TETRA TECHNOLOGIES INC - Quarter Report: 2011 June (Form 10-Q)

tti10q-20110809.htm

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 ENDED JUNE 30, 2011

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

OF THE SECURITIES EXCHANGE ACT OF 1934

FOR THE TRANSITION PERIOD FROM TO

COMMISSION FILE NUMBER 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 [ X ]	Accelerated filer [ ]
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 of August 5, 2011, there were 77,179,949 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						Six Months Ended
	June 30,						June 30,
	2011			2010			2011			2010
Revenues:
Product sales	$	105,290		$	113,915		$	211,813		$	217,108
Services and rentals		129,824			127,703			245,846			230,403
Total revenues		235,114			241,618			457,659			447,511

Cost of revenues:
Cost of product sales		82,686			71,327			159,704			136,259
Cost of services and rentals		79,678			76,824			161,449			145,857
Depreciation, depletion, amortization, and accretion		36,937			45,635			74,329			82,469
Total cost of revenues		199,301			193,786			395,482			364,585
Gross profit		35,813			47,832			62,177			82,926

General and administrative expense		29,006			24,955			56,768			47,732
Interest expense, net		4,085			4,238			8,276			8,266
(Gain) loss on sale of assets		(59,577	)		157			(60,309	)		250
Other (income) expense, net		14,745			(2,056	)		13,929			(2,332	)
Income before taxes and discontinued operations		47,554			20,538			43,513			29,010
Provision for income taxes		17,031			6,903			15,502			9,919
Income before discontinued operations		30,523			13,635			28,011			19,091
Loss from discontinued operations, net of taxes		(54	)		(75	)		(57	)		(104	)
Net income		30,469			13,560			27,954			18,987
Net (income) loss attributable to noncontrolling interest		(95	)		-			(95	)		-
Net income attributable to TETRA stockholders	$	30,374		$	13,560		$	27,859		$	18,987

Basic net income per common share:
Income before discontinued operations attributable to
TETRA stockholders	$	0.40		$	0.18		$	0.36		$	0.25
Loss from discontinued operations attributable to
TETRA stockholders		(0.00	)		(0.00	)		(0.00	)		(0.00	)
Net income attributable to TETRA stockholders	$	0.40		$	0.18		$	0.36		$	0.25
Average shares outstanding		76,579			75,491			76,415			75,434

Diluted net income per common share:
Income before discontinued operations attributable to
TETRA stockholders	$	0.39		$	0.18		$	0.36		$	0.25
Loss from discontinued operations attributable to
TETRA stockholders		(0.00	)		(0.00	)		(0.00	)		(0.00	)
Net income attributable to TETRA stockholders	$	0.39		$	0.18		$	0.36		$	0.25
Average diluted shares outstanding		78,315			76,857			77,985			76,819

See Notes to Consolidated Financial Statements

TETRA Technologies, Inc. and Subsidiaries

Consolidated Balance Sheets

(In Thousands)

	June 30, 2011			December 31, 2010
	(Unaudited)
ASSETS
Current assets:
Cash and cash equivalents	$	323,774		$	65,360
Restricted cash		102			360
Trade accounts receivable, net of allowances for doubtful
accounts of $2,591 in 2011 and $2,590 in 2010		161,082			162,405
Inventories		94,945			104,305
Derivative assets		-			2,436
Deferred tax asset		32,575			29,685
Oil and gas properties held for sale		9,215			-
Prepaid expenses and other current assets		22,568			50,387
Total current assets		644,261			414,938

Property, plant, and equipment
Land and building		76,994			79,368
Machinery and equipment		445,450			482,677
Automobiles and trucks		46,315			43,492
Chemical plants		157,637			176,853
Oil and gas producing assets (successful efforts method)		-			761,449
Construction in progress		22,689			15,677
Total property, plant, and equipment		749,085			1,559,516
Less accumulated depreciation and depletion		(281,968	)		(819,646	)
Net property, plant, and equipment		467,117			739,870

Other assets:
Goodwill		99,132			99,005
Patents, trademarks and other intangible assets, net of accumulated
amortization of $21,512 in 2011 and $21,499 in 2010		13,246			13,024
Deferred tax assets		12			899
Other assets		27,184			31,892
Total other assets		139,574			144,820
Total assets	$	1,250,952		$	1,299,628

See Notes to Consolidated Financial Statements

TETRA Technologies, Inc. and Subsidiaries

Consolidated Balance Sheets

(In Thousands)

	June 30, 2011			December 31, 2010
	(Unaudited)
LIABILITIES AND EQUITY
Current liabilities:
Trade accounts payable	$	50,931		$	55,555
Accrued liabilities		78,129			83,804
Decommissioning and other asset retirement obligations, net		89,390			72,265
Derivative liabilities		-			5,208
Total current liabilities		218,450			216,832

Long-term debt, net		305,035			305,035
Deferred income taxes		59,677			46,789
Decommissioning and other asset retirement obligations, net		55,135			200,550
Other liabilities		11,047			14,099
Total long-term liabilities		430,894			566,473
Commitments and contingencies

Equity:
TETRA stockholders' equity:
Common stock, par value $0.01 per share; 100,000,000 shares
authorized; 78,843,704 shares issued at June 30, 2011,
and 77,825,398 shares issued at December 31, 2010		788			778
Additional paid-in capital		210,558			203,044
Treasury stock, at cost; 1,696,989 shares held at June 30, 2011,
and 1,533,653 shares held at December 31, 2010		(9,836	)		(8,382	)
Accumulated other comprehensive income		9,483			1,107
Retained earnings		347,635			319,776
Total TETRA stockholders' equity		558,628			516,323
Noncontrolling interest		42,980			-
Total equity		601,608			516,323
Total liabilities and equity	$	1,250,952		$	1,299,628

See Notes to Consolidated Financial Statements

TETRA Technologies, Inc. and Subsidiaries

Consolidated Statements of Cash Flows

(In Thousands)

(Unaudited)

	Six Months Ended June 30,
	2011			2010
Operating activities:
Net income	$	27,954		$	18,987
Reconciliation of net income to cash provided by operating activities:
Depreciation, depletion, amortization, and accretion		61,795			72,542
Impairments of long-lived assets		12,534			9,927
Provision (benefit) for deferred income taxes		9,754			(1,217	)
Stock compensation expense		3,140			3,055
Provision (benefit) for doubtful accounts		974			(1,302	)
(Gain) loss on sale of property, plant, and equipment		(60,309	)		250
Non-cash income from sold hedge derivatives		-			(11,161	)
Other non-cash charges and credits		19,997			2,370
Proceeds from insurance settlements		-			39,772
Changes in operating assets and liabilities:
Accounts receivable		597			(1,802	)
Inventories		11,812			12,445
Prepaid expenses and other current assets		28,952			(557	)
Trade accounts payable and accrued expenses		(17,608	)		(19,672	)
Decommissioning liabilities		(43,572	)		(33,796	)
Operating activities of discontinued operations		35			(380	)
Other		3,859			993
Net cash provided by operating activities		59,914			90,454

Investing activities:
Purchases of property, plant, and equipment		(36,284	)		(33,866	)
Business combinations		(1,500	)		-
Proceeds from sale of property, plant, and equipment		187,384			353
Other investing activities		(4,929	)		(303	)
Net cash provided by (used in) investing activities		144,671			(33,816	)

Financing activities:
Proceeds from long-term debt		-			35
Proceeds from exercise of stock options		2,245			732
Proceeds from issuance of Compressco Partners' common units,
net of underwriters' discount		50,234			-
Compressco Partners' offering costs		(2,038	)		-
Excess tax benefit from exercise of stock options		1,394			250
Net cash provided by financing activities		51,835			1,017

Effect of exchange rate changes on cash		1,994			(1,822	)

Increase in cash and cash equivalents		258,414			55,833
Cash and cash equivalents at beginning of period		65,360			33,394
Cash and cash equivalents at end of period	$	323,774		$	89,227

Supplemental cash flow information:
Interest paid	$	9,073		$	9,007
Income taxes paid (refunded)		(16,138	)		25,391

Supplemental disclosure of non-cash investing activities:
Adjustment of fair value of decommissioning liabilities
capitalized to oil and gas properties	$	1,810		$	4,447

See Notes to Consolidated Financial Statements

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 services, production testing, wellhead compression, and selected offshore services including well plugging and abandonment, decommissioning, and diving. We were incorporated in Delaware in 1981. We are composed of five reporting segments organized into three divisions – Fluids, Offshore, and Production Enhancement. Included in our Offshore Division is our Maritech segment, an oil and gas exploration and production business that sold approximately 95% of its proved oil and gas reserves in the first eight months of 2011, and whose continuing operations consist primarily of the ongoing well plugging, abandonment, and decommissioning associated with its remaining offshore production platforms. 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.

The consolidated financial statements include the accounts of our wholly owned subsidiaries. Investments in unconsolidated joint ventures in which we participate are accounted for using the equity method. Our interests in oil and gas properties are proportionately consolidated. All significant intercompany accounts and transactions have been eliminated in consolidation.

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. However, 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. The accompanying unaudited consolidated financial statements should be read in conjunction with the audited financial statements for the year ended December 31, 2010.

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.

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, 2011, reflects the assignment during March 2011 of restricted cash to the landowner of one of our former Fluids Division leased facility locations related to agreed repairs to be expended at the facility.

Inventories

Inventories are stated at the lower of cost or market value and consist primarily of finished goods. Cost is determined using the weighted average method. Significant components of inventories as of June 30, 2011, and December 31, 2010, are as follows:

	June 30, 2011		December 31, 2010
	(In Thousands)

Finished goods	$	67,964	$	75,874
Raw materials		3,611		5,103
Parts and supplies		22,361		22,457
Work in progress		1,009		871
Inventories	$	94,945	$	104,305

Finished goods inventories include, in addition to newly manufactured clear brine fluids, recycled brines that are repurchased from certain of our customers. Recycled brines are recorded at cost, using the weighted average method.

Net Income 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 per common and common equivalent share:

	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2011		2010		2011		2010
Number of weighted average common
shares outstanding		76,578,565		75,491,288		76,415,527		75,433,742
Assumed exercise of stock options		1,736,132		1,366,009		1,569,904		1,385,443
Average diluted shares outstanding		78,314,697		76,857,297		77,985,431		76,819,185

In applying the treasury stock method to determine the dilutive effect of the stock options outstanding during the first six months of 2011, we used the average market price of our common stock of $13.09. For the three months ended June 30, 2011 and 2010, the calculations of the average diluted shares outstanding excludes the impact of 1,733,435 and 2,110,024 outstanding stock options, respectively, that have exercise prices in excess of the average market price, as the inclusion of these shares would have been antidilutive. For the six months ended June 30, 2011 and 2010, the calculations of the average diluted shares outstanding excludes the impact of 1,783,096 and 2,130,597 outstanding stock options, respectively, that have exercise prices in excess of the average market price, as the inclusion of these shares would have been antidilutive.

Environmental Liabilities

Environmental expenditures that result in additions to property and equipment are capitalized, while other environmental expenditures are expensed. Environmental remediation liabilities are recorded on an undiscounted basis when environmental assessments or cleanups are probable and the costs can be reasonably estimated. Estimates of future environmental remediation expenditures often consist of a range of possible expenditure amounts, a portion of which may be in excess of amounts of liabilities recorded. In this instance, we disclose the full range of amounts reasonably possible of being incurred. Any changes or developments in environmental remediation efforts are accounted for and disclosed each quarter as they occur. Any recoveries of environmental remediation costs from other parties are recorded as assets when their receipt is deemed probable.

Complexities involving environmental remediation efforts can cause the estimates of the associated liability to be imprecise. Factors that cause uncertainties regarding the estimation of future expenditures include, but are not limited to, the effectiveness of the anticipated work plans in achieving targeted results and changes in the desired remediation methods and outcomes as prescribed by regulatory agencies. Uncertainties associated with environmental remediation contingencies are pervasive and often result in wide ranges of reasonably possible outcomes. Estimates developed in the early stages of remediation can vary significantly. Normally, a finite estimate of cost does not become fixed and determinable at a specific point in time. Rather, the costs associated with environmental remediation become estimable as the work is performed and the range of ultimate cost becomes more defined. It is possible that cash flows and results of operations could be materially affected by the impact of the ultimate resolution of these contingencies.

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 generally accepted accounting principles, 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. 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. The fair value of our financial instruments, which may include cash, temporary investments, accounts receivable, short-term borrowings, and long-term debt pursuant to our bank credit agreement, approximate their carrying amounts. The fair value of our long-term Senior Notes at June 30, 2011, was approximately $319.9 million compared to a carrying amount of approximately $305.0 million, as current rates are more favorable than the Senior Note interest rates. We calculate the fair value of our Senior Notes internally, using current market conditions and average cost of debt. We have not calculated or disclosed recurring fair value measurements of non-financial assets and non-financial liabilities.

During the second quarter of 2011, in connection with the sale of substantially all of our Maritech oil and gas producing properties, we liquidated our derivative contracts by paying $14.2 million to the counterparty. For further discussion see Note F – Hedge Contracts.

During the second quarter of 2011, Maritech recorded impairment charges of approximately $9.2 million associated with its remaining oil and gas properties. Throughout the first six months of 2011, Maritech sold approximately 92% of its oil and gas reserves as of December 31, 2010, and is seeking to sell its remaining properties at current market values. Accordingly, all of Maritech’s remaining oil and gas properties as of June 30, 2011, have been reclassified to oil and gas properties held for sale and their net book values have been adjusted to fair value less cost to sell. Fair values are estimated based on current market prices being received for these properties’ expected future production cash flows, using forward oil and natural gas pricing data from published sources. Because such published forward pricing data was applied to estimated oil and gas reserve volumes based on our internally prepared reserve estimates, such fair value calculation is based on significant unobservable inputs (Level 3) in accordance with the fair value hierarchy.

A summary of the nonrecurring fair value measurements discussed above as of June 30, 2011 and 2010, using the fair value hierarchy is as follows:

Fair Value Measurements as of

June 30, 2011 Using

Quoted Prices in

Active Markets for

Significant Other

Significant

Total Fair

Identical Assets

Observable

Unobservable

Year-to-Date

Value as of

or Liabilities

Inputs

Impairment

Description

June 30, 2011

(Level 1)

(Level 2)

(Level 3)

Losses

(In Thousands)

Oil and gas properties

9,215

12,534

Total

9,215

12,534

			Fair Value Measurements as of
	June 30, 2010 Using
			Quoted Prices in
			Active Markets for		Significant Other		Significant
	Total Fair		Identical Assets		Observable		Unobservable		Year-to-Date
	Value as of		or Liabilities		Inputs		Inputs		Impairment
Description	June 30, 2010		(Level 1)		(Level 2)		(Level 3)		Losses
	(In Thousands)
Oil and gas properties	$	8,460	$	-	$	-	$	8,460	$	8,859
Other properties		2,415		-		-		2,415		1,068
Total	$	10,875							$	9,927

NOTE B – ACQUISITIONS AND DISPOSITIONS

In March 2011, we acquired a project management and engineering consulting services business that provides liability and risk assessment services for domestic and international offshore well abandonment and decommissioning projects. The purchase price for this acquisition was $1.5 million, and the assets acquired consist primarily of intangible assets.

In late 2010, we began to decrease our investment in Maritech by suspending oil and gas property acquisitions, decreasing our development activities, exploring strategic alternatives to our ownership of Maritech and its oil and gas properties, and reviewing opportunities to sell Maritech oil and gas property packages to industry participants and other third parties. As part of this overall effort, in February and March 2011, Maritech sold certain properties, along with the associated decommissioning liabilities. As part of these transactions, Maritech paid an aggregate of approximately $2.8 million after normal purchase price adjustments. These sold properties, in the aggregate, accounted for approximately 12% of Maritech’s proved reserves as of December 31, 2010.

On May 31, 2011, Maritech completed the sale of approximately 79% of its proved oil and gas reserves as of December 31, 2010, to Tana Exploration Company LLC (Tana), a subsidiary of TRT Holdings, Inc. (TRT), pursuant to a Purchase and Sale Agreement dated April 1, 2011. The sale was made to Tana for a base purchase price of $222.3 million. At the closing of the sale, Tana assumed approximately $72.7 million of associated asset retirement obligations, and Maritech received $173.3 million cash, representing the base purchase price less $11.1 million that was prepaid in April 2011 and purchase price adjustments, including those adjustments reflecting cash flows subsequent to the January 1, 2011, effective date. The proceeds are subject to additional post-closing adjustments. As a result of the sale, we recorded a consolidated gain on sale of assets of $58.2 million. Due to Maritech’s continuing efforts to sell its remaining oil and gas properties, all of Maritech’s remaining oil and gas properties have been reclassified to oil and gas properties held for sale, and their net book values have been adjusted to fair value. In connection with the sale of Maritech oil and gas producing properties, during the second quarter of 2011, we charged to general and administrative expenses approximately $2.7 million of employee retention and incentive benefits paid in connection with these sales.

In August 2011, Maritech sold an additional remaining oil and gas property in exchange for the purchaser assuming the associated decommissioning liability. The sold property represents approximately 3% of Maritech’s yearend oil and gas reserves.

On July 20, 2011, we acquired a new heavy lift derrick barge (which we have named the TETRA Hedron) with a 1,600-metric-ton lift capacity, fully revolving crane. The vessel was purchased from Wison (Nantong) Heavy Industry Co., Ltd. and Nantong MLC Tongbao Shipbuilding Co., Ltd. for $62.8 million. Approximately $20.8 million of the purchase price is held in certain escrow accounts and will be released to the sellers in accordance with the terms of the purchase agreement, less the value of any claims we have under the purchase agreement. The amount of remaining cash in escrow will be included in restricted cash on our consolidated balance sheet until the final release of escrow cash on April 30, 2014. The vessel was recently completed under our supervision in Nantong, China, and is in the process of being transported to the Gulf of Mexico, where it will undergo final outfitting and sea trials.

NOTE C – COMPRESSCO PARTNERS, L.P. INITIAL PUBLIC OFFERING

On June 20, 2011, our subsidiary, Compressco Partners, L.P. (Compressco Partners), completed the initial public offering of 2,670,000 of its common units (representing a 17.3% limited partner interest) in exchange for $53.4 million of gross proceeds (the Offering). As a result of the Offering, our ownership in Compressco Partners was reduced to 82.7%, including common units, subordinated units and a 2% general partner interest. In connection with the Offering, certain of our wholly owned subsidiaries, including Compressco Partners GP Inc. (the General Partner), contributed substantially all of our Compressco segment’s natural gas wellhead compression-based production enhancement service business, operations, and related assets and liabilities into Compressco Partners and its wholly owned subsidiaries. In exchange, Compressco Partners issued to us 6,026,757 common units (representing a 39.0% limited partner interest), 6,273,970 subordinated units (representing a 40.7% limited partner interests), an aggregate 2.0% notional general partner interest, and incentive distribution rights. Also, certain directors, executive officers, and other employees of the General Partner were then issued 157,870 restricted units (representing a 1.0% limited partner interest) granted pursuant to a long-term incentive plan. The issuance of the 2,670,000 common units in the Offering, at a $20 per unit Offering Price, resulted in Compressco Partners receiving $53.4 million of gross proceeds, $32.2 million of which was distributed to us to repay an intercompany loan balance. Approximately $10.5 million of the Offering proceeds was used to satisfy Offering expenses, including underwriters’ discount and approximately $7.3 million that was paid to us by Compressco Partners to reimburse us for costs we incurred on their behalf. The contribution transactions described above represent transactions between entities under common control. Consequently, the contributed assets were recorded at our carrying value.

Also pursuant to the Offering, the underwriters received an option whereby they could purchase 400,500 common units at the $20 per unit Offering Price. At July 15, 2011, this underwriters’ option expired unexercised, resulting in the additional 400,500 units being issued to us. As a result, our ownership of Compressco Partners increased to 83.2%

The contribution of the majority of the operations and related assets and liabilities of our Compressco segment were effected pursuant to the terms of a Contribution, Conveyance and Assumption Agreement (the Contribution Agreement). Compressco Partners’ is to be governed by the First Amended and Restated Agreement of Limited Partnership (the Partnership Agreement). The Partnership Agreement requires Compressco Partners to distribute all of its available cash, as defined in the Partnership Agreement, to the common units, the subordinated units, the 2% general partner interest, and the incentive distribution rights in accordance with the terms of the Partnership Agreement. The Partnership Agreement also provides for the management of Compressco Partners by the General Partner. The reimbursement of direct and indirect costs incurred by us or the General Partner in providing personnel and services on behalf of Compressco Partners, as well as other transactions between us and Compressco Partners, is governed by the terms of an Omnibus Agreement between us and Compressco Partners.

Following the Offering, as of June 30, 2011, the 17.3% portion of Compressco Partners then owned by public unitholders is reflected as a noncontrolling interest in our consolidated financial statements.

NOTE D – LONG-TERM DEBT AND OTHER BORROWINGS

Long-term debt consists of the following:

		June 30, 2011		December 31, 2010
		(In Thousands)
	Scheduled Maturity
Bank revolving line of credit facility	June 26, 2015	$	-	$	-
5.90% Senior Notes, Series 2006-A	April 30, 2016		90,000		90,000
6.30% Senior Notes, Series 2008-A	April 30, 2013		35,000		35,000
6.56% Senior Notes, Series 2008-B	April 30, 2015		90,000		90,000
5.09% Senior Notes, Series 2010-A	December 15, 2017		65,000		65,000
5.67% Senior Notes, Series 2010-B	December 15, 2020		25,000		25,000
Partnership line of credit facility	June 24, 2015		-		-
European bank credit facility			-		-
Other			35		35
Total long-term debt			305,035		305,035
Less current portion			-		-
Long-term debt, net		$	305,035	$	305,035

On June 24, 2011, Compressco Partners entered into a new $20.0 million revolving credit facility agreement (the Partnership Credit Agreement) with JPMorgan Chase Bank, N.A. Under the Partnership Credit Agreement, Compressco Partners, along with certain of its subsidiaries, are named as borrowers, and all obligations under the revolving credit facility are guaranteed by all of Compressco Partners’ existing and future, direct and indirect, domestic subsidiaries. All obligations under the Partnership Credit Agreement are secured, subject to certain exceptions, by a first lien security interest in substantially all of Compressco Partners’ and its subsidiaries’ assets (excluding real property) and all of the capital stock of the existing and future subsidiaries of Compressco Partners (with some limitations). The Partnership Credit Agreement includes borrowing capacity of $20.0 million, less $3.0 million that is required to be set aside as a reserve that cannot be borrowed. The facility is available for letters of credit (at a sublimit of $5.0 million) and includes a $20.0 million uncommitted expansion feature. The Partnership Credit Agreement will be used to fund Compressco Partners’ working capital needs, letters of credit, and for general partnership purposes, including capital expenditures and potential future expansions or acquisitions. So long as it is not in default, Compressco Partners may use its credit facility to fund its quarterly distributions at the option of the board of directors of the General Partner. Borrowings under the Partnership Credit Agreement are subject to the satisfaction of customary conditions, including the absence of a default. As of June 30, 2011, there is no balance outstanding under the Partnership Credit Agreement.

NOTE E – DECOMMISSIONING AND OTHER ASSET RETIREMENT OBLIGATIONS

The large majority of our asset retirement obligations consists of the future well abandonment and decommissioning costs for offshore oil and gas properties and platforms owned by our Maritech subsidiary, including the remaining abandonment, decommissioning, and debris removal costs associated with offshore platforms destroyed by hurricanes. The amount of decommissioning liabilities recorded by Maritech is reduced by amounts allocable to joint interest owners, anticipated insurance recoveries, and any contractual amount to be paid by the previous owner of the oil and gas property when the liabilities are satisfied.

The changes in the asset retirement obligations during the three month and six month periods ended June 30, 2011 and 2010 are as follows:

	Three Months Ended June 30,
	2011			2010
	(In Thousands)

Beginning balance as of March 31	$	230,834		$	236,418
Activity in the period:
Accretion of liability		1,264			1,350
Retirement obligations incurred		-			-
Revisions in estimated cash flows		16,045			4,902
Settlement of retirement obligations		(103,618	)		(26,523	)
Ending balance as of June 30	$	144,525		$	216,147

	Six Months Ended June 30,
	2011			2010
	(In Thousands)
Beginning balance as of December 31 of
the preceding year	$	272,815		$	224,110
Activity in the period:
Accretion of liability		3,158			2,698
Retirement obligations incurred		-			-
Revisions in estimated cash flows		25,809			22,184
Settlement of retirement obligations		(157,257	)		(32,845	)
Ending balance as of June 30	$	144,525		$	216,147

Revisions in estimated cash flows for the three months and six months ended June 30, 2011, are primarily related to the retained Maritech property assets. Settlements of retirement obligations during the three months and six months ended June 30, 2011, include approximately $72.7 million and $118.7 million, respectively, of obligations associated with oil and gas properties sold by Maritech during the periods. In August 2011, Maritech sold an additional oil and gas property, which will result in the further reduction of asset retirement obligations by an additional $3.3 million.

NOTE F – HEDGE CONTRACTS

We are exposed to financial and market risks that affect our businesses. We have currency exchange rate risk exposure related to specific transactions denominated in a foreign currency as well as to investments in certain of our international operations. As a result of our variable rate bank credit facilities and the variable rate credit facility of Compressco Partners, to the extent we have debt outstanding, we face market risk exposure related to changes in applicable interest rates. We have concentrations of credit risk as a result of trade receivables from companies in the energy industry. In addition, we have market risk exposure in the sales prices we receive for the remainder of our oil and gas production. Our financial risk management activities may 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. Prior to the execution of the purchase and sale agreement in April 2011 pursuant to which we sold substantially all of our remaining Maritech oil and gas properties in May 2011, we utilized cash flow commodity hedge transactions to reduce our exposure related to the volatility of oil and gas prices. For these and other hedge contracts, we formally document all relationships between hedging instruments and hedged items, as well as our risk management objectives, our strategies for undertaking various hedge transactions, and our methods for assessing and testing correlation and hedge ineffectiveness. All hedging instruments are linked to the hedged asset, liability, firm commitment, or forecasted transaction. We also assess, both at the inception of the hedge and on an ongoing basis, whether the derivatives that are used in these hedging transactions are highly effective in offsetting changes in cash flows of the hedged items. As indicated below, these cash flow commodity hedge contracts were liquidated in the second quarter of 2011.

Derivative Hedge Contracts

In April 2011, in connection with the execution of the purchase and sale agreement pursuant to which Maritech agreed to sell approximately 79% of its proved reserves as of December 31, 2010, we liquidated our remaining oil hedge contracts and paid cash totaling $14.2 million to the counterparty. Therefore, as of June 30, 2011, we had no remaining cash flow hedging swap contracts outstanding associated with our Maritech subsidiary’s oil or gas production.

Pretax gains and losses associated with oil and gas derivative swap contracts for the three month and six month periods ended June 30, 2011 and 2010, are summarized below:

	Three Months Ended June 30, 2011
Derivative Swap Contracts	Oil			Natural Gas		Total
	(In Thousands)
Amount of pretax gain reclassified from accumulated other comprehensive
income into product sales revenue (effective portion)	$	-		$	-	$	-
Amount of pretax gain (loss) from change in derivative fair value
recognized in other comprehensive income		-			-		-
Amount of pretax gain (loss) recognized in other income (expense)
(ineffective portion)		(14,224	)		-		(14,224	)

	Three Months Ended June 30, 2010
Derivative Swap Contracts	Oil			Natural Gas			Total
	(In Thousands)
Amount of pretax gain reclassified from accumulated other comprehensive
income into product sales revenue (effective portion)	$	4,858		$	7,725		$	12,583
Amount of pretax gain (loss) from change in derivative fair value
recognized in other comprehensive income		(11,097	)		1,371			(9,726	)
Amount of pretax gain (loss) recognized in other income (expense)
(ineffective portion)		419			(35	)		384

	Six Months Ended June 30, 2011
Derivative Swap Contracts	Oil			Natural Gas		Total
	(In Thousands)
Amount of pretax gain reclassified from accumulated other comprehensive
income into product sales revenue (effective portion)	$	1,177		$	-	$	1,177
Amount of pretax gain (loss) from change in derivative fair value
recognized in other comprehensive income		(7,854	)		-		(7,854	)
Amount of pretax gain (loss) recognized in other income (expense)
(ineffective portion)		(13,947	)		-		(13,947	)

	Six Months Ended June 30, 2010
Derivative Swap Contracts	Oil			Natural Gas			Total
	(In Thousands)
Amount of pretax gain reclassified from accumulated other comprehensive
income into product sales revenue (effective portion)	$	9,939		$	12,225		$	22,164
Amount of pretax gain (loss) from change in derivative fair value
recognized in other comprehensive income		(9,320	)		(7,287	)		(16,607	)
Amount of pretax gain (loss) recognized in other income (expense)
(ineffective portion)		125			215			340

NOTE G – EQUITY

Changes in equity for the three month and six month periods ended June 30, 2011 and 2010, are as follows:

	Three Months Ended June 30,
	2011								2010
	(In Thousands)
				Noncontrolling								Noncontrolling
	TETRA			Interest		Total			TETRA			Interest		Total
Beginning balance for the period	$	517,353		$	-	$	517,353		$	581,650		$	-	$	581,650
Comprehensive income:
Net income		30,374			95		30,469			13,560			-		13,560
Changes in commodity derivatives, net of
taxes of $4,165 and $(1,206), respectively		7,030			-		7,030			(2,035	)		-		(2,035	)
Foreign currency translation adjustment, net of
taxes of $(582) and $(1,112), respectively		2,229			-		2,229			(1,650	)		-		(1,650	)
Comprehensive income		39,633			95		39,728			9,875			-		9,875
Exercise of common stock options		491			-		491			365			-		365
Issuance of Compressco Partners common
units, net of offering costs		-			42,885		42,885			-			-		-
Purchases of treasury stock and other		(684	)		-		(684	)		(81	)		-		(81	)
Stock based compensation		1,303			-		1,303			1,505			-		1,505
Tax benefit upon exercise of stock options		532			-		532			126			-		126
Ending balance as of June 30,	$	558,628		$	42,980	$	601,608		$	593,440		$	-	$	593,440

	Six Months Ended June 30,
	2011								2010
	(In Thousands)
				Noncontrolling								Noncontrolling
	TETRA			Interest		Total			TETRA			Interest		Total
Beginning balance for the period	$	516,323		$	-	$	516,323		$	576,494		$	-	$	576,494
Comprehensive income:
Net income		27,859			95		27,954			18,987			-		18,987
Changes in commodity derivatives, net of
taxes of $1,578 and $(2,194), respectively		2,663			-		2,663			(3,703	)		-		(3,703	)
Foreign currency translation adjustment, net of
taxes of $(770) and $(1,648), respectively		5,713			-		5,713			(2,303	)		-		(2,303	)
Comprehensive income		36,235			95		36,330			12,981			-		12,981
Exercise of common stock options		2,805			-		2,805			784			-		784
Issuance of Compressco Partners common
units, net of offering costs		-			42,885		42,885			-			-		-
Purchases of treasury stock and other		(1,269	)		-		(1,269	)		(123	)		-		(123	)
Stock based compensation		3,140			-		3,140			3,055			-		3,055
Tax benefit upon exercise of stock options		1,394			-		1,394			249			-		249
Ending balance as of June 30	$	558,628		$	42,980	$	601,608		$	593,440		$	-	$	593,440

NOTE H – 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 reasonably expect these matters to have a material adverse impact on the financial statements.

Derivative Lawsuit

Between May 28, 2008 and June 27, 2008, two petitions were filed by alleged stockholders in the District Courts of Harris County, Texas, 133rd and 113th Judicial Districts, purportedly on our behalf. The suits name our directors and certain officers as defendants. The factual allegations in these lawsuits mirror those in a federal class action lawsuit which was settled during 2010. The claims are for breach of fiduciary duty, unjust enrichment, abuse of control, gross mismanagement, and waste of corporate assets. The petitions seek disgorgement, costs, expenses, and unspecified equitable relief. On September 22, 2008, the 133rd District Court consolidated these complaints as In re TETRA Technologies, Inc. Derivative Litigation, Cause No. 2008-23432 (133rd Dist. Ct., Harris County, Tex.), and appointed Thomas Prow and Mark Patricola as Co-Lead Plaintiffs. This lawsuit was stayed by agreement of the parties pending the Court’s ruling on our motion to dismiss the federal class action. On September 8, 2009, the plaintiffs in this state court action filed a consolidated petition which makes factual allegations similar to the surviving allegations in the federal lawsuit prior to it being settled. On April 19, 2010, the Court granted our motion to abate the suit, based on plaintiff’s inability to demonstrate derivative standing. On June 8, 2010, we received a letter from plaintiff’s counsel demanding that our board of directors take action against the defendants named in the previously filed derivative lawsuit. We have reached an agreement in principle to settle the plaintiffs’ claims. The parties are finalizing the settlement papers for filing with the Court, and the Court has set a preliminary hearing on August 22, 2011. The settlement is subject to Court approval.

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 styled In 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 future remediation costs and 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.

In August of 2009, the Environmental Protection Agency (EPA), pursuant to Sections 308 and 311 of the Clean Water Act (CWA), served a request for information with regard to a release of zinc bromide that occurred from one of our transport barges on the Mississippi River on March 11, 2009. We timely filed a response to that request for information in August 2009. In January 2010, the EPA issued a Notice of Violation and Opportunity to Show Cause related to the spill. We met with the EPA in April 2010 to discuss potential violations and penalties. It has been agreed that no injunctive relief will be required. We have finalized a joint stipulation of settlement with the EPA, whereby we are responsible for a penalty of $487,000, which was submitted to the Department of Justice and the U.S. District Court for the Western District of Tennessee. The settlement was entered into the record on April 28, 2011. The penalty amount was paid during May 2011 and we expect the full amount to be covered by insurance.

NOTE I – INDUSTRY SEGMENTS

We manage our operations through five operating segments: Fluids, Offshore Services, Maritech, Production Testing, and Compressco.

Our Fluids Division manufactures and markets clear brine fluids, additives, and other associated products and services to the oil and gas industry for use in well drilling, completion, and workover operations both in the United States and in certain regions of Latin America, Europe, Asia, the Middle East, and Africa. The Division also markets liquid and dry calcium chloride products manufactured at its production facilities to a variety of markets outside the energy industry.

Our Offshore Division consists of two operating segments: Offshore Services and Maritech, an oil and gas exploration, exploitation, and production segment. The Offshore Services segment provides (1) downhole and subsea oil and gas services such as well plugging and abandonment, workover, and wireline services, (2) various decommissioning and certain construction services utilizing heavy lift barges and various cutting technologies in the decommissioning or construction of offshore oil and gas production platforms and pipelines, and (3) diving services involving conventional and saturated air diving.

The Maritech segment consists of our Maritech subsidiary, which is an oil and gas exploration, development, and production operation focused in the offshore, inland waters, and onshore U.S. Gulf Coast region. As a result of certain sales transactions during the first eight months of 2011, including the May 31, 2011, sale of a significant portion of Maritech’s oil and gas properties, Maritech has sold approximately 95% of its proved reserves as of December 31, 2010. Maritech’s remaining operations consist primarily of the ongoing well plugging, abandonment, and decommissioning associated with its remaining offshore production platforms. Maritech intends to acquire a significant portion of these services from the Offshore Division’s Offshore Services segment.

Our Production Enhancement Division consists of two operating segments: Production Testing and Compressco. The Production Testing segment provides production testing services in many of the major oil and gas basins in the United States, as well as onshore basins in certain regions in Mexico, Brazil, Northern Africa, the Middle East, and other international markets.

The Compressco segment provides wellhead compression-based and other production enhancement services throughout many of the onshore producing regions of the United States, as well as certain basins in Canada, Mexico, South America, Europe, Asia, and other international locations. Beginning June 20, 2011, following Compressco Partners’ initial public offering, we allocate and charge certain corporate and divisional direct and indirect administrative costs to Compressco Partners.

We generally evaluate performance and allocate resources based on profit or loss from operations before income taxes and nonrecurring charges, return on investment, and other criteria. Transfers between segments, as well as 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 from continuing operations is as follows:

	Three Months Ended June 30,				Six Months Ended June 30,
	2011		2010		2011		2010
	(In Thousands)
Revenues from external customers
Product sales
Fluids Division	$	68,430	$	62,599	$	127,934	$	113,854
Offshore Division
Offshore Services		1,192		499		2,127		1,147
Maritech		33,155		49,576		76,749		95,794
Intersegment eliminations		-		-		-		-
Total Offshore Division		34,347		50,075		78,876		96,941
Production Enhancement Division
Production Testing		-		-		-		3,610
Compressco		2,513		1,241		5,003		2,703
Total Production Enhancement Division		2,513		1,241		5,003		6,313
Consolidated	$	105,290	$	113,915	$	211,813	$	217,108

	Three Months Ended June 30,						Six Months Ended June 30,
	2011			2010			2011			2010
	(In Thousands)
Revenues from external customers
Services and rentals
Fluids Division	$	20,365		$	16,714		$	38,191		$	31,704
Offshore Division
Offshore Services		86,060			84,839			136,840			135,448
Maritech		227			759			655			1,140
Intersegment eliminations		(28,421	)		(18,156	)		(34,037	)		(23,296	)
Total Offshore Division		57,866			67,442			103,458			113,292
Production Enhancement Division
Production Testing		31,738			24,342			64,948			46,934
Compressco		19,813			19,205			39,207			38,473
Total Production Enhancement Division		51,551			43,547			104,155			85,407
Corporate overhead		42			-			42			-
Consolidated	$	129,824		$	127,703		$	245,846		$	230,403

Intersegment revenues
Fluids Division	$	34		$	16		$	48		$	32
Offshore Division
Offshore Services		3			63			3			204
Maritech		-			-			-			35
Intersegment eliminations		-			-			-			-
Total Offshore Division		3			63			3			239
Production Enhancement Division
Production Testing		1			4			1			4
Compressco		-			-			-			-
Total Production Enhancement Division		1			4			1			4
Intersegment eliminations		(38	)		(83	)		(52	)		(275	)
Consolidated	$	-		$	-		$	-		$	-

Total revenues
Fluids Division	$	88,829		$	79,329		$	166,173		$	145,590
Offshore Division
Offshore Services		87,255			85,401			138,970			136,799
Maritech		33,382			50,335			77,404			96,969
Intersegment eliminations		(28,421	)		(18,156	)		(34,037	)		(23,296	)
Total Offshore Division		92,216			117,580			182,337			210,472
Production Enhancement Division
Production Testing		31,739			24,346			64,949			50,548
Compressco		22,326			20,446			44,210			41,176
Total Production Enhancement Division		54,065			44,792			109,159			91,724
Corporate overhead		42			-			42			-
Intersegment eliminations		(38	)		(83	)		(52	)		(275	)
Consolidated	$	235,114		$	241,618		$	457,659		$	447,511

Income before taxes and discontinued operations
Fluids Division	$	11,545		$	10,191		$	18,794		$	16,377
Offshore Division
Offshore Services		13,577			14,269			9,201			11,828
Maritech		38,523			1,044			34,003			9,687
Intersegment eliminations		1,588			81			1,747			572
Total Offshore Division		53,688			15,394			44,951			22,087
Production Enhancement Division
Production Testing		5,988			3,020			15,071			7,015
Compressco		3,809			5,037			7,814			10,133
Total Production Enhancement Division		9,797			8,057			22,885			17,148
Corporate overhead		(27,476	)(1)		(13,104	)(1)		(43,117	)(1)		(26,602	)(1)
Consolidated	$	47,554		$	20,538		$	43,513		$	29,010

	June 30,
	2011			2010
Total assets	(In Thousands)
Fluids Division	$	384,744		$	381,485
Offshore Division
Offshore Services		167,749			177,656
Maritech		30,775			308,292
Intersegment eliminations		(55	)		(1,674	)
Total Offshore Division		198,469			484,274
Production Enhancement Division
Production Testing		97,675			101,997
Compressco		218,020			197,487
Total Production Enhancement Division		315,695			299,484
Corporate overhead		352,044	(2)		171,779	(2)
Consolidated	$	1,250,952		$	1,337,022

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

	Three Months Ended June 30,					Six Months Ended June 30,
	2011		2010			2011		2010
	(In Thousands)
General and administrative expense	$	8,282	$	9,083		$	18,650	$	17,769
Depreciation and amortization		729		727			1,414		1,503
Interest expense		4,140		4,303			8,494		8,279
Other general corporate (income) expense, net		14,325		(1,009	)		14,559		(949	)
Total	$	27,476	$	13,104		$	43,117	$	26,602

(2) Includes assets of discontinued operations.

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

Business Overview

We continue to take strategic steps to respond to the increasing demand for our products and services. The domestic oil and gas industry continues to increase its demand for services, as reflected by the eight consecutive quarters of increasing domestic rig counts. Most of this domestic growth has been onshore and includes continued strong activity in shale fields, where our Fluids segment has continued to capitalize on the increasing demand for frac water services. Our Production Testing segment also has seen significant domestic growth as a result of increased activity. In addition to growing these domestic businesses, we also continue to pursue international growth opportunities, capitalizing on escalating activity in the regions we serve. In June 2011, our Compressco Partners, L.P. subsidiary completed its initial public offering, issuing approximately 17% of its common units to the public for $53.4 million gross proceeds. Compressco Partners intends to continue growing its business, both organically and through acquisitions. To better serve the Gulf of Mexico decommissioning market, in July 2011, we purchased a heavy lift derrick barge with a 1,600-metric-ton lift capacity, fully-revolving crane. With this heavy lift vessel, which we expect to place into service in the Gulf of Mexico during the fourth quarter of 2011, our Offshore Services segment will significantly increase its heavy lift capacity and enable us for the first time to serve customers with heavier structures in the Gulf of Mexico. Lastly, to fund our growth initiatives and to increase our focus on our service operations, during the second quarter of 2011, Maritech sold a significant portion of its yearend proved reserves to Tana Exploration Company LLC (Tana).

Each of our segments, with the exception of Maritech, reported increased revenues during the second quarter of 2011 compared to the prior year period. In particular, our Fluids and Production Testing segments each reported significant revenue increases, primarily due to increased onshore and international activity. Offshore Fluids segment activity levels continue to be hampered by the uncertain regulatory environment following the 2010 Macondo accident. Despite high activity levels, our Offshore Services segment reported decreased profitability due to decreased diving services profits. Our Compressco segment also reported decreased profitability, primarily due to increased domestic operating expenses. Excluding the net gain reported from sales of oil and gas producing properties, Maritech’s profitability dropped significantly during the second quarter compared to the prior year period, primarily due to increased impairments and excess decommissioning expenses. Maritech’s remaining decommissioning

liabilities total $136.9 million, and the significant majority of this decommissioning and abandonment work is planned during the next two year period. Overall consolidated earnings during the current year quarter were increased compared to the prior year period, due to the gain on the sale of Maritech properties and despite the hedge ineffectiveness loss upon liquidation of the associated swap derivatives that previously hedged Maritech production cash flows.

With approximately $323.8 million of consolidated cash as of June 30, 2011, significant borrowing capacity under the terms of our existing bank revolving credit facilities, and the potential to access additional capital resources, we have significant capacity to fund our plans for future growth. Consolidated cash as of June 30, 2011, includes approximately $19.3 million held by our Compressco Partners subsidiary that is available solely for its plans for growth and operating needs. The heavy lift barge we purchased in July 2011 utilized $62.8 million of available cash, excluding the costs of transportation, outfitting, and inspection of the vessel. We expect to increase capital expenditure activity levels for 2011 for all of our businesses, except Maritech, compared to the reduced levels of the past year. We continue to seek new markets and new product development for our existing businesses and pursue strategic acquisition opportunities.

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, 2010. In preparing our consolidated financial statements, we make assumptions, estimates, and judgments that affect the amounts reported. 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 cost of future abandonment and decommissioning obligations. Our estimates are based on historical experience and on future expectations that we believe are reasonable. The fair values of large 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. 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.

Results of Operations

Three months ended June 30, 2011 compared with three months ended June 30, 2010.

Consolidated Comparisons

	Three Months Ended June 30,						Period to Period Change
	2011			2010			2011 vs 2010			% Change
	(In Thousands, Except Percentages)

Revenues	$	235,114		$	241,618		$	(6,504	)		-2.7	%
Gross profit		35,813			47,832			(12,019	)		-25.1	%
Gross profit as a percentage of revenue		15.2	%		19.8	%
General and administrative expense		29,006			24,955			4,051			16.2	%
General and administrative expense as
a percentage of revenue		12.3	%		10.3	%
Interest expense, net		4,085			4,238			(153	)		-3.6	%
(Gain) loss on sale of assets		(59,577	)		157			(59,734	)
Other (income) expense, net		14,745			(2,056	)		16,801
Income before taxes and discontinued operations		47,554			20,538			27,016			131.5	%
Income before taxes and discontinued operations as
a percentage of revenue		20.2	%		8.5	%
Provision for income taxes		17,031			6,903			10,128			146.7	%
Income before discontinued operations		30,523			13,635			16,888			123.9	%
Loss from discontinued operations, net of taxes		(54	)		(75	)		21
Net income		30,469			13,560			16,909			124.7	%
Net (income) attributable to noncontrolling interest		(95	)		-			(95	)
Net income attriubtable to TETRA stockholders	$	30,374		$	13,560		$	16,814			124.0	%

Consolidated revenues for the quarter ended June 30, 2011, decreased compared to the prior year period primarily due to a reduction in revenues from our Maritech segment, which sold approximately 95% of its yearend proved oil and gas reserves during the first eight months of the year. These sales of oil and gas properties will significantly reduce Maritech segment revenues going forward, and Maritech continues to seek buyers for its remaining producing properties. In addition, although our Offshore Services segment recorded increased revenues, an increased amount of this activity was performed for Maritech and eliminated in consolidation, thereby contributing to decreased consolidated Offshore Division revenues. Each of our Fluids, Production Testing, and Compressco segments reflected increased activity as compared to the prior year period. Our Fluids segment’s increased revenues were primarily due to increased manufactured chemicals and international CBF sales, which more than offset decreased domestic offshore activity due to continuing regulatory uncertainty. Growth in both of our Production Testing and Compressco segments was primarily due to increased domestic activity. Overall gross profit decreased primarily due to higher excess decommissioning costs and impairments incurred by Maritech, although Offshore Services and Compressco gross profit also decreased compared to the prior year period. These decreases were partially offset by increased gross profit from our Production Testing and Fluids segments.

Consolidated general and administrative expenses increased during the second quarter of 2011 compared to the prior year period due to approximately $2.7 million of increased employee-related costs, primarily related to employee retention and incentive benefits paid in connection with the sale of Maritech properties. In addition, general and administrative expenses increased due to approximately $0.4 million of increased professional fee expenses and $0.7 million of increased insurance and other general expenses during the current year period. These increases were partially offset by decreased office expense.

Net consolidated interest expense decreased slightly during the second quarter of 2011 as compared to the prior year period due to increased capitalized interest during the period. Proceeds from the issuance of the 2010 Senior Notes were used to repay the 2004 Senior Notes in December 2010.

During the second quarter of 2011, Maritech oil and gas property sales generated approximately $58.2 million of consolidated net gains. In addition, our Offshore Services segment generated an additional $1.6 million of gain from the sale of certain equipment assets.

Consolidated other expense increased during the second quarter of 2011 compared to the prior year period, primarily due to approximately $14.6 million of increased hedge ineffectiveness loss during the current year period that was realized upon the liquidation of commodity swap derivatives that previously hedged Maritech’s production cash flows. Other expense also increased due to approximately $1.5 million of decreased foreign currency gains.

Our provision for income taxes during the second quarter of 2011 increased due to increased earnings compared to the prior year period.

Divisional Comparisons

Fluids Division

	Three Months Ended June 30,						Period to Period Change
	2011			2010			2011 vs 2010		% Change
	(In Thousands, Except Percentages)

Revenues	$	88,829		$	79,329		$	9,500		12.0	%
Gross profit		18,778			15,369			3,409		22.2	%
Gross profit as a percentage of revenue		21.1	%		19.4	%
General and administrative expense		7,363			5,684			1,679		29.5	%
General and administrative expense as
a percentage of revenue		8.3	%		7.2	%
Interest (income) expense, net		26			(5	)		31
Other (income) expense, net		(156	)		(501	)		345
Income before taxes and discontinued operations	$	11,545		$	10,191		$	1,354		13.3	%
Income before taxes and discontinued operations as
a percentage of revenue		13.0	%		12.8	%

The increase in Fluids Division revenues during the second quarter of 2011 compared to the prior year period was primarily due to $5.8 million of increased product sales revenues. This increase in product sales revenues was due to $8.5 million of increased revenue from our chemicals operations. This increase in chemicals operations revenues is primarily attributed to increased sales of calcium chloride products, particularly in Europe, although our domestic production and sales volumes increased also. This increase in chemical product sales revenues was partially offset by approximately $2.6 million of decreased sales of clear brine fluids (CBFs). This decrease in CBF sales was due to decreased domestic activity that more than offset the increased international sales. Domestic offshore activity levels continue to be decreased as a result of the uncertain regulations governing offshore drilling activities following the April 2010 Macondo accident. Increased onshore domestic activity levels resulted in approximately $3.7 million of increased service revenues, including increased revenues from frac water services.

Our Fluids Division gross profit increased compared to the prior year period, primarily as a result of improved efficiencies at our El Dorado, Arkansas, plant. In addition, during the prior year period, we reflected certain startup costs associated with the El Dorado plant, which began operations in late 2009. We continue to take steps to improve the operational efficiency of this plant, which are expected to continue to result in improved plant performance during the remainder of 2011. Associated with these plant operational inefficiencies, on March 18, 2011, we filed a lawsuit in the Circuit Court of Union County, Arkansas, seeking to recover damages related to certain design and other services provided in connection with the construction of the El Dorado plant. Partially offsetting the increased gross profit from the El Dorado plant, gross profit from sales of CBFs decreased during the second quarter of 2011 compared to the prior year period, due to the decrease in domestic activity levels as discussed above.

Fluids Division income before taxes increased compared to the prior year period due to the increase in gross profit discussed above and despite increased administrative costs and a decrease in other income. Fluids Division administrative costs increased primarily due to increased professional fees and personnel-related costs.

Offshore Division

Offshore Services Segment

	Three Months Ended June 30,						Period to Period Change
	2011			2010			2011 vs 2010			% Change
	(In Thousands, Except Percentages)

Revenues	$	87,255		$	85,401		$	1,854			2.2	%
Gross profit		16,433			18,334			(1,901	)		-10.4	%
Gross profit as a percentage of revenue		18.8	%		21.5	%
General and administrative expense		4,093			4,010			83			2.1	%
General and administrative expense as
a percentage of revenue		4.7	%		4.7	%
Interest (income) expense, net		-			1			(1	)
Other (income) expense, net		(1,237	)		54			(1,291	)
Income before taxes and discontinued operations	$	13,577		$	14,269		$	(692	)		-4.8	%
Income before taxes and discontinued operations
as a percentage of revenue		15.6	%		16.7	%

Revenues from our Offshore Services segment increased during the second quarter of 2011 compared to the prior year quarter. Increased offshore well abandonment and decommissioning revenues were largely offset by decreased diving services and cutting services activity and a softer pricing environment. In addition, during May 2011, we sold our onshore abandonment operations, although this sale is not expected to significantly reduce our revenues in the future. During 2010, the BOEMRE issued NTL 2010-G05, the “Idle Iron Guidance” regulations, which require that wells located in Federal waters must be permanently plugged within three years of becoming uneconomic and that platforms and other infrastructure must be removed within five years of becoming uneconomic to operate. We anticipate that these new regulations will increase the future demand for well abandonment and decommissioning services to be performed by our Offshore Services segment. In July 2011, we purchased a new heavy lift derrick barge (which we have named the TETRA Hedron) with a 1,600-metric-ton lift capacity, fully-revolving crane.

With this vessel, which we expect to place into service in the Gulf of Mexico during the fourth quarter of 2011, our Offshore Services segment will significantly increase its heavy lift capacity and enable us to better serve the important Gulf of Mexico decommissioning market and now enable us to serve customers with heavier structures in the Gulf of Mexico. Still, we anticipate that levels of Offshore Services segment activity in 2011 will again be lower than the record activity levels we experienced during 2009. Approximately $28.5 million of Offshore Services revenues was from work performed for Maritech during the second quarter of 2011, compared to $18.2 million of such work in the prior year period. These intercompany revenues are eliminated in consolidation. Despite the sale of Maritech’s oil and gas producing properties, a significant amount of abandonment and decommissioning work remains for Maritech going forward.

Gross profit for the Offshore Services segment during the second quarter of 2011 decreased as compared to the prior year period, primarily due to decreased profitability of our diving services operations, and despite increased profitability of our offshore well abandonment and decommissioning operations. A portion of the decrease in gross profit was also caused by approximately $1.8 million of due diligence and inspection costs incurred during the second quarter of 2011 associated with the new heavy lift derrick barge we purchased in July 2011. Overall segment profitability was also affected by a lower pricing environment for diving services during the second quarter of 2011 compared to the prior year period. Due to the anticipated increased activity as a result of the “Idle Iron Guidance” regulations discussed above, we anticipate that pricing and profitability for many of the Offshore Services segment operations will increase going forward.

Offshore Services income before taxes decreased due to the decrease in gross profit described above and due to increased administrative expenses. These decreases were partially offset by the increase in other income, which was primarily generated from the sale of onshore abandonment operations during the second quarter of 2011.

Maritech Segment

	Three Months Ended June 30,						Period to Period Change
	2011			2010			2011 vs 2010			% Change
	(In Thousands, Except Percentages)

Revenues	$	33,382		$	50,335		$	(16,953	)		-33.7	%
Gross profit		(14,737	)		2,332			(17,069	)		-731.9	%
Gross profit as a percentage of revenue		-44.1	%		4.6	%
General and administrative expense		3,338			1,349			1,989			147.4	%
General and administrative expense as
a percentage of revenue		10.0	%		2.7	%
Interest (income) expense, net		(1	)		(61	)		60
Other (income) expense, net		(56,597	)		-			(56,597	)
Income before taxes and discontinued operations	$	38,523		$	1,044		$	37,479			3,589.9	%
Income before taxes and discontinued operations
as a percentage of revenue		115.4	%		2.1	%

Maritech revenues decreased significantly during the second quarter of 2011 compared to the prior year period due to approximately $15.2 million of decreased revenues from decreased production volumes following the sales of oil and gas producing properties during the first half of 2011. In particular, the May 31, 2011 sale of oil and gas properties to Tana resulted in the sale of approximately 79% of Maritech’s December 31, 2010 proved reserves. In addition, during the first quarter and in August of 2011, Maritech sold an aggregate of approximately 15% of its December 31, 2010 proved reserves in additional sales transactions. These decreased production volumes occurred despite recent production increases at the Timbalier Bay and East Cameron 328 fields, properties that were included in the sale to Tana. In addition to the decreased production volumes, revenues decreased $1.2 million during the second quarter of 2011 compared to the prior year period due to decreased realized oil and gas prices during the period compared to the prior year period. Maritech had previously hedged a portion of its expected production cash flows by entering into derivative hedge contracts with terms that extended through 2011. Maritech’s hedges over its natural gas production expired at the end of 2010. However, in connection with the planned sale of a significant portion of its oil and gas producing properties to Tana, Maritech liquidated its remaining derivative hedge

contracts in April 2011. Accordingly, Maritech reflected average realized oil prices during the second quarter of 2011 of $116.40/barrel compared to $99.26/barrel during the prior year period. Maritech’s average natural gas price received during the second quarter of 2011 was $4.40/MMBtu compared to $8.43/MMBtu average realized price received during the prior year period. Other revenues decreased $0.5 million during the second quarter of 2011 compared to the prior year period. Following the above mentioned sales of producing properties, Maritech revenues are expected to be minimal going forward.

Maritech gross profit decreased significantly during the second quarter of 2011 compared to the prior year period due to the decreased revenues discussed above. The impact of decreased operating expenses and depletion expense due to the sale of producing properties was largely offset by approximately $13.0 million of increased excess decommissioning costs and $0.3 million of increased impairments as compared to the prior year period. The increased excess decommissioning costs were associated with asset retirement obligations on nonproductive properties retained by Maritech.

Maritech income before taxes during the second quarter of 2011 increased significantly compared to the prior year period due to the recording of the net gain of $56.6 million ($58.2 million consolidated) on the sales of oil and gas properties during the period. This net gain was partially offset by the decrease in gross profit discussed above, as well as increased administrative expenses during the current year period. The increased administrative expenses were primarily caused by retention and incentive compensation associated with the sale of Maritech properties.

Production Enhancement Division

Production Testing Segment

	Three Months Ended June 30,						Period to Period Change
	2011			2010			2011 vs 2010		% Change
	(In Thousands, Except Percentages)

Revenues	$	31,739		$	24,346		$	7,393		30.4	%
Gross profit		9,065			4,510			4,555		101.0	%
Gross profit as a percentage of revenue		28.6	%		18.5	%
General and administrative expense		2,935			2,014			921		45.7	%
General and administrative expense as
a percentage of revenue		9.2	%		8.3	%
Interest (income) expense, net		-			(5	)		5
Other (income) expense, net		142			(519	)		661
Income before taxes and discontinued operations	$	5,988		$	3,020		$	2,968		98.3	%
Income before taxes and discontinued operations
as a percentage of revenue		18.9	%		12.4	%

Production Testing revenues increased during the second quarter of 2011 compared to the prior year period primarily due to an increase of approximately $7.6 million in domestic revenues. This increase was a result of increased onshore oil and gas drilling activity domestically, as reflected by rig count data. Partially offsetting this domestic increase, international revenues decreased by approximately $0.2 million primarily due to decreased revenues associated with a South American technical management contract.

The increase in Production Testing gross profit during the second quarter of 2011 was primarily due to the increased domestic activity discussed above. Gross profit on international operations also increased during the quarter due to increased activity in Mexico and Brazil.

Production Testing income before taxes increased due to the increased gross profit discussed above, but was partially offset by increased administrative expenses and decreased other income. Administrative expenses increased primarily due to increased salaries and employee-related costs. Other income decreased mainly due to decreased earnings from an unconsolidated joint venture.

Compressco Segment

	Three Months Ended June 30,						Period to Period Change
	2011			2010			2011 vs 2010			% Change
	(In Thousands, Except Percentages)

Revenues	$	22,326		$	20,446		$	1,880			9.2	%
Gross profit		6,925			7,944			(1,019	)		-12.8	%
Gross profit as a percentage of revenue		31.0	%		38.9	%
General and administrative expense		2,994			2,815			179			6.4	%
General and administrative expense as
a percentage of revenue		13.4	%		13.8	%
Interest (income) expense, net		(4	)		5			(9	)
Other (income) expense, net		126			87			39
Income before taxes and discontinued operations	$	3,809		$	5,037		$	(1,228	)		-24.4	%
Income before taxes and discontinued operations
as a percentage of revenue		17.1	%		24.6	%

The increase in Compressco revenues during the second quarter of 2011 compared to the prior year period was due to an increase of approximately $1.3 million of revenues from sales of compressor units and parts. This increase was primarily due to sales to a single domestic customer. Compressco service revenue increased by approximately $0.6 million compared to the prior year period, due to increased domestic demand for compression services. International service revenues were flat during the second quarter of 2011 compared to the prior year period. Although activity levels in Mexico are expected to increase going forward, Compressco was negatively affected by conditions in Mexico during the current year quarter compared to the prior year period, as customer budgetary issues and security disruptions have reduced activity levels. Compressco has reduced the fabrication of new compressor units until demand for its services increases and inventories of available units are reduced.

Despite the increased revenues, Compressco gross profit decreased during the second quarter of 2011 compared to the prior year period primarily due to its domestic operations, where increased operating expenses have hampered profitability. The increased domestic operating expenses included increased fuel, repair and maintenance, and field labor costs. In addition, conditions in Mexico have also contributed to lower gross profit compared to the prior year period.

Income before taxes for Compressco decreased during the second quarter of 2011 compared to the prior year period primarily due to the decreased gross profit discussed above. In addition, Compressco administrative expenses increased, primarily due to increased allocated employee-related costs. As a consequence of the June 20, 2011, initial public offering by Compressco Partners, administrative expenses for the Compressco segment will increase as a result of the allocation of the portion of our corporate administrative expenses associated with Compressco Partners’ activities pursuant to the Omnibus Agreement with Compressco Partners.

Corporate Overhead

	Three Months Ended June 30,						Period to Period Change
	2011			2010			2011 vs 2010			% Change
	(In Thousands, Except Percentages)

Gross profit (primarily depreciation expense)	$	(686	)	$	(737	)	$	51			6.9	%
General and administrative expense		8,283			9,083			(800	)		-8.8	%
Interest (income) expense, net		4,065			4,303			(238	)		-5.5	%
Other (income) expense, net		14,442			(1,019	)		15,461
Income (loss) before taxes and discontinued
operations	$	(27,476	)	$	(13,104	)	$	(14,372	)		-109.7	%

closing date of the initial public offering, we have begun allocating and charging Compressco Partners for its share of our corporate administrative costs directly related to Compressco Partners’ activities. Corporate Overhead increased significantly during the second quarter of 2011 compared to the prior year period due to increased other expenses, primarily due to approximately $14.3 million of increased hedge ineffectiveness losses that were mostly due to the April 2011 liquidation of the remaining commodity derivative swap agreements that previously were designated as hedges of Maritech production cash flows. Other expenses also increased due to approximately $0.8 million of decreased foreign currency gains. Partially offsetting the increase in other expense, corporate administrative costs decreased due to approximately $0.9 million of decreased professional fee expenses, approximately $0.1 million of decreased salaries and other general employee expenses, and approximately $0.2 million of decreased office expenses. These decreases were partially offset by approximately $0.5 million of increased insurance expense. In addition, corporate interest expense decreased during the second quarter of 2011 due to increased capitalized interest.

Six months ended June 30, 2011 compared with six months ended June 30, 2010.

Consolidated Comparisons

	Six Months Ended June 30,						Period to Period Change
	2011			2010			2011 vs 2010			% Change
	(In Thousands, Except Percentages)

Revenues	$	457,659		$	447,511		$	10,148			2.3	%
Gross profit		62,177			82,926			(20,749	)		-25.0	%
Gross profit as a percentage of revenue		13.6	%		18.5	%
General and administrative expense		56,768			47,732			9,036			18.9	%
General and administrative expense as
a percentage of revenue		12.4	%		10.7	%
Interest expense, net		8,276			8,266			10			0.1	%
(Gain) loss on sale of assets		(60,309	)		250			(60,559	)
Other (income) expense, net		13,929			(2,332	)		16,261
Income before taxes and discontinued operations		43,513			29,010			14,503			50.0	%
Income before taxes and discontinued operations as
a percentage of revenue		9.5	%		6.5	%
Provision for income taxes		15,502			9,919			5,583			56.3	%
Income before discontinued operations		28,011			19,091			8,920			46.7	%
Loss from discontinued operations, net of taxes		(57	)		(104	)		47
Net income		27,954			18,987			8,967			47.2	%
Net (income) attributable to noncontrolling interest		(95	)		-			(95	)
Net income attributable to TETRA stockholders	$	27,859		$	18,987		$	8,872			46.7	%

Consolidated revenues for the six months ended June 30, 2011 increased compared to the prior year period primarily due to growth in revenues from each of our segments, other than Maritech. In particular, revenues from our Fluids segment increased during the current year period due to increased international CBF sales activity in the regions we serve as well as increased domestic calcium chloride sales activity. Our Production Testing segment’s increased growth was due to increased domestic onshore activity. Our Compressco and Offshore Services segments also reported increased activity as well. These increases were partially offset by decreased revenues from our Maritech segment as compared to the prior year period. The decrease in Maritech revenues was primarily caused by the May 2011 sale of a significant portion of Maritech producing properties, which when combined with the impact of other property sales during the first eight months of this year, has resulted in Maritech selling approximately 95% of its proved oil and gas reserves as of December 31, 2010. Overall gross profit decreased primarily due to higher excess decommissioning costs and impairments incurred by Maritech, although Offshore Services and Compressco gross profit also decreased compared to the prior year period. These decreases were partially offset by increased gross profit from our Production Testing and Fluids segments.

Consolidated general and administrative expenses increased during the first six months of 2011 compared to the prior year period due to approximately $4.5 million of increased employee-related costs, a large portion of which was associated with retention and incentive benefits paid related to the sale of Maritech properties. In addition, general and administrative expenses also increased due to approximately $1.4 million of increased professional fee expenses, and $2.3 million of increased bad debt

expense, primarily due to the reversal of $1.3 million of bad debt expense during the prior year period. In addition, insurance, taxes, and other general expenses increased by approximately $0.8 million.

Net consolidated interest expense increased very slightly during the first six months of 2011, as the impact from issuing the 2010 Senior Notes to repay the 2004 Senior Notes in December 2010 was offset by decreased capitalized interest during the current year period.

Consolidated gains on sales of assets increased significantly during the first six months of 2011, primarily due to the sale of Maritech oil and gas producing properties, particularly the May 2011 sale of properties to Tana, which resulted in a consolidated net gain on sales of properties of approximately $58.2 million.

Consolidated other expense increased during the first six months of 2011 compared to the prior year period, primarily due to an approximately $14.6 million increase of hedge ineffectiveness expenses, due to the $14.2 million charge to expense upon the liquidation of commodity derivative swap contracts in connection with the decision to sell Maritech oil and gas producing properties. In addition, current year other income includes $2.4 million of decreased foreign currency gains compared to the prior year period. These increases in other expense were partially offset by approximately $0.9 million of increased earnings from unconsolidated joint ventures and $0.6 million of increased minority interest income.

Our provision for income taxes during the first six months of 2011 increased due to our increased earnings during the current year period compared to the prior year period.

Divisional Comparisons

Fluids Division

	Six Months Ended June 30,						Period to Period Change
	2011			2010			2011 vs 2010		% Change
	(In Thousands, Except Percentages)

Revenues	$	166,173		$	145,590		$	20,583		14.1	%
Gross profit		32,385			26,340			6,045		22.9	%
Gross profit as a percentage of revenue		19.5	%		18.1	%
General and administrative expense		13,766			10,757			3,009		28.0	%
General and administrative expense as
a percentage of revenue		8.3	%		7.4	%
Interest (income) expense, net		30			13			17
Other (income) expense, net		(205	)		(807	)		602
Income before taxes and discontinued operations	$	18,794		$	16,377		$	2,417		14.8	%
Income before taxes and discontinued operations as
a percentage of revenue		11.3	%		11.2	%

The increase in Fluids Division revenues during the first six months of 2011 compared to the prior year period was primarily due to $14.1 million of increased product sales revenues. This increase was due to $4.0 million of increased clear brine fluids (CBFs) product sales revenues, as increased activity internationally, particularly in Brazil, more than offset a decrease in domestic activity. Domestic offshore activity levels continue to be decreased as a result of the uncertain regulations governing offshore drilling activities following the April 2010 Macondo accident. Also contributing to the increased revenues was $10.6 million of increased sales of calcium chloride associated with our El Dorado, Arkansas, calcium chloride plant. In addition, European calcium chloride sales revenues also increased compared to the prior year period. Increased onshore domestic activity levels resulted in approximately $6.5 million of increased service revenues, including increased revenues from frac water services.

Our Fluids Division gross profit increased compared to the prior year period, primarily as a result of the increased gross profit from our chemicals manufacturing operations, both in Europe and from our El Dorado, Arkansas, plant, which continues to improve the efficiency of its operations. In addition, during the prior year period, we reflected certain startup costs associated with the El Dorado plant, which began operations in late 2009. We will continue to take steps to improve the operational efficiency of this plant, which are expected to result in improved plant performance throughout the remainder of 2011. Associated

with these plant operational inefficiencies, on March 18, 2011, we filed a lawsuit in the Circuit Court of Union County, Arkansas, seeking to recover damages related to certain design and other services provided in connection with the construction of the El Dorado plant. In addition to the increased gross profit from our chemicals manufacturing operations, sales of CBFs also generated increased gross profit, as the increased international activity discussed above more than offset decreased profitability domestically.

Fluids Division income before taxes increased compared to the prior year period due to the increase in gross profit discussed above, and despite increased administrative costs and a decrease in other income. Fluids Division administrative costs increased mainly due to increased professional fees and personnel-related costs.

Offshore Division

Offshore Services Segment

	Six Months Ended June 30,						Period to Period Change
	2011			2010			2011 vs 2010			% Change
	(In Thousands, Except Percentages)

Revenues	$	138,970		$	136,799		$	2,171			1.6	%
Gross profit		15,770			20,242			(4,472	)		-22.1	%
Gross profit as a percentage of revenue		11.3	%		14.8	%
General and administrative expense		7,819			8,356			(537	)		-6.4	%
General and administrative expense as
a percentage of revenue		5.6	%		6.1	%
Interest (income) expense, net		-			1			(1	)
Other (income) expense, net		(1,250	)		57			(1,307	)
Income before taxes and discontinued operations	$	9,201		$	11,828		$	(2,627	)		-22.2	%
Income before taxes and discontinued operations
as a percentage of revenue		6.6	%		8.6	%

Revenues from our Offshore Services segment increased during the first half of 2011 compared to the prior year quarter. Increased offshore well abandonment and decommissioning revenues were largely offset by decreased cutting services and diving services activity and a softer pricing environment. In addition, during May 2011, we sold our onshore abandonment operations, although this sale is not expected to significantly reduce our revenues in the future. During 2010, the BOEMRE issued NTL 2010-G05, the “Idle Iron Guidance” regulations, which require that wells located in Federal waters must be permanently plugged within three years of becoming uneconomic and that platforms and other infrastructure must be removed within five years of becoming uneconomic to operate. We anticipate that these new regulations will increase the future demand for well abandonment and decommissioning services to be performed by our Offshore Services segment. In July 2011, we purchased a new heavy lift derrick barge (which we named the TETRA Hedron) with a 1,600-metric-ton lift capacity, fully-revolving crane. With this vessel, which we expect to place into service in the Gulf of Mexico during the fourth quarter of 2011, our Offshore Services segment will significantly increase its heavy lift capacity and enable us to better serve the important Gulf of Mexico decommissioning market and now enable us to serve customers with heavier structures in the Gulf of Mexico. Still, we anticipate that levels of Offshore Services segment activity in 2011 will again be lower than the record activity levels we experienced during 2009. Approximately $34.1 million of Offshore Services revenues were from work performed for Maritech during the first six months of 2011, compared to $23.3 million of such work in the prior year period. These intercompany revenues are eliminated in consolidation. Despite the sale of Maritech’s oil and gas producing properties, a significant amount of abandonment and decommissioning work remains for Maritech going forward.

Gross profit for the Offshore Services segment during the first six months of 2011 decreased as compared to the prior year period primarily due to decreased profitability of our cutting services and diving services operations despite increased profitability of our decommissioning operations. A portion of the decrease in gross profit was caused by approximately $2.3 million of due diligence and inspection costs incurred during the second quarter of 2011 associated with the new heavy lift derrick barge we purchased in July 2011. Overall segment profitability was also affected by a lower pricing environment during the first six months of 2011 compared to the prior year period. Due to the anticipated increased activity as a result of

the “Idle Iron Guidance” regulations discussed above, we anticipate that pricing and profitability of many of the Offshore Services segment operations will increase going forward.

Offshore Services segment income before taxes decreased due to the decrease in gross profit described above despite the decreased administrative expenses, which resulted primarily from decreased insurance and salaries and employee-related costs. The decreased gross profit also more than offset the increase in other income, which was primarily generated from the sale of onshore abandonment operations during the second quarter of 2011.

Maritech Segment

	Six Months Ended June 30,						Period to Period Change
	2011			2010			2011 vs 2010			% Change
	(In Thousands, Except Percentages)

Revenues	$	77,404		$	96,969		$	(19,565	)		-20.2	%
Gross profit		(19,314	)		10,797			(30,111	)		-278.9	%
Gross profit as a percentage of revenue		-25.0	%		11.1	%
General and administrative expense		4,027			1,158			2,869			247.8	%
General and administrative expense as
a percentage of revenue		5.2	%		1.2	%
Interest (income) expense, net		20			(52	)		72
Other (income) expense, net		(57,364	)		4			(57,368	)
Income before taxes and
discontinued operations	$	34,003		$	9,687		$	24,316			251.0	%
Income (loss) before taxes and discontinued
operations as a percentage of revenue		43.9	%		10.0	%

Maritech revenues decreased during the first half of 2011 compared to the prior year period, primarily due to the sale of the significant majority of Maritech’s oil and gas producing properties. In addition to the first quarter sale of approximately 12% of Maritech’s December 31, 2010 total proved reserves, on May 31, 2011, Maritech completed the sale to Tana of additional oil and gas properties that collectively represent approximately 79% of Maritech’s December 31, 2010, total proved reserves. In August 2011, Maritech entered into an additional sale of approximately 3% of its total proved reserves. Primarily as a result of these sales and despite increased production at its Timbalier Bay and East Cameron 328 fields prior to their sale, decreased production volumes resulted in decreased revenues of approximately $10.2 million. In addition to the impact of decreased production, Maritech revenues decreased approximately $8.9 million due to decreased realized commodity prices. Most of this decrease was associated with Maritech’s natural gas production. Maritech had previously hedged a portion of its expected production cash flows by entering into derivative hedge contracts and its contracts hedging its oil production extended through 2011. However, Maritech’s hedges over its natural gas production expired at the end of 2010. In April 2011, in connection with the planned sale of oil and gas producing properties to Tana, we liquidated the oil derivative hedge contracts. As a result, beginning April 2011, Maritech’s remaining oil and gas production cash flows are no longer hedged. Including the impact of its oil hedge contracts through March 2011, Maritech reflected average realized oil prices during the first six months of 2011 of $102.02/barrel compared to $96.61/barrel during the prior year period. Maritech’s average natural gas price received during the first six months of 2011 was $4.34/MMBtu compared to the $8.38/MMBtu average realized price received during the prior year period. Following the above mentioned sales of producing properties, Maritech revenues are expected to be minimal going forward.

Maritech gross profit decreased significantly during the first six months of 2011 compared to the prior year period due to the decreased revenues discussed above as well as from approximately $18.2 million of increased excess decommissioning costs and $3.7 million of increased impairments as compared to the prior year period. In addition, Maritech recorded approximately $1.7 million of insurance settlement gains during the prior year period as a result of settlement and claim proceeds from Hurricane Ike damages.

Maritech income before taxes during the first six months of 2011 increased significantly compared to the prior year period despite the decrease in gross profit discussed above, due to approximately $57.4 million ($59.3 million consolidated) of net gains on sales of properties during the current year period associated with the above described sales of producing properties. Partially offsetting this increase in gain

on sale was the increase in administrative expenses during the current year period, primarily due to increased administrative expenses from retention and incentive compensation associated with the sale of Maritech properties. In addition, administrative expense during the prior year period included a $1.0 million reversal of bad debt expense.

Production Enhancement Division

Production Testing Segment

	Six Months Ended June 30,						Period to Period Change
	2011			2010			2011 vs 2010			% Change
	(In Thousands, Except Percentages)

Revenues	$	64,949		$	50,548		$	14,401			28.5	%
Gross profit		21,057			10,718			10,339			96.5	%
Gross profit as a percentage of revenue		32.4	%		21.2	%
General and administrative expense		6,989			4,171			2,818			67.6	%
General and administrative expense as
a percentage of revenue		10.8	%		8.3	%
Interest (income) expense, net		(36	)		(8	)		(28	)
Other (income) expense, net		(967	)		(460	)		(507	)
Income before taxes and discontinued operations	$	15,071		$	7,015		$	8,056			114.8	%
Income before taxes and discontinued operations
as a percentage of revenue		23.2	%		13.9	%

Production Testing revenues increased during the first six months of 2011 due to an increase of approximately $15.3 million in domestic revenues. This increase was a result of increased onshore oil and gas drilling activity domestically, as reflected by rig count data. This increase was partially offset by $0.9 million of decreased international revenues despite increased activity in Mexico and Brazil and due to decreased revenues associated with a South American technical management contract.

The increase in Production Testing gross profit during the first six months of 2011 was primarily due to the increased domestic activity discussed above. Gross profit on international Production Testing operations also increased during the six month period due to increased profitability on the South American technical management contract, despite the decreased revenues from the contract.

Production Testing income before taxes increased due to the increased gross profit discussed above, as well as due to increased other income as a result of $0.6 million of increased earnings from an unconsolidated joint venture. These increases were partially offset by increased administrative expenses primarily from increased bad debt expense during the 2011 period, particularly associated with the segment’s Libyan operations. Administrative expenses also increased due to increased salary and employee-related expenses and increased professional service expenses.

Compressco Segment

	Six Months Ended June 30,						Period to Period Change
	2011			2010			2011 vs 2010			% Change
	(In Thousands, Except Percentages)

Revenues	$	44,210		$	41,176		$	3,034			7.4	%
Gross profit		13,544			15,766			(2,222	)		-14.1	%
Gross profit as a percentage of revenue		30.6	%		38.3	%
General and administrative expense		5,517			5,520			(3	)		-0.1	%
General and administrative expense as
a percentage of revenue		12.5	%		13.4	%
Interest (income) expense, net		(3	)		33			(36	)
Other (income) expense, net		216			80			136
Income before taxes and discontinued operations	$	7,814		$	10,133		$	(2,319	)		-22.9	%
Income before taxes and discontinued operations
as a percentage of revenue		17.7	%		24.6	%

The increase in Compressco revenues was due to an increase of approximately $2.3 million of revenues from sales of compressor units and parts during the first six months of 2011 compared to the prior year period. This increase was primarily due to sales of compressor units to a single domestic customer. Compressco service revenue increased by approximately $0.8 million compared to the prior year period due to increased domestic demand for compression services. The increase in domestic service revenues was partially offset by decreased international service revenues, due to decreased activity in Mexico. Compressco continues to be negatively affected by conditions in Mexico, where customer budgetary issues and security disruptions have reduced activity levels. Compressco has reduced the fabrication of new compressor units until demand for its services increases and inventories of available units are reduced.

Compressco gross profit decreased during the first six months of 2011 compared to the prior year period primarily due to its domestic operations, where increased operating expenses hampered profitability. The increased domestic operating expenses included increased maintenance, fuel, and labor costs, including costs associated with preparing unutilized compressor units to be placed into service.

Income before taxes for Compressco decreased during the first six months of 2011 compared to the prior year period, primarily due to the decreased gross profit discussed above. Compressco administrative expenses were flat compared to the prior year period. As a consequence of the June 20, 2011 Offering, administrative expenses for the Compressco segment will increase as a result of the allocation of the portion of our corporate administrative expenses associated with Compressco Partners’ activities pursuant to the Omnibus Agreement with Compressco Partners.

Corporate Overhead

	Six Months Ended June 30,						Period to Period Change
	2011			2010			2011 vs 2010			% Change
	(In Thousands, Except Percentages)

Gross profit (primarily depreciation expense)	$	(1,373	)	$	(1,509	)	$	136			9.0	%
General and administrative expense		18,649			17,769			880			5.0	%
Interest (income) expense, net		8,265			8,278			(13	)		-0.2	%
Other (income) expense, net		14,830			(954	)		15,784
Income (loss) before taxes and discontinued
operations	$	(43,117	)	$	(26,602	)	$	(16,515	)		-62.1	%

Corporate Overhead includes corporate general and administrative expense, interest income and expense, and other income and expense. Such expenses and income are generally not allocated to our operating divisions, as they relate to our general corporate activities. However, in connection with the public offering of common units in our Compressco Partners, L.P. subsidiary, beginning on the June 20, 2011, closing date of the Offering, we have begun allocating and charging Compressco Partners for its share of our corporate administrative costs directly related to Compressco Partners’ activities. Corporate Overhead increased significantly during the first six months of 2011 compared to the prior year period, primarily due to increased other expense which resulted from approximately $14.3 million of increased hedge ineffectiveness loss. This increased hedge ineffectiveness loss was due to the April 2011 liquidation of hedge derivative contracts, following the planned sale of a significant portion of Maritech oil and gas producing properties, which resulted in a $14.2 million charge to corporate other expense for hedge ineffectiveness. In addition, other expense increased due to approximately $1.4 million of decreased foreign currency gains. Corporate administrative costs increased due to approximately $0.9 million of increased salaries and other general employee expenses, approximately $0.8 million of increased insurance and tax expenses, and approximately $0.1 million of increased general expenses. These increases were partially offset by approximately $0.5 million of decreased professional fee expenses and $0.3 million of decreased office expenses.

Liquidity and Capital Resources

In May 2011, Maritech completed the sale of a significant portion of its oil and gas producing properties to Tana in exchange for Tana’s assumption of the associated asset retirement obligations and payment of approximately $173.3 million cash at closing in addition to the approximately $11.1 million that was paid at the signing of the purchase and sale agreement. The properties sold to Tana collectively represent approximately 79% of Maritech’s total proved reserves and approximately $72 million of associated asset retirement obligations as of December 31, 2010. Maritech’s remaining asset retirement obligation is approximately $136.9 million as of June 30, 2011, and well abandonment and platform decommissioning activities will continue to be a significant use of our cash provided from operations going forward. Still, these sales of Maritech’s oil and gas reserve assets significantly changes our liquidity position and the nature of our cash flows from operating and investing activities going forward. The net proceeds from this sale will further strengthen our financial position, which we anticipate using to continue our strategy of growing our remaining businesses.

In June 2011, our Compressco Partners subsidiary completed its initial public offering. Net of expenses of the Offering, approximately $48.2 million was generated, including $32.2 million which Compressco Partners distributed to us to repay certain intercompany note balances. Following the Offering, we will continue to consolidate Compressco Partners as part of our Compressco segment in our consolidated financial statements; however, separate cash balances are now maintained by Compressco Partners to satisfy its operating requirements as well as to fund the quarterly distributions pursuant to its partnership agreement. We entered into an Omnibus Agreement with Compressco Partners, under which we will provide and be compensated for personnel and services reasonably necessary to manage the operations of Compressco Partners. To provide additional funding for its operating cash flow requirements, Compressco Partners entered into a $20.0 million bank line of credit agreement.

As a result of the above transactions, our consolidated cash has increased to $323.8 million as of June 30, 2011. Approximately $19.3 million of this consolidated cash is held by our Compressco Partners subsidiary for its operating and capital expenditure needs and is not available for our purposes. In July 2011, our Offshore Services segment purchased a heavy lift barge for $62.8 million. In addition to this significant investment, our other ongoing capital expenditure needs for the remainder of the year are expected to be increased compared to 2010, and we continue to fund these expenditures from our available cash, operating cash flows, or from the proceeds from asset sales. Operating cash flows during 2011, particularly for our domestic offshore operations, have continued to be negatively affected by the current uncertain regulatory environment following the prior year events in the Gulf of Mexico. However, excluding the impact from the sale of Maritech’s oil and gas producing properties, we expect the increases in our revenues and operating cash flows experienced during the first half of 2011 to continue for the remainder of the year.

Operating Activities

Cash flows generated by operating activities totaled approximately $59.9 million during the first six months of 2011 compared to $90.5 million during the prior year period, a decrease of $30.5 million or 33.8%. Approximately $39.8 million of prior period operating cash flows were generated from insurance settlements and claims proceeds from a portion of Maritech’s insurance coverage related to damages suffered from Hurricane Ike during 2008. The remaining increase in operating cash flows during 2011 primarily reflects the decreased use of operating cash flows for working capital mainly as a result of the collection of federal tax refunds during the first quarter of 2011.

Operating cash flows for our offshore Gulf of Mexico operations were reduced during the first six months of 2011 as a result of the continuing regulatory uncertainty that has followed the April 2010 Macondo oil spill in the U.S. Gulf of Mexico. Future operating cash flows for the offshore activities of our Fluids and Offshore Services segments will also be largely dependent upon the level of offshore oil and gas industry activity in the U.S. Gulf of Mexico region. As a result of the Macondo oil spill, regulatory requirements for offshore operators, particularly deepwater operators, have increased. Although the deepwater drilling moratorium was lifted in October 2010, the impact of regulatory uncertainty is expected to continue to negatively affect the cost and timing of offshore activities in the future, perhaps significantly. Many within the oil and gas industry are expecting further increases in regulatory requirements for all U.S. offshore drilling and production operations, particularly for deepwater projects. Operators are currently experiencing delays in permitting for deepwater as well as shallow water offshore projects.

Following the Macondo spill and the announcement of the drilling moratorium, the U.S. Gulf of Mexico offshore rig count dropped significantly, and, while this offshore rig count has improved recently, it is still below pre-Macondo spill levels. For certain of our businesses, increased government regulations could affect us positively. However, to the extent more stringent government regulations affecting deepwater and shallow water drilling are enacted, our future revenues and operating cash flows could be negatively affected overall.

Perhaps the most significant impact affecting our operations from the regulations enacted after the Macondo oil spill is the NTL 2010-G05 “Idle Iron Guidance” regulation, which requires that wells must be plugged within three years of becoming uneconomic and platform and other infrastructure must be removed within five years of becoming uneconomic to operate. Previously, the requirement was to perform this work after the last well in a field was depleted. The BOEMRE identified approximately 3,500 nonproducing wells and 650 oil and gas production platforms that meet the new criteria currently. These “Idle Iron Guidance” requirements are expected to increase the future demand for the abandonment and decommissioning services of our Offshore Services segment. Also significantly affected by these requirements is our Maritech subsidiary, as the new requirements have affected Maritech’s estimates for the plugging, abandonment, and decommissioning of its remaining oil and gas properties. Despite the sale of substantially all of Maritech’s oil and gas reserves, Maritech’s total remaining decommissioning liabilities are significant and our future operating cash flow will continue to be affected by the actual timing and amount of these decommissioning expenditures.

As of June 30, 2011, and following the sale of substantially all of Maritech’s producing oil and gas properties, the estimated third-party discounted fair value, including an estimated profit, of Maritech’s decommissioning liabilities totals $136.9 million ($137.2 million undiscounted). Approximately $89.4 million of the cash outflow necessary to extinguish Maritech’s remaining decommissioning liabilities is expected to occur prior to June 30, 2012. An additional $3.3 million of decommissioning liabilities was assumed by the purchaser of an additional oil and gas producing property sold by Maritech in August 2011. Maritech’s remaining decommissioning liabilities relate primarily to approximately 30 properties with no reserves, which represent an inventory of approximately $130.0 million of abandonment and decommissioning work, including an estimated profit margin, to be completed over the next two years. Our Offshore Services segment is expected to perform the significant majority of this work. The amount and timing of the cash outflows associated with all of Maritech’s remaining decommissioning liabilities are estimated based on expected costs and project scheduling. Such estimates are imprecise and subject to change due to changing cost estimates, further changes to BOEMRE requirements, and other factors.

In some cases, the previous owners of the properties that were acquired by Maritech are contractually obligated to pay Maritech a fixed amount for the future well abandonment and decommissioning work on these properties as the work is performed, which partially offsets Maritech’s future expenditures. Maritech’s estimated decommissioning liabilities are net of amounts allocable to joint interest owners and any contractual amounts to be paid by the previous owners of the properties. As of June 30, 2011, Maritech’s total undiscounted decommissioning obligation is approximately $146.5 million and consists of Maritech’s total liability of $137.2 million plus $9.3 million of such contractual reimbursement arrangements with the previous owners. An additional $12.0 of such contractual reimbursement arrangements as of June 30, 2011, is classified as receivable assets related to amounts waiting to be invoiced and collected.

While the overall global economy continues to be difficult to predict, industry rig count and other data indicates that domestic oil and gas industry spending is increasing, spurred by the current strong pricing for crude oil and the recent trends for onshore shale exploitation. Demand for a large portion of our products and services is driven by oil and gas drilling and production activity, which is affected by oil and natural gas commodity pricing. In particular, our Production Testing, Compressco, and Fluids segments reported increased domestic activity levels during the last half of 2010 and the first half of 2011. We are anticipating similar increases in revenues and cash flows for these businesses throughout the remainder of 2011; however, these planned levels are expected to continue to be significantly below the levels generated by these businesses during the first half of 2008.

During the past two years, Maritech has performed an extensive amount of well intervention, abandonment, decommissioning, debris removal, and platform construction associated with the six offshore platforms that were destroyed by Hurricanes Rita and Ike during 2005 and 2008, respectively. As of June 30, 2011, Maritech has remaining work associated with two of the downed platforms. The estimated cost to perform the remaining abandonment, decommissioning, and debris removal will be approximately $33.9 million net to our interest before any insurance recoveries. Due to the unique nature of the remaining work to be performed, actual costs could greatly exceed these estimates and, depending on the nature of any excess costs incurred, could result in significant charges to earnings in future periods. All of this $33.9 million estimated amount has been accrued as part of Maritech’s decommissioning liabilities. Maritech has additional maximum remaining insurance coverage available of approximately $19.5 million, all of which relates to Hurricane Ike, although a portion of these costs may not be reimbursed. One of the underwriters associated with our windstorm insurance coverage for Hurricane Ike damages has contested whether certain repair costs incurred are covered costs under the policy. During December 2010, we initiated legal proceedings against this underwriter in an attempt to collect the amount of claim reimbursements provided for under the policy. The timing of the collection of any future reimbursements is beyond our control, and we will continue to use a significant amount of our working capital until such reimbursements are received.

Last year’s explosion and subsequent oil spill at the Macondo well evidences the general operating risks associated with offshore oil and gas activities. While we have no liability associated with this specific incident, we are subject to operating hazards normally associated with the oilfield service industry and offshore oil and gas production operations, including fires, explosions, blowouts, cratering, mechanical problems, abnormally pressured formations, and environmental accidents. We maintain various types of business insurance that would be applicable in the event of an explosion or other catastrophic event involving our offshore operations. This insurance includes third-party liability, workers’ compensation and employers’ liability, general liability, vessel pollution liability, and operational risk coverage for our Maritech oil and gas properties, including removal of debris, operator’s extra expense, control of well, and pollution and clean up coverage. We have elected not to maintain windstorm insurance on Maritech’s remaining offshore oil and gas property assets. Our insurance coverage includes deductibles that must be met prior to recovery. Additionally, our insurance is subject to certain exclusions and limitations. We believe our policy of insuring against such risks, as well as the levels of insurance we maintain, is typical in the industry. In addition, we provide services and products in the offshore Gulf of Mexico generally pursuant to agreements that create insurance and indemnity obligations for both parties. Our Maritech subsidiary maintains a formalized oil spill response plan that it submits to BOEMRE. Maritech has designated employees and third-party contracts in place to ensure that resources are available as required in the event of an environmental accident. While it is impossible to anticipate every potential accident or incident involving our offshore operations, we believe we have taken appropriate steps to mitigate the potential impact of such an event on the environment in the regions in which we operate.

Investing Activities

During the first six months of 2011, we generated $144.7 million of cash flows from investing activities, reflecting the significant proceeds received from asset sales, primarily from the sales of Maritech properties. During the six months ended June 30, 2011, we expended $36.3 million of capital expenditures. This capital expenditure activity was spread among each of our operating segments. For certain of our businesses, our capital expenditure plans have been, and will continue to be, reviewed carefully, and a significant amount of planned capital expenditures have been deferred until activity levels increase. This restraint on capital expenditure activity may also affect future growth. The sale of our Maritech assets ended our investing activities on oil and gas exploration and development activities, which was previously a significant portion of our total investing activities. With a portion of the proceeds from the sale of these Maritech assets, in July 2011, we purchased a heavy lift derrick barge with a 1,600-metric-ton lift capacity, fully-revolving crane for approximately $62.8 million. Additional costs will be subsequently incurred for inspection, transportation, and outfitting costs on this barge prior to placing it into service, which will result in a total investment in the barge of approximately $71 million. This asset purchase will significantly expand the capability of our Offshore Services segment, and now enables us to serve customers with heavier structures in the Gulf of Mexico.

During the first six months of 2011, our cash capital expenditures totaled approximately $36.3 million. In March 2011, we also expended $1.5 million for the acquisition of a consulting service business associated with our Offshore Services segment. Approximately $9.5 million of our first six months of 2011 capital expenditures was expended by our Fluids Division, approximately $4.4 million of which related to the ongoing modification of our new calcium chloride plant facility. Our Offshore Division expended approximately $13.6 million, consisting of approximately $7.2 million of development expenditures for Maritech prior to the sale of substantially all of its oil and gas properties. In addition, the Offshore Division expended approximately $6.4 million on its Offshore Services operations for costs on its various heavy lift and dive support vessels exclusive of the March 2011 acquisition and the July 2011 purchase of the TETRA Hedron barge. Our Production Enhancement Division spent approximately $12.4 million, consisting of approximately $9.2 million by the Production Testing segment to replace or enhance a portion of its production testing equipment fleet and approximately $3.2 million by the Compressco segment for general infrastructure needs, along with expansion of its wellhead compressor fleet. Corporate capital expenditures were approximately $0.7 million.

Generally, a significant majority of our planned capital expenditures is related to identified opportunities to grow and expand our existing businesses; however, certain of these expenditures may be postponed or cancelled in our continuing efforts to conserve capital. Including the July 2011 purchase of the TETRA Hedron heavy lift barge, we plan to expend up to $175 million on total capital expenditures during 2011. This anticipated level of capital expenditure activity would result in increased spending compared to 2010 for each of our business segments other than Maritech and Compressco. The deferral of certain capital projects, such as the additional replacement or upgrading of vessels in our Offshore Services fleet, could affect our ability to compete in the future. Particularly following the receipt of the net proceeds from the May 2011 sale of Maritech properties, our long-term growth strategy continues to include the pursuit of suitable acquisitions or opportunities to expand operations in oil and gas service markets. To the extent we consummate a significant acquisition transaction, our liquidity position will be affected.

Financing Activities

To fund our capital and working capital requirements, we may supplement our existing cash balances and cash flow from operating activities as needed from long-term borrowings, short-term borrowings, equity issuances, and other sources of capital.

Our Bank Credit Facility

We have a revolving credit facility with a syndicate of banks pursuant to a credit facility agreement that was most recently amended in October 2010 (the Credit Agreement). As of August 9, 2011, we did not have any outstanding balance on the revolving credit facility and had $8.0 million in letters of credit and guarantees against the $278 million revolving credit facility, leaving a net availability of $270.0 million. In addition, the amended credit facility agreement allows us to increase the facility by $150 million up to a $428 million limit upon the agreement of the lenders and the satisfaction of certain conditions.

Under the amended credit facility agreement (the Credit Agreement), the revolving credit facility is unsecured and guaranteed by certain of our material U.S. subsidiaries. Borrowings generally bear interest at the British Bankers Association LIBOR rate plus 1.5% to 2.5%, depending on one of our financial ratios. We pay a commitment fee ranging from 0.225% to 0.500% on unused portions of the facility. The Credit Agreement contains customary covenants and other restrictions, including certain financial ratio covenants involving 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. Access to our revolving credit line is dependent upon our ability to comply with the certain financial ratio covenants set forth in the Credit Agreement, as discussed above. Significant deterioration of the financial ratios could result in a default under the Credit Agreement and, if not remedied, could result in termination of the agreement and acceleration of any outstanding balances. In June 2011, associated with the contribution of the majority of the operations and related assets and liabilities of our Compressco segment into Compressco Partners, Compressco Partners was designated as an unrestricted subsidiary and is no longer a borrower or a guarantor under our bank credit facility.

The Credit Agreement also includes cross-default provisions relating to any other indebtedness greater than a defined amount. If any such indebtedness is not paid or is accelerated and such event is not remedied in a timely manner, a default will occur under the Credit Agreement. 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. We are in compliance with all covenants and conditions of our Credit Agreement as of June 30, 2011. Our continuing ability to comply with these financial covenants depends largely upon our ability to generate adequate cash flow. Historically, our financial performance has been more than adequate to meet these covenants, and we expect this trend to continue.

Senior Notes

In April 2006, we issued, and sold through a private placement, $90.0 million in aggregate principal amount of Series 2006-A Senior Notes pursuant to a Master Note Purchase Agreement dated September 2004, as supplemented as of April 18, 2006. The Series 2006-A Senior Notes bear interest at the fixed rate of 5.90% and mature on April 30, 2016. Interest on the 2006-A Senior Notes is due semiannually on April 30 and October 30 of each year.

In April 2008, we issued, and sold through a private placement, $35.0 million in aggregate principal amount of Series 2008-A Senior Notes and $90.0 million in aggregate principal amount of Series 2008-B Senior Notes (collectively the Series 2008 Senior Notes) pursuant to a Note Purchase Agreement dated April 30, 2008. The Series 2008-A Senior Notes bear interest at the fixed rate of 6.30% and mature on April 30, 2013. The Series 2008-B Senior Notes bear interest at the fixed rate of 6.56% and mature on April 30, 2015. Interest on the Series 2008 Senior Notes is due semiannually on April 30 and October 31 of each year.

In December 2010, we issued and sold through a private placement, $65.0 million in aggregate principal amount of Series 2010-A Senior Notes and $25.0 million in aggregate principal amount of Series 2010-B Senior Notes (collectively, the 2010 Senior Notes) pursuant to a Note Purchase Agreement dated September 30, 2010. The Series 2010-A Senior Notes bear interest at the fixed rate of 5.09% and mature on December 15, 2017. The Series 2010-B Senior Notes bear interest at the fixed rate of 5.67% and mature on December 15, 2020. Interest on the Series 2010 Senior Notes is due semiannually on June 15 and December 15 of each year.

Each of the Senior Notes was sold in the United States to accredited investors pursuant to an exemption from the Securities Act of 1933. We may prepay the Senior Notes, in whole or in part, at any time at a price equal to 100% of the principal amount outstanding, plus accrued and unpaid interest and a “make-whole” prepayment premium. The Senior Notes are unsecured and are guaranteed by substantially all of our wholly owned U.S. subsidiaries. The Note Purchase Agreement and the Master Note Purchase Agreement, as supplemented, contain customary covenants and restrictions and require us to maintain certain financial ratios, including a minimum level of net worth and a ratio between our long-term debt balance and a defined measure of operating cash flow over a twelve month period. The Note Purchase Agreements and the Master Note Purchase Agreement also contain customary default provisions as well as a cross-default provision relating to any other of our indebtedness of $20 million or more. We are in compliance with all covenants and conditions of the Note Purchase Agreements and the Master Note Purchase Agreement as of June 30, 2011. Upon the occurrence and during the continuation of an event of default under the Note Purchase Agreements and the Master Note Purchase Agreement, as supplemented, the Senior Notes may become immediately due and payable, either automatically or by declaration of holders of more than 50% in principal amount of the Senior Notes outstanding at the time.

Compressco Partners’ Bank Credit Facility

Partners’ working capital needs, letters of credit, and for general partnership purposes, including capital expenditures and potential future expansions or acquisitions. So long as Compressco Partners is not in default, the Partnership Credit Agreement could also be used to fund Compressco Partners’ quarterly distributions at the option of the board of directors of its general partner. Borrowings under the Partnership Credit Agreement are subject to the satisfaction of customary conditions, including the absence of a default. As of June 30, 2011, there is no balance outstanding under the Partnership Credit Agreement. The maturity date of the Partnership Credit Agreement is June 24, 2015.

All obligations under the Partnership Credit Agreement and the guarantees of those obligations are secured, subject to certain exceptions, by a first lien security interest in substantially all of Compressco Partners’ existing and future, direct and indirect, domestic subsidiaries’ assets (excluding real property) and all of the capital stock of its existing and future, direct and indirect, domestic subsidiaries (limited, in the case of foreign subsidiaries, to 65% of the capital stock of first tier foreign subsidiaries).

Borrowings under the Partnership Credit Agreement bear interest at a rate per annum equal to, at our option, either (a) LIBOR (adjusted to reflect any required bank reserves) for an interest period equal to one, two, three or six months (as we select) plus a margin of 2.25% per annum or (b) a base rate determined by reference to the highest of (1) the prime rate of interest announced from time to time by JPMorgan Chase Bank, N.A. or (2) LIBOR (adjusted to reflect any required bank reserves) for a one-month interest period on such day plus 2.50% per annum. In addition to paying interest on any outstanding principal under the Partnership Credit Agreement, Compressco Partners is required to pay customary collateral monitoring fees and letter of credit fees, including without limitation, a letter of credit fee equal to the applicable margin on revolving credit LIBOR loans and fronting fees.

The Partnership Credit Agreement requires Compressco Partners to maintain a minimum interest coverage ratio (ratio of earnings before interest and taxes to interest) of 2.5 to 1.0 as of the last day of any fiscal quarter, calculated on a trailing four quarter basis, whenever availability is less than $5 million. In addition, the Partnership Credit Agreement includes customary negative covenants, which, among other things, limit Compressco Partners’ ability to incur additional debt, incur or permit certain liens to exist, or make certain loans, investments, acquisitions or other restricted payments. The Partnership Credit Agreement provides that Compressco Partners can make distributions to holders of its common units, but only if there is no default or event of default under the facility. If an event of default occurs, the lenders would be entitled to take various actions, including the acceleration of amounts due under the Partnership Credit Agreement and all actions permitted to be taken by secured creditors.

Other Sources

In addition to the aforementioned revolving credit facility, we fund our short-term liquidity requirements from existing cash balances, cash generated by operations, short-term vendor financing and, to a lesser extent, leasing with institutional leasing companies. Should additional capital be required, we believe that we have the ability to raise such capital through the 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. As discussed above, our Credit Agreement matures in 2015 and our Senior Notes mature at various dates between April 2013 and December 2020. The replacement of these capital sources at similar or more favorable terms is not certain. If it is necessary to utilize our equity to fund our capital needs, dilution to our common stockholders could occur.

The June 2011 initial public offering by Compressco Partners provides it with the ability to issue additional common units to the public for cash or to use such units as consideration in an acquisition transaction. Additional issuances of Compressco Partners common units would dilute our ownership interest in Compressco Partners.

In November 2009, we filed a universal shelf registration statement on Form S-3 that permits us to issue an indeterminate amount of securities including common stock, preferred stock, senior and subordinated debt securities, warrants, and units. Such securities may be used for working capital needs, capital expenditures, and expenditures related to general corporate purposes, including possible future acquisitions. In May 2004, we filed a universal acquisition shelf registration statement on Form S-4 that permits us to issue up to $400 million of common stock, preferred stock, senior and subordinated debt securities, and warrants in one or more acquisition transactions that we may undertake from time to time.

Off Balance Sheet Arrangements

As of June 30, 2011, 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

Derivative Lawsuit

Environmental

Cautionary Statement for Purposes of Forward-Looking Statements

Certain statements contained herein and elsewhere may be deemed to be forward-looking within the meaning of the Private Securities Litigation Reform Act of 1995 and are subject to the “safe harbor” provisions of that act, including, without limitation, statements concerning future or expected sales, earnings, costs, expenses, acquisitions or corporate combinations, including the pending sale of oil and gas properties and the anticipated benefits to be realized from this sale, asset recoveries, expected costs associated with damage from hurricanes and the ability to recover such costs under our insurance policies, the ability to resume operations and production from our damaged or destroyed platforms, the ability to obtain alternate sources of raw materials for certain of our calcium chloride facilities, working capital, capital expenditures, financial condition, other results of operations, the expected impact of current economic and capital market conditions on the oil and gas industry and our operations, other statements regarding our beliefs, plans, goals, future events and performance, and other statements that are not purely historical. Such statements involve risks and uncertainties, many of which are beyond our control. Actual results could differ materially from the expectations expressed in such forward-looking statements. Some of the risk factors that could affect our actual results and cause actual results to differ materially from any such results that might be projected, forecast, estimated, or budgeted by us in such forward-looking statements are described in our Annual Report on Form 10-K for the year ended December 31, 2010, and this Quarterly Report on Form 10-Q, and are set forth from time to time in our filings with the Securities and Exchange Commission.

Item 3. Quantitative and Qualitative Disclosures about Market Risk.

In April 2011, in connection with a purchase and sale agreement to sell a significant amount of Maritech’s remaining oil and gas properties, we liquidated the derivative swap financial instruments that were designated as hedges of Maritech’s future oil production. As a result, we will be exposed to the commodity price risk associated with Maritech’s oil and natural gas production that we will continue to own following the sale. Due to the minimal amount of expected production following the sale, such commodity price risk exposure is not expected to be significant.

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, 2011, 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, 2011, 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.

The information regarding litigation matters described in the Notes to Consolidated Financial Statements, Note H – Commitments and Contingencies, Litigation, and included elsewhere in this Quarterly Report on Form 10-Q is incorporated herein by reference.

Item 1A. Risk Factors.

The terms of the subordinated units we hold in Compressco Partners may result in us not receiving our share of the distributable cash flows of Compressco Partners.

Compressco Partners may not have sufficient cash from operations to enable it to make cash distributions to holders of common units at the minimum quarterly distribution rate under its cash distribution policy. To the extent sufficient distributable cash is not available, the distribution shortfall will first be attributed to the subordinated units we hold, resulting in a reduction in our financing cash flows from distributions from Compressco Partners. Any shortfall in quarterly distributions attributed to the subordinated units will not be carried forward in arrears or recovered in future distributions.

We have elected to self-insure windstorm damage to our Maritech assets in the Gulf of Mexico and hurricane damages could result in significant uninsured losses.

Despite the sale of approximately 95% of Maritech’s yearend oil and gas reserves, we retained approximately $136.9 million of decommissioning liabilities associated with offshore platforms and associated wells to be decommissioned and abandoned. During the second quarter of 2011, we determined that the cost of premiums and the associated deductibles and coverage limits for windstorm damage for Maritech’s remaining offshore platforms and wells was uneconomical. Therefore, Maritech has discontinued its insurance coverage for windstorm damage for the 2011 hurricane season, electing to self-insure for these damages. Accordingly, Maritech is currently exposed to losses from uninsured windstorm damages during the current year and may be similarly exposed to storms in future years if we choose to remain self-insured. Depending on the severity and location of the storms, such losses could be significant and could have a material adverse effect on our financial position, results of operation, and cash flows.

There can be no assurance that future insurance coverage with more favorable deductible and maximum coverage amounts will be available in the market or that its cost will be justifiable. There can be no assurance that any insurance will be adequate to cover losses or liabilities associated with operational hazards. We cannot predict the continued availability of insurance or its availability at premium levels that justify its purchase.

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

(a) None.

(b) None.

								Maximum Number (or
				Average		Total Number of Shares		Approximate Dollar Value) of
	Total Number			Price		Purchased as Part of		Shares that May Yet be
	of Shares			Paid per		Publicly Announced		Purchased Under the Publicly
Period	Purchased			Share		Plans or Programs(1)		Announced Plans or Programs(1)

Apr 1 - Apr 30, 2011		30,775	(2)	$	14.39		-	$	14,327,000
May 1 - May 31, 2011		40,356	(2)		13.34		-		14,327,000
Jun 1 - Jun 30, 2011		1,224	(2)		14.23		-		14,327,000
Total		72,355					-	$	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 employee restricted stock. These shares were not acquired pursuant to the stock repurchase program.

Item 3. Defaults Upon Senior Securities.

None.

Item 4. (Removed and Reserved.)

Item 5. Other Information.

None.

Item 6. Exhibits.

Exhibits:

10.1	Contribution, Conveyance and Assumption Agreement, dated June 20, 2011, by and among Compressco, Inc., Compressco Field Services, Inc., Compressco Canada, Inc., Compressco de Mexico, S. de R.L. de C.V., Compressco Partners GP Inc., Compressco Partners, L.P., Compressco Partners Operating, LLC, Compressco Netherlands B.V., Compressco Holdings, LLC, Compressco Netherlands Coöperatief U.A., Compressco Partners Sub, Inc., TETRA International Incorporated, Production Enhancement Mexico, S. de R.L. de C.V. and TETRA Technologies, Inc. (incorporated by reference to Exhibit 10.1 to the Company’s Current Report on Form 8-K filed on June 30, 2011 (SEC File No. 001-13455)).
10.2	Omnibus Agreement, dated June 20, 2011, by and among Compressco Partners, L.P., TETRA Technologies, Inc. and Compressco Partners GP Inc. (incorporated by reference to Exhibit 10.2 to the Company’s Current Report on Form 8-K filed on June 30, 2011 (SEC File No. 001-13455)).
10.3*	Purchase and Sale Agreement, dated April 1, 2011, by and between Maritech Resources, Inc. as Seller and Tana Exploration Company LLC as Buyer.
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 months ended June 30, 2011 and 2010; (ii) Consolidated Balance Sheets as of June 30, 2011 and December 31, 2010; (iii) Consolidated Statements of Cash Flows for the six months ended June, 2011 and 2010; and (iv) Notes to Consolidated Financial Statements for the six months ended June 30, 2011. Users of this data are advised pursuant to Rule 406T of Regulation S-T that the interactive data files in Exhibit 101 to this Quarterly Report on Form 10-Q shall not be “filed” for purposes of Section 18 of the Securities Exchange Act of 1934, as amended, or otherwise subject to the liabilities of that section, and shall not be part of any registration statement or other document filed under the Securities Act of 1933, as amended, or the Securities Exchange Act of 1934, as amended, except as shall be expressly set forth by specific reference in such filing.

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.

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, 2011	By:	/s/Stuart M. Brightman
		Stuart M. Brightman
		President
		Chief Executive Officer


Date: August 9, 2011	By:	/s/Joseph M. Abell
		Joseph M. Abell
		Senior Vice President
		Chief Financial Officer


Date: August 9, 2011	By:	/s/Ben C. Chambers
		Ben C. Chambers
		Vice President – Accounting
		Principal Accounting Officer

EXHIBIT INDEX

10.1	Contribution, Conveyance and Assumption Agreement, dated June 20, 2011, by and among Compressco, Inc., Compressco Field Services, Inc., Compressco Canada, Inc., Compressco de Mexico, S. de R.L. de C.V., Compressco Partners GP Inc., Compressco Partners, L.P., Compressco Partners Operating, LLC, Compressco Netherlands B.V., Compressco Holdings, LLC, Compressco Netherlands Coöperatief U.A., Compressco Partners Sub, Inc., TETRA International Incorporated, Production Enhancement Mexico, S. de R.L. de C.V. and TETRA Technologies, Inc. (incorporated by reference to Exhibit 10.1 to the Company’s Current Report on Form 8-K filed on June 30, 2011 (SEC File No. 001-13455)).
10.2	Omnibus Agreement, dated June 20, 2011, by and among Compressco Partners, L.P., TETRA Technologies, Inc. and Compressco Partners GP Inc. (incorporated by reference to Exhibit 10.2 to the Company’s Current Report on Form 8-K filed on June 30, 2011 (SEC File No. 001-13455)).
10.3*	Purchase and Sale Agreement, dated April 1, 2011, by and between Maritech Resources, Inc. as Seller and Tana Exploration Company LLC as Buyer.
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 months ended June 30, 2011 and 2010; (ii) Consolidated Balance Sheets as of June 30, 2011 and December 31, 2010; (iii) Consolidated Statements of Cash Flows for the six months ended June 30, 2011 and 2010; and (iv) Notes to Consolidated Financial Statements for the six months ended June 30, 2011. Users of this data are advised pursuant to Rule 406T of Regulation S-T that the interactive data files in Exhibit 101 to this Quarterly Report on Form 10-Q shall not be “filed” for purposes of Section 18 of the Securities Exchange Act of 1934, as amended, or otherwise subject to the liabilities of that section, and shall not be part of any registration statement or other document filed under the Securities Act of 1933, as amended, or the Securities Exchange Act of 1934, as amended, except as shall be expressly set forth by specific reference in such filing.