UNITED STATES SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

 

Form 10-Q

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

For the quarterly period ended June 30, 2008

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

For the transition period from               to

Basic Energy Services, Inc.

Delaware (State or other jurisdiction of incorporation or organization)		54-2091194 (I.R.S. Employer Identification No.)
500 W. Illinois, Suite 100 Midland, Texas (Address of principal executive offices)		79701 (Zip code)

(432) 620-5500
(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 þ No o

     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):

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

     41,331,605 shares of the registrant’s Common Stock were outstanding as of August 1, 2008.

 

 

BASIC ENERGY SERVICES, INC.

Index to Form 10-Q

Part I. FINANCIAL INFORMATION			4
Item 1. Financial Statements			4
Consolidated Balance Sheets as of June 30, 2008 and December 31, 2007			4
Consolidated Statements of Operations and Comprehensive Income for the three months and six months ended June 30, 2008 and 2007			5
Consolidated Statements of Stockholders’ Equity for the six months ended June 30, 2008			6
Consolidated Statements of Cash Flows for the six months ended June 30, 2008 and 2007			7
Notes to the Consolidated Financial Statements			8
Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations			26
Management’s Overview			26
Segment Overview			28
Operating Cost Overview			31
Critical Accounting Policies and Estimates			32
Results of Operations			33
Liquidity and Capital Resources			36
Other Matters			39
Item 3. Quantitative and Qualitative Disclosures About Market Risk			40
Item 4. Controls and Procedures			41
Part II. OTHER INFORMATION			41
Item 1. Legal Proceedings			41
Item 1A. Risk Factors			41
Item 6. Exhibits			42
Signatures			43

CAUTIONARY STATEMENT
REGARDING FORWARD-LOOKING STATEMENTS

     This quarterly report contains certain statements that are, or may be deemed to be, “forward-looking statements” within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended, or the Exchange Act. We have based these forward-looking statements largely on our current expectations and projections about future events and financial trends affecting the financial condition of our business. These forward-looking statements are subject to a number of risks, uncertainties and assumptions, including, among other things, the risk factors discussed in this quarterly report and other factors, most of which are beyond our control.

     The words “believe,” “may,” “estimate,” “continue,” “anticipate,” “intend,” “plan,” “expect” and similar expressions are intended to identify forward-looking statements. All statements other than statements of current or historical fact contained in this quarterly report are forward looking-statements. Although we believe that the forward-looking statements contained in this quarterly report are based upon reasonable assumptions, the forward-looking events and circumstances discussed in this quarterly report may not occur and actual results could differ materially from those anticipated or implied in the forward-looking statements.

     Important factors that may affect our expectations, estimates or projections include:

	•		a decline in, or substantial volatility of, oil and gas prices, and any related changes in expenditures by our customers;
	•		the effects of future acquisitions on our business;
	•		changes in customer requirements in markets or industries we serve;
	•		competition within our industry;
	•		general economic and market conditions;
	•		our access to current or future financing arrangements;
	•		our ability to replace or add workers at economic rates; and
	•		environmental and other governmental regulations.

     Our forward-looking statements speak only as of the date of this quarterly report. Unless otherwise required by law, we undertake no obligation to publicly update or revise any forward-looking statements, whether as a result of new information, future events or otherwise.

     This quarterly report includes market share, industry data and forecasts that we obtained from internal company surveys (including estimates based on our knowledge and experience in the industry in which we operate), market research, consultant surveys, publicly available information, industry publications and surveys. Industry surveys, publications, consultant surveys and forecasts generally state that the information contained therein has been obtained from sources believed to be reliable. Although we believe such information is accurate and reliable, we have not independently verified any of the data from third party sources cited or used for our management’s industry estimates, nor have we ascertained the underlying economic assumptions relied upon therein. For example, the number of onshore well servicing rigs in the U.S. could be lower than our estimate to the extent our two larger competitors have continued to report as stacked rigs equipment that is not actually complete or subject to refurbishment. Statements as to our position relative to our competitors or as to market share refer to the most recent available data.

PART I — FINANCIAL INFORMATION

ITEM 1.		FINANCIAL STATEMENTS

Basic Energy Services, Inc.
Consolidated Balance Sheets
(in thousands, except share data)

		June 30,				December 31,
		2008				2007
		(Unaudited)
ASSETS
Current assets:
Cash and cash equivalents		$	77,784			$	91,941
Trade accounts receivable, net of allowance of $5,607 and $6,090, respectively			165,377				138,384
Accounts receivable — related parties			170				91
Income tax receivable			214				1,130
Inventories			10,977				11,034
Prepaid expenses			4,689				6,999
Other current assets			5,535				6,353
Deferred tax assets			10,737				10,593
Total current assets			275,483				266,525
Property and equipment, net			665,922				636,924
Deferred debt costs, net of amortization			5,618				6,100
Goodwill			230,777				204,963
Other intangible assets, net of amortization			29,670				26,975
Other assets			2,306				2,122
		$	1,209,776			$	1,143,609
LIABILITIES AND STOCKHOLDERS’ EQUITY
Current liabilities:
Accounts payable		$	23,137			$	22,146
Accrued expenses			54,702				51,003
Current portion of long-term debt			20,521				17,413
Other current liabilities			524				1,474
Total current liabilities			98,884				92,036
Long-term debt			412,846				406,306
Deferred tax liabilities			126,506				114,604
Other long-term liabilities			4,857				5,842
Commitments and contingencies
Stockholders’ equity:
Preferred stock; $.01 par value; 5,000,000 shares authorized; none designated at June 30, 2008 and December 31, 2007, respectively			—				—
Common stock; $.01 par value; 80,000,000 shares authorized; 41,331,605 issued; 41,330,247 shares outstanding at June 30, 2008 and 40,925,530 issued; 40,896,217 shares outstanding at December 31, 2007, respectively			413				409
Additional paid-in capital			318,966				314,705
Retained earnings			247,304				209,707
Treasury stock, at cost, 1,358 and 29,313 shares, respectively			—				—
Total stockholders’ equity			566,683				524,821
		$	1,209,776			$	1,143,609

See accompanying notes to consolidated financial statements.

