs, where possible. Observable inputs are developed based on market data obtained from sources independent of the reporting entity. Unobservable inputs may be needed to measure fair value in situations where there is little or no market activity for the asset or liability at the measurement date and are developed based on the best information available in the circumstances, which could include the reporting entity’s own judgments about the assumptions market participants would utilize in pricing the asset or liability.

We utilize fair value measurements to account for certain items and account balances within our consolidated financial statements. Fair value measurements are utilized in the allocation of purchase consideration for acquisition transactions to the assets and liabilities acquired, including intangible assets and goodwill (a level 3 fair value measurement). In addition, we utilize fair value measurements in the initial recording of our decommissioning and other asset retirement obligations. Fair value measurements may also be utilized on a nonrecurring basis, such as for the impairment of long-lived assets, including goodwill (a level 3 fair value measurement). The fair value of certain of our financial instruments, which include cash, restricted cash, accounts receivable, short-term borrowings, and long-term debt pursuant to our bank credit agreements, approximate their carrying amounts. The aggregate fair values of our long-term 11% Senior Notes and Tender Offer Senior Notes at June 30, 2016 and December 31, 2015, were approximately $117.7 million and $229.8 million, respectively, compared to carrying amounts of $125.0 million and $275.0 million, respectively, as current interest rates onthose dates were different than the stated interest rates on these notes . The fair values of the publicly traded CCLP Senior Notes (as herein defined) at June 30, 2016 and December 31, 2015, were approximately $287.9 million and $259.9 million (a level 2 fair value measurement) compared to a face amount of $350.0 million (see Note C - Long-Term Debt and Other Borrowings, for further discussion), as current rates onthose dates were different from the stated interest rates on the CCLP Senior Notes. We calculated the fair values of our 11% Senior Notes and Tender Offer Senior Notes as of June 30, 2016 and December 31, 2015, internally, using current market conditions and average cost of debt (a level 2 fair value measurement).

We also utilize fair value measurements on a recurring basis in the accounting for our foreign currency forward sale derivative contracts. For these fair value measurements, we utilize the quoted value as determined by

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our counterparty financial institution (a level 2 fair value measurement). A summary of these fair value measurements as of June 30, 2016 and December 31, 2015, is as follows:

				Fair Value Measurements Using
	Total as of			Quoted Prices in Active Markets for Identical Assets or Liabilities	Significant Other Observable Inputs		Significant Unobservable Inputs
Description	June 30, 2016			(Level 1)	(Level 2)		(Level 3)
	(In Thousands)
Asset for foreign currency derivative contracts	$	271		—	271		—
Liability for foreign currency derivative contracts	(745		)	—	(745	)	—
Net liability	$	(474	)

				Fair Value Measurements Using
	Total as of			Quoted Prices in Active Markets for Identical Assets or Liabilities		Significant Other Observable Inputs		Significant Unobservable Inputs
Description	Dec 31, 2015			(Level 1)		(Level 2)		(Level 3)
	(In Thousands)
Asset for foreign currency derivative contracts	$	23		$	—	23		—
Liability for foreign currency derivative contracts	(385		)	—		(385	)	—
Acquisition contingent consideration liability	—			—		—		—
Net liability	$	(362	)

During the first quarter of 2016, in connection with the review of goodwill impairment of our Compression and Production Testing Divisions, these segments recorded total impairment charges of $117.1 million, reflecting the decreased fair value for certain assets. For further discussion, see "Goodwill" and "Impairment of Long-Lived Assets" section above. The fair values used in these impairment calculations were estimated based on a variety of measurements, including current replacement cost and discounted estimated future cash flows, all of which are based on significant unobservable inputs (a level 3 fair value measurement) in accordance with the fair value hierarchy.A summary of these nonrecurring fair value measurements as of June 30, 2016, using the fair value hierarchy is as follows:

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			Fair Value Measurements Using
	Total as of		Quoted Prices in Active Markets for Identical Assets or Liabilities	Significant Other Observable Inputs	Significant Unobservable Inputs	Year-to-Date Impairment
Description	Jun 30, 2016		(Level 1)	(Level 2)	(Level 3)	Losses
	(In Thousands)
Compression intangible assets	$	—	—	—	—	$	7,865
Compression goodwill	—		—	—	—	92,333
Production Testing intangible assets	—		—	—	—	2,805
Production Testing goodwill	—		—	—	—	13,872
Other	—		—	—	—	257
Total	$	—				$	117,132

New Accounting Pronouncements

In May 2014, the Financial Accounting Standards Board ("FASB") issued Accounting Standards Update ("ASU") 2014-09, "Revenue from Contracts with Customers." ASU 2014-09 supersedes the revenue recognition requirements in Accounting Standards Codification ("ASC") 605, Revenue Recognition, and most industry-specific guidance. The core principle of the guidance is that an entity should recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services. This ASU is effective for annual periods beginning after December 15, 2017, and interim periods within those years, under either full or modified retrospective adoption. We are currently assessing the potential effects of these changes to our consolidated financial statements.

In March 2016, the FASB issued ASU 2016-08, "Revenue from Contracts with Customers (Topic 606): Principal versus Agent Considerations (Reporting Revenue Gross versus Net)" to clarify the guidance on principal versus agent considerations. This ASU does not change the effective date or adoption method under ASU 2014-09 which is noted above.

In April 2016, the FASB issued ASU 2016-10, "Revenue from Contracts with Customers (Topic 606): Identifying Performance Obligations and Licensing" to clarify the guidance on identifying performance obligations and the licensing implementation guidance. This ASU does not change the effective date or adoption method under ASU 2014-09, which is noted above.

Additionally in May 2016, the FASB issued ASU 2016-12, "Revenue from Contracts with Customers (Topic 606): Narrow-Scope Improvements and Practical Expedients". This ASU addresses and amends several aspects of ASU 2014-09, but does not change the core principle of the guidance. This ASU does not change the effective date or adoption method under ASU 2014-09 which is noted above.

In August 2014, the FASB issued ASU No. 2014-15, “Presentation of Financial Statements - Going Concern.” The ASU provides guidance on management's responsibility to evaluate whether there is substantial doubt about an entity's ability to continue as a going concern and in certain circumstances to provide related footnote disclosures. The ASU is effective for annual periods ending after December 15, 2016, and for annual and interim periods thereafter. Early adoption is permitted. We do not expect the adoption of this standard to have a material impact on our consolidated financial statements.

In April 2015, the FASB issued ASU No. 2015-03, “Interest - Imputation of Interest (Subtopic 835-30): Simplifying the Presentation of Debt Issuance Costs.”  The ASU requires entities that have historically presented debt financing costs as an asset to present those costs as a direct deduction from the carrying amount of the related debt liability. This presentation will result in the debt issuance costs being presented the same way debt discounts have historically been handled. The ASU does not change the recognition, measurement, or subsequent measurement guidance for debt issuance costs. The ASU is effective for annual periods beginning after December

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15, 2015, and interim periods within those annual periods and is to be applied retrospectively. As a result of the retrospective adoption of this guidance during the quarter, deferred financing costs of $10.6 million and $13.5 million at June 30, 2016 and December 31, 2015, respectively, are netted against the carrying values of the Senior Notes of TETRA and CCLP.

Additionally, in accordance with ASU No. 2015-15, "Interest-Imputation of Interest (Subtopic 835-30): Presentation and Subsequent Measurement of Debt Issuance Costs Associated with Line-of-Credit Arrangements", issued in August 2015, we elected to present the deferred financing costs associated with the bank credit facilities of $5.8 million and $6.7 million at June 30, 2016 and December 31, 2015, respectively, as netted against the outstanding amount of the bank credit facilities of TETRA and CCLP.

In July 2015, the FASB issued ASU No. 2015-11, “Simplifying the Measurement of Inventory” (Topic 330), which simplifies the subsequent measurement of inventory by requiring entities to measure inventory at the lower of cost or net realizable value, except for inventory measured using the last-in, first-out (LIFO) or the retail inventory methods. The ASU requires entities to compare the cost of inventory to one measure - net realizable value. Net realizable value is the estimated selling price in the ordinary course of business, less reasonably predictable costs of completion, disposal and transportation. The ASU is effective for annual periods beginning after December 15, 2016, and interim periods within those annual periods, and is to be applied prospectively with early adoption permitted. We do not expect the adoption of this standard to have a material impact on our consolidated financial statements.

In February 2016, the FASB issued ASU 2016-02, "Leases" (Topic 842) to increase comparability and transparency among different organizations. Organizations are required to recognize lease assets and lease liabilities on the balance sheet and disclose key information about the leasing arrangements and cash flows. The ASU is effective for annual periods beginning after December 15, 2018, and interim periods within those annual periods, under a modified retrospective adoption with early adoption permitted. We are currently assessing the potential effects of these changes to our consolidated financial statements.

In March 2016, the FASB issued ASU 2016-09, "Compensation-Stock Compensation (Topic 718): Improvements to Employee Share-Based Payment Accounting" as part of a simplification initiative. The update addresses and simplifies several aspects of accounting for share-based payment transactions. The ASU is effective for annual periods beginning after December 15, 2016, and interim periods within those annual periods, with early adoption permitted, and is to be applied using either modified retrospective, retrospective, or prospective transition method based on which amendment is being applied. We are currently assessing the potential effects of these changes to our consolidated financial statements.

In June 2016, the FASB issued ASU 2016-13, "Financial Instruments - Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments." ASU 2016-13 amends the impairment model to utilize an expected loss methodology in place of the currently used incurred loss methodology, which will result in the more timely recognition of losses. ASU 2016-13 also applies to employee benefit plan accounting, with an effective date of the first quarter of fiscal year 2022. We are currently assessing the potential effects of these changes to our consolidated financial statements and employee benefit plans accounting.

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NOTE B – LONG-TERM DEBT AND OTHER BORROWINGS

It is important to consider TETRA's capital structure and CCLP's capital structure separately, as we have no cross default provisions, cross collateralization provisions, or cross guarantees with CCLP's debt, nor does CCLP with TETRA's debt.

Long-term debt consists of the following:

		June 30, 2016		December 31, 2015
		(In Thousands)
TETRA	Scheduled Maturity
Bank revolving line of credit facility (presented net of the unamortized deferred financing costs of $1.1 million as of June 30, 2016 and $1.3 million as of December 31, 2015)	September 30, 2019	$	101,604	$	21,572
5.09% Senior Notes, Series 2010-A (presented net of unamortized deferred financing costs of $0 million as of June 30, 2016 and $0.1 million as of December 31, 2015)	December 15, 2017	—		46,809
5.67% Senior Notes, Series 2010-B (presented net of unamortized deferred financing costs of $0 million as of June 30, 2016 and $0.1 million as of December 31, 2015)	December 15, 2020	—		17,964
4.00% Senior Notes, Series 2013 (presented net of unamortized deferred financing costs of $0 million as of June 30, 2016 and $0.2 million as of December 31, 2015)	April 29, 2020	—		34,753
11.00% Senior Notes, Series 2015 (presented net of the unamortized discount of $4.7 million as of June 30, 2016 and $4.9 million as of December 31, 2015 and net of unamortized deferred financing costs of $2.9 million as of June 30, 2016 and $3.2 million as of December 31, 2015)	November 5, 2022	117,446		116,837
Senior Secured Notes (presented net of unamortized deferred financing costs of $0 million as of June 30, 2016 and $1.4 million as of December 31, 2015)	April 1, 2019	—		48,635
Other		—		50
TETRA total debt		219,050		286,620
Less current portion		—		(50		)
TETRA total long-term debt		$	219,050	$	286,570
CCLP
CCLP Bank Credit Facility (presented net of the unamortized deferred financing costs of $4.8 million as of June 30, 2016 and $5.4 million as of December 31, 2015)	August 4, 2019	231,171		229,555
CCLP 7.25% Senior Notes (presented net of the unamortized discount of $4.3 million as of June 30, 2016 and $4.5 million as of December 31, 2015 and net of unamortized deferred financing costs of $7.7 million as of June 30, 2016 and $8.4 million as of December 31, 2015)	August 15, 2022	338,001		337,103
CCLP total long-term debt		569,172		566,658
Consolidated total long-term debt		$	788,222	$	853,228

As a result of the retrospective adoption of ASU 2015-03 during the three months ended March 31, 2016, deferred financing costs of $16.4 million and $20.2 million at June 30, 2016 and December 31, 2015, respectively, were reclassified out of long-term other assets and are netted against the carrying values of the bank credit facilities and Senior Notes of TETRA and CCLP. In addition, $1.0 million and $2.1 million of expense for the amortization of deferred financing costs for the three and six month periods ended June 30, 2016, respectively, and $1.0 million

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and $1.8 million for the three and six month periods ended June 30, 2015, respectively, were reclassified from Other Expense, net to Interest Expense, net in the accompanying consolidated statements of operations.

As of June 30, 2016, TETRA (excluding CCLP) had an outstanding balance on its Credit Agreement of $102.7 million, andhad $8.1 million in letters of credit and guaranteesagainst therevolving credit facility, leaving a net availability of $114.2 million. As of June 30, 2016, CCLP had a balance outstanding under the CCLP Credit Agreement of $236.0 million, had $2.1 million letters of credit and performance bonds outstanding, leaving a net availability under the CCLP Credit Agreement of $101.9 million. Availability under each of the TETRA Credit Agreement and the CCLP Credit Agreement is subject to compliance with the respective financial covenants and other provisions in the respective credit agreements that may limit borrowings thereunder.

As described below, we and CCLP are in compliance with all covenants of our respective credit agreements and senior note agreements as of June 30, 2016. Based on our financial projections and including the impact of cost reduction efforts and expected activity levels on future estimated operating cash flows, we anticipate that, despite the current industry environment and activity levels, we will have sufficient operating cash flows to maintain compliance with the financial covenants under our amended debt agreements through June 30, 2017. With regard to CCLP, considering financial forecasts based on current market conditions as of August 9, 2016, and as a result of the impact of recent cost reduction efforts, the May 2016 amendment of certain financial covenants under the CCLP Credit Agreement, and the August 2016 receipt of $49.8 million of net proceeds from the Private Placement of the CCLP Preferred Units (including $10.0 million of proceeds received from us related to our purchase of a portion of the CCLP Preferred Units), CCLP believes that it will have adequate liquidity to fund its operations and debt obligations and maintain compliance with the financial covenants under our amended debt agreements through June 30, 2017.

Our Long-Term Debt

Our Credit Agreement.On July 1, 2016, we entered into an amendment (the "Fourth Amendment") of our Credit Agreement that replaced and modified certain financial covenants in the Credit Agreement. Pursuant to the Fourth Amendment, the interest charge coverage ratio covenant was deleted and replaced with a fixed charge coverage ratio. The fixed charge coverage ratio compares (a) EBITDA (as adjusted and defined in the Credit Agreement) less (1) cash income tax expense, (2) non-financed capital expenditures, and (3) cash dividends and distributions to (b) interest expense plus (1) scheduled principal payments and (2) stock purchases. The Fourth Amendment provides that the fixed charge coverage ratio may not be less than 1.25 to 1 as of the end of any fiscal quarter. The consolidated leverage ratio covenant was amended and may not exceed (a) 4.00 to 1 at the end of the fiscal quarters ending during the period from and including June 30, 2016 through and including March 31, 2018, (b) 3.75 to 1 at the end of the fiscal quarters ending during the period from and including June 30, 2018 through and including December 31, 2018, and (c) 3.5 to 1 at the end of each of the fiscal quarters thereafter. In addition, subsequent to the Fourth Amendment, borrowings will bear interest at the British Bankers Association LIBOR rate plus 2.25% to 4.00%, or an alternate base rate plus 0.00% to 1.00%, in each case depending on one of our financial ratios, and the commitment fee on unused portions of the facility will range from 0.35% to 0.75%. The Fourth Amendment also resulted in additional modifications, including a requirement that all obligations under the Credit Agreement and the guarantees of such obligations be secured by first-lien security interests in substantially all of our assets and the assets of our subsidiaries (limited, in the case of foreign subsidiaries, to 66% of the voting stock or equity interests of first-tier foreign subsidiaries). Such security interests are for the benefit of the lenders of the Credit Agreement as well as the holder of our 11% Senior Notes. Pursuant to the Fourth Amendment, bank fees and other financing costs of $0.8 million were incurred, including $0.1 million that were charged to general and administrative expense during the three month period ended June 30, 2016.

At June 30, 2016, our consolidated leverage ratio was 2.27 to 1 (compared to 4.00 to 1 maximum as required under the Credit Agreement) and our fixed charge coverage ratio was 4.32 to 1 (compared to a 1.25 to 1 minimum required under the Credit Agreement).

Our Senior Notes. In May 2016, we purchased for cash the Tender Offer Senior Notes, in the aggregate principal amount of $100.0 million, plus accrued and unpaid interest, pursuant to previously announced Tender Offers. The consideration paid for the Tender Offer Senior Notes was a cash amount equal to $100,000 per $100,000 principal amount of the Tender Offer Senior Notes validly tendered (and not validly withdrawn) prior to the expiration time of each Tender Offer, and validly accepted for purchase by us. The purchase of the Tender Offer Senior Notes was funded by borrowings under our Credit Agreement. In connection with the repayment of the

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Tender Offer Senior Notes, approximately $0.4 million of remaining unamortized deferred finance costs were charged to other expense during the three month period ended June 30, 2016.

In June 2016, and following the issuance of 11.5 million shares of our common stock, we utilized a portion of the $60.4 million of net proceeds to repay the remaining $30.0 million outstanding under our Senior Secured Notes. The remaining proceeds were used to pay offering related expenses and reduce the amount of borrowings outstanding under our Credit Agreement. In connection with the repayment of the Senior Secured Notes, $1.1 million of remaining unamortized deferred finance costs were charged to other expense during the three month period ended June 30, 2016.

On July 1, 2016, we entered into an Amended and Restated Note Purchase Agreement (the "Amended and Restated 11% Senior Note Agreement") with GSO Tetra Holdings LP ("GSO"), to amend and replace the previous Note Purchase Agreement relating to our $125.0 million aggregate principal amount of 11% Senior Notes due November 5, 2022 (the "11% Senior Notes"). The Amended and Restated 11% Senior Note Agreement amends certain financial covenants, including replacing the interest coverage ratio covenant in the previous Note Purchase Agreement with a minimum permitted fixed charge coverage ratio at the end of any fiscal quarter of 1.1 to 1. Additionally, the maximum permitted ratio of consolidated funded indebtedness at the end of any fiscal quarter to a defined measure of earnings increased from 3.50 to 1 to (a) 4.50 to 1 as of the end of any fiscal quarter ending during the period commencing July 1, 2016 and ending on March 31, 2018, (b) 4.25 to1 as of the end of any fiscal quarter ending during the period commencing on June 30, 2018 and ending on December 31, 2018 and (c) 4.00 to 1 as of the end of any fiscal quarter ending thereafter. Pursuant to the Amended and Restated 11% Senior Note Agreement, the 11% Senior Notes are now secured by first-lien security interests in substantially all of our assets and the assets of our subsidiaries. See the above discussion of the Fourth Amendment to our Credit Agreement for a description of these security interests. The 11% Senior Notes are now pari passu in right of payment to all borrowings under the Credit Agreement and rank at least pari passu in right of payment with all other outstanding indebtedness. The Amended and Restated 11% Senior Note Agreement contains customary covenants that limit our ability to, among other things; incur or guarantee additional indebtedness; incur or create liens; merge or consolidate or sell substantially all of our assets; engage in a different business; enter into transactions with affiliates; and make certain payments as set forth in the Amended and Restated 11% Senior Note Agreement. Pursuant to the Amended and Restated 11% Senior Note Agreement, lender fees and other financing costs of $1.2 million were incurred, including $0.2 million that were charged to general and administrative expense during the three month period ended June 30, 2016.

The Amended and Restated 11% Senior Note Agreement contains customary default provisions, as well as the following cross-default provision. An event of default will occur if we (i) fail to make any payment when due beyond any applicable grace period under any indebtedness of at least $20.0 million, (ii) default in the performance of any obligation under the Amended and Restated 11% Senior Note Agreement or collateral documents and such default is not remedied within the applicable cure period, (iii) default in the performance of or compliance with any term of any indebtedness in an aggregate outstanding principal amount of at least $20.0 million or of any mortgage, indenture or other agreement relating to such indebtedness or any other condition exists, and as a result of such default or condition such indebtedness is accelerated and declared due and payable before its stated maturity or before its regularly scheduled dates for payment, (iv) we become obligated to purchase or repay indebtedness before its regular maturity or before its regularly scheduled dates of payment in an aggregate outstanding principal amount of at least $20.0 million or one or more persons have the right to require us to purchase or repay such indebtedness or (v) with certain exceptions, the security interest in the collateral ceases to be in full force and effect. Upon the occurrence and during the continuation of an event of default under the Amended and Restated 11% Senior Note Agreement, the 11% Senior Notes may become immediately due and payable, either automatically or by declaration of holders of more than 50% in principal amount of the 11% Senior Notes at the time outstanding.

CCLP Long-Term Debt

CCLP Credit Agreement.On May 25, 2016, CCLP entered into an amendment (the "CCLP Third Amendment") to the CCLP Credit Agreement that, among other things, modified certain financial covenants in the CCLP Credit Agreement. Pursuant to the CCLP Third Amendment, the consolidated total leverage ratio may not exceed (a) 5.50 to 1 as of June 30, 2016 and September 30, 2016; (b) 5.75 to 1 as of December 31, 2016, March 31, 2017, June 30, 2017 and September 30, 2017; (c) 5.50 to 1 as of December 31, 2017 and March 31, 2018; (d) 5.25 to 1 as of June 30, 2018 and September 30, 2018, and (e) 5.00 to 1 as of December 31, 2018 and thereafter. In addition, the consolidated secured leverage ratio was reduced from 4.00 to 1 to 3.50 to 1. The consolidated total leverage ratio and the consolidated secured leverage ratio, as both are calculated under the CCLP Credit

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Agreement, will exclude the long-term liability for the CCLP Preferred Units, among other items, in the determination of total indebtedness. In addition, the CCLP Third Amendment provided for other changes related to the CCLP Credit Agreement including (i) reducing the maximum aggregate lender commitments from $400.0 million to $340.0 million; (ii) increasing the applicable margin by 0.25% with a range between 2.00% and 3.00% per annum for LIBOR-based loans and 1.00% to 2.00% per annum for base-rate loans, based on the applicable consolidated total leverage ratio; (iii) imposed a requirement that CCLP use designated consolidated cash and cash equivalent balances in excess of $35.0 million to prepay the loans; (iv) imposed a requirement to deliver on an annual basis, and at such other times as may be required, an appraisal of CCLP's compressor equipment; (v) increased the amount of equipment and real property that may be disposed of in any four consecutive fiscal quarters from $5.0 million to $20.0 million; (vi) allows the prepayment or purchase of indebtedness with proceeds from the issuances of equity securities or in exchange for the issuances of equity securities; and (vii) reduced the amount of CCLP's permitted capital expenditures in the ordinary course of business during each fiscal year from $150.0 million to an amount generally ranging from $25.0 million in 2016 to $75.0 million in 2019. Pursuant to the CCLP Third Amendment, bank fees and financing costs of $0.7 million were incurred and charged to Other Expense during the three month period ended June 30, 2016.

At June 30, 2016, CCLP's consolidated total leverage ratio was 5.04 to 1 (compared to 5.50 to 1 maximum as required under the CCLP Credit Agreement) and its interest coverage ratio was 3.81 to 1 (compared to a 3.0 to 1 minimum required under the CCLP Credit Agreement).

CCLP 7.25% Senior Notes

On August 8, 2016, in connection with the closing of the Private Placement, CCLP entered into a Note Repurchase Agreement (the “CCLP Note Repurchase Agreement”) with Hudson Bay Fund LP pursuant to which CCLP agreed to repurchase up to $20.0 million of its CCLP 7.25% Senior Notes due August 15, 2022 (the “CCLP 7.25% Senior Notes”). At any time and up to four times in the aggregate during the period beginning on September 12, 2016 and ending on October 12, 2016, Hudson Bay Fund LP may deliver a written notice to CCLP indicating the applicable closing date (the “CCLP Note Repurchase Closing Date”) and the principal amount of CCLP 7.25% Senior Notes to be purchased by CCLP. The repurchase of the CCLP 7.25% Senior Notes by CCLP is conditioned on it receiving proceeds from the sale of additional equity securities of CCLP, including, without limitation, additional CCLP Preferred Units or Series A Parity Securities (as defined in the Series A Preferred Unit Purchase Agreement) between August 8, 2016 and October 12, 2016. Additionally, the repurchase price on any CCLP Note Repurchase Closing Date shall not be greater than the proceeds then received by CCLP from the sale of equity described in the preceding sentence. For further discussion of the CCLP Preferred Units, see Note C - CCLP Series A Convertible Preferred Units.

NOTE C – CCLP SERIES A CONVERTIBLE PREFERRED UNITS

On August 8, 2016, CCLP entered into a Series A Preferred Unit Purchase Agreement (the “CCLP Preferred Unit Purchase Agreement”) with certain purchasers (collectively, the “Purchasers”) to issue and sell in a private placement (the “Private Placement”) an aggregate of 4,374,454 of CSI Compressco LP Series A Convertible Preferred Units representing limited partner interests in CCLP (the “CCLP Preferred Units”) for a cash purchase price of $11.43 per CCLP Preferred Unit (the “Issue Price”), resulting in total net proceeds to CCLP, after deducting certain offering expenses, of $49.8 million. We purchased 874,891 of the CCLP Preferred Units at the Issue Price, aggregating $10.0 million. The CCLP Preferred Units, net of the units we purchased, will be classified as long-term liabilities in our consolidated balance sheet. The net proceeds from the Private Placement will be used to pay additional offering expenses and reduce outstanding CCLP indebtedness under the CCLP Credit Agreement or the CCLP 7.25% Senior Notes.

Pursuant to the Unit Purchase Agreement, in connection with the closing, CSI Compressco GP Inc (our wholly owned subsidiary) executed a Second Amended and Restated Agreement of Limited Partnership of CCLP (the “Amended and Restated CCLP Partnership Agreement”) to, among other things, authorize and establish the rights and preferences of the CCLP Preferred Units. The CCLP Preferred Units are a new class of equity security that will rank senior to all classes or series of equity securities of CCLP with respect to distribution rights and rights upon liquidation. We and the other holders of CCLP Preferred Units (each, a “CCLP Preferred Unitholder”) will receive quarterly distributions, which will be paid in kind in additional CCLP Preferred Units, equal to an annual rate of 11.00% of the Issue Price ($1.2573 per unit annualized), subject to certain adjustments. The rights of the CCLP Preferred Units include certain anti-dilution adjustments, including adjustments for economic dilution resulting from the issuance of common units in the future below a set price.

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A ratable portion of the CCLP Preferred Units will be converted each month over a period of thirty months beginning in the seventh calendar month following the closing (each, a “Conversion Date”), subject to certain provisions of the Amended and Restated CCLP Partnership Agreement that may delay or accelerate all or a portion of such monthly conversions. On each Conversion Date, the CCLP Preferred Units will convert into common units representing limited partner interests in CCLP in an amount equal to, with respect to each CCLP Preferred Unitholder, the number of CCLP Preferred Units held by such CCLP Preferred Unitholder divided by the number of Conversion Dates remaining, subject to adjustment described in the Amended and Restated CCLP Partnership Agreement, with the conversion price determined by a the trading prices of the common units over the previous month, among other factors, and as otherwise impacted by the existence of certain conditions related to the common units. CCLP may, at its option, pay cash, or a combination of cash and common units, to the CCLP Preferred Unitholders instead of issuing common units on any Conversion Date, subject to certain restrictions as described in the Amended and Restated CCLP Partnership Agreement and the CCLP Credit Agreement.

In addition, each Purchaser may convert its CCLP Preferred Units, generally on a one-for-one basis and subject to adjustment for certain splits, combinations, reclassifications or other similar transactions and certain anti-dilution adjustments, in whole or in part, at any time following May 31, 2017 so long as any conversion is not for less than $250,000 or such lesser amount, if such conversion relates to all of such Purchaser’s remaining CCLP Preferred Units. CCLP has the right to be reimbursed for any cash distributions paid with respect to common units issued in any such optional conversion until March 31, 2018. The CCLP Preferred Units will vote on an as-converted basis with the common units and will have certain other rights to vote as a class with respect to any amendment to the Amended and Restated CCLP Partnership Agreement that would affect any rights, preferences or privileges of the CCLP Preferred Units, as more fully described in the Amended and Restated CCLP Partnership Agreement.

In addition, the CCLP Preferred Unit Purchase Agreement includes certain provisions regarding change of control, transfer of CCLP Preferred Units, indemnities, and other matters described in detail in the CCLP Preferred Unit Purchase Agreement. In connection with the closing, CCLP agreed to pay a transaction fee of $1.2 million to its financial advisor for this transaction. The CCLP Preferred Unit Purchase Agreement contains customary representations, warranties and covenants of CCLP and the Purchasers.

On August 8, 2016, in connection with the closing, CCLP entered into a Registration Rights Agreement (the “Registration Rights Agreement”) with the Purchasers relating to the registered resale of the common units issuable upon conversion of the CCLP Preferred Units, including any CCLP Preferred Units issued in kind pursuant to the terms of the Amended and Restated CCLP Partnership Agreement. Pursuant to the Registration Rights Agreement, CCLP is required to file or cause to be filed a registration statement for such registered resale at its expense no later than 90 days after the closing and is required to cause the registration statement to become effective no later than 180 days after the closing, subject to certain liquidated damages set forth in the Registration Rights Agreement if such obligations are not met.

CCLP 7.25% Senior Notes Purchase Agreement. On August 8, 2016, in connection with the closing of the Private Placement for CCLP Preferred Units, CCLP entered into a CCLP Note Repurchase Agreement pursuant to which it agreed to repurchase up to $20.0 million of its 7.25% Senior Notes. For further discussion of this CCLP Note Repurchase Agreement, see Note B - Long-Term Debt.

NOTE D – DECOMMISSIONING AND OTHER ASSET RETIREMENT OBLIGATIONS

The large majority of our asset retirement obligations consists of the remaining future well abandonment and decommissioning costs for offshore oil and gas properties and platforms owned by our Maritech subsidiary, including the decommissioning and debris removal costs associated with its remaining offshore platforms previously destroyed by hurricanes. The amount of decommissioning liabilities recorded by Maritech is reduced by amounts allocable to joint interest owners in these properties and platforms.

We also operate facilities in various U.S. and foreign locations that are used in the manufacture, storage, and sale of our products, inventories, and equipment. These facilities are a combination of owned and leased assets. The values of our asset retirement obligations for these non-Maritech properties were $9.5 million and $9.1 million as of June 30, 2016 and December 31, 2015, respectively. We are required to take certain actions in connection with the retirement of these assets. We have reviewed our obligations in this regard in detail and estimated the cost of these actions. The original estimates are the fair values that have been recorded for retiring

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these long-lived assets. The associated asset retirement costs are capitalized as part of the carrying amount of these long-lived assets. The costs for non-oil and gas assets are depreciated on a straight-line basis over the life of the assets.

The changes in the values of our asset retirement obligations during the three and six month period ended June 30, 2016, are as follows:

	Three Months Ended June 30, 2016			Six Months Ended June 30, 2016
	(In Thousands)
Beginning balance for the period, as reported	$	54,591		$	57,449
Activity in the period:
Accretion of liability	404			806
Retirement obligations incurred	—			—
Revisions in estimated cash flows	92			213
Settlement of retirement obligations	(64		)	(3,445		)
Ending balance	$	55,023		$	55,023

We review the adequacy of our asset retirement obligation liabilities whenever indicators suggest that the estimated cash flows underlying the liabilities have changed. For our Maritech segment, the timing and amounts of these cash flows are subject to changes in the oil and gas industry environment and other factors and may result in additional liabilities and charges to earnings to be recorded.

Asset retirement obligations are recorded in accordance with FASB ASC 410, Asset Retirement and Environmental Obligations, whereby the estimated fair value of a liability for asset retirement obligations be recorded in the period in which it is incurred and in which a reasonable estimate can be made. Such estimates are based on relevant assumptions that we believe are reasonable. The cost estimates for our Maritech asset retirement obligations are considered reasonable estimates consistent with current market conditions, and we believe reflect the amount of work legally obligated to be performed in accordance with Bureau of Safety and Environmental Enforcement ("BSEE") standards, as revised from time to time.

NOTE E – MARKET RISKS AND DERIVATIVE CONTRACTS

We are exposed to financial and market risks that affect our businesses. We have concentrations of credit risk as a result of trade receivables owed to us by companies in the energy industry. We have currency exchange rate risk exposure related to transactions denominated in foreign currencies as well as to investments in certain of our international operations. As a result of our variable rate bank credit facilities,including the variable rate credit facility of CCLP, we face market risk exposure related to changes in applicable interest rates. Our financial risk management activities may at times involve, among other measures, the use of derivative financial instruments, such as swap and collar agreements, to hedge the impact of market price risk exposures.

Derivative Contracts

Foreign Currency Derivative Contracts. We and CCLP enter into 30-day foreign currency forward derivative contracts as part of a program designed to mitigate the currency exchange rate risk exposure on selected transactions of certain foreign subsidiaries. As of June 30, 2016, we and CCLP had the following foreign currency derivative contracts outstanding relating to portions of our foreign operations:

Derivative Contracts	US Dollar Notional Amount		Traded Exchange Rate	Settlement Date
	(In Thousands)
Forward purchase Euro	$	7,415	1.13	7/18/2016
Forward purchase pounds sterling	6,980		1.42	7/18/2016
Forward sale Mexican peso	6,990		19.03	7/18/2016
Forward sale Norwegian krone	1,759		8.36	7/18/2016
Forward purchase Mexican peso	2,943		19.03	7/18/2016

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Under this program, we and CCLP may enter into similar derivative contracts from time to time. Although contracts pursuant to this program will serve as an economic hedge of the cash flow of our currency exchange risk exposure, they are not formally designated as hedge contracts or qualify for hedge accounting treatment. Accordingly, any change in the fair value of these derivative instruments during a period will be included in the determination of earnings for that period.

The fair value of foreign currency derivative instruments are based on quoted market values as reported to us by our counterparty (a level 2 fair value measurement). The fair values of our and CCLP's foreign currency derivative instruments as of June 30, 2016 and December 31, 2015, are as follows:

Foreign currency derivative instruments	Balance Sheet Location	Fair Value at June 30, 2016			Fair Value at December 31, 2015
		(In Thousands)
Forward sale contracts	Current assets	$	271		$	23
Forward purchase contracts	Current assets	—			—
Forward sale contracts	Current liabilities	(111		)	(31		)
Forward purchase contracts	Current liabilities	(634		)	(354		)
Net asset (liability)		$	(474	)	$	(362	)

None of the foreign currency derivative contracts contain credit risk related contingent features that would require us to post assets or collateral for contracts that are classified as liabilities. During the three and six month periods ended June 30, 2016, we recognized $1.1 million and $1.2 million of net losses, respectively, reflected in other income (expense) associated with our foreign currency derivative program. During the three and six month periods ended June 30, 2015, we recognized $0.2 million and $(0.3) million, of net losses and gains, respectively, reflected in other income (expense) associated with this program.

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NOTE F – EQUITY

Changes in equity for the three and six month periods ended June 30, 2016 and 2015 are as follows:

	Three Months Ended June 30,
	2016									2015
	TETRA			Non- controlling Interest			Total			TETRA			Non- controlling Interest			Total
	(In Thousands)
Beginning balance for the period	$	155,621		$	206,476		$	362,097		$	357,723		$	386,872		$	744,595
Net income (loss)	(26,574		)	(2,650		)	(29,224		)	14,925			442			15,367
Foreign currency translation adjustment	(3,305		)	(62		)	(3,367		)	2,541			(183		)	2,358
Comprehensive Income (loss)	(29,879		)	(2,712		)	(32,591		)	17,466			259			17,725
Exercise of common stock options	2			—			2			(183		)	—			(183		)
Proceeds from the issuance of stock	60,277			—			60,277			—			—			—
Distributions to public unitholders	—			(7,209		)	(7,209		)	—			(9,450		)	(9,450		)
Equity-based compensation	5,801			844			6,645			1,874			727			2,601
Treasury stock and other	(1,373		)	(64		)	(1,437		)	(244		)	—			(244		)
Ending balance as of June 30	$	190,449		$	197,335		$	387,784		$	376,636		$	378,408		$	755,044

	Six Months Ended June 30,
	2016									2015
	TETRA			Non- controlling Interest			Total			TETRA			Non- controlling Interest			Total
	(In Thousands)
Beginning balance for the period	$	241,217		$	272,963		$	514,180		$	369,713		$	395,888		$	765,601
Net income (loss)	(114,899		)	(62,056		)	(176,955		)	10,477			1,266			11,743
Foreign currency translation adjustment	(2,333		)	(516		)	(2,849		)	(6,202		)	(1,227		)	(7,429		)
Comprehensive Income (loss)	(117,232		)	(62,572		)	(179,804		)	4,275			39			4,314
Exercise of common stock options	27						27			101			—			101
Proceeds from the issuance of stock	60,277						60,277			—			—			—
Distributions to public unitholders	—			(14,418		)	(14,418		)	—			(18,723		)	(18,723		)
Equity-based compensation	7,539			1,462			9,001			2,993			1,204			4,197
Treasury stock and other	(1,379		)	(100		)	(1,479		)	(244		)	—			(244		)
Tax adjustment upon cancellation of stock options	—			—			—			(202		)	—			(202		)
Ending balance as of June 30	$	190,449		$	197,335		$	387,784		$	376,636		$	378,408		$	755,044

Activity within the foreign currency translation adjustment account during the periods includes no reclassifications to net income.

Issuance of Common Stock.On June 21, 2016, we completed an underwritten public offering of 11.5 million shares of our common stock, which included 1.5 million shares of common stock pursuant to an option granted to the underwriters to purchase additional shares, at a price to the public of $5.50 per share ($5.2525 per share net of underwriting discounts). We utilized the net offering proceeds of $60.4 million to repay the remaining balance outstanding of our Senior Secured Notes, to reduce the balance outstanding under our Credit Agreement, to pay offering related discounts and expenses, and for general corporate purposes. The offering was made pursuant to a shelf registration statement filed with the Securities and Exchange Commission on March 23, 2016.

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Issuance of CCLP Preferred Units. In August 2016, CCLP received $49.8 million of net proceeds, after deducting certain offering expenses, from the Private Placement of the CCLP Preferred Units. (For further discussion of the issuance of CCLP Preferred Units, see Note C - CCLP Series A Convertible Preferred Units.)

NOTE G – COMMITMENTS AND CONTINGENCIES

Litigation

We are named defendants in several lawsuits and respondents in certain governmental proceedings arising in the ordinary course of business. While the outcome of lawsuits or other proceedings against us cannot be predicted with certainty, management does not consider it reasonably possible that a loss resulting from such lawsuits or other proceedings in excess of any amounts accrued has been incurred that is expected to have a material adverse impact on our financial condition, results of operations, or liquidity.

Environmental

One of our subsidiaries, TETRA Micronutrients, Inc. ("TMI"), previously owned and operated a production facility located in Fairbury, Nebraska. TMI is subject to an Administrative Order on Consent issued to American Microtrace, Inc. (n/k/a/ TETRA Micronutrients, Inc.) in the proceeding styledIn the Matter of American Microtrace Corporation, EPA I.D. No. NED00610550, Respondent, Docket No. VII-98-H-0016, dated September 25, 1998 (the "Consent Order"), with regard to the Fairbury facility. TMI is liable for ongoing environmental monitoring at the Fairbury facility under the Consent Order; however, the current owner of the Fairbury facility is responsible for costs associated with the closure of that facility. While the outcome cannot be predicted with certainty, management does not consider it reasonably possible that a loss in excess of any amounts accrued has been incurred or is expected to have a material adverse impact on our financial condition, results of operations, or liquidity.

Other Contingencies

During 2011, in connection with the sale of a significant majority of Maritech’s oil and gas producing properties, the buyers of the properties assumed the associated decommissioning liabilities pursuant to the purchase and sale agreements. For those oil and gas properties Maritech previously operated, the buyers of the properties assumed the financial responsibilities associated with the properties' operations, including abandonment and decommissioning, and generally became the successor operator. Some buyers of these Maritech properties subsequently sold certain of these properties to other buyers who also assumed these financial responsibilities associated with the properties' operations, and these buyers also typically became the successor operator of the properties. To the extent that a buyer of these properties fails to perform the abandonment and decommissioning work required, the previous owner, including Maritech, may be required to perform the abandonment and decommissioning obligation. A significant portion of the decommissioning liabilities that were assumed by the buyers of the Maritech properties in 2011 remains unperformed and we believe the amounts of these remaining liabilities are significant. We monitor the financial condition of the buyers of these properties from Maritech, and if current oil and natural gas pricing levels continue, we expect that one or more of these buyers may be unable to perform the decommissioning work required on the properties acquired from Maritech.

During the six months ended June 30, 2016, continued low oil and natural gas prices have resulted in reduced revenues and cash flows for all oil and gas producing companies, including those companies that bought Maritech properties in the past. Certain of these oil and gas producing companies that bought Maritech properties are currently experiencing severe financial difficulties. With regard to certain of these properties, Maritech has security in the form of bonds or cash escrows intended to secure the buyers' obligations to perform the decommissioning work. One company that bought, and subsequently sold, Maritech properties filed for Chapter 11 bankruptcy protection in August 2015. Maritech and its legal counsel continue to monitor the status of these companies. As of June 30, 2016, we do not consider the likelihood of Maritech becoming liable for decommissioning liabilities on sold properties to be probable.

Maritech has encountered situations where previously plugged and abandoned wells on its properties have later exhibited a buildup of pressure, which is evidenced by gas bubbles coming from the plugged well head. We refer to this situation as “wells under pressure” and this can either be discovered when performing additional work at the property or by notification from a third party. Wells under pressure require Maritech to return to the site to perform additional plug and abandonment procedures that were not originally anticipated and included in the estimate of the asset retirement obligation for such property. Remediation work at previously abandoned well sites

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is particularly costly, due to the lack of a platform from which to base these activities. Maritech is the last operator of record for its plugged wells, and bears the risk of additional future work required as a result of wells becoming pressurized in the future.

NOTE H – INDUSTRY SEGMENTS

We manage our operations through five reporting segments organized into four divisions: Fluids, Production Testing, Compression, and Offshore.

Our Fluids Division manufactures and markets clear brine fluids, additives, and associated products and services to the oil and gas industry for use in well drilling, completion, and workover operations in the United States and in certain countries in Latin America, Europe, Asia, the Middle East, and Africa. The division also markets liquid and dry calcium chloride products manufactured at its production facilities or purchased from third-party suppliers to a variety of markets outside the energy industry.The Fluids Division also provides domestic onshore oil and gas operators with comprehensive water management services.

Our Production Testing Division provides frac flowback, production well testing, offshore rig cooling, and other associated services in many of the major oil and gas producing regions in the United States, Mexico, and Canada, as well as in basins in certain regions in South America, Africa, Europe, the Middle East, and Australia.

The Compression Division is a provider of compression services and equipment for natural gas and oil production, gathering, transportation, processing, and storage. The Compression Division's equipment sales business includes the fabrication and sale of standard compressor packages, custom-designed compressor packages, and oilfield pump systems designed and fabricated at the division's facilities. The Compression Division's aftermarket services business provides compressor package reconfiguration and maintenance services as well as providing compressor package parts and components manufactured by third-party suppliers. The Compression Division provides its services and equipment to a broad base of natural gas and oil exploration and production, midstream, transmission, and storage companies operating throughout many of the onshore producing regions of the United States as well as in a number of foreign countries, including Mexico, Canada, and Argentina.

Our Offshore Division consists of two operating segments: Offshore Services and Maritech. The Offshore Services segment provides (1) downhole and subsea services such as well plugging and abandonment and workover services, (2) decommissioning and certain construction services utilizing heavy lift barges and various cutting technologies with regard to offshore oil and gas production platforms and pipelines, and (3) conventional and saturation diving services.

The Maritech segment is a limited oil and gas production operation. During 2011 and the first quarter of 2012, Maritech sold substantially all of its oil and gas producing property interests. Maritech’s operations consist primarily of the ongoing abandonment and decommissioning associated with its remaining offshore wells and production platforms. Maritech intends to acquire a portion of these services from the Offshore Services segment.

We generally evaluate the performance of and allocate resources to our segments based on profit or loss from their operations before income taxes and nonrecurring charges, return on investment, and other criteria. Transfers between segments and geographic areas are priced at the estimated fair value of the products or services as negotiated between the operating units. “Corporate overhead” includes corporate general and administrative expenses, corporate depreciation and amortization, interest income and expense, and other income and expense.

 Summarized financial information concerning the business segments is as follows:

	Three Months Ended   June 30,				Six Months Ended   June 30,
	2016		2015		2016		2015
	(In Thousands)
Revenues from external customers
Product sales
Fluids Division	$	50,156	$	99,930	$	92,487	$	164,924
Production Testing Division	—		—		—		—

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	Three Months Ended   June 30,						Six Months Ended   June 30,
	2016			2015			2016			2015
	(In Thousands)
Compression Division	14,042			48,968			29,203			67,119
Offshore Division
Offshore Services	—			360			116			595
Maritech	248			394			337			1,900
Total Offshore Division	248			754			453			2,495
Consolidated	$	64,446		$	149,652		$	122,143		$	234,538
Services and rentals
Fluids Division	$	10,677		$	23,026		27,374			$	57,308
Production Testing Division	12,362			33,692			31,156			69,601
Compression Division	62,049			77,487			128,583			162,225
Offshore Division
Offshore Services	26,119			35,371			36,249			46,919
Maritech	—			—			—			—
Intersegment eliminations	7			(2,909		)	(516		)	(3,180		)
Total Offshore Division	26,126			32,462			35,733			43,739
Consolidated	$	111,214		$	166,667		$	222,846		$	332,873
Interdivision revenues
Fluids Division	$	—		$	18		$	85		$	31
Production Testing Division	1,022			1,150			2,099			2,342
Compression Division	—			—			—			—
Offshore Division
Offshore Services	—			—			—			—
Maritech	—			—			—			—
Intersegment eliminations	—			—			—			—
Total Offshore Division	—			—			—			—
Interdivision eliminations	(1,022		)	(1,168		)	(2,184		)	(2,373		)
Consolidated	$	—		$	—		$	—		$	—
Total revenues
Fluids Division	$	60,833		$	122,974		$	119,946		$	222,263
Production Testing Division	13,384			34,842			33,255			71,943
Compression Division	76,091			126,455			157,786			229,344
Offshore Division
Offshore Services	26,119			35,731			36,365			47,514
Maritech	248			394			337			1,900
Intersegment eliminations	7			(2,909		)	(516		)	(3,180		)
Total Offshore Division	26,374			33,216			36,186			46,234
Interdivision eliminations	(1,022		)	(1,168		)	(2,184		)	(2,373		)
Consolidated	$	175,660		$	316,319		$	344,989		$	567,411

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	Three Months Ended   June 30,						Six Months Ended   June 30,
	2016			2015			2016			2015
	(In Thousands)
Income (loss) before taxes
Fluids Division	$	454		$	32,583		$	96		$	50,320
Production Testing Division	(4,328		)	(472		)	(23,702		)	(433		)
Compression Division	(4,040		)	1,498			(108,740		)	3,904
Offshore Division
Offshore Services	37			2,095			(7,671		)	(6,553		)
Maritech	(3,401		)	(313		)	(4,021		)	662
Intersegment eliminations	—			—			—			—
Total Offshore Division	(3,364		)	1,782			(11,692		)	(5,891		)
Interdivision eliminations	3			(12		)	7			(10		)
Corporate Overhead(1)	(16,179		)	(17,271		)	(32,563		)	(31,837		)
Consolidated	$	(27,454	)	$	18,108		$	(176,594	)	$	16,053

	June 30,
	2016			2015
	(In Thousands)
Total assets
Fluids Division	$	331,912		$	408,144
Production Testing Division	101,647			208,929
Compression Division	863,572			1,261,051
Offshore Division
Offshore Services	121,061			134,422
Maritech	3,543			27,267
Total Offshore Division	124,604			161,689
Corporate Overhead and eliminations	(35,312		)	(36,168		)
Consolidated	$	1,386,423		$	2,003,645

(1) Amounts reflected include the following general corporate expenses:

	Three Months Ended   June 30,				Six Months Ended   June 30,
	2016		2015		2016		2015
	(In Thousands)
General and administrative expense	$	8,021	$	11,688	$	17,950	$	20,537
Depreciation and amortization	112		254		226		512
Interest expense	5,596		4,415		11,647		9,412
Other general corporate expense, net	2,450		914		2,740		1,376
Total	$	16,179	$	17,271	$	32,563	$	31,837

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

The following discussion and analysis of financial condition and results of operations should be read in conjunction with our unaudited consolidated financial statements and accompanying notes included in this Quarterly Report.In addition, the following discussion and analysis also should be read in conjunction with our Annual Report on Form 10-K for the year ended December 31, 2015 filed with the SEC on March 4, 2016. This discussion includes forward-looking statements that involve certain risks and uncertainties.

Business Overview  

In response to the continuing current oil and gas industry environment and the diminished demand for many of our products and services, we and our CSI Compressco LP subsidiary ("CCLP") have taken several steps to reduce costs and preserve liquidity. Our consolidated results of operations during the three months ended June 30, 2016 continue to reflect the challenges experienced by each of our businesses and they also reflect the aggressive reductions in operating and administrative costs we and CCLP have made through headcount reductions, salary reductions, work week reductions, suspension of matching contribution under the 401(k) retirement plan, and other cost reduction efforts designed to partially mitigate the impact of decreased revenues. We also continue to negotiate with our suppliers and service providers to reduce costs in the current environment. Growth and maintenance capital expenditure levels continue to be significantly reduced for each of our businesses, as we are conserving cash in the current environment until such reductions are no longer justified by expected future activity levels. Significant steps have been taken to strengthen our consolidated balance sheet, maximize liquidity, and enhance our compliance with debt financial covenants. These efforts included (i) entering into amendments to our revolving bank credit facility, our Note Purchase Agreement dated November 5, 2015, and the revolving bank credit facility for CCLP; (ii) tender offers to retire $100 million principal amount of certain of our outstanding senior notes; (iii) our issuance of common equity for proceeds used to retire indebtedness; and (iv) the issuance by CCLP of preferred units for proceeds used to retire CCLP indebtedness. Following these transactions, our earliest scheduled maturity of long-term debt is in September 2019 and CCLP's earliest scheduled maturity of long-term debt is in August 2019. We and CCLP believe that each of the cost reduction and capital structuring measures taken enhances our respective abilities to continue to remain fiscally responsible for the uncertain duration of the current operating environment, and position each of us to capitalize on growth opportunities as industry conditions improve. We and CCLP will, as applicable, consider certain additional debt and/or equity financing transactions with a view of generating additional cash to reduce the amounts of our outstanding borrowings under our respective credit agreements, repay or refinance additional amounts of our 11% Senior Notes due November 5, 2022 (the "11% Senior Notes"), and generate additional liquidity.     

Our consolidated results of operations during the three months ended June 30, 2016 continue to reflect the challenges experienced by each of our businesses in the current oil and gas services environment. Decreased demand for most of our products and services reflects the industry-wide reduction in drilling and completion activity which has resulted in decreased revenues for each of our segments during the current year period compared to the corresponding prior year period. The 44.5% decrease in consolidated revenues during the current year quarter compared to the prior year quarter reflects both the decrease in activity and the competitive pricing pressures experienced by the majority of our businesses in each of their operating regions. Consolidated gross profit decreased 76.7%, despite cost reduction measures taken by each of our businesses, largely due to the benefit during the prior year period from a customer project associated with a completion fluids technology that was introduced during 2015. The impact from decreased consolidated cash provided from operating activities during the current year period compared to the prior year period was more than offset by decreased capital expenditure activity for these periods. We continue to consider additional cost reductions as well as maintaining our efforts to manage working capital, particularly in the collection of customer receivables. We also continue to monitor the evolving financial condition of many of our customers during this current downturn, balancing the benefits of generating operating cash flows with the risk of exposing our businesses to additional credit risk exposure.

We do not analyze or manage our capital structure on a consolidated basis, as there are no cross default provisions, cross collateralization provisions, or cross guarantees between CCLP's long-term debt and TETRA's long-term debt. Approximately $569.2 million of our consolidated debt balance is owed by CCLP, and is to be serviced by CCLP's existing cash balances and cash provided by CCLP's operations (less its capital expenditures) and is secured by the assets of CCLP.

The following table provides condensed consolidating balance sheet information reflecting our net assets and CCLP's net assets that service and secure our and CCLP's respective capital structures.

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	June 30, 2016
Condensed Consolidating Balance Sheet	TETRA		CCLP		Eliminations			Consolidated
	(In Thousands)
Cash, excluding restricted cash	$	7,226	$	16,691	$	—		$	23,917
Affiliate receivables	5,423		—		(5,423		)	—
Other current assets	171,737		92,016		—			263,753
Property, plant and equipment, net	325,274		674,895		—			1,000,169
Other assets, including investment in CCLP	59,211		39,123		250			98,584
Total assets	$	568,871	$	822,725	$	(5,173	)	$	1,386,423
Affiliate payables	$	—	$	5,423	$	(5,423	)	$	—
Other current liabilities	81,496		49,934		—			131,430
Long-term debt, net	219,050		569,172		—			788,222
Other non-current liabilities	77,876		1,111		—			78,987
Total equity	190,449		197,085		250			387,784
Total liabilities and equity	$	568,871	$	822,725	$	(5,173	)	$	1,386,423

TETRA’s debt is serviced by its existing cash balances and cash provided from operating activities (excluding CCLP) and the distributions received from CCLP in excess of cash capital expenditures (excluding CCLP). During the six months ended June 30, 2016, consolidated cash provided from operating activities was $33.6 million, which included $35.6 million generated by CCLP. Our cash provided from operating activities is reduced by the amount we spent on Maritech decommissioning liabilities, which was $3.4 million during the six months ended June 30, 2016. In addition, during the first six months of 2016 we received $11.2 million from CCLP as our share of CCLP distributions. 

Our consolidated operating cash flows during the six months ended June 30, 2016 decreased by $48.6 million, or 59.1%, compared to the corresponding prior year period. Partially offsetting the decrease in revenues and earnings, our consolidated operating cash flows reflect the impact of the fiscal management steps noted above, including a focus on timely collection of accounts receivable and other steps to manage working capital. Consolidated capital expenditures were $9.0 million during the six months ended June 30, 2016, and included $3.8 million of capital expenditures by our Compression Division, compared to $73.3 million of consolidated capital expenditures during the corresponding prior year period, including $57.1 million by our Compression Division. Our lower capital expenditure levels reflect our efforts to defer or reduce capital expenditure projects in the current market environment. Key objectives associated with our separate capital structure (excluding the capital structure of CCLP) include the ongoing management of amounts outstanding and available under our bank revolving credit facility and repayment of our 11% Senior Notes. CCLP also continues to monitor its 2016 capital expenditure program, in light of current low demand levels for its compression products and services in the current environment, minimizing borrowings under its revolving bank credit facility (the "CCLP Credit Agreement"). TETRA's future consolidated operating cash flows are also affected by the continuing challenges associated with extinguishing the remaining Maritech asset retirement obligations. The amount of recorded liability for these remaining obligations is approximately $45.6 million as of June 30, 2016. Approximately $3.3 million of this amount is expected to be performed during the twelve month period ending June 30, 2017, with the timing of a portion of this work being discretionary.

Critical Accounting Policies

There have been no material changes or developments in the evaluation of the accounting estimates and the underlying assumptions or methodologies pertaining to our Critical Accounting Policies and Estimates disclosed in our Form 10-K for the year ended December 31, 2015, except as discussed below. In preparing our consolidated financial statements, we make assumptions, estimates, and judgments that affect the amounts reported. We base these estimates on historical experience, available information, and various other assumptions that we believe are reasonable.We periodically evaluate these estimates and judgments, including those related to potential impairments of long-lived assets (including goodwill), the collectability of accounts receivable, and the current cost of future abandonment and decommissioning obligations. The fair values of portions of our total assets and liabilities are measured using significant unobservable inputs. The combination of these factors forms the basis for judgments made about the carrying values of assets and liabilities that are not readily apparent from other sources.

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These judgments and estimates may change as new events occur, as new information is acquired, and as changes in our operating environments are encountered. Actual results are likely to differ from our current estimates, and those differences may be material.

Impairment of Long-Lived Assets

The determination of impairment of long-lived assets, including identified intangible assets, is conducted periodically whenever indicators of impairment are present. If such indicators are present, the determination of the amount of impairment is based on our judgments as to the future operating cash flows to be generated from these assets throughout their estimated useful lives. If an impairment of a long-lived asset is warranted, we estimate the fair value of the asset based on a present value of these cash flows or the value that could be realized from disposing of the asset in a transaction between market participants. The oil and gas industry is cyclical, and our estimates of the amount of future cash flows, the period over which these estimated future cash flows will be generated, as well as the fair value of an impaired asset, are imprecise. Our failure to accurately estimate these future operating cash flows or fair values could result in certain long-lived assets being overstated, which could result in impairment charges in periods subsequent to the time in which the impairment indicators were first present. Alternatively, if our estimates of future operating cash flows or fair values are understated, impairments might be recognized unnecessarily or in excess of the appropriate amounts. During the first six months of 2016, primarily as a result of the significant decrease in oil and natural gas prices, we recorded consolidated long-lived asset impairments of $10.9 million. During periods of economic uncertainty, the likelihood of additional material impairments of long-lived assets is higher due to the possibility of decreased demand for our products and services.

Impairment of Goodwill

The impairment of goodwill is also assessed whenever impairment indicators are present, but not less than once annually.The assessment for goodwill impairment begins with a qualitative assessment of whether it is “more likely than not” that the fair value of each reporting unit is less than its carrying value. This qualitative assessment requires the evaluation, based on the weight of evidence, of the significance of all identified events and circumstances for each reporting unit. Due to the decrease in the price of our common stock and the price per common unit of CCLP during the first three months of 2016, our and CCLP's market capitalizations as of March 31, 2016, were below their respective recorded net book values, including all goodwill. In addition, the continuing low oil and natural gas commodity prices have resulted in a further negative impact on demand for the products and services for each of our reporting units. As a result of these factors, we determined that it was “more likely than not” that the fair values of certain of our reporting units were less than their respective carrying values as of March 31, 2016. When the qualitative analysis indicates that it is “more likely than not” that a reporting unit’s fair value is less than its carrying value, the resulting goodwill impairment test consists of a two-step accounting test performed on a reporting unit basis.The first step of the impairment test is to compare the estimated fair value with the recorded net book value (including goodwill) of our reporting units. If the estimated fair value is higher than the recorded net book value, no impairment is deemed to exist and no further testing is required. If, however, the carrying amount of the reporting unit exceeds its estimated fair value, an impairment loss is calculated by comparing the carrying amount of the reporting unit’s goodwill to our estimated implied fair value of that goodwill. Our estimates of reporting unit fair value, if required,are based on a combination of an income and market approach. These estimates are imprecise and are subject to our estimates of the future cash flows of each business and our judgment as to how these estimated cash flows translate into each business’ estimated fair value. These estimates and judgments are affected by numerous factors, including the general economic environment at the time of our assessment, which affects our overall market capitalization. If we overestimate the fair value of our reporting units, the balance of our goodwill asset may be overstated. Alternatively, if our estimated reporting unit fair values are understated, impairments might be recognized unnecessarily or in excess of the appropriate amounts.

Throughout 2015, and continuing during the first six months of 2016, lower oil and natural gas commodity prices have resulted in a decreased demand for many of the products and services of each of our reporting units. With regard to our Compression Division, demand for low-horsepower wellhead compression services and for sales of compressor equipment decreased significantly and are expected to continue to be decreased for the foreseeable future. Accordingly, the fair value for the Compression Division reporting unit, including the market capitalization for CCLP, was less than its carrying value as of March 31, 2016. For our Production Testing Division reporting unit, demand for production testing services decreased in each of the market areas in which we operate, resulting in decreased estimated future cash flows. As a result, the fair value of the Production Testing reporting unit was also less than its carrying value as of March 31, 2016. As part of our internal annual business outlook for each of our

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reporting units that we performed during the fourth quarter of 2015, we considered changes in the global economic environment that affected the equity prices and market capitalizations of TETRA and CCLP. As part of the first step of goodwill impairment testing as of March 31, 2016, we updated our annual assessment of the future cash flows for each of our reporting units, applying expected long-term growth rates, discount rates, and terminal values that we consider reasonable for each reporting unit. Our Maritech and Offshore Services reporting units are excluded, because they do not contain goodwill. We calculated a present value of the respective cash flows for each of the other reporting units to arrive at an estimate of fair value under the income approach and then used the market approach to corroborate these values. Based on these assumptions, we determined that the fair value of our Fluids Division was significantly in excess of its carrying value, which includes $6.6 million of goodwill as of March 31, 2016 and June 30, 2016.

After making the hypothetical purchase price adjustments as part of the second step of the goodwill impairment test, there was $0.0 million residual purchase price to be allocated to the goodwill of both the Compression and the Production Testing reporting units as of March 31, 2016. Based on this analysis, we concluded that full impairments of the $92.4 million of recorded goodwill for Compression and $13.9 million of recorded goodwill for Production Testing were required as of March 31, 2016.

Results of Operations

Three months ended June 30, 2016 compared with three months ended June 30, 2015.

Consolidated Comparisons

	Three Months Ended   June 30,						Period to Period Change
	2016			2015			2016 vs 2015			% Change
	(In Thousands, Except Percentages)
Revenues	$	175,660		$	316,319		$	(140,659	)	(44.5	)%
Gross profit	16,272			69,861			(53,589		)	(76.7	)%
Gross profit as a percentage of revenue	9.3		%	22.1		%
General and administrative expense	27,181			37,472			(10,291		)	(27.5	)%
General and administrative expense as a percentage of revenue	15.5		%	11.8		%
Interest expense, net	14,335			13,319			1,016			7.6	%
Other (income) expense, net	2,210			962			1,248
Income (loss) before taxes	(27,454		)	18,108			(45,562		)
Income (loss) before taxes as a percentage of revenue	(15.6		)%	5.7		%
Provision (benefit) for income taxes	1,770			2,741			(971		)
Net income (loss)	(29,224		)	15,367			(44,591		)
Net (income) loss attributable to noncontrolling interest	2,650			(442		)	3,092
Net income (loss) attributable to TETRA stockholders	$	(26,574	)	$	14,925		$	(41,499	)

Consolidated revenuesfor the current quarter decreased compared to the prior year quarter due to continuing overall industry market challenges as a result of lower oil and natural gas commodity prices compared to early 2015. Each of our segments reported decreased revenues due to the impact of reduced demand for our products and services. The Fluids Division reported the most significant reduction in revenues, with decreased water management services, manufactured product sales, and completion services and products combining for $62.1 million of decreased revenues. Our Compression and Production Testing Divisions each also reported significantly decreased revenues during the current year period, due to lower industry demand and activity levels in each of the domestic and international markets we serve. See Divisional Comparisons section below for additional discussion.

Consolidated gross profit decreased during the current year quarter compared to the prior year quarter due to the reduced demand for our products and services, as well as the impact of pricing pressures in each of our businesses. Our Fluids Division reported the most significant reduction in gross profit, due to the reasons noted above and due to the impact from offshore completion fluids products and services associated with the new fluid technology projects during the prior year quarter. Our Compression Division reported the highest gross profit during

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the current year period, despite the decreased demand, particularly for its low horsepower compression services and new compressor unit sales compared to the prior year quarter. The results of each of our businesses reflect the impact of additional company-wide salary reductions that were implemented during the current year period, which are expected to result in reduced operating expenses going forward. We continue to review the cost structure of each of our businesses for opportunities to further improve gross profit.

Consolidated general and administrative expenses decreased during the current year quartercompared to the prior year quarter, due to cost reduction efforts across all segments resulting in lower salary and employee related expenses. In addition, professional service expense and other general expenses were also decreased. Despite the cost reductions made during the current year period, consolidated general and administrative expense increased as a percentage of consolidated revenues due to the significant decrease in revenues.

Consolidated interest expense increased in the current year quarter compared to the prior year quarter due to the increased interest rate applicable to the 11% Senior Notes. In addition, Compression Division interest expense increased compared to the prior year quarter due to increased borrowings during early 2015 under the CCLP Credit Agreement. Interest expense during the current and prior year periods includes $1.0 million of finance cost amortization.

Consolidated other expense was $2.2 million during the current year quarter compared to $1.0 million during the prior year quarter, primarily due to $1.5 million of non-cash charges associated with the repayment of senior notes and senior secured notes.

Our consolidated provision for income taxes during the first six months of 2015 and 2016 is primarily attributable to taxes in certain foreign jurisdictions and Texas gross margin taxes. Our consolidated effective tax rate for the three month period ended June 30, 2016 of negative 6.4% was primarily the result of losses generated in entities for which no related tax benefit has been recorded. The losses generated by these entities do not result in tax benefits due to offsetting valuation allowances being recorded against the related net deferred tax assets. We establish a valuation allowance to reduce the deferred tax assets when it is more likely than not that some portion or all of the deferred tax assets will not be realized. Included in our deferred tax assets are net operating loss carryforwards and tax credits that are available to offset future income tax liabilities in the U.S. as well as in certain foreign jurisdictions.

Divisional Comparisons

Fluids Division

	Three Months Ended   June 30,						Period to Period Change
	2016			2015			2016 vs 2015			% Change
	(In Thousands, Except Percentages)
Revenues	$	60,833		$	122,974		$	(62,141	)	(50.5	)%
Gross profit	6,585			40,354			(33,769		)	(83.7	)%
Gross profit as a percentage of revenue	10.8		%	32.8		%
General and administrative expense	6,686			7,777			(1,091		)	(14.0	)%
General and administrative expense as a percentage of revenue	11.0		%	6.3		%
Interest (income) expense, net	2			(76		)	78
Other (income) expense, net	(557		)	70			(627		)
Income before taxes	$	454		$	32,583		$	(32,129	)	(98.6	)%
Income before taxes as a percentage of revenue	0.7		%	26.5		%

The decrease in Fluids Division revenues during the current year quarter compared to the prior year quarter was primarily due to $49.8 million of decreased product sales revenues, primarily due to decreased clear brine fluids ("CBF") and associated product sales revenues in the U.S. Gulf of Mexico, reflecting the decreased rig count activity compared to the prior year quarter and including decreased revenue resulting from a customer well completion project during the prior year quarter using a new completion fluid technology that was introduced during 2015. In addition, product sales revenues also decreased compared to the prior year quarter due to decreased domestic manufactured products sales revenues. Service revenues decreased$12.3 million, primarily due to

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reduced demand in the U.S. Gulf of Mexico for completion services as a result of a reduction in completion activity, including the impact from the prior year well completion project noted above. In addition, service revenues also decreased due to decreased water management services activity resulting from the impact of lower oil and natural gas commodity prices. We have begun to see an increased demand in the U.S. Gulf of Mexico for certain of our completion products and services for the second half of the year.

Fluids Division gross profit during the current year quarter decreased compared to the prior year quarter primarily due to decreased revenues and decreased profitability associated with the mix of CBF products and services, particularly for offshore completion fluids products and services associated with the new fluid technology projects during the prior year period. In addition, gross profit declined as a result of reduced demand for manufactured products during the current year quarter compared to the prior year quarter.

Fluids Division reported minimal pretax earnings during the current year quarter compared to significant pretax earnings during the prior year quarter primarily due to the decreased gross profit discussed above. Fluids Division administrative cost levels decreased compared to the prior year quarter, primarily due to $1.4 million of decreased salary and employee related expenses, partly offset by increased legal and professional fees. The Fluids Division continues to review opportunities to further reduce its administrative costs. Partially offsetting the decreased gross profit, other income increased primarily due to increased foreign currency gains.

Production Testing Division

	Three Months Ended   June 30,						Period to Period Change
	2016			2015			2016 vs 2015			% Change
	(In Thousands, Except Percentages)
Revenues	$	13,383		$	34,842		$	(21,459	)	(61.6	)%
Gross profit (loss)	(2,601		)	3,918			(6,519		)	(166.4	)%
Gross profit as a percentage of revenue	(19.4		)%	11.2		%
General and administrative expense	2,257			4,608			(2,351		)	(51.0	)%
General and administrative expense as a percentage of revenue	16.9		%	13.2		%
Interest (income) expense, net	(143		)	14			(157		)
Other (income) expense, net	(387		)	(232		)	(155		)
Loss before taxes	$	(4,328	)	$	(472	)	$	(3,856	)	816.9	%
Loss before taxes as a percentage of revenue	(32.3		)%	(1.4		)%

Production Testing Division revenues decreased significantly during the current year quarter compared to the prior year quarter due to reduced overall market activity. Production Testing service revenues decreased $21.5 million during the current year quarter compared to the prior year quarter, as the impact of lower oil and natural gas pricing has negatively impacted demand for services in each of the division's areas of operations, including certain shale reservoir markets that were a source of revenue growth prior to 2015. Decreased U.S. demand reflects the significant decrease in onshore rig count activity compared to the prior year quarter. In addition, increased competition for decreased market activity negatively affected pricing levels for services, particularly internationally.

Production Testing Division had a gross loss during the current year quarter compared to gross profit during the prior year quarter due to the decreased industry activity and increased competition as discussed above. This decrease and resulting gross loss occurred despite cost reduction efforts, which have included headcount reductions, salary reductions, and other steps to adjust the Production Testing Division's cost structure in light of current market conditions.

The Production Testing Division reported an increased pretax loss during the current year quarter compared to the prior year quarter, primarily due to the gross loss discussed above. General and administrative expenses decreased due to $1.2 million of decreased employee-related expenses, primarily from reduced headcount, salary reductions, and other employee related cost reductions, and $1.2 million of decreased bad debt and other general expenses. The division continues to review additional opportunities to further reduce its operating and administrative cost levels in light of current market conditions.

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Compression Division

	Three Months Ended   June 30,						Period to Period Change
	2016			2015			2016 vs 2015			% Change
	(In Thousands, Except Percentages)
Revenues	$	76,090		$	126,456		$	(50,366	)	(39.8	)%
Gross profit	13,727			21,150			(7,423		)	(35.1	)%
Gross profit as a percentage of revenue	18.0		%	16.7		%
General and administrative expense	8,190			10,531			(2,341		)	(22.2	)%
General and administrative expense as a percentage of revenue	10.8		%	8.3		%
Interest (income) expense, net	8,870			8,657			213
Other (income) expense, net	707			464			243
Income (loss) before taxes	$	(4,040	)	$	1,498		$	(5,538	)	(369.7	)%
Income (loss) before taxes as a percentage of revenue	(5.3		)%	1.2		%

Compression Division revenues decreased during the current year quarter compared to the prior year quarter, primarily due to decreased sales of compressors and parts. The $34.9 million decrease in compressor equipment and parts sales revenue was due to a lower number of customer projects compared to the prior year quarter, particularly for high-horsepower projects. The current reduced equipment fabrication backlog indicates that this decrease in compressor package sales revenues will continue going forward. Compression service revenues also decreased $15.4 million, primarily from the reduction in overall utilization in total horsepower as well as compression services pricing compared to the prior year quarter. The decreased overall utilization has affected each horsepower class of the Compression Division's service fleet, but has particularly decreased the demand for low-horsepower production enhancement compression services as a result of lower oil and natural gas commodity prices.

Compression Division gross profit decreased during the current year quarter compared to the prior year quarter as a result of the lower demand for compressors and compression services discussed above. Competitive pricing pressures and rate reduction requests in the current market environment have also resulted in reduced gross profit. During the second quarter of 2016, the Compression Division took additional steps to reduce its operating costs and improve operating efficiencies. The impact of these cost reduction efforts is expected to result in additional cost efficiencies in future periods.

The Compression Division recorded a pretax loss during the current year quarter compared to pretax earnings during the prior year quarter primarily due to the decreased gross profit discussed above. General and administrative expense levels decreased compared to the prior year period, mainly due to administrative cost and salary reductions.

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Offshore Division

Offshore Services Segment

	Three Months Ended   June 30,						Period to Period Change
	2016			2015			2016 vs 2015			% Change
	(In Thousands, Except Percentages)
Revenues	$	26,119		$	35,731		$	(9,612	)	(26.9	)%
Gross profit	1,767			4,690			(2,923		)	(62.3	)%
Gross profit as a percentage of revenue	6.8		%	13.1		%
General and administrative expense	1,734			2,579			(845		)	(32.8	)%
General and administrative expense as a percentage of revenue	6.6		%	7.2		%
Interest (income) expense, net	—			—			—
Other (income) expense, net	(3		)	16			(19		)
Income before taxes	$	36		$	2,095		$	(2,059	)	(98.3	)%
Income before taxes as a percentage of revenue	0.1		%	5.9		%

Revenues for the Offshore Services segment decreased during the current year quarter compared to the prior year quarter primarily due to reduced revenues from its well abandonment and diving services businesses, more than offsetting the increased revenues from heavy lift services. Decreased diving services and well abandonment activity levels in the U.S. Gulf of Mexico during the current quarter reflected an overall reduction in demand in this market, due to a postponement of certain well abandonment projects and increased competition. Given the current low oil and natural gas commodity price environment, Offshore Services anticipates continued low demand for its services for the foreseeable future. There was no Offshore Services work performed for our Maritech segment during the current year quarter, compared to $2.9 million of revenues during the prior year quarter. Revenues for work performed for Maritech, which are eliminated in consolidation, are expected to continue to be low in future periods.

Gross profit for the Offshore Services segment decreased during the current year quarter compared to the prior year quarter as the impact of the decreased activity levels for diving and well abandonment services discussed above more than offset the cost reduction measures and process efficiencies that have been implemented. The Offshore Services segment continues to consider additional opportunities to optimize its operating cost structure.

Offshore Services segment reported a decrease in pretax earnings before taxes during the current year quarter compared to the prior year quarter primarily due to the decreased gross profit discussed above that more than offset a reduction in general and administrative expenses. Administrative expenses decreased primarily from reduced salary and employee related expenses of $0.8 million and decreased professional services of $0.2 million. These decreases were offset by an increased provision of $0.2 million related to doubtful accounts. The Offshore Services segment continues to review its administrative cost structure for additional cost reductions and process efficiency actions in response to current market conditions.

Maritech Segment

	Three Months Ended   June 30,						Period to Period Change
	2016			2015			2016 vs 2015			% Change
	(In Thousands, Except Percentages)
Revenues	$	248		$	394		$	(146	)	(37.1	)%
Gross profit (loss)	(3,097		)	3			(3,100		)
General and administrative expense	293			290			3			1.0	%
General and administrative expense as a percentage of revenue	118.1		%	73.6		%
Interest (income) expense, net	10			26			(16		)
Other (income) expense, net	—			—			—
Loss before taxes	$	(3,400	)	$	(313	)	$	(3,087	)	986.3	%

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As a result of the sale of almost all of its producing properties during 2011 and 2012, Maritech revenues were negligible and are expected to continue to be negligible going forward. Revenue decreased during the current year quarter compared to the prior year quarter due to decreased production and commodity pricing.

Maritech reported a gross loss during the current year quarter compared to gross profit during the prior year quarter, primarily due to charges during the period for decommissioning costs incurred in prior periods no longer considered collectible from third parties.

Maritech reported an increased pretax loss during the current year quarter compared to the prior year period primarily due to the gross loss as discussed above.

Corporate Overhead

	Three Months Ended   June 30,						Period to Period Change
	2016			2015			2016 vs 2015			% Change
	(In Thousands, Except Percentages)
Gross profit (loss) (depreciation expense)	$	(112	)	$	(254	)	$	(142	)	(55.9	)%
General and administrative expense	8,021			11,688			(3,667		)	(31.4	)%
Interest (income) expense, net	5,596			4,697			899
Other (income) expense, net	2,450			632			1,818
Loss before taxes	$	(16,179	)	$	(17,271	)	$	1,092		6.3	%

Corporate Overhead pretax lossdecreased during the current year quarter compared to the prior year quarter, primarily due to decreased general and administrative expense. Corporate general and administrative expenses decreased due to $3.5 million of decreased salary and employee related expenses and $0.2 million of decreased professional service fees. Interest expense increased primarily due to the higher interest rate of the 11% Senior Notes that were issued in November 2015. Corporate other expenses increased compared to the prior year quarter due to $1.5 million of unamortized deferred finance costs that were charged to earnings pursuant to the repayment of senior notes and senior secured notes, as well as increased losses associated with foreign currency derivative instruments of $0.2 million.

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Results of Operations

Six months endedJune 30, 2016 compared with six months ended June 30, 2015.

Consolidated Comparisons

	Six Months Ended June 30,						Period to Period Change
	2016			2015			2016 vs 2015			% Change
	(In Thousands, Except Percentages)
Revenues	$	344,989		$	567,411		$	(222,422	)	(39.2	)%
Gross profit	20,883			115,947			(95,064		)	(82.0	)%
Gross profit as a percentage of revenue	6.1		%	20.4		%
General and administrative expense	60,792			72,741			(11,949		)	(16.4	)%
General and administrative expense as a percentage of revenue	17.6		%	12.8		%
Goodwill impairment	106,205			—			106,205
Interest expense, net	28,974			27,035			1,939			7.2	%
Other (income) expense, net	1,506			118			1,388
Income (loss) before taxes	(176,594		)	16,053			(192,647		)
Income (loss) before taxes as a percentage of revenue	(51.2		)%	2.8		%
Provision (benefit) for income taxes	361.0			4,310			(3,949		)
Net income (loss)	(176,955		)	11,743			(188,698		)
Net (income) loss attributable to noncontrolling interest	62,056			(1,266		)	63,322
Net income (loss) attributable to TETRA stockholders	$	(114,899	)	$	10,477		$	(125,376	)

Consolidated revenuesfor the current year period decreased compared to the prior year period due to continuing overall industry market challenges as a result of lower oil and natural gas commodity prices compared to early 2015. Each of our segments reported decreased revenues due to the impact of reduced demand for our products and services. The Fluids Division reported the most significant reduction in revenues, with decreased water management services, manufactured product sales, and completion services and products combining for $102.3 million of decreased revenues. Our Compression and Production Testing Divisions each also reported significantly decreased revenues during the current year period, due to lower industry demand and activity levels in each of the domestic and international markets we serve. See Divisional Comparisons section below for additional discussion.

Consolidated gross profit decreased during the current year period compared to the prior year period due to the reduced demand for our products and services, as well as the impact of pricing pressures in each of our businesses. Our Fluids Division reported the most significant reduction in gross profit, due to the reasons noted above and due to the impact from offshore completion fluids products and services associated with the new fluid technology projects during the prior year period. Our Compression Division reported the highest gross profit during the current year period, despite also reporting a decrease compared to the prior year period largely due to impairments of long-lived intangible assets. The results of each of our businesses reflect the impact of company-wide salary reductions that were implemented during the current year period, and which are expected to result in reduced operating expenses going forward. We continue to review the cost structure of each of our businesses for opportunities to further improve gross profit.

Consolidated general and administrative expenses decreased during the current year periodcompared to the prior year period, primarily due to cost reduction efforts across all segments resulting in lower salary and employee related expenses. The decrease in general and administrative expenses for Production Testing, Compression, and Offshore Divisions was partially offset by increased Corporate Overhead expenses. Despite the cost reductions made during the current year period, consolidated general and administrative expense increased as a percentage of consolidated revenues due to the significant decrease in revenues.

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During the first quarter of 2016, we updated our test of goodwill impairment in accordance with the Financial Accounting Standards Board ("FASB") Accounting Standards Codification ("ASC") 350-20 "Goodwill" due to the decreases in the price of our common stock and the common unit price of CCLP. The continued decreased oil and natural gas commodity prices had, and are expected to have, a continuing negative impact on industry drilling and capital expenditure activity, which affects the expected demand for products and services of each of our reporting units. Specifically, demand for our Compression Division's compression services and for sales of compressor equipment decreased significantly and are expected to continue to be decreased for the foreseeable future. Demand for our Production Testing Division's services also decreased as a result of decreased drilling and completion activity. This expected decreased demand, along with the decreases in the price of our common stock and the common unit price of our CCLP subsidiary, also caused an overall reduction in the fair values of each of our reporting units, particularly our Compression and Production Testing reporting units. As part of the test of goodwill impairment, we estimated the fair value of each of our reporting units, and determined, based on these estimated values, that impairments of the remaining goodwill of our Compression and Production Testing reporting units were necessary, primarily due to the market factors discussed above. Accordingly, during the first quarter of 2016, we recorded total impairment charges of $106.2 million associated with the goodwill of these reporting units.

Consolidated interest expense increased in the current year period due to the increased interest rate applicable to the 11% Senior Notes. In addition, interest expense also increased due to increased borrowings by the Compression Division, through CCLP, during early 2015 to fund its capital expenditures. Interest expense during the current and prior year periods includes $2.1 million and $1.8 million, respectively, of finance cost amortization.

Consolidated other expense was $1.5 million during the six months ended June 30, 2016 compared to $0.1 million during the prior year period, primarily due to the charges during the period for unamortized deferred financing costs that were expensed as a result of the repayment of senior notes and senior secured notes.

Our consolidated provision for income taxes during the first six months of 2015 and 2016 is primarily attributable to taxes in certain foreign jurisdictions and Texas gross margin taxes. Our consolidated effective tax rate for the six month period ended June 30, 2016 of negative 0.2% was primarily the result of losses generated in entities for which no related tax benefit has been recorded. The losses generated by these entities do not result in tax benefits due to offsetting valuation allowances being recorded against the related net deferred tax assets. We establish a valuation allowance to reduce the deferred tax assets when it is more likely than not that some portion or all of the deferred tax assets will not be realized. Included in our deferred tax assets are net operating loss carryforwards and tax credits that are available to offset future income tax liabilities in the U.S. as well as in certain foreign jurisdictions. Further, the effective tax rate is negatively impacted by the nondeductible portion of our goodwill impairments recorded during the six month period ended June 30, 2016.

Divisional Comparisons

Fluids Division

	Six Months Ended June 30,						Period to Period Change
	2016			2015			2016 vs 2015			% Change
	(In Thousands, Except Percentages)
Revenues	$	119,946		$	222,261		$	(102,315	)	(46.0	)%
Gross profit	14,076			65,720			(51,644		)	(78.6	)%
Gross profit as a percentage of revenue	11.7		%	29.6		%
General and administrative expense	15,179			15,799			(620		)	(3.9	)%
General and administrative expense as a percentage of revenue	12.7		%	7.1		%
Interest (income) expense, net	(23		)	(84		)	61
Other (income) expense, net	(1,177		)	(315		)	(862		)
Income before taxes	$	97		$	50,320		$	(50,223	)	(99.8	)%
Income before taxes as a percentage of revenue	0.1		%	22.6		%

The decreased Fluids Division revenues during the six month period compared to the prior year period was primarily due to $72.4 million of decreased product sales revenues, primarily due to decreased CBF and associated product sales revenues in the U.S. Gulf of Mexico, reflecting the decreased rig count activity compared to the prior

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year period and a decrease resulting from a customer well completion project during the prior year period using a new completion fluid technology that was introduced during 2015. In addition, product sales revenues also decreased compared to the prior year period due to decreased domestic manufactured products sales revenues (as a result of reduced demand due to milder winter weather). Service revenues decreased $29.9 million, primarily due to decreased water management services activity resulting from the impact of lower oil and natural gas commodity prices. Service revenues also decreased due to reduced demand in the U.S. Gulf of Mexico for completion services as a result of a reduction in completion activity. We have begun to see an increased demand in the U.S. Gulf of Mexico for our completion products and services during the second half of the year.

Fluids Division gross profit during the six month period decreased compared to the prior year period primarily due to decreased revenues and decreased profitability associated with the mix of CBF products and services, particularly for offshore completion fluids products and services associated with the new fluid technology projects during the prior year period. In addition, Fluids Division gross profit declined and as a result of reduced demand for manufactured products during the current year period compared to the prior year period.

Fluids Division reported a significant decrease in pretax earnings compared to the prior year period primarily due to the decreased gross profit discussed above. Fluids Division administrative cost levels decreased compared to the prior year period, primarily due to $2.0 million of decreased salary and employee expenses due to administrative cost and salary reductions. This increase was offset primarily by increased legal and professional fees. The Fluids Division continues to review opportunities to further reduce its administrative costs. Partially offsetting the decreased gross profit, other income increased primarily due to increased foreign currency gains.

Production Testing Division

	Six Months Ended June 30,						Period to Period Change
	2016			2015			2016 vs 2015			% Change
	(In Thousands, Except Percentages)
Revenues	$	33,255		$	71,944		$	(38,689	)	(53.8	)%
Gross profit (loss)	(6,022		)	6,777			(12,799		)	(188.9	)%
Gross profit as a percentage of revenue	(18.1		)%	9.4		%
General and administrative expense	5,191			8,702			(3,511		)	(40.3	)%
General and administrative expense as a percentage of revenue	15.6		%	12.1		%
Goodwill impairment	13,871			—			13,871
Interest (income) expense, net	(332		)	5			(337		)
Other (income) expense, net	(1,051		)	(1,497		)	446
Loss before taxes	$	(23,701	)	$	(433	)	$	(23,268	)
Loss before taxes as a percentage of revenue	(71.3		)%	(0.6		)%

Production Testing Division revenues decreased significantly during the current year period compared to the prior year period due to reduced overall market activity. Production Testing service revenues decreased $38.4 million during the current year compared to the prior year period, as the impact of lower oil and natural gas pricing has negatively impacted demand for services in each of the division's areas of operations, including certain shale reservoir markets that were a source of revenue growth during the past several years. Decreased U.S. demand reflects the significant decline in onshore rig count activity compared to the prior year quarter. In addition, increased competition for decreased market activity negatively affected pricing levels for services, particularly internationally.

Production Testing Division had a gross loss during the current year period compared to gross profit during the prior year period due to the decreased industry activity and increased competition as discussed above. In addition, the Production Testing Division recorded $2.8 million of long-lived intangible asset impairments as of March 31, 2016. This decrease and resulting gross loss occurred despite cost reduction efforts, which have included headcount reductions, salary reductions, and other steps to adjust the Production Testing Division's cost structure in light of current market conditions.

The Production Testing Division reported an increased pretax loss compared to the prior year period, primarily due to the gross loss discussed above and the goodwill impairment recorded during the current year period. We account for goodwill in accordance with ASC 350-20, and the impairments of goodwill reflect the

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significant decreases in future profitability and cash flows expected in the current market environment. General and administrative expenses decreased due to $2.0 million of decreased employee-related expenses, primarily from reduced headcount, salary reductions, and other employee related cost reductions, and $1.5 million of decreased general, office and bad debt expenses. The division continues to review additional opportunities to further reduce its operating and administrative cost levels in light of current market conditions.

Compression Division

	Six Months Ended June 30,						Period to Period Change
	2016			2015			2016 vs 2015			% Change
	(In Thousands, Except Percentages)
Revenues	$	157,786		$	229,344		$	(71,558	)	(31.2	)%
Gross profit	20,682			43,937			(23,255		)	(52.9	)%
Gross profit as a percentage of revenue	13.1		%	19.2		%
General and administrative expense	18,421			21,769			(3,348		)	(15.4	)%
General and administrative expense as a percentage of revenue	11.7		%	9.5		%
Goodwill Impairment	92,334			—			92,334
Interest (income) expense, net	17,672			17,260			412
Other (income) expense, net	995			1,004			(9		)
Income (loss) before taxes	$	(108,740	)	$	3,904		$	(112,644	)
Income (loss) before taxes as a percentage of revenue	(68.9		)%	1.7		%

Compression Division revenues decreased significantly during the current year period compared to the prior year period, due to reductions in both compressor sales and compression and related services revenues. Revenues from sales of compressor packages and parts during the current year period decreased $37.9 million compared to the prior year period due to a reduction in customer projects, particularly for high-horsepower compressor packages. The current reduced equipment fabrication backlog indicates that this decrease in compressor package sales revenues will continue going forward. The $33.6 million decrease in compression service revenues resulted primarily from the reduction in overall utilization in total horsepower as well as compression services pricing compared to the prior year period. The decreased overall utilization has affected each horsepower class of the Compression Division's fleet, but has particularly decreased the demand for low-horsepower production enhancement compression services as a result of lower oil and natural gas commodity prices.

Compression Division gross profit decreased during the current year period compared to the prior year period as a result of the lower demand for compressors and compression services discussed above. In addition, the Compression Division recorded $7.9 million of long-lived intangible asset impairments. Competitive pricing pressures and rate reduction requests in the current market environment have also resulted in reduced gross profit. During the first six months of 2016, the Compression Division took additional steps to reduce its operating costs and improve operating efficiencies. The impact of these cost reduction efforts is expected to result in additional cost efficiencies in future periods.

The Compression Division recorded a pretax loss during the current year period compared to pretax earnings during the prior year period. The amount of the pretax loss for the current year period was significantly increased due to the impairment of goodwill during the current year period pursuant to ASC 350-20. In addition to the decreased gross profit discussed above, interest expense increased as a result of increased borrowings outstanding by CCLP under the CCLP Credit Agreement during the current year period compared to the prior year period. General and administrative expense levels decreased compared to the prior year period, mainly due to $3.4 million of administrative salary reductions.

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Offshore Division

Offshore Services Segment

	Six Months Ended June 30,						Period to Period Change
	2016			2015			2016 vs 2015			% Change
	(In Thousands, Except Percentages)
Revenues	$	36,365		$	47,515		$	(11,150	)	(23.5	)%
Gross loss	(4,222		)	(1,279		)	(2,943		)	230.1	%
Gross profit as a percentage of revenue	(11.6		)%	(2.7		)%
General and administrative expense	3,452			5,322			(1,870		)	(35.1	)%
General and administrative expense as a percentage of revenue	9.5		%	11.2		%
Interest (income) expense, net	—			—			—
Other (income) expense, net	(3		)	(48		)	45
Loss before taxes	$	(7,671	)	$	(6,553	)	$	(1,118	)	(17.1	)%
Loss before taxes as a percentage of revenue	(21.1		)%	(13.8		)%

Revenues for the Offshore Services segment decreased during the current year period compared to the prior year period primarily due to reduced revenues from its well abandonment and diving services businesses. Decreased diving services and well abandonment activity levels in the U.S. Gulf of Mexico during the current quarter reflected an overall reduction in demand in this market, due to a postponement of certain well abandonment projects. These decreases were partially offset by increased revenues from heavy lift services due to increased activity during the second quarter of 2016. Given the current low oil and natural gas commodity price environment, Offshore Services anticipates a continued decrease in demand for its services for the foreseeable future. Offshore Services revenues during the current year period include work performed for our Maritech segment, with $0.5 million of such work being performed during the current year period compared to $3.2 million of revenues during the prior year period. Revenues for work performed for Maritech, which are eliminated in consolidation, are expected to continue to be lower in future periods.

Gross loss for the Offshore Services segment increased compared to the prior year period as the impact of decreased activity levels for well abandonment and diving services as discussed above more than offset cost reduction measures and process efficiencies that have been implemented. The Offshore Services segment continues to consider additional opportunities to optimize its operating cost structure.

Offshore Services segment loss before taxes increased compared to the prior year period primarily due to the increased gross loss discussed above, and despite a reduction in general and administrative expenses, that was primarily from reduced salary and employee related expenses of $1.4 million and decreased professional services and general expenses of $0.3 million and other decreased general expenses of $0.2 million, respectively. The Offshore Services segment continues to review its administrative cost structure for additional cost reductions and process efficiency actions in response to current market conditions.

Maritech Segment

	Six Months Ended June 30,						Period to Period Change
	2016			2015			2016 vs 2015			% Change
	(In Thousands, Except Percentages)
Revenues	$	337		$	1,900		$	(1,563	)	(82.3	)%
Gross profit (loss)	(3,412		)	1,301			(4,713		)	362.3	%
General and administrative expense	599			613			(14		)	(2.3	)%
General and administrative expense as a percentage of revenue	177.7		%	32.3		%
Interest (income) expense, net	10			26			(16		)
Other (income) expense, net	—			—			—
Income (loss) before taxes	$	(4,021	)	$	662		$	(4,683	)	707.4	%

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As a result of the sale of almost all of its producing properties during 2011 and 2012, Maritech revenues were negligible and are expected to continue to be negligible going forward. Revenue decreased compared to the prior year period due to the lower volumes and pricing and the suspension of production on one of Maritech's non-operated properties during a portion of the current year period.

Maritech reported a gross loss during the current year period compared to gross profit during the prior year period, primarily due to charges during the period for decommissioning costs incurred in prior periods no longer considered collectible from third parties.

Maritech reported a pretax loss during the current year period compared to pretax income during the prior year period primarily due to the gross loss as discussed above.

Corporate Overhead

	Six Months Ended June 30,						Period to Period Change
	2016			2015			2016 vs 2015			% Change
	(In Thousands, Except Percentages)
Gross profit (loss) (depreciation expense)	$	(226	)	$	(512	)	$	286		55.9	%
General and administrative expense	17,950			20,537			(2,587		)	(12.6	)%
Interest (income) expense, net	11,647			9,828			1,819
Other (income) expense, net	2,740			960			1,780
Loss before taxes	$	(32,563	)	$	(31,837	)	$	(726	)	(2.3	)%

Corporate Overhead pretax loss increased during the current year period compared to the prior year period, despite decreased general and administrative expense, due to increased interest expense caused by the higher interest rate on the Series 2015 Senior Notes that were issued in November 2015. Corporate general and administrative expenses decreased due to $3.6 million of decreased salary, incentives and other employee related expenses. This decrease was offset by $0.8 million of increased professional service fees, and $0.7 million of increased general expenses. Decreased administrative salary expenses reflect the company-wide salary reduction steps taken, as well as decreased incentives. Corporate other expenses increased compared to the prior year period due to the expensing of $1.5 million of deferred financing costs associated with the repayment of senior notes and senior secured notes, and from increased losses associated with foreign currency derivative instruments of $0.2 million.

Liquidity and Capital Resources

Due to the significantly challenging market environment for a number of our businesses, our consolidated cash flows from operating activities decreased significantly during the first six months of 2016 compared to the corresponding prior year period. This decrease occurred as a result of a significant decrease in revenues and profitability, and despite a number of mitigating factors, including the impact of cost reduction efforts and the focus on improved collections of customer accounts receivable compared to the corresponding prior year period. Approximately $35.6 million of our consolidated operating cash flows during the six months ended June 30, 2016 were generated by CCLP, and we received $11.2 million of distributions from CCLP during the six months ended June 30, 2016 compared to $15.0 million during the corresponding prior year period. We believe the cost reduction steps we have taken have enhanced our capital structure and operating cash flows and additional steps may be taken to enhance our operating cash flows in the future. Our ability to meet our financial obligations and fund future growth is dependent on future levels of consolidated operating cash flows and the availability of capital resources in uncertain operating and financial markets.

We and CCLP are in compliance with all covenants of our respective credit agreements and senior note agreements as of June 30, 2016. Considering financial forecasts based on current market conditions as of August 9, 2016, we anticipate that, despite the current industry environment and activity levels, we will have sufficient operating cash flows to maintain compliance with the financial covenants under our long-term debt agreements, as amended, through June 30, 2017. With regard to CCLP, also considering financial forecasts based on current market conditions as of August 9, 2016, as a result of the impact of recent cost reduction efforts, the May 2016

41

amendment of certain financial covenants under the CCLP Credit Agreement, and the August 2016 receipt of $49.8 million of net proceeds from the private placement (the "Private Placement") of its Series A Convertible Preferred Units (the "CCLP Preferred Units"), CCLP believes that it will have adequate liquidity to fund its operations and debt obligations and maintain compliance with the financial covenants under its long-term debt agreements, as amended, through June 30, 2017.

Our consolidated sources and uses of cash during the six months ended June 30, 2016 and 2015 are as follows:

	Six Months Ended June 30, 2016			Six months ended June 30, 2015
	(In Thousands)
Operating activities	$	33,597		$	82,162
Investing activities	(6,690		)	(69,649		)
Financing activities	(25,310		)	(18,040		)

Because of the level of consolidated debt, it is increasingly important to consider our capital structure and CCLP's capital structure separately, as we have no cross default provisions, cross collateralization provisions, or cross guarantees with CCLP's debt, nor does CCLP with our debt. (See Financing Activities section below for a complete discussion of the terms of our and CCLP's respective debt arrangements.) Our consolidated debt outstanding has a carrying value of approximately $788.2 million as of June 30, 2016. However, approximately $569.2 million of this consolidated debt balance is owed by CCLP and is serviced from the existing cash balances and cash flows of CCLP and secured by its assets. Through our 42% common unit ownership interest in CCLP and ownership of an approximately 2% general partner interest that includes incentive distribution rights, we receive our share of the distributable cash flows of CCLP through its quarterly distributions. Approximately $16.7 million of the $23.9 million of the cash balance reflected on our consolidated balance sheet is owned by CCLP and is not accessible by us. As of June 30, 2016, and subject to compliance with the respective financial covenants and other provisions of the agreements that may limit borrowings under the respective credit facilities, CCLP had availability of $101.9 million under the CCLP Credit Agreement, and we had availability of $114.2 million under our Credit Agreement.

Operating Activities

Cash flowsgeneratedby operating activitiestotaled $33.6 millionduring the first six months of 2016 compared to $82.2 million during the corresponding prior year period, a decreaseof $48.6 million. Operating cash flows decreased primarily due to decreased earnings compared to the prior year period. We have taken steps to aggressively manage working capital, which resulted in increased collections of accounts receivable during the first six months of 2016 compared to the corresponding prior year period, despite decreased activity levels. In addition, we also are focused on managing inventory levels. We continue to monitor customer credit risk in the current environment and have historically focused on serving larger capitalized oil and gas operators and national oil companies.

Demand for the vast majority of our products and services is driven by oil and gas industry activity, which is affected by oil and natural gas commodity pricing. The dramatic decreases in oil and natural gas prices during 2015 and through mid-2016, particularly oil prices, significantly reduced the current capital expenditure and operating plans of our oil and gas customers, affecting each of our operating segments. The volatility of oil and natural gas prices is expected to continue in the future. Worldwide drilling activity related to oil and natural gas wells has decreased, particularly affecting our Production Testing and Fluids Divisions. In addition, our Compression Division operations are also highly vulnerable to the impact of a sustained low natural gas price environment. A large portion of our consolidated cash flows generated by operating activities during 2015 resulted from equipment and product sales and specific customer projects that may not recur in 2016 at current oil and natural gas industry activity levels. If oil and gas industry activity levels remain at current levels or decrease in the future, we expect that our levels of operating cash flows will be negatively affected.

During the first portion of 2016, we have continued to take steps to reduce operating and administrative headcount, defer salary increases, reduce salaries, and implement other cost reductions for each of our segments. These steps are designed to further streamline our operations and downsize our organization, particularly in

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response to continuing market challenges for certain of our businesses. Together with the specific cost reduction steps taken during prior periods, these cost reduction efforts have partially mitigated the decreased operating cash flows and profitability resulting from the current market environment. We will continue to review for other opportunities to reduce costs.

As of June 30, 2016, Maritech’s decommissioning liabilities associated with its remaining offshore oil and gas production wells, platforms, and facilities totaled approximately $45.6 million. Approximately $3.3 million of this amount is expected to be performed during the twelve month period ended June 30,2017, with the timing of a portion of this work being discretionary. Until the remaining decommissioning liabilities are extinguished, our future operating cash flows will continue to be affected by Maritech’s decommissioning expenditures as they are incurred.Included in Maritech’s decommissioning liabilities is the remaining abandonment, decommissioning, and debris removal work associated with offshore platforms that were previously destroyed byahurricane as well as certain remediation work required on wells that were previously plugged. Due to the unique nature of the remaining work to be performed associated with these properties, actual costs could greatly exceed these estimates and could therefore result in significant charges to earnings and cash flows in future periods.

Asset retirement obligations are recorded in accordance with Financial Accounting Standards Board ("FASB") Accounting Standards Codification ("ASC") 410, Asset Retirement and Environmental Obligations, whereby the estimated fair value of a liability for asset retirement obligations is recorded in the period in which it is incurred and a reasonable estimate can be made. Such estimates are based on relevant assumptions that we believe are reasonable. The cost estimates for Maritech asset retirement obligations are considered reasonable estimates consistent with market conditions at the time they are made, and we believe reflect the amount of work required to be performed in accordance with Bureau of Safety and Environmental Enforcement ("BSEE") standards, as revised from time to time.

The amount of work performed or estimated to be performed on a Maritech property asset retirement obligation often exceeds amounts previously estimated for numerous reasons including physical subsea, geological, or downhole conditions, that are different from those anticipated at the time of estimation due to the age of the property and the quality of information available about the particular property conditions. Maritech’s remaining oil and gas properties and production platforms were drilled and constructed by other operators many years ago and frequently there is not a great deal of detailed documentation on which to base the estimated asset retirement obligation for these properties. Appropriate underwater surveys are typically performed to determine the condition of such properties as part of our due diligence in estimating the costs, but not all conditions are able to be determined prior to the commencement of the actual work. During the performance of asset retirement activities, unforeseen weather or other conditions may also extend the duration and increase the cost of the projects, which are normally not done on a fixed price basis, thereby resulting in costs in excess of the original estimate.

Maritech has one remaining property that was damaged by a hurricane in the past, leaving the production platform toppled on the seabed and production tubing from the wells (which may be under pressure) bent underwater. While the basic procedures involved in the plugging and abandonment of wells and decommissioning of platforms and pipelines and removal of debris is generally similar for these types of properties, the cost of performing work at these damaged locations is particularly difficult to estimate due to the unique conditions encountered, including the uncertainty regarding the extent of physical damage to many of the structures.

In addition, Maritech has encountered situations where previously plugged and abandoned wells on its properties have later exhibited a build-up of pressure that is evidenced by gas bubbles coming from the plugged well head. We refer to this situation as “wells under pressure” and this can either be discovered by us when we perform additional work at the property or by notification from a third party. Wells under pressure require Maritech to return to the site to perform additional plug and abandonment procedures that were not originally anticipated or included in the estimate of the asset retirement obligation for such property. Remediation work at previously abandoned well sites is particularly costly due to the lack of a platform from which to base these activities. Maritech is the last operator of record for its plugged wells and bears the risk of additional future work required as a result of wells becoming under pressure in the future.

For oil and gas properties previously operated by Maritech, the purchaser of the properties generally became the successor operator and assumed the financial responsibilities associated with the properties’ operations and abandonment and decommissioning. However, to the extent that purchasers of these oil and gas properties fail to perform the abandonment and decommissioning work required and there is insufficient bonding or

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other security, the previous owners and operators of the properties, including Maritech, may be required to assume responsibility for the abandonment and decommissioning obligations.

Investing Activities

During the first six months of 2016, the total amount of our net cash utilized on investing activities was $6.7 million. Total cashcapital expenditures during the first six months of 2016 were $9.0 million. Our Fluids Division spent $0.9 million of our capital expenditures during the first six months of 2016, the majority of which related primarily to chemical plant improvements. Our Production Testing Division spent $0.3 million on capital expenditures, primarily to add to its international production testing equipment fleet. Our Compression Division spent $3.8 million, primarily for the expansion of its high-horsepower compressor and equipment fleet. Our Offshore Services segment spent $3.8 million on its various heavy lift barges and dive support vessels, primarily for required drydock expenditures.

Generally, a significant majority of our planned capital expenditures has been related to identified opportunities to grow and expand certain of our existing businesses. However, a majority of these planned expenditures have been postponed or canceled in an effort to conserve capital or otherwise address expected future market conditions. We currently have no long-term capital expenditure commitments and are reviewing all capital expenditure plans carefully during the current period of reduced demand for our products and services in an effort to conserve cash and fund our liquidity needs. The deferral of capital projects could affect our ability to compete in the future. Excluding the capital expenditures of our Compression Division, we expect to spend approximately $10 to $15 million during 2016, primarily for maintenance projects. Our Compression Division expects to spend approximately $20 to $25 million during 2016. The level of future growth capital expenditures depends on forecasted demand for our products and services. If the forecasted demand for our products and services during 2016 increases or decreases, the amount of planned expenditures on growth and expansion will be adjusted accordingly.

Financing Activities 

During the first six months of 2016, the total amount of cash used by financing activities was $25.3 million. To fund our capital and working capital requirements, we may supplement our existing cash balances and cash flow from operating activities from short-term borrowings, long-term borrowings, leases, equity issuances, and other sources of capital. On March 23, 2016, we filed a universal shelf Registration Statement on Form S-3 with the Securities and Exchange Commission and it was declared effective on April 13, 2016. In June 2016, pursuant to this shelf registration statement, we completed an underwritten public offering of 11.5 million shares of our common stock, which included 1.5 million shares of common stock pursuant to an option granted to the underwriters to purchase additional shares, which generated net proceeds of $60.4 million. These offering proceeds were used to repay indebtedness, pay offering expenses, and for general corporate purposes. For further discussion, see Other Sources and Uses section below. We and CCLP are in compliance with all covenants of our respective credit agreements and senior note agreements as of June 30, 2016.

See CCLP Long-Term Debt below for discussion of CCLP's long-term debt.

Our Long-Term Debt

Our Bank Credit Facility. As of August 8, 2016, TETRA (excluding CCLP) has an outstanding balance on its revolving credit facility (as amended, the "Credit Agreement"), of $149.3 million, andhad $8.1 million in letters of credit and guaranteesagainst therevolving credit facility, leaving a net availability, subject to compliance with our financial covenants and other provisions of the Credit Agreement that limit borrowings under the Credit Facility, of $67.6 million. These amounts do not reflect the CCLP Credit Agreement, which is separate and distinct from TETRA's Credit Agreement, and is discussed further below. All obligations under the Credit Agreement and the guarantees of such obligations are secured by first-lien security interests in substantially all of our assets and the assets of our subsidiaries (limited, in the case of foreign subsidiaries, to 66% of the voting stock or equity interests of first-tier foreign subsidiaries). Such security interests are for the benefit of the lenders of the Credit Agreement as well as the holder of our 11% Senior Notes.

Under the Credit Agreement, which matures on September 30, 2019, borrowings generally bear interest at the British Bankers Association LIBOR rate plus 2.25% to 4.00%, depending on one of our financial ratios. We pay a commitment fee ranging from 0.35% to 0.75% on unused portions of the facility. The Credit Agreement contains

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customary covenants and other restrictions, including certain financial ratio covenants based on our levels of debt and interest cost compared to a defined measure of our operating cash flows over a twelve month period. In addition, the Credit Agreement includes limitations on aggregate asset sales, individual acquisitions, and aggregate annual acquisitions and capital expenditures and requires us to use designated consolidated cash and cash equivalents of TETRA and certain subsidiaries in excess of $25.0 million to prepay loans. Access to our revolving credit line is dependent upon our compliance with the financial ratio covenants set forth in the Credit Agreement. These financial ratios include a fixed charge coverage ratio and a consolidated leverage ratio. The fixed charge coverage ratio compares (a) EBITDA as adjusted and defined in our Credit Agreement less (1) cash income tax expense, (2) non-financed capital expenditures, and (3) cash dividends and distributions to (b) interest expense plus (1) scheduled principal payments and (2) stock purchases. As amended by the Agreement and Fourth Amendment dated July 1, 2016 (the "Fourth Amendment"), the Credit Agreement provides that the fixed charge coverage ratio may not be less than 1.25 to 1 as of the end of any fiscal quarter. The consolidated leverage ratio covenant was amended by the Fourth Amendment and may not exceed (a) 4.00 to 1 at the end of the fiscal quarters ending during the period from and including June 30, 2016 through and including March 31, 2018, (b) 3.75 to 1 at the end of the fiscal quarters ending during the period from and including June 30, 2018 through and including December 31, 2018, and (c) 3.5 to 1 at the end of each of the fiscal quarters thereafter. Consolidated net earnings under the credit facility is defined as the aggregate of our net income (or loss) and our consolidated restricted subsidiaries (which does not include CCLP), including cash dividends and distributions (not the return of capital) received from persons other than consolidated restricted subsidiaries (including CCLP) and after allowances for taxes for such period determined on a consolidated basis in accordance with GAAP, excluding certain items more specifically described therein. At June 30, 2016, our consolidated leverage ratio was 2.27 to 1 (compared to a 4.00 to 1 maximum as required under the Credit Agreement), compared to 1.86 to 1 at December 31, 2015 and 2.94 to 1 at December 31, 2014. At June 30, 2016, our fixed charge coverage ratio was 4.32 to 1 (compared to a 1.25 to 1 minimum required under the Credit Agreement), compared to 6.33 to 1 at December 31, 2015. Deterioration of these financial ratios could result in a default by us under the Credit Agreement that, if not remedied, could result in termination of the Credit Agreement and acceleration of any outstanding balances. Any such default could also result in a cross-default under our Senior Unsecured Notes and Senior Secured Notes. CCLP is an unrestricted subsidiary and is not a borrower or a guarantor under the Credit Agreement.

The Credit Agreement includes cross-default provisions relating to any other indebtedness (excluding indebtedness of CCLP) greater than a defined amount. Our Credit Agreement also contains a covenant that restricts us from paying dividends in the event of a default or if such payment would result in an event of default.

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Our Senior Notes. In May 2016, we purchased for cash all of the outstanding Series 2010-A Senior Notes, Series 2010-B Senior Notes, and Series 2013 Senior Notes (together the "Tender Offer Senior Notes"), in the aggregate principal amount of $100 million, plus accrued and unpaid interest, pursuant to tender offers (the "Tender Offers"). The purchase of the Tender Offer Senior Notes was funded by borrowings under our Credit Agreement. In June 2016, following the issuance of 11.5 million shares of our common stock, we utilized a portion of the proceeds to repay the remaining $30.0 million outstanding under our Senior Secured Notes. The remaining proceeds were used to pay offering related expenses and reduce the amount of borrowings outstanding under our Credit Agreement. Following the purchase of the Tender Offer Senior Notes and the repayment of the Senior Secured Notes, our remaining senior notes consist of the 11% Senior Notes that were issued and sold in November 2015. The 11% Senior Notes were issued pursuant to a Note Purchase Agreement with GSO Tetra Holdings LP ("GSO"). On July 1, 2016, we entered into an Amended and Restated Note Purchase Agreement (the "Amended and Restated 11% Senior Note Agreement") with GSO to amend and replace the previous note purchase agreement. The Amended and Restated 11% Senior Note Agreement contains customary default provisions, as well as the following cross-default provision. An event of default will occur if we (i) fail to make any payment when due beyond any applicable grace period under any indebtedness of at least $20.0 million, (ii) default in the performance of any obligation under the Amended and Restated 11% Senior Note Agreement or collateral documents and such default is not remedied within the applicable cure period, (iii) default in the performance of or compliance with any term of any indebtedness in an aggregate outstanding principal amount of at least $20.0 million or of any mortgage, indenture or other agreement relating to such indebtedness or any other condition exists, and as a result of such default or condition such indebtedness is accelerated and declared due and payable before its stated maturity or before its regularly scheduled dates for payment, (iv) we become obligated to purchase or repay indebtedness before its regular maturity or before its regularly scheduled dates of payment in an aggregate outstanding principal amount of at least $20.0 million or one or more persons have the right to require us to purchase or repay such indebtedness or (v) with certain exceptions, the security interest in the collateral ceases to be in full force and effect. Upon the occurrence and during the continuation of an event of default under the Amended and Restated 11% Senior Note Agreement, the 11% Senior Notes may become immediately due and payable, either automatically or by declaration of holders of more than 50% in principal amount of the 11% Senior Notes at the time outstanding.

In addition, the Amended and Restated 11% Senior Note Agreement requires a minimum permitted fixed charge coverage ratio at the end of any fiscal quarter of 1.1 to 1 and a maximum permitted ratio of consolidated funded indebtedness at the end of any fiscal quarter of a defined measure of earnings of (a) 4.50 to 1 as of the end of any fiscal quarter ending during the period commencing July 1, 2016 and ending on March 31, 2018, (b) 4.25 to1 as of the end of any fiscal quarter ending during the period commencing on June 30, 2018 and ending on December 31, 2018 and (c) 4.00 to 1 as of the end of any fiscal quarter ending thereafter. Pursuant to the Amended and Restated 11% Senior Note Agreement, the 11% Senior Notes are secured by first-lien security interests in substantially all of our assets and the assets of our subsidiaries. See the above discussion of the Fourth Amendment to our Credit Agreement for a description of these security interests. The 11% Senior Notes are pari passu in right of payment to all borrowings under the Credit Agreement and rank at least pari passu in right of payment with all other outstanding indebtedness. The Amended and Restated 11% Senior Note Agreement contains customary covenants that limit our ability to, among other things; incur or guarantee additional indebtedness; incur or create liens; merge or consolidate or sell substantially all of our assets; engage in a different business; enter into transactions with affiliates; and make certain payments as set forth in the Amended and Restated 11% Senior Note Purchase Agreement. We are in compliance with all covenants of the Senior Unsecured Note Purchase Agreements as of June 30, 2016. At June 30, 2016, our leverage ratio was 2.27 to 1, compared to 1.86 to 1 at December 31, 2015.

Deterioration of these financial ratios could result in a default by us under the Amended and Restated 11% Senior Note Agreement and, if not remedied, could result in termination of the Amended and Restated 11% Senior Note Agreement and acceleration of any outstanding balances of the 11% Senior Notes. CCLP is an unrestricted subsidiary and is not a borrower or a guarantor under our Amended and Restated 11% Senior Note Agreement.

CCLP Long-Term Debt

CCLP Preferred Units. On August 8, 2016, CCLP entered into a Series A Preferred Unit Purchase Agreement (the “CCLP Preferred Unit Purchase Agreement”) with certain purchasers (collectively, the “Purchasers”) to issue and sell in a private placement (the “Private Placement”) an aggregate of 4,374,454 of CSI Compressco LP Series A Convertible Preferred Units representing limited partner interests in CCLP (the “CCLP Preferred Units”) for a cash purchase price of $11.43 per CCLP Preferred Unit (the “Issue Price”), resulting in total net proceeds to

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CCLP, after deducting certain offering expenses, of $49.8 million. We purchased 874,891 of the CCLP Preferred Units at the Issue Price, aggregating $10.0 million. The CCLP Preferred Units, net of the units we purchased, will be classified as long-term liabilities in our consolidated balance sheet. Proceeds from the Private Placement will be used to pay additional offering expenses and reduce outstanding CCLP indebtedness under the CCLP Credit Agreement or the CCLP 7.25% Senior Notes.

Pursuant to the Unit Purchase Agreement, in connection with the closing, CSI Compressco GP Inc (our wholly owned subsidiary) executed a Second Amended and Restated Agreement of Limited Partnership of CCLP (the “Amended and Restated CCLP Partnership Agreement”) to, among other things, authorize and establish the rights and preferences of the CCLP Preferred Units. The CCLP Preferred Units are a new class of equity security that will rank senior to all classes or series of equity securities of CCLP with respect to distribution rights and rights upon liquidation. We and the other holders of CCLP Preferred Units (each, a “CCLP Preferred Unitholder”) will receive quarterly distributions, which will be paid in kind in additional CCLP Preferred Units, equal to an annual rate of 11.00% of the Issue Price ($1.2573 per unit annualized), subject to certain adjustments. The rights of the CCLP Preferred Units include certain anti-dilution adjustments, including adjustments for economic dilution resulting from the issuance of common units in the future below a set price.

A ratable portion of the CCLP Preferred Units will be converted each month over a period of thirty months beginning in the seventh calendar month following the closing (each, a “Conversion Date”), subject to certain provisions of the Amended and Restated CCLP Partnership Agreement that may delay or accelerate all or a portion of such monthly conversions. On each Conversion Date, the CCLP Preferred Units will convert into common units representing limited partner interests in CCLP in an amount equal to, with respect to each CCLP Preferred Unitholder, the number of CCLP Preferred Units held by such CCLP Preferred Unitholder divided by the number of Conversion Dates remaining, subject to adjustment described in the Amended and Restated CCLP Partnership Agreement, with the conversion price determined by trading prices of the common units over the prior month, among other factors, and as otherwise impacted by the existence of certain conditions related to the common units. CCLP may, at its option, pay cash, or a combination of cash and common units, to the CCLP Preferred Unitholders instead of issuing common units on any Conversion Date, subject to certain restrictions as described in the Amended and Restated CCLP Partnership Agreement and the CCLP Credit Agreement.

In addition, each Purchaser may convert its CCLP Preferred Units, generally on a one-for-one basis and subject to adjustment for certain splits, combinations, reclassifications or other similar transactions and certain anti-dilution adjustments, in whole or in part, at any time following May 31, 2017 so long as any conversion is not for less than $250,000 or such lesser amount, if such conversion relates to all of such Purchaser’s remaining CCLP Preferred Units. CCLP has the right to be reimbursed for any cash distributions paid with respect to common units issued in any such optional conversion until March 31, 2018. The CCLP Preferred Units will vote on an as-converted basis with the common units and will have certain other rights to vote as a class with respect to any amendment to the Amended and Restated CCLP Partnership Agreement that would affect any rights, preferences or privileges of the CCLP Preferred Units, as more fully described in the Amended and Restated CCLP Partnership Agreement.

In addition, the CCLP Preferred Unit Purchase Agreement includes certain provisions regarding change of control, transfer of CCLP Preferred Units, indemnities, and other matters described in detail in the CCLP Preferred Unit Purchase Agreement. In connection with the Closing, CCLP agreed to pay a transaction fee of $1.2 million to its financial advisor for this transaction. The CCLP Preferred Unit Purchase Agreement contains customary representations, warranties and covenants of CCLP and the Purchasers.

CCLP’s Bank Credit Facilities. Under CCLP's bank credit agreement, (as amended, the "CCLP Credit Agreement"), CCLP and CSI Compressco Sub, Inc. are named as the borrowers and all obligations under the CCLP Credit Agreement are guaranteed by all of CCLP's existing and future, direct and indirect, domestic restricted subsidiaries (other than domestic subsidiaries that are wholly owned by foreign subsidiaries), and secured by substantially all of CCLP's assets and the assets of its domestic subsidiaries. We are not a borrower or a guarantor under the CCLP Credit Agreement. The CCLP Credit Agreement matures on August 4, 2019 and includes a maximum credit commitment of $340.0 million, and included within such amount is availability for letters of credit (with a sublimit of $20.0 million) and swingline loans (with a sublimit of $60.0 million). The amount of borrowings under the CCLP Credit Agreement is subject to certain limitations, including borrowing limitations as a result of financial covenants. As of August 8, 2016, and prior to the use of CCLP Preferred Unit proceeds to reduce the amount of borrowings outstanding, CCLP has a balance outstanding under the CCLP Credit Agreement of $230.0 million, has $4.9 million letters of credit and performance bonds outstanding, and subject to compliance with

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financial covenants and other provisions in the CCLP Credit Agreement that limit borrowings under the CCLP Credit Agreement, has availability under the CCLP Credit Agreement of $105.1 million.

The CCLP Credit Agreement requires CCLP to maintain (i) a minimum consolidated interest coverage ratio (ratio of consolidated earnings before interest, taxes, depreciation, and amortization ("EBITDA") to consolidated interest charges) of 3.0 to 1, (ii) a maximum consolidated total leverage ratio (ratio of consolidated total indebtedness to consolidated EBITDA) of (a) 5.50 to 1 as of June 30, 2016 and September 30, 2016; (b) 5.75 to 1 as of December 31, 2016, March 31, 2017, June 30, 2017 and September 30, 2017; (c) 5.50 to 1 as of December 31, 2017 and March 31, 2018; (d) 5.25 to 1 as of June 30, 2018 and September 30, 2018, and (e) 5.00 to 1 as of December 31, 2018 and thereafter, and (iii) a maximum consolidated secured leverage ratio (consolidated secured indebtedness to consolidated EBITDA) of 3.5 to 1.0, in each case, as of the last day of each fiscal quarter, calculated on a trailing four quarters basis. At June 30, 2016, the CCLP consolidated total leverage ratio was 5.04 to 1 and the CCLP interest coverage ratio was 3.81 to 1. In addition, the CCLP Credit Agreement includes customary negative covenants that, among other things, limit CCLP's ability to incur additional debt, incur, or permit certain liens to exist, or make certain loans, investments, acquisitions, or other restricted payments. In addition, the CCLP Credit Agreement requires that, among other conditions, CCLP use designated consolidated cash and cash equivalent balances in excess of $35.0 million to prepay the loans; allows the prepayment or purchase of indebtedness with proceeds from the issuances of equity securities or in exchange for the issuances of equity securities; and restricts the amount of CCLP's permitted capital expenditures in the ordinary course of business during each fiscal year ranging from $25.0 million in 2016 to $75.0 million in 2019. The CCLP Credit Agreement provides that CCLP can make distributions to holders of its common units, but only if there is no default or event of default under the facility.

CCLP 7.25% Senior Notes. In August 2014, CCLP, and CSI Compressco Finance Inc., a Delaware corporation and indirect wholly owned subsidiary of CCLP (CSI Compressco Finance and, together with CCLP, the "Issuers"), issued $350.0 million aggregate principal amount of the Issuers’ 7.25% Senior Notes due 2022 (the "CCLP Senior Notes") in a private offering exempt from the registration requirements under the Securities Act of 1933, as amended (the "Securities Act") pursuant to a Note Purchase Agreement dated July 29, 2014. The CCLP Senior Notes were subsequently registered through a public exchange offer that closed on July 20, 2015.

The obligations under the CCLP Senior Notes are jointly and severally and fully and unconditionally, guaranteed on a senior unsecured basis by each of CCLP’s domestic restricted subsidiaries (other than CSI Compressco Finance) that guarantee CCLP’s other indebtedness (the "Guarantors" and together with the Issuers, the "Obligors"). The CCLP Senior Notes and the subsidiary guarantees thereof (together, the "CCLP Securities") were issued pursuant to an indenture described below.

The Obligors issued the CCLP Securities pursuant to the Indenture dated as of August 4, 2014 (the "Indenture") by and among the Obligors and U.S. Bank National Association, as trustee (the "Trustee"). The CCLP Senior Notes accrue interest at a rate of 7.25% per annum. Interest on the CCLP Senior Notes is payable semi-annually in arrears on February 15 and August 15 of each year. The CCLP Senior Notes are scheduled to mature on August 15, 2022.

The Indenture contains customary covenants restricting CCLP’s ability and the ability of its restricted subsidiaries to: (i) pay dividends and make certain distributions, investments and other restricted payments; (ii) incur additional indebtedness or issue certain preferred shares; (iii) create certain liens; (iv) sell assets; (v) merge, consolidate, sell or otherwise dispose of all or substantially all of its assets; (vi) enter into transactions with affiliates; and (vii) designate its subsidiaries as unrestricted subsidiaries under the Indenture. The Indenture also contains customary events of default and acceleration provisions relating to such events of default, which provide that upon an event of default under the Indenture, the Trustee or the holders of at least 25% in aggregate principal amount of the CCLP Senior Notes then outstanding may declare all amounts owing under the CCLP Senior Notes to be due and payable. CCLP is in compliance with all covenants of the CCLP Senior Note Purchase Agreement as of June 30, 2016.

Other Sources and Uses

In addition to the aforementioned revolving credit facilities, we and CCLP fund our respective short-term liquidity requirements from cash generated by our respective operations, leases, and from short-term vendor financing. Should additional capital be required, we believe that we have the ability to raise such capital through the

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issuance of additional debt or equity. However, instability or volatility in the capital markets at the times we need to access capital may affect the cost of capital and the ability to raise capital for an indeterminable length of time.

TETRA's Credit Agreement, as amended, matures in September 2019, the CCLP Credit Agreement matures in August 2019, TETRA's 11% Senior Notes mature in November 2022, and the CCLP Senior Notes mature in August 2022. The replacement of these capital sources at similar or more favorable terms is not certain. If it is necessary to issue additional equity to fund our capital needs, additional dilution to our common stockholders will occur.

Although near-term growth plans have been suspended and are subject to our efforts to conserve cash and rationalize our cost structure during the current period of low oil and natural gas prices, we maintain a long-term growth strategy for our core businesses. On March 23, 2016, we filed a universal shelf Registration Statement on Form S-3 with the Securities and Exchange Commission ("SEC"). On April 13, 2016, the Registration Statement on Form S-3 was declared effective by the SEC. Pursuant to this registration statement, we may sell debt or equity securities in one or more public offerings up to a total public offering price of $400 million. In June 2016, pursuant to this shelf registration statement, we completed an underwritten public offering of 11.5 million shares of our common stock, which included 1.5 million shares of common stock pursuant to an option granted to the underwriters to purchase additional shares, at a price to the public of $5.50 per share ($5.2525 per share net of underwriting discounts). We utilized the net offering proceeds of $60.4 million to repay the remaining balance outstanding of our Senior Secured Notes, to reduce the balance outstanding under our Credit Agreement, to pay offering related discounts and expenses, and for general corporate purposes. This shelf registration statement currently provides us additional flexibility with regard to potential financings that we may undertake when market conditions permit or our financial condition may require. As part of our long-term strategic growth plans, we will evaluate opportunities to acquire businesses and assets that may involve the payment of cash. Such acquisitions may be funded with existing cash balances, funds under credit facilities, or cash generated from the issuance of equity or debt securities. CCLP has also temporarily suspended many of its capital expenditure projects, CCLP's long-term growth objectives are funded from cash available under its credit facilities, other borrowings, cash generated from the issuance of its common units, as well as its available cash.

CCLP’s Partnership Agreement requires that within 45 days after the end of each quarter, it distribute all of its available cash, as defined in the Partnership Agreement, to its unitholders of record on the applicable record date. During the six months ended June 30, 2016, CCLP distributed $25.6 million, including $14.4 million to its non-affiliated unitholders.

Off Balance Sheet Arrangements

As of June 30, 2016, we had no “off balance sheet arrangements” that may have a current or future material effect on our consolidated financial condition or results of operations.

Commitments and Contingencies

Litigation

We are named defendants in several lawsuits and respondents in certain governmental proceedings arising in the ordinary course of business. While the outcome of lawsuits or other proceedings against us cannot be predicted with certainty, management does not consider it reasonably possible that a loss resulting from such lawsuits or other proceedings in excess of any amounts accrued has been incurred that is expected to have a material adverse impact on our financial condition, results of operations, or liquidity.

Other Contingencies

During 2011, in connection with the sale of a significant majority of Maritech’s oil and gas producing properties, the buyers of the properties assumed the associated decommissioning liabilities pursuant to the purchase and sale agreements. For oil and gas properties Maritech previously operated, the buyers of the properties assumed the financial responsibilities associated with the properties' operations, including abandonment and decommissioning, and generally became the successor operator. Some buyers of these Maritech properties subsequently sold certain of these properties to other buyers who also assumed these financial responsibilities associated with the properties' operations, and these buyers also typically became the successor operator of the properties. To the extent that a buyer of these properties fails to perform the abandonment and decommissioning

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work required, the previous owner, including Maritech, may be required to perform the abandonment and decommissioning obligation. A significant portion of the decommissioning liabilities that were assumed by the buyers of the Maritech properties in 2011 remains unperformed and we believe the amounts of these remaining liabilities are significant. We monitor the financial condition of the buyers of these properties from Maritech, and if current oil and natural gas pricing levels continue, we expect that one or more of these buyers may be unable to perform the decommissioning work required on the properties acquired from Maritech.

During the six months ended June 30, 2016, continued low oil and natural gas prices have resulted in reduced revenues and cash flows for all oil and gas producing companies, including those companies that bought Maritech properties in the past. Certain of these oil and gas producing companies that bought Maritech properties are currently experiencing severe financial difficulties. With regard to certain of these properties, Maritech has security in the form of bonds or cash escrows that are intended to secure the buyers' obligations to perform the decommissioning work. One company that bought, and subsequently resold, Maritech properties filed for Chapter 11 bankruptcy protection in August 2015. Maritech and its legal counsel continue to monitor the status of these companies. As of June 30, 2016, we do not consider the likelihood of Maritech becoming liable for decommissioning liabilities on sold properties to be probable.

Contractual Obligations

Our consolidated contractual obligations and commitments principally consist of obligations associated with our outstanding indebtedness, CCLP's outstanding indebtedness, product purchase obligations, decommissioning and other asset retirement obligations, and obligations under operating and capital leases. During the first six months of 2016, there were no material changes outside of the ordinary course of business in the specified contractual obligations.

For additional information about our contractual obligations as of December 31, 2015, see "Management's Discussion and Analysis of Financial Condition and Results of Operations" in our annual Report on Form 10-K for the year ended December 31, 2015.

Cautionary Statement for Purposes of Forward-Looking Statements

This Quarterly Report on Form 10-Q contains “forward-looking statements” within the meaning of Section 27A of the Securities Act of 1933, as amended and Section 21E of the Securities Exchange Act of 1934, as amended. Forward-looking statements in this quarterly report are identifiable by the use of words and other similar words: “anticipates", "assumes", “believes,” "budgets", “could,” “estimates,” "expects", "forecasts", "goal", "intends", "may", "might", "plans", "predicts", "projects", "schedules", "seeks", "should", "targets", "will", and "would".

Such forward-looking statements reflect our current views with respect to future events and financial performance and are based on assumptions that we believe to be reasonable but such forward-looking statements are subject to numerous risks, and uncertainties, including, but not limited to:

• economic and operating conditions that are outside of our control, including the supply, demand, and prices of crude oil and natural gas;

• the levels of competition we encounter;

• the activity levels of our customers;

• the availability of adequate sources of capital to us;

• our ability to comply with contractual obligations, including those under our financing arrangements;

• our operational performance;

• risks related to acquisitions and our growth strategy;

• the availability of raw materials and labor at reasonable prices;

• risks related to our foreign operations;

• the effect and results of litigation, regulatory matters, settlements, audits, assessments, and contingencies;

• information technology risks including the risk from cyberattack, and

• other risks and uncertainties under “Item 1A. Risk Factors” in our Annual Report on Form 10-K for the year ended December 31, 2015, those set forth in Item 1A "Risk Factors" in Part II of this Quarterly

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Report on Form 10-Q, and as included in our other filings with the U.S. Securities and Exchange Commission (“SEC”), which are available free of charge on the SEC website at www.sec.gov.

The risks and uncertainties referred to above are generally beyond our ability to control and we cannot predict all the risks and uncertainties that could cause our actual results to differ from those indicated by the forward-looking statements. If any of these risks or uncertainties materialize, or if any of the underlying assumptions prove incorrect, actual results may vary from those indicated by the forward-looking statements, and such variances may be material.

All subsequent written and oral forward-looking statements made by or attributable to us or to persons acting on our behalf are expressly qualified in their entirety by reference to these risks and uncertainties. You should not place undue reliance on forward-looking statements. Each forward-looking statement speaks only as of the date of the particular statement, and we undertake no obligation to update or revise any forward-looking statements we may make, except as may be required by law.

Item 3. Quantitative and Qualitative Disclosures about Market Risk.

Market risk is the risk of loss arising from adverse changes in market rates and prices. Fora discussion of our indirect exposure to fluctuatingcommodityprices, please read “Risk Factors —CertainBusinessRisks” in our Annual Report on Form 10-K filed with the SEC on March 4, 2016.We depend on U.S. and international demand for and production ofoil andnatural gas, and a reduction in this demand or production could adversely affect the demand or the prices we charge for our services, which could cause our revenuesand operating cash flows to decreasein thefuture.We do notcurrently hedge, and do notintend to hedge,our indirect exposure to fluctuating commodity prices.

Interest Rate Risk

Through June 30, 2016, there have been no material changes pertaining to our interest risk rate exposures as disclosed in our Form 10-K for the year ended December 31, 2015.

Exchange Rate Risk

As of June 30, 2016, there have been no material changes pertaining to our exchange rate exposures as disclosed in our Form 10-K for the year ended December 31, 2015.

Item 4. Controls and Procedures.

Under the supervision and with the participation of our management, including our Chief Executive Officer and Chief Financial Officer, we conducted an evaluation of our disclosure controls and procedures, as such term is defined under Rule 13a-15(e) promulgated under the Securities Exchange Act of 1934, as amended. Based on this evaluation, the Chief Executive Officer and Chief Financial Officer concluded that our disclosure controls and procedures were effective as of June 30, 2016, the end of the period covered by this quarterly report.

There were no changes in our internal control over financial reporting that occurred during the fiscal quarter ended June 30, 2016, that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

PART II

OTHER INFORMATION

Item 1. Legal Proceedings.

We are named defendants in several lawsuits and respondents in certain governmental proceedings arising in the ordinary course of business. While the outcome of lawsuits or other proceedings against us cannot be predicted with certainty, management does not consider it reasonably possible that a loss resulting from such lawsuits or other proceedings in excess of amounts accrued has been incurred that is expected to have a material adverse impact on our financial condition, results of operations, or liquidity.

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Environmental Proceedings

One of our subsidiaries, TETRA Micronutrients, Inc. ("TMI"), previously owned and operated a production facility located in Fairbury, Nebraska. TMI is subject to an Administrative Order on Consent issued to American Microtrace, Inc. (n/k/a/ TETRA Micronutrients, Inc.) in the proceeding styledIn the Matter of American Microtrace Corporation, EPA I.D. No. NED00610550, Respondent, Docket No. VII-98-H-0016, dated September 25, 1998 (the "Consent Order"), with regard to the Fairbury facility. TMI is liable for ongoing environmental monitoring at the Fairbury facility under the Consent Order; however, the current owner of the Fairbury facility is responsible for costs associated with the closure of that facility.While the outcome cannot be predicted with certainty, management does not consider it reasonably possible that a loss in excess of any amounts accrued has been incurred or is expected to have a material adverse impact on our financial condition, results of operations, or liquidity.

Item 1A. Risk Factors.

There have been no material changes in the information pertaining to our Risk Factors as disclosed in our Form 10-K for the year ended December 31, 2015, except for the following:

Deterioration of our financial ratios could result in covenant defaults under our long-term debt agreements and result in decreased credit availability.

As of June 30, 2016, our total debt outstanding included $101.6 million under our bank revolving credit agreement (as amended, the "Credit Agreement") and $117.4 million of our 11% Senior Notes due November 5, 2022 (the "11% Senior Notes"). In addition, our consolidated balance sheet includes $569.2 million of long-term debt of CCLP (consisting of $231.2 million under the CCLP Credit Agreement and $338.0 million under the CCLP Senior Notes). Additionalgrowth could result in increased debt levels to support our or CCLP's capital expenditure needs or acquisition activities. Debt service costs related to outstanding long-term debt represent a significant use of our operating cash flow and increase our vulnerability to general adverse economic and industry conditions.

Each of these long-term debt agreements contains customary covenants and other restrictions and requirements. The agreements require us to maintain certain financial ratios, including a minimum fixed charge coverage ratio and a maximum leverage ratio, both of which are defined in our Credit Agreement, and in the Amended and Restated Note Purchase Agreements relating to our 11% Senior Notes (the "Amended and Restated 11% Senior Note Agreement"). Deterioration of these ratios could result in a default under the agreements. Although these agreements include cross-default provisions relating to other of our indebtedness that is greater than a defined amount, we have no cross default provisions, cross collateralization provisions, or cross guarantees with CCLP's debt, nor does CCLP with our debt. If any of our indebtedness is not paid or is accelerated and such event is not remedied in a timely manner, a default will occur under our long-term debt agreements. Any event of default, if not timely remedied, could result in a termination of all commitments of our lenders thereunder and an acceleration of all amounts owed thereunder and of our senior notes.

Access to our revolving credit line is dependent upon our compliance with the financial ratio covenants set forth in the Credit Agreement, as amended. Following the Fourth Amendment to the Credit Agreement in July 2016, these financial ratios include a minimum fixed charge coverage ratio (ratio of a defined measure of earnings to interest) of 1.25 to 1 and a maximum leverage ratio (ratio of debt and letters of credit outstanding to a defined measure of earnings) of (a) 4.00 to 1 at the end of fiscal quarters ending during the period from and including June 30, 2016 through and including March 31, 2018, (b) 3.75 to 1 at the end of the fiscal quarters ending during the period from and including June 30, 2018 through and including December 31, 2018, and (c) 3.5 to 1 at the end of each of the fiscal quarters thereafter. Consolidated net earnings under our Credit Agreement is the aggregate of our net income (or loss) and the net income (or loss) of our consolidated restricted subsidiaries, including cash dividends and distributions (not the return of capital) received from persons other than consolidated restricted subsidiaries (such as distributions from CCLP) and after allowances for taxes for such period determined on a consolidated basis in accordance with U.S. generally accepted accounting principles ("GAAP"), excluding certain items more specifically described therein. This definition of consolidated net earnings excludes an amount of extraordinary and nonrecurring gains and losses up to 25% of a measure of earnings. Under the Amended and Restated 11% Senior Note Agreement, the financial ratio requirements include a minimum fixed charge coverage ratio of 1.1 to 1 and a maximum leverage ratio of 3.5 as of June 30, 2016, increasing to (a) 4.50 to1 as of the end of any fiscal quarter ending during the period commencing on July 1, 2016 and ending on March 31, 2018, (b) 4.25 to 1 as of the end of any fiscal quarter ending during the period commencing on June 30, 2018 and ending on

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December 31, 2018 and (c) 4.00 to 1 as of the end of any fiscal quarter ending thereafter. At June 30, 2016, our leverage ratio was 2.27 to 1 and our fixed charge coverage ratio was 4.32 to 1.

Our continuing ability to comply with these financial covenants depends largely upon our ability to generate adequate operating cash flows. Historically, our financial performance has been more than adequate to meet these covenants. Due to the decreased demand for certain of our products and services by our customers in response to decreased oil and natural gas prices, we have taken strategic cost reduction efforts, including headcount reductions, deferral of salary increases, salary reductions, and other efforts to reduce costs and generate cash to mitigate the reduced demand for our products and services. In addition, in June 2016 we utilized the $60.4 million of net proceeds from the issuance of 11.5 million shares of our common stock to repay the remaining balance outstanding under our senior secured notes, reduce borrowings outstanding under our Credit Agreement, and to pay for offering expenses. We believe the steps taken have enhanced our capital structure and operating cash flows and will continue to enhance our operating cash flows in the future. We and CCLP are in compliance with all covenants of our respective credit agreements and senior note agreements as of June 30, 2016. Based on our financial projections and including the impact of cost reduction efforts and expected activity levels on future estimated operating cash flows, we anticipate that, despite the current industry environment and activity levels, we will have sufficient operating cash flows to maintain compliance with the financial covenants under our long-term debt agreements through June 30, 2017. However, there can be no assurance that we will remain in compliance with these financial covenants going forward, and would consequently be in a condition of default under our Credit Agreement and 2015 11% Senior Notes if we were unable to obtain a waiver or amendment from our lenders. There can be no assurance that the cost reduction steps will be successful or that market conditions and operating performance will not be further decreased compared to our projections.

Deterioration of CCLP's financial ratios could result in covenant defaults under the CCLP Credit Agreement and result in decreased credit availability and reduced distributions to us.

CCLP has a credit agreement (as amended, the "CCLP Credit Agreement"),with a borrowing capacity of up to $340 million, subject to borrowing base requirements.As of June 30, 2016, CCLP's outstanding borrowings under the CCLP Credit Agreement were $231.2 million. In addition, as of August 8, 2016, CCLP has outstanding borrowings under the CCLP Credit Agreement of $230.0 million. In addition, CCLP has $350 million in aggregate principal amount of CCLP 7.25% Senior Notes outstanding. CCLP depends on the earnings and cash flow generated by its operations to meet its debt service obligations. Payment of CCLP's debt service obligations reduces cash available for distribution to its common unitholders including to us. The operating and financial restrictions and covenants applicable to the CCLP Credit Agreement and the CCLP 7.25% Senior Notes restrict its ability to take certain actions. Violations of these restrictions and covenants may result in a breach of, or CCLP's inability to borrow under, the CCLP Credit Agreement, including to fund distributions (if CCLP elected to do so).

The CCLP Credit Agreement contains covenants requiring CCLP to maintain (i) a consolidated interest coverage ratio (ratio of consolidated EBITDA to consolidated interest charges) of not less than 3.0 to 1; (ii) a consolidated total leverage ratio (ratio of consolidated total indebtedness to consolidated EBTIDA) of not more than (a) 5.50 to 1 as of June 30, 2016 and September 30, 2016; (b) 5.75 to 1 as of December 31, 2016, March 31, 2017, June 30, 2017 and September 30, 2017; (c) 5.50 to 1 as of December 31, 2017 and March 31, 2018; (d) 5.25 to 1 as of June 30, 2018 and September 30, 2018, and (e) 5.00 to 1 as of December 31, 2018 and thereafter; and (iii) a consolidated secured leverage ratio (consolidated secured indebtedness to consolidated EBITDA) of not more than 3.5 to 1, in each case calculated on a quarterly basis for the trailing four quarters. The CCLP Credit Agreement provides that CCLP may make distributions to holders of its common units, but only if there is no default under the CCLP Credit Agreement. CCLP's ability to comply with the covenants and restrictions contained in the CCLP Credit Agreement may be affected by events beyond its control, including prevailing economic, financial, and industry conditions. If market or other economic conditions deteriorate, CCLP's ability to comply with these covenants may be impaired. A failure to comply with the provisions of the CCLP Credit Agreement could result in an event of default. Upon an event of default, unless waived, the lenders under the CCLP Credit Agreement would have all remedies available to secured lenders and could elect to terminate their commitments, cease making further loans, require cash collateralization of letters of credit, cause their loans to become due and payable in full, institute foreclosure proceedings against CCLP or its subsidiaries’ assets, and force CCLP and its subsidiaries into bankruptcy or liquidation. If the payment of CCLP's debt is accelerated, its assets may be insufficient to repay such debt in full, and the holders of CCLP common units, including us, could experience a partial or total loss of their investment. An event of default by CCLP under the CCLP Credit Agreement could also result in a default under the CCLP 7.25% Senior Notes

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CCLP is in compliance with all covenants of the CCLP Credit Agreement as of June 30, 2016. At June 30, 2016, the CCLP consolidated total leverage ratio was 5.04 to 1 and the CCLP interest coverage ratio was 3.81 to 1. CCLP's continuing ability to comply with its financial covenants depends largely upon CCLP's ability to generate adequate cash flow. Historically, CCLP financial performance has been more than adequate to meet these covenants, and CCLP expects this trend to continue. However, as a result of the recent decreased demand for certain of CCLP's products and services by CCLP's customers in response to decreased oil and natural gas prices beginning in 2014, and CCLP's expectation that the reduced demand will continue for an indefinite period, CCLP has taken strategic cost reduction efforts, including headcount reductions, deferral of salary increases, salary reductions, and other efforts to reduce costs and generate cash. In August 2016, CCLP completed a private placement of CCLP Preferred Units and will use the $49.8 million of net proceeds to pay other offering expenses and reduce outstanding indebtedness of CCLP. CCLP believes the steps taken have enhanced its operating cash flows and preserved its cash, and additional steps may be taken to continue to enhance its operating cash flows and preserve cash in the future. Considering financial forecasts based on current market conditions as of August 9, 2016, there can be no assurance that CCLP will remain in compliance with these financial covenants of the CCLP Credit Agreement in the future.

We may have continuing exposure on abandonment and decommissioning obligations associated with oil and gas properties sold by Maritech.

During 2011, in connection with the sale of a significant majority of Maritech’s oil and gas producing properties, the buyers of the properties assumed the associated decommissioning liabilities having a value at the time of sale of approximately $122.0million pursuant to the purchase and sale agreements. For oil and gas properties Maritech previously operated, the buyer of the properties assumed the financial responsibilities associated with the properties' operations, including abandonment and decommissioning, and generally became the successor operator. Some buyers of these Maritech properties subsequently sold certain of these properties to other buyers who also assumed the financial responsibilities associated with the properties' operations, and these buyers also typically became the successor operator of the properties. To the extent that a buyer of these properties fails to perform the abandonment and decommissioning work required, the previous owner, including Maritech, may be required to perform the abandonment and decommissioning obligation. A significant portion of the decommissioning liabilities that were assumed by the buyers of the Maritech properties in 2011 remains unperformed and we believe the amounts of these remaining liabilities are significant. We monitor the financial condition of the buyers of these properties from Maritech, and if current oil and natural gas pricing levels continue or deteriorate further, we expect that one or more of these buyers may be unable to perform the decommissioning work required on properties they acquired from Maritech. To the extent Maritech is required to perform a significant portion of the abandonment and decommissioning obligations associated with these previously owned oil and gas properties, our financial condition and results of operations may be negatively affected.

During the six months ended June 30, 2016, continued low oil and natural gas prices have resulted in reduced revenues and cash flows for all oil and gas producing companies, including those companies that bought Maritech properties in the past. Certain of these oil and gas producing companies that bought Maritech properties are currently experiencing severe financial difficulties. With regard to certain of these properties, Maritech has security in the form of bonds or cash escrows that are intended to secure the buyers' obligations to perform the decommissioning work. One company that bought, and subsequently resold, Maritech properties filed for Chapter 11 bankruptcy protection in August 2015. Maritech estimates that of the total amount of decommissioning liabilities associated with properties sold to this company, Maritech is exposed to a high level of risk on properties that had decommissioning liabilities at the time they were sold in 2011 of approximately $6 million. Some of these liabilities are currently part of a liquidation plan being administered for this company. This amount, which is net to Maritech's interest, may not be representative of the current fair value of these obligations and does not reflect the potential benefit of bonding that may be available to Maritech if it were to be required to perform such obligations. Maritech and its legal counsel monitor the status of these companies. There can be no assurance that Maritech will not become legally responsible to perform decommissioning work on properties it previously sold, resulting in charges to our future earnings and increases to our future operating cash requirements.

We are exposed to significant credit risks.

We face credit risk associated with the significant amounts of accounts receivable we have with our customers in the energy industry. Many of our customers, particularly those associated with our onshore operations, are small- to medium-sized oil and gas operators that may be more susceptible to declines in oil and gas

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commodity prices or generally increased operating expenses than larger companies. Our ability to collect from our customers is impacted by the current decreased oil and natural gas price environment.

As the owner and operator of its oil and gas property interests, Maritech is liable for the proper abandonment and decommissioning of these properties. We have guaranteed a portion of the abandonment and decommissioning liabilities of Maritech. With respect to certain properties, Maritech is entitled to be paid in the future for all or a portion of these obligations by the previous owner of the property once the liability is satisfied. We and Maritech are subject to the risk that the previous owner(s) will be unable to make these future payments. In addition, for certain remaining Maritech properties to be decommissioned or abandoned, theco-ownersof such propertiesare responsible for the payment of their portions of the associated operating expenses and abandonment liabilities. However, if one or more co-owners do not pay their portions, Maritech and any other nondefaulting co-owners may be liable for the defaulted amount. If any required payment is not made by a previous owner or a co-owner and any security is not sufficient to cover the required payment, we could suffer material losses.

During the six months ended June 30, 2016, continued decreased oil and natural gas prices have resulted in reduced revenues and cash flows for oil and gas producing companies, including companies that are joint-owners in Maritech oil and gas properties and decommissioning obligations currently owned or from whom Maritech is entitled to receive payments upon satisfaction of certain decommissioning obligations. Certain of these previous owners of Maritech properties who are obligated to pay Maritech in the future are currently experiencing severe financial difficulties and have filed for bankruptcy protection. During the three month period ended June 30, 2016, Maritech charged to earnings $2.8 million of such contractual payment receivables no longer considered realizable. The majority of the remaining amounts owed to Maritech by these companies are not contractually required to be paid to Maritech until several years in the future. Nevertheless, we are monitoring the financial condition of these companies, and if current oil and natural gas pricing levels continue, certain of these companies may be unable to pay Maritech for contractual amounts owed. Maritech intends to take any action necessary to protect Maritech's interests. Although certain of these decommissioning obligations may not be performed for many years, there can be no assurance that the current oil and gas price environment will not result in additional charges to our future earnings and increases to our future operating cash requirements.

New federal requirements for financial assurance on offshore oil and gas decommissioning obligations may restrict our borrowing capacity.

Through our Maritech subsidiary, we have interests in oil and gas production platforms and facilities in the U.S. Gulf of Mexico. As of June 30, 2016, Maritech’s decommissioning liabilities associated with its remaining offshore oil and gas production wells, platforms, and facilities totaled approximately $45.6 million. In July 2016, the Bureau of Ocean Engineering Management ("BOEM") notified companies holding oil and gas leases in federal waters that it is updating financial assurance and risk management requirements to ensure that U.S. taxpayers never have to pay for decommissioning and removing a company’s offshore production facilities. The issuance of Notice to Lessees No. 2016-N01 ("NTL 2016-N01"), which becomes effective September 12, 2016, provides updated procedures for requiring additional financial security for oil and gas or sulphur leases. The NTL 2016-N01 will provide updated criteria for determining a lessee's ability to self-insure its decommissioning liabilities on the outer continental shelf of the U.S. Gulf of Mexico based on the lessee's financial capacity and financial strength. It also provides new methods and additional flexibility for lessees to meet their additional financial security requirements through a tailored plan. The guidance and clarification will apply to all BOEM regions and planning areas. In addition to lease holders, the NTL also applies to right of use and easement holders.

The issuance of NTL 2016-N01 may require us, and our Maritech subsidiary, to increase or modify the type of financial assurance we provide in connection with Maritech's remaining decommissioning obligations. Such requirements may include the provision of new or increased bonding or other collateral that could serve to reduce the amount of borrowing capacity we have under our Credit Agreement, thus reducing our liquidity.

The Series A Convertible Preferred Units of CCLP issued onAugust 2016(the "CCLP Preferred Units") are senior in right of distributions, liquidation and voting to the common units, and will result in the issuance of additional CCLP common units in the future, resulting in dilution of our existing common unit ownership in CCLP, and such dilution is potentially unlimited.

CCLP's partnership agreement does not limit the number of additional common units that CCLP may issue at any time without the approval of its common unitholders. In addition, subject to the provisions of the August 8, 2016 CCLP Series A Preferred Unit Purchase Agreement, CCLP may issue an unlimited number of partnership

55

units that are senior to the common units in right of distribution, liquidation, or voting. On August 8, 2016, CCLP issued an aggregate of 4,374,454 of CCLP Preferred Units for a cash purchase price of $11.43 per CCLP Preferred Unit (the “Issue Price”), resulting in total net proceeds, after deducting certain offering expenses, of $49.8 million. We purchased 874,891 of the CCLP Preferred Units at the Issue Price, aggregating $10.0 million.

Pursuant to the CCLP Series A Convertible Unit Purchase Agreement, our wholly owned CSI Compressco GP Inc subsidiary (the general partner of CCLP), executed the Second Amended and Restated Agreement of Limited Partnership of the Partnership (the “Amended and Restated CCLP Partnership Agreement”) to, among other things, authorize and establish the rights and preferences of the CCLP Preferred Units. The CCLP Preferred Units are a new class of equity security that ranks senior to CCLP's common units with respect to distribution rights and rights upon liquidation. The holders of CCLP Preferred Units (each, a “CCLP Preferred Unitholder”) will receive quarterly distributions in kind in additional Preferred Units, equal to an annual rate of 11.00% of the Issue Price ($1.2573 per unit annualized), subject to certain adjustments, including adjustments relating to any future issuances of common units below a set price. Beginning on the first Trading Day (as defined in the Amended and Restated CCLP Partnership Agreement) after the seventh calendar month following the closing date and on the first Trading Day of each calendar month thereafter for a total of thirty months (each, a “Conversion Date”), the CCLP Preferred Units will convert into common units in an amount equal to, with respect to each CCLP Preferred Unitholder, the number of CCLP Preferred Units held by such CCLP Preferred Unitholder divided by the number of Conversion Dates remaining. CCLP may, at its option, pay cash, or a combination of cash and common units, to the CCLP Preferred Unitholders instead of issuing common units on any Conversion Date, subject to certain restrictions as described in the Amended and Restated CCLP Partnership Agreement and the CCLP Credit Agreement.

Because we own 42.4% of the outstanding CCLP common units, 20% of the newly issued CCLP Preferred Units, and approximately 2% general partner interest in CCLP (including incentive distribution rights), the issuance by CCLP of the CCLP Preferred Units will have the following effects:

• our previously existing common unitholders’ proportionate ownership interests in CCLP will decrease;

• the amount of cash available for distribution on each CCLP common unit may decrease;

• the relative voting power of our previously existing CCLP common unitholder interest will be diminished; and

• the market price of CCLP common units may decline.

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

(a) None.

(b) None.

(c) Purchases of Equity Securities by the Issuer and Affiliated Purchasers.

Period	Total Number of Shares Purchased		Average Price Paid per Share		Total Number of Shares Purchased as Part of Publicly Announced Plans or Programs(1)	Maximum Number (or Approximate Dollar Value) of Shares that May Yet be Purchased Under the Publicly Announced Plans or Programs(1)
April 1 – April 30, 2016	1,217	(2)	$	6.00	—	$	14,327,000
May 1 – May 31, 2016	51,314	(2)	6.38		—	14,327,000
June 1 – June 30, 2016	1,138	(2)	5.60		—	14,327,000
Total	53,669				—	$	14,327,000

(1) In January 2004, our Board of Directors authorized the repurchase of up to $20 million of our common stock.Purchases will be made from time to time in open market transactions at prevailing market prices. The repurchase program may continue until the authorized limit is reached, at which time the Board of Directors may review the option of increasing the authorized limit.

(2) Shares we received in connection with the exercise of certain employee stock options or the vesting of certain shares of employee restricted stock. These shares were not acquired pursuant to the stock repurchase program.

Item 3. Defaults Upon Senior Securities.

None.

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Item 4.Mine Safety Disclosures.

None.

Item 5. Other Information.

None.

Item 6. Exhibits.

Exhibits:

3.1*	Certificate of Amendment of Restated Certificate of Incorporation of TETRA Technologies, Inc.
10.1	Third Amended and Restated 2011 Long Term Incentive Compensation Plan (incorporated by reference to Exhibit 10.1 to the Company's Form 8-K filed on May 6, 2016 (SEC File No. 001-13455)).
10.2	Third Amendment to Credit Agreement dated May 25, 2016, by and among CSI Compressco LP, CSI Compressco Sub Inc., Bank of America, N.A., in its capacity as administrative agent, collateral agent, lender, letter of credit issuer and swing line issuer, and the other lenders and loan parties a party thereto (incorporated by reference to Exhibit 10.1 to the Company's Form 8-K filed on May 25, 2016 (SEC File No. 001-13455)).
31.1*	Certification Pursuant to Rule 13a-14(a) or 15d-14(a) of the Exchange Act, As Adopted Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
31.2*	Certification Pursuant to Rule 13a-14(a) or 15d-14(a) of the Exchange Act, As Adopted Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
32.1**	Certification Furnished Pursuant to 18 U.S.C. Section 1350, As Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
32.2**	Certification Furnished Pursuant to 18 U.S.C. Section 1350, As Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
101.INS+	XBRL Instance Document.
101.SCH+	XBRL Taxonomy Extension Schema Document.
101.CAL+	XBRL Taxonomy Extension Calculation Linkbase Document.
101.LAB+	XBRL Taxonomy Extension Label Linkbase Document.
101.PRE+	XBRL Taxonomy Extension Presentation Linkbase Document.
101.DEF+	XBRL Taxonomy Extension Definition Linkbase Document.

* Filed with this report.

** Furnished with this report.

+ Attached as Exhibit 101 to this report are the following documents formatted in XBRL (Extensible Business Reporting Language): (i) Consolidated Statements of Operations for the three and six month periods ended June 30, 2016 and 2015; (ii) Consolidated Statements of Comprehensive Income for the three and six month periods ended June 30, 2016 and 2015; (iii) Consolidated Balance Sheets as of June 30, 2016 and December 31, 2015; (iv) Consolidated Statements of Cash Flows for the six month periods ended June 30, 2016 and 2015; and (v) Notes to Consolidated Financial Statements for the six months ended June 30, 2016.

A statement of computation of per share earnings is included in Note A of the Notes to Consolidated Financial Statements included in this report and is incorporated by reference into Part II of this report.

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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.

		TETRA Technologies, Inc.
Date:	August 9, 2016	By:	/s/Stuart M. Brightman
			Stuart M. Brightman
			President
			Chief Executive Officer
Date:	August 9, 2016	By:	/s/Elijio V. Serrano
			Elijio V. Serrano
			Senior Vice President
			Chief Financial Officer
Date:	August 9, 2016	By:	/s/Ben C. Chambers
			Ben C. Chambers
			Vice President – Accounting
			Principal Accounting Officer

58

EXHIBIT INDEX

3.1*	Certificate of Amendment of Restated Certificate of Incorporation of TETRA Technologies, Inc.
10.1	Third Amended and Restated 2011 Long Term Incentive Compensation Plan (incorporated by reference to Exhibit 10.1 to the Company's Form 8-K filed on May 6, 2016 (SEC File No. 001-13455)).
10.2	Third Amendment to Credit Agreement dated May 25, 2016, by and among CSI Compressco LP, CSI Compressco Sub Inc., Bank of America, N.A., in its capacity as administrative agent, collateral agent, lender, letter of credit issuer and swing line issuer, and the other lenders and loan parties a party thereto (incorporated by reference to Exhibit 10.1 to the Company's Form 8-K filed on May 25, 2016 (SEC File No. 001-13455)).
31.1*	Certification Pursuant to Rule 13a-14(a) or 15d-14(a) of the Exchange Act, As Adopted Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
31.2*	Certification Pursuant to Rule 13a-14(a) or 15d-14(a) of the Exchange Act, As Adopted Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
32.1**	Certification Furnished Pursuant to 18 U.S.C. Section 1350, As Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
32.2**	Certification Furnished Pursuant to 18 U.S.C. Section 1350, As Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
101.INS+	XBRL Instance Document.
101.SCH+	XBRL Taxonomy Extension Schema Document.
101.CAL+	XBRL Taxonomy Extension Calculation Linkbase Document.
101.LAB+	XBRL Taxonomy Extension Label Linkbase Document.
101.PRE+	XBRL Taxonomy Extension Presentation Linkbase Document.
101.DEF+	XBRL Taxonomy Extension Definition Linkbase Document.

* Filed with this report.

** Furnished with this report.

+ Attached as Exhibit 101 to this report are the following documents formatted in XBRL (Extensible Business Reporting Language): (i) Consolidated Statements of Operations for the three and six month periods ended June 30, 2016 and 2015; (ii) Consolidated Statements of Comprehensive Income for the three and six month periods ended June 30, 2016 and 2015; (iii) Consolidated Balance Sheets as of June 30, 2016 and December 31, 2015; (iv) Consolidated Statements of Cash Flows for the six month periods ended June 30, 2016 and 2015; and (v) Notes to Consolidated Financial Statements for the six months ended June 30, 2016.

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