Basic Energy Services, Inc.
Consolidated Statements of Operations and Comprehensive Income
(in thousands, except per share amounts)

		Three Months Ended June 30,								Six Months Ended June 30,
		2008				2007				2008				2007
		(Unaudited)								(Unaudited)
Revenues:
Well servicing		$	89,018			$	86,111			$	169,537			$	172,780
Fluid services			72,581				63,191				143,980				127,373
Completion and Remedial Services			79,579				63,736				148,037				109,873
Contract drilling			10,344				10,218				19,841				12,160
Total revenues			251,522				223,256				481,395				422,186
Expenses:
Well servicing			55,293				52,084				103,759				102,178
Fluid services			48,554				40,379				94,987				80,481
Completion and Remedial Services			42,651				33,374				78,439				56,509
Contract drilling			7,529				6,184				14,589				8,998
General and administrative, including stock-based compensation of $1,184 and $1,062 in three months ended June 30, 2008 and 2007, and $2,264 and $2,155 in the six months ended June 30, 2008 and 2007, respctively			26,811				25,592				52,663				48,241
Depreciation and amortization			28,732				24,007				56,764				43,232
(Gain) loss on disposal of assets			(809	)			(166	)			(584	)			175
Total expenses			208,761				181,454				400,617				339,814
Operating income			42,761				41,802				80,778				82,372
Other income (expense):
Interest expense			(6,453	)			(7,190	)			(13,802	)			(12,784	)
Interest income			471				413				1,172				883
Loss on early extinguishment of debt			—				—				—				(230	)
Other income (expense)			(6,469	)			40				(6,431	)			101
Income from continuing operations before income taxes			30,310				35,065				61,717				70,342
Income tax expense			(11,597	)			(13,373	)			(23,348	)			(26,577	)
Net income		$	18,713			$	21,692			$	38,369			$	43,765
Earnings per share of common stock:
Basic		$	0.46			$	0.54			$	0.94			$	1.11
Diluted		$	0.45			$	0.52			$	0.92			$	1.08

See accompanying notes to consolidated financial statements.

Basic Energy Services, Inc.
Consolidated Statements of Stockholders’ Equity
(in thousands, except share data)

										Additional												Total
		Common Stock								Paid-In				Treasury				Retained				Stockholders’
		Shares				Amount				Capital				Stock				Earnings				Equity
Balance — December 31, 2007			40,925,530			$	409			$	314,705			$	—			$	209,707			$	524,821
Issuances of restricted stock			361,700				4				(4	)			—				—				—
Amortization of share based compensation			—				—				2,180				—				—				2,180
Treasury stock issued as compensation to Chairman of the Board			—				—				—				89				(4	)			85
Purchase of treasury stock			—				—				—				(1,149	)			—				(1,149	)
Exercise of stock options			44,375				—				2,085				1,060				(768	)			2,377
Net income			—				—				—				—				38,369				38,369
Balance — June 30, 2008 (unaudited)			41,331,605			$	413			$	318,966			$	—			$	247,304			$	566,683

See accompanying notes to consolidated financial statements.

Basic Energy Services, Inc.
Consolidated Statements of Cash Flows
(in thousands)

		Six Months Ended June 30,
		2008				2007
		(Unaudited)
Cash flows from operating activities:
Net income		$	38,369			$	43,765
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization			56,764				43,232
Accretion on asset retirement obligation			63				56
Change in allowance for doubtful accounts			(483	)			1,350
Amortization of deferred financing costs			482				473
Non-cash compensation			2,264				2,155
Loss on early extinguishment of debt			—				230
(Gain) loss on disposal of assets			(584	)			175
Deferred income taxes			7,666				8,860
Changes in operating assets and liabilities, net of acquisitions:
Accounts receivable			(23,934	)			(3,545	)
Inventories			402				(437	)
Prepaid expenses and other current assets			5,177				4,945
Other assets			(198	)			(462	)
Accounts payable			991				(6,151	)
Excess tax benefits from exercise of employee stock options			(1,583	)			(2,159	)
Income tax payable			1,015				(12,543	)
Other liabilities			(3,414	)			(545	)
Accrued expenses			4,331				5,708
Net cash provided by operating activities			87,328				85,107
Cash flows from investing activities:
Purchase of property and equipment			(45,023	)			(52,854	)
Proceeds from sale of assets			6,470				1,629
Payments for other long-term assets			(2,048	)			(8,082	)
Payments for businesses, net of cash acquired			(51,239	)			(175,470	)
Net cash used in investing activities			(91,840	)			(234,777	)
Cash flows from financing activities:
Proceeds from debt			—				150,000
Payments of debt			(10,874	)			(7,090	)
Purchase of treasury stock			(1,149	)			(462	)
Excess tax benefits from exercise of employee stock options			1,583				2,159
Tax withholding from exercise of stock options			(842	)			(1,279	)
Exercise of employee stock options			1,637				2,237
Deferred loan costs and other financing activities			—				(756	)
Net cash provided by (used in) financing activities			(9,645	)			144,809
Net increase (decrease) in cash and equivalents			(14,157	)			(4,861	)
Cash and cash equivalents — beginning of period			91,941				51,365
Cash and cash equivalents — end of period		$	77,784			$	46,504

See accompanying notes to consolidated financial statements.

BASIC ENERGY SERVICES, INC.
Notes to Consolidated Financial Statements
June 30, 2008 (unaudited)

1. Basis of Presentation and Nature of Operations

Basis of Presentation

     The accompanying unaudited consolidated financial statements of Basic Energy Services, Inc. and subsidiaries (“Basic” or the “Company”) have been prepared in accordance with accounting principles generally accepted in the United States for interim financial reporting. Accordingly, they do not include all of the information and footnotes required by accounting principles generally accepted in the United States for complete financial statements. In the opinion of management, all adjustments considered necessary for a fair presentation have been made in the accompanying unaudited financial statements.

Nature of Operations

     Basic Energy Services, Inc. provides a range of well site services to oil and gas drilling and producing companies, including well servicing, contract drilling, fluid services and completion and remedial services. These services are primarily provided by Basic’s fleet of equipment. Basic’s operations are concentrated in the major United States onshore oil and gas producing regions in Texas, New Mexico, Oklahoma, Arkansas, Kansas and Louisiana, and the Rocky Mountain states.

2. Summary of Significant Accounting Policies

Principles of Consolidation

     The accompanying consolidated financial statements include the accounts of Basic and its wholly-owned subsidiaries. Basic has no interest in any other organization, entity, partnership, or contract that could require any evaluation under FASB Interpretation No. 46R or Accounting Research Bulletin No. 51. All intercompany transactions and balances have been eliminated.

Estimates and Uncertainties

     Preparation of the accompanying consolidated financial statements in conformity with accounting principles generally accepted in the United States of America requires management to make estimates and assumptions that affect the reported amount of assets and liabilities and disclosure of contingent assets and liabilities at the date of the consolidated financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates. Areas where critical accounting estimates are made by management include:

	•		Depreciation and amortization of property and equipment and intangible assets
	•		Impairment of property and equipment, goodwill and intangible assets
	•		Allowance for doubtful accounts
	•		Litigation and self-insured risk reserves
	•		Fair value of assets acquired and liabilities assumed
	•		Stock-based compensation
	•		Income taxes
	•		Asset retirement obligation

Revenue Recognition

     Well Servicing — Well servicing consists primarily of maintenance services, workover services, completion services and plugging and abandonment services. Basic recognizes revenue when services are performed, collection of the relevant receivables is probable, persuasive evidence of an arrangement exists and the price is fixed or determinable. Basic prices well servicing by the hour or by the day of service performed.

     Fluid Services — Fluid services consists primarily of the sale, transportation, storage and disposal of fluids used in drilling, production and maintenance of oil and natural gas wells, and well site construction and maintenance services. Basic recognizes revenue when services are performed, collection of the relevant receivables is probable, persuasive evidence of an arrangement exists and the price is fixed or determinable. Basic prices fluid services by the job, by the hour or by the quantities sold, disposed of or hauled.

     Completion and Remedial Services — Basic recognizes revenue when services are performed, collection of the relevant receivables is probable, persuasive evidence of an arrangement exists and the price is fixed or determinable. Basic prices completion and remedial services by the hour, day, or project depending on the type of service performed. When Basic provides multiple services to a customer, revenue is allocated to the services performed based on the fair values of the services.

     Contract Drilling — Basic recognizes revenues based on either a “daywork” contract, in which an agreed upon rate per day is charged to the customer, or a “footage” contract, in which an agreed upon rate is charged per the number of feet drilled.

     Taxes assessed on sales transactions are presented on a net basis and are not included in revenue.

Inventories

     For Rental and Fishing Tools, inventories consisting mainly of grapples, controls, and drill bits are stated at the lower of cost or market, which cost being determined on the average cost method. Other inventories, consisting mainly of rig components, repair parts, drilling and completion materials and gravel, are held for use in the operations of Basic and are stated at the lower of cost or market, with cost being determined on the first-in, first-out (“FIFO”) method.

Impairments

     In accordance with Statement of Financial Accounting Standards No. 144, Accounting for the Impairment or Disposal of Long-Lived Assets (“SFAS No. 144”), long-lived assets, such as property, plant, and equipment, and purchased intangibles subject to amortization, are reviewed for impairment at a minimum annually, or whenever, in management’s judgment events or changes in circumstances indicate that the carrying amount of such assets may not be recoverable. Recoverability of assets to be held and used is measured by a comparison of the carrying amount of such assets to estimated undiscounted future cash flows expected to be generated by the assets. Expected future cash flows and carrying values are aggregated at their lowest identifiable level. If the carrying amount of such assets exceeds its estimated future cash flows, an impairment charge is recognized by the amount by which the carrying amount of such assets exceeds the fair value of the assets. Assets to be disposed of would be separately presented in the consolidated balance sheet and reported at the lower of the carrying amount or fair value less costs to sell, and are no longer depreciated. The assets and liabilities, if material, of a disposed group classified as held for sale would be presented separately in the appropriate asset and liability sections of the consolidated balance sheet. These assets are normally sold within a short period of time through a third party auctioneer.

     Goodwill is tested annually for impairment, and is tested for impairment more frequently if events and circumstances indicate that the asset might be impaired. An impairment loss is recognized to the extent that the carrying amount exceeds the asset’s fair value.

     Basic had no impairment expense in the six months ended June 30, 2008 and 2007.

Deferred Debt Costs

     Basic capitalizes certain costs in connection with obtaining its borrowings, such as lender’s fees and related attorney’s fees. These costs are being amortized to interest expense using the effective interest method.

     Deferred debt costs were approximately $5.6 million net of accumulated amortization of $1.9 million and $6.1 million net of accumulated amortization of $1.5 million at June 30, 2008 and December 31, 2007, respectively. Amortization of deferred debt costs totaled approximately $242,000 for the three months ended June 30, 2008 and 2007. For the six months ended June 30, 2008 and 2007, amortization of deferred debt costs totaled approximately $482,000 and $473,000, respectively.

Goodwill and Other Intangible Assets

     Statement of Financial Accounting Standards No. 142, Goodwill and Other Intangible Assets (“SFAS No. 142”) eliminates the amortization of goodwill and other intangible assets with indefinite lives. Intangible assets with lives restricted by contractual, legal, or other means will continue to be amortized over their useful lives. Goodwill and other intangible assets not subject to amortization are tested for impairment annually or more frequently if events or changes in circumstances indicate that the asset might be impaired. SFAS No. 142 requires a two-step process for testing impairment. First, the fair value of each reporting unit is compared to its carrying value to determine whether an indication of impairment exists. If impairment is indicated, then the fair value of the reporting unit’s goodwill is determined by allocating the unit’s fair value to its assets and liabilities (including any unrecognized intangible assets) as if the reporting unit had been acquired in a business combination. The amount of impairment for goodwill is measured as the excess of its carrying value over its fair value. Basic completed its assessment of goodwill impairment as of the date of adoption and completed a subsequent annual impairment assessment as of December 31 each year thereafter. The assessments did not result in any indications of goodwill impairment.

     Basic has identified its reporting units to be well servicing, fluid services, completion and remedial services and contract drilling. The goodwill allocated to such reporting units as of June 30, 2008 is $34.3 million, $46.2 million, $127.0 million and $23.4 million, respectively. The change in the carrying amount of goodwill for the six months ended June 30, 2008 of $25.8 million relates to goodwill from acquisitions and payments pursuant to contingent earn-out agreements, with approximately $7.5 million, $2.9 million and $15.4 million of goodwill additions relating to the well servicing, fluid services and completion and remedial, respectively.

     Intangible assets subject to amortization under SFAS No. 142 consist of customer relationships and non-compete agreements. The gross carrying amount of customer relationships subject to amortization was $27.6 million and $23.8 million as of June 30, 2008 and December 31, 2007, respectively. The gross carrying amount of non-compete agreements subject to amortization totaled approximately $5.4 million and $5.2 million at June 30, 2008 and December 31, 2007, respectively. Accumulated amortization related to these intangible assets totaled approximately $3.4 million and $2.1 million at June 30, 2008 and December 31, 2007, respectively. Amortization expense for the three months ended June 30, 2008 and 2007 was approximately $636,000 and $181,000, respectively. For the six months ended June 30, 2008 and 2007, amortization expense totaled approximately $1.3 million and $351,000, respectively. Other intangibles net of accumulated amortization allocated to reporting units as of June 30, 2008 is $246,000, $637,000, $22.6 million and $6.1 million for well servicing, fluid services, completion and remedial services and contract drilling, respectively.

     Customer relationships are amortized over a 15-year life. Non-Compete agreements are amortized over a five-year life.

Stock-Based Compensation

     Basic accounts for stock-based compensation based on Statement of Financial Accounting Standards No. 123 (revised 2004), “Share Based Payment” (“SFAS No. 123R”). Options issued are valued on the grant date using the Black-Scholes-Merton option-pricing model and all awards are adjusted for an expected forfeiture rate. Awards are amortized over the vesting period. Compensation expense of the unvested portion of awards granted as a private company and outstanding as of January 1, 2006 will be based upon the intrinsic value method calculated under APB No. 25.

Income Taxes

     Basic accounts for income taxes based upon Statement of Financial Accounting Standards No. 109, “Accounting for Income Taxes” (“SFAS 109”). Under SFAS No. 109, deferred tax assets and liabilities are recognized for the future tax consequences attributable to differences between the financial statement carrying amounts of existing assets and liabilities and their respective tax bases. Deferred tax assets and liabilities are measured using statutory tax rates expected to apply to taxable income in the years in which those temporary differences are expected to be recovered or settled. The effect on deferred tax assets and liabilities of a change in tax rate is recognized in the period that includes the statutory enactment date. A valuation allowance for deferred tax assets is recognized when it is more likely than not that the benefit of deferred tax assets will not be realized.

     Interest charges are recorded in interest expense and penalties are recorded in income tax expense.

Concentrations of Credit Risk

     Financial instruments, which potentially subject Basic to concentration of credit risk, consist primarily of temporary cash investments and trade receivables. Basic restricts investment of temporary cash investments to financial institutions with high credit standing. Basic’s customer base consists primarily of multi-national and independent oil and natural gas producers. It performs ongoing credit evaluations of its customers but generally does not require collateral on its trade receivables. Credit risk is considered by management to be limited due to the large number of customers comprising its customer base. Basic maintains an allowance for potential credit losses on its trade receivables, and such losses have been within management’s expectations.

     Basic did not have any one customer which represented 10% or more of consolidated revenue during the six months ended June 30, 2008 or 2007.

Asset Retirement Obligations

     As of January 1, 2003, Basic adopted Statement of Financial Accounting Standards No. 143, “Accounting for Asset Retirement Obligation” (“SFAS No. 143”). SFAS No. 143 requires Basic to record the fair value of an asset retirement obligation as a liability in the period in which it incurs a legal obligation associated with the retirement of tangible long-lived assets and capitalize an equal amount as a cost of the asset depreciating it over the life of the asset. Subsequent to the initial measurement of the asset retirement obligation, the obligation is adjusted at the end of each quarter to reflect the passage of time, changes in the estimated future cash flows underlying the obligation, acquisition or construction of assets, and settlements of obligations.

     Basic owns and operates salt water disposal sites, brine water wells, gravel pits and land farm sites, each of which is subject to rules and regulations regarding usage and eventual closure. The following table reflects the changes in the liability during the six months ended June 30, 2008 (in thousands):

Balance, December 31, 2007		$	1,552
Additional asset retirement obligations recognized through acquisitions			34
Accretion expense			63
Balance, June 30, 2008		$	1,649

Environmental

     Basic is subject to extensive federal, state and local environmental laws and regulations. These laws, which are constantly changing, regulate the discharge of materials into the environment and may require Basic to remove or mitigate the adverse environmental effects of disposal or release of petroleum, chemical and other substances at various sites. Environmental expenditures are expensed or capitalized depending on the future economic benefit. Expenditures that relate to an existing condition caused by past operations and that have no future economic benefits are expensed. Liabilities for expenditures of a non-capital nature are recorded when environmental assessment and/or remediation is probable and the costs can be reasonably estimated.

Litigation and Self-Insured Risk Reserves

     Basic estimates its reserves related to litigation and self-insured risks based on the facts and circumstances specific to the litigation and self-insured claims and its past experience with similar claims in accordance with Statement of Financial Accounting Standard No. 5 “Accounting for Contingencies.” Basic maintains accruals in the consolidated balance sheets to cover self-insurance retentions (See note 6).

Recent Accounting Pronouncements

     In September 2006, the FASB issued SFAS No. 157, Fair Value Measurements (SFAS 157), which became effective for financial assets and liabilities of the company on January 1, 2008 and will become effective for non-financial assets and liabilities of the Company on January 1, 2009. This standard defines fair value, establishes a framework for measuring fair value and expands disclosures about fair value measurements. SFAS 157 does not require any new fair value measurements but would apply to assets and

liabilities that are required to be recorded at fair value under other accounting standards. This standard was adopted for financial assets and liabilities as of January 1, 2008 and will be adopted for non-financial assets and liabilities, including fair value measurements for asset impairments, goodwill and intangible asset impairments and purchase price allocations, January 1, 2009. The adoption of this standard did not have any impact on the fair value of any of our financial assets or liabilities.

     In February 2007, the FASB issued SFAS No. 159, The Fair Value Option for Financial Assets and Financial Liabilities (SFAS 159), which became effective for the company on January 1, 2008. This standard permits companies to choose to measure many financial instruments and certain other items at fair value and report unrealized gains and losses in earnings. Such accounting is optional and is generally to be applied instrument by instrument. The adoption of this standard has not had any material effect on the results of operations or consolidated financial position.

     In December 2007, the FASB issued SFAS No. 141R, Business Combinations (SFAS 141R), which becomes effective for the Company on January 1, 2009. This Statement requires an acquirer to recognize the assets acquired, the liabilities assumed, and any noncontrolling interest in the acquiree at the acquisition date be measured at their fair values as of that date. An acquirer is required to recognize assets or liabilities arising from all other contingencies (contractual contingencies) as of the acquisition date, measured at their acquisition-date fair values, only if it is more likely than not that they meet the definition of an asset or a liability in FASB Concepts Statement No. 6, Elements of Financial Statements. Any acquisition related costs are to be expensed instead of capitalized. The impact to the Company from the adoption of SFAS 141R in 2009 will depend on acquisitions at the time.

     In December 2007, the FASB issued SFAS No. 160, Noncontrolling Interests in Consolidated Financial Statements (SFAS 160), which becomes effective for the Company on January 1, 2009. This standard establishes accounting and reporting standards for ownership interests in subsidiaries held by parties other than the parent, the amount of consolidated net income attributable to the parent and to the noncontrolling interest, changes in a parent’s ownership interest and the valuation of retained non-controlling equity investments when a subsidiary is deconsolidated. The Statement also establishes reporting requirements that provide sufficient disclosures that clearly identify and distinguish between the interests of the parent and the interests of the non-controlling owners. The Company does not anticipate that this pronouncement will have a material impact on its results of operations or consolidated financial position.

     In March 2008, the FASB issued SFAS No. 161, Disclosures about Derivative Instruments and Hedging Activities (SFAS 161), which becomes effective for the Company on January 1, 2009. This standard improves financial reporting for derivative instruments and hedging activities by requiring enhanced disclosures to expand on these instruments’ effects on the company’s financial position, financial performance and cash flows. The Company does not anticipate that this pronouncement will have a material impact on its results of operations or consolidated financial position.

     In May 2008, the FASB issued SFAS No. 162, The Hierarchy of Generally Accepted Accounting Principles (SFAS 162), which becomes effective for the Company 60 days following the SEC’s approval of the Public Company Accounting Oversight Board amendments to AU Section 411, The Meaning of Present Fairly in Conformity With General Accepted Accounting Principles. This standard identifies the sources of accounting principles and the framework for selecting the principles used in the preparation of financial statements that are presented in conformity with generally accepted accounting principles (GAAP). The Company does not anticipate that this pronouncement will have a material impact on its results of operations or consolidated financial position.

     In June 2008, the FASB issued FASB Staff Position EITF 03-6-1 “Determining Whether Instruments Granted in Share-Based Payment Transactions are Participating Securities” (“FSP EITF 03-6-1”). FSP EITF 03-6-1 addresses whether instruments granted in share-based payment transactions are participating securities prior to vesting and, therefore, need to be included in the earnings allocation in computing earnings per share (“EPS”) under the two-class method described in paragraphs 60 and 61 of SFAS No. 128, “Earnings Per Share”. FSP EITF 03-6-1 is effective for financial statements issued for fiscal years and interim periods beginning after December 15, 2008 and requires retrospective adjustment for all comparable prior periods presented. The Company does not anticipate that the adoption of FSP EITF 03-6-1 will have a material impact on our EPS disclosures.

3. Acquisitions

     In 2008 and 2007, Basic acquired either substantially all of the assets or all of the outstanding capital stock of each of the following businesses, each of which were accounted for using the purchase method of accounting (in thousands):

						Total Cash Paid
		Closing Date				(net of cash acquired)
Parker Drilling Offshore USA, LLC		January 3, 2007				$	20,594
Davis Tool Company, Inc.		January 17, 2007					4,164
JetStar Consolidated Holdings, Inc.		March 6, 2007					87,763
Sledge Drilling Holding Corp.		April 2, 2007					50,632
Eagle Frac Tank Rentals, LP		May 30, 2007					3,813
Wildhorse Services, Inc.		June 1, 2007					17,318
Bilco Machine, Inc.		June 21, 2007					600
Steve Carter Inc. and Hughes Services Inc.		September 26, 2007					19,808
Total 2007						$	204,692
Xterra Fishing and Rental Tools Co.		January 28, 2008				$	21,106
Lackey Construction, LLC		January 30, 2008					4,328
B&S Disposal, LLC and B&S Equipment, Ltd		April 30, 2008					6,736
Triple N Services, Inc.		May 27, 2008					17,306
Total 2008						$	49,476

     The operations of each of the acquisitions listed above are included in Basic’s statement of operations as of each respective closing date. The acquisitions of JetStar Consolidated Holdings, Inc. and Sledge Drilling Holding Corp. in 2007 have been deemed material and are discussed below in further detail.

Contingent Earn-out Arrangements and Purchase Price Allocations

     Contingent earn-out arrangements are generally arrangements entered into on certain acquisitions to encourage the owner/manager to continue operating and building the business after the purchase transaction. The contingent earn-out arrangements of the related acquisitions are generally linked to certain financial measures and performance of the assets acquired in the various acquisitions. All amounts paid or reasonably accrued for related to the contingent earn-out payments are reflected as increases to the goodwill associated with the acquisition or compensation expense depending on the terms and conditions of the earn-out arrangement.

JetStar Consolidated Holdings, Inc.

     On March 6, 2007, Basic acquired all of the capital stock of JetStar Consolidated Holdings, Inc. (“JetStar”). The results of JetStar’s operations have been included in the financial statements since that date. The aggregate purchase price was approximately $128.7 million, including $87.7 million in cash which included the retirement of JetStar’s outstanding debt. Basic issued 1,794,759 shares of common stock, at a fair value of $22.86 per share, for a total fair value of approximately $41 million. The value of the 1,794,759 shares issued was determined based on the average market price of Basic’s common shares over the 2-day period before and after the date the number of shares were determined. This acquisition allowed us to enter into the Kansas market and increased our presence in North Texas. JetStar operates in Basic’s completion and remedial segment. The following table summarizes the final estimated fair value of the assets acquired and liabilities assumed at the date of acquisition for JetStar (in thousands):

Current Assets		$	13,263
Property and Equipment			59,517
Amortizable Intangible Assets (1)			17,857
Goodwill (2)			61,722
Total Assets Acquired		$	152,359
Current Liabilities		$	(4,581	)
Deferred Income Taxes			(18,650	)
Current and Long Term Debt (3)			(37,563	)
Total Liabilities Assumed		$	(60,794	)
Net Assets Acquired		$	91,565

     Sledge Drilling Holding Corp.

     On April 2, 2007, Basic acquired all of the capital stock of Sledge Drilling Holding Corp. (“Sledge”). The results of Sledge’s operations have been included in the financial statements since that date. The aggregate purchase price was approximately $60.8 million, including $50.6 million in cash which included the retirement of Sledge’s outstanding debt. Basic issued 430,191 shares of common stock at a fair value of $23.63 per share for a total fair value of approximately $10.2 million. The value of the 430,191 shares issued was determined based on the average market price of Basic’s common shares over the 2-day period before and after the date the number shares were determined. This acquisition allowed Basic to expand its drilling operations in the Permian Basin. The following table summarizes the final estimated fair value of the assets acquired and liabilities assumed at the date of acquisition for Sledge (in thousands):

Current Assets		$	6,029
Property and Equipment			30,638
Intangible Assets (1)			6,365
Goodwill (2)			23,382
Total Assets Acquired		$	66,414
Current Liabilities		$	(587	)
Deferred Income Taxes			(3,886	)
Current and Long Term Debt (3)			(19,093	)
Total Liabilities Assumed		$	(23,566	)
Net Assets Acquired		$	42,848

     The following unaudited pro-forma results of operations have been prepared as though the JetStar and Sledge acquisitions had been completed on January 1, 2007. Pro forma amounts are based on the purchase price allocations of the significant acquisitions and are not necessarily indicative of the results that may be reported in the future (in thousands, except per share data).

		Six Months Ended
		June 30, 2007
Revenues		$	444,745
Net income		$	47,672
Earnings per common share — basic		$	1.18
Earnings per common share — diluted		$	1.15

     Basic does not believe the pro-forma effect of the remainder of the acquisitions completed in 2008 or 2007 are material, either individually or when aggregated, to the reported results of operations.

4. Property and Equipment

     Property and equipment consists of the following (in thousands):

		June 30,				December 31,
		2008				2007
Land		$	4,140			$	3,475
Buildings and improvements			26,049				21,655
Well service units and equipment			356,324				328,468
Fluid services equipment			108,912				91,830
Brine and fresh water stations			9,587				8,964
Frac/test tanks			94,556				85,649
Pressure pumping equipment			145,889				132,746
Construction equipment			22,950				28,798
Contract drilling			59,763				59,231
Disposal facilities			34,978				27,790
Vehicles			36,735				36,440
Rental equipment			33,195				33,381
Aircraft			4,119				4,119
Other			17,839				15,858
			955,036				878,404
Less accumulated depreciation and amortization			289,114				241,480
Property and equipment, net		$	665,922			$	636,924

     Basic is obligated under various capital leases for certain vehicles and equipment that expire at various dates during the next five years. The gross amount of property and equipment and related accumulated amortization recorded under capital leases and included above consists of the following (in thousands):

		June 30,				December 31,
		2008				2007
Light vehicles		$	26,909			$	25,768
Well service units and equipment			1,170				1,016
Fluid services equipment			41,607				34,668
Pressure pumping equipment			11,911				4,540
Construction equipment			3,556				4,440
Software			8,562				6,308
Other			29				—
			93,744				76,740
Less accumulated amortization			29,305				22,660
		$	64,439			$	54,080

     Amortization of assets held under capital leases of approximately $3.2 million and $2.1 million for the three months ended June 30, 2008 and 2007 and $6.6 million and $3.8 million for the six months ended June 30, 2008 and 2007, respectively, is included in depreciation and amortization expense in the consolidated statements of operations.

5. Long-Term Debt

     Long-term debt consists of the following (in thousands):

		June 30,				December 31,
		2008				2007
Credit Facilities:
Revolver		$	150,000			$	150,000
7.125% Senior Notes			225,000				225,000
Capital leases and other notes			58,367				48,719
			433,367				423,719
Less current portion			20,521				17,413
		$	412,846			$	406,306

Senior Notes

     On April 12, 2006, Basic issued $225.0 million of 7.125% Senior Notes due April 2016 in a private placement. Proceeds from the sale of the Senior Notes were used to retire the outstanding balance on the $90.0 million Term B Loan and to pay down approximately $96.0 million under the revolving credit facility, which amounts may be reborrowed to fund future acquisitions or for general corporate purposes. Interest payments on the Senior Notes are due semi-annually, on April 15 and October 15, which began on October 15, 2006. The Senior Notes are unsecured. Under the terms of the sale of the Senior Notes, Basic was required to take appropriate steps to offer to exchange other Senior Notes with the same terms that have been registered with the Securities and Exchange Commission for the private placement Senior Notes. Basic completed the exchange offer for all of the Senior Notes on October 16, 2006.

     The Senior Notes are redeemable at the option of Basic on or after April 15, 2011 at the specified redemption price as described in the Indenture. Prior to April 15, 2011, Basic may redeem, in whole or in part, at a redemption price equal to 100% of the principal amount of the Senior Notes redeemed plus the Applicable Premium as defined in the Indenture. Prior to April 15, 2009, Basic may redeem up to 35% of the Senior Notes with the proceeds of certain equity offerings at a redemption price equal to 107.125% of the principal amount of the 7.125% Senior Notes, plus accrued and unpaid interest to the date of redemption. This redemption must occur less than 90 days after the date of the closing of any such equity offering.

     Following a change of control, as defined in the Indenture, Basic will be required to make an offer to repurchase all or any portion of the 7.125% Senior Notes at a purchase price of 101% of the principal amount, plus accrued and unpaid interest to the date of repurchase.

     Pursuant to the Indenture, Basic is subject to covenants that limit the ability of Basic and its restricted subsidiaries to, among other things: incur additional indebtedness, pay dividends or repurchase or redeem capital stock, make certain investments, incur liens, enter into certain types of transactions with affiliates, limit dividends or other payments by restricted subsidiaries, and sell assets or consolidate or merge with or into other companies. These limitations are subject to a number of important qualifications and exceptions set forth in the Indenture. Basic was in compliance with the restrictive covenants at June 30, 2008.

     As part of the issuance of the above-mentioned Senior Notes, Basic incurred debt issuance costs of approximately $4.6 million, which are being amortized to interest expense using the effective interest method over the term of the Senior Notes.

     The Senior Notes are jointly and severally guaranteed by Basic and all of its restricted subsidiaries. Basic Energy Services, Inc., the ultimate parent company, does not have any independent operating assets or operations. Subsidiaries other than the restricted subsidiaries that are guarantors are minor.

2007 Credit Facility

     On February 6, 2007, Basic entered into a $225 million Fourth Amended and Restated Credit Agreement with a syndicate of lenders (the “2007 Credit Facility”), which refinanced all of the existing credit facilities. Under the 2007 Credit Facility, Basic Energy

Services, Inc. is the sole borrower and each of our subsidiaries is a subsidiary guarantor. The 2007 Credit Facility provides for a $225 million revolving line of credit (“Revolver”). The 2007 Credit Facility includes provisions allowing us to request an increase in commitments of up to $100.0 million aggregate principal amount at any time. Additionally, the 2007 Credit Facility permits us to make greater expenditures for acquisitions, capital expenditures and capital leases and to incur greater purchase money obligations, acquisition indebtedness and general unsecured indebtedness. The commitment under the Revolver provides for (1) the borrowing of funds, (2) the issuance of up to $30 million of letters of credit and (3) $2.5 million of swing-line loans. All of the outstanding amounts under the Revolver are due and payable on December 15, 2010. The 2007 Credit Facility is secured by substantially all of our tangible and intangible assets. Basic incurred approximately $0.7 million in debt issuance costs in connection with the 2007 Credit Facility.

     At Basic’s option, borrowings under the Revolver bear interest at either (1) the “Alternative Base Rate” (i.e., the higher of the bank’s prime rate or the federal funds rate plus .50% per year) plus a margin ranging from 0.25% to 0.5% or (2) an “Adjusted LIBOR Rate” (equal to (a) the London Interbank Offered Rate (the “LIBOR rate”) as determined by the Administrative Agent in effect for such interest period divided by (b) one minus the Statutory Reserves, if any, for such borrowing for such interest period) plus a margin ranging from 1.25% to 1.5%. The margins vary depending on our leverage ratio. Fees on the letters of credit are due quarterly on the outstanding amount of the letters of credit at a rate ranging from 1.25% to 1.5% for participation fees and 0.125% for fronting fees. A commitment fee is due quarterly on the available borrowings under the Revolver at a rate of 0.375%.

     At June 30, 2008, Basic, under its Revolver, had outstanding $150.0 million of borrowings and $14.5 million of letters of credit and no amounts outstanding in swing-line loans. At June 30, 2008, Basic had availability under its Revolver of $60.5 million.

     Pursuant to the 2007 Credit Facility, Basic must apply proceeds from certain specified events to reduce principal outstanding borrowings under the Revolver, from (a) assets sales greater than $2.0 million individually or $7.5 million in the aggregate on an annual basis, (b) 100% of the net cash proceeds from any debt issuance, including certain permitted unsecured senior or senior subordinated debt, but excluding certain other permitted debt issuances and (c) 50% of the net cash proceeds from any equity issuance (including equity issued upon the exercise of any warrant or option).

     The 2007 Credit Facility contains various restrictive covenants and compliance requirements, which include (a) limitations on the incurrence of additional indebtedness, (b) restrictions on mergers, sales or transfer of assets without the lenders’ consent (c) limitations on dividends and distributions and (d) various financial covenants, including (1) a maximum leverage ratio of 3.25 to 1.00, and (2) a minimum interest coverage ratio of 3.00 to 1.00. At June 30, 2008, Basic was in compliance with its covenants.

Other Debt

     Basic has a variety of other capital leases and notes payable outstanding that are generally customary in its business. None of these debt instruments are individually material.

     Basic’s interest expense consisted of the following (in thousands):

		Six Months Ended June 30,
		2008				2007
Cash payments for interest		$	12,935			$	10,032
Commitment and other fees paid			51				148
Amortization of debt issuance costs			482				473
Accrued interest			51				1,777
Other			283				354
		$	13,802			$	12,784

Losses on Extinguishment of Debt

     In February 2007, Basic wrote off unamortized debt issuance costs of approximately $230,000, which related to the 2005 Credit Facility.

6. Commitments and Contingencies

Environmental

     Basic is subject to various federal, state and local environmental laws and regulations that establish standards and requirements for protection of the environment. Basic cannot predict the future impact of such standards and requirements which are subject to change and can have retroactive effectiveness. Basic continues to monitor the status of these laws and regulations. Management believes that the likelihood of the disposition of any of these items resulting in a material adverse impact to Basic’s financial position, liquidity, capital resources or future results of operations is remote.

     Currently, Basic has not been fined, cited or notified of any environmental violations that would have a material adverse effect upon its financial position, liquidity or capital resources. However, management does recognize that by the very nature of its business, material costs could be incurred in the near term to bring Basic into total compliance. The amount of such future expenditures is not determinable due to several factors including the unknown magnitude of possible contamination, the unknown timing and extent of the corrective actions which may be required, the determination of Basic’s liability in proportion to other responsible parties and the extent to which such expenditures are recoverable from insurance or indemnification.

Litigation

     From time to time, Basic is a party to litigation or other legal proceedings that Basic considers to be a part of the ordinary course of business. Basic is not currently involved in any legal proceedings that it considers probable or reasonably possible, individually or in the aggregate, to result in a material adverse effect on its financial condition, results of operations or liquidity.

Self-Insured Risk Accruals

     Basic is self-insured up to retention limits as it relates to workers’ compensation and medical and dental coverage of its employees. Basic, generally, maintains no physical property damage coverage on its workover rig fleet, with the exception of certain of its 24-hour workover rigs and newly manufactured rigs. Basic has deductibles per occurrence for workers’ compensation and medical and dental coverage of $250,000 and $180,000, respectively. Basic has lower deductibles per occurrence for automobile liability and general liability. Basic maintains accruals in the accompanying consolidated balance sheets related to self-insurance retentions by using third-party data and claims history.

     At June 30, 2008 and December 31, 2007, self-insured risk accruals totaled approximately $15.2 million net of a $78,000 receivable for medical and dental coverage and $15.1 million for medical and dental coverage, respectively.

7. Stockholders’ Equity

Common Stock

     During the year ended December 31, 2007, Basic issued 169,875 shares of newly-issued common stock and 22,800 shares of treasury stock for the exercise of stock options.

     In March and April 2007, Basic issued 1,794,759 and 430,191 shares of common stock in connection with the acquisitions of JetStar Consolidated Holdings, Inc. and Sledge Drilling Holding Corp., respectively. (See note 3).

     In March 2007, Basic granted various employees 217,100 unvested shares of common stock which vest over a five year period. Also, in March 2007, Basic granted the Chairman of the Board 4,000 shares of common stock which vested immediately. In July 2007, Basic granted, a vice president, 12,000 shares of unvested shares of common stock which vest over a four-year period.

     During the first six months of 2008, Basic received 51,720 shares of treasury stock, at $22.21 per share, as part of net share settlements for payment of taxes upon the vesting of restricted stock. Basic also issued 44,375 shares of newly-issued common stock and 86,875 shares of treasury stock for the exercise of stock options.

     In March 2008, Basic granted various employees 361,700 unvested shares of common stock which vest over a five-year period. Also, in March 2008, Basic granted the Chairman of the Board 4,000 shares of common stock which vested immediately in lieu of annual cash director fees.

Preferred Stock

     At June 30, 2008 and December 31, 2007, Basic had 5,000,000 shares of $.01 par value preferred stock authorized, of which none is designated.

8. Incentive Plan

     In May 2003, Basic’s board of directors and stockholders approved the Basic 2003 Incentive Plan (as amended effective April 22, 2005) (the “Plan”), which provides for granting of incentive awards in the form of stock options, restricted stock, performance awards, bonus shares, phantom shares, cash awards and other stock-based awards to officers, employees, directors and consultants of Basic. The Plan assumed awards of the plans of Basic’s successors that were awarded and remained outstanding prior to adoption of the Plan. The Plan provides for the issuance of 5,000,000 shares. The Plan is administered by the Plan committee, and in the absence of a Plan committee, by the Board of Directors, which determines the awards, and the associated terms of the awards and interprets its provisions and adopts policies for implementing the Plan. The number of shares authorized under the Plan and the number of shares subject to an award under the Plan will be adjusted for stock splits, stock dividends, recapitalizations, mergers and other changes affecting the capital stock of Basic.

     On March 15, 2007, the board of directors granted various employees options to purchase 92,000 shares of common stock of Basic at an exercise price of $22.66 per share. All of the 92,000 options granted in 2007 vest over a five-year period and expire 10 years from the date they were granted. These option awards were granted with an exercise price equal to the market price of the Company’s stock at the date of grant.

     The fair value of each option award is estimated on the date of grant using the Black-Scholes-Merton option-pricing model that uses the subjective assumptions noted in the following table. Since the Company has only been public since December 2005, expected volatility for options granted during 2007 is a combination of the Company’s historical data and implied volatility based upon a peer group. The expected term of options granted represents the period of time that options granted are expected to be outstanding. For options granted in 2007, the Company used the simplified method to calculate the expected term. For options granted in 2007, the risk-free rate for periods within the contractual life of the options is based on the U.S. Treasury yield curve in effect at the time of grant. The estimates involve inherent uncertainties and the application of management judgment. In addition, we are required to estimate the expected forfeiture rate and only recognize expense for those options expected to vest. During the three months ended June 30, 2008 and 2007 compensation expense related to share-based arrangements was approximately $1.2 million and $1.1 million, respectively. For compensation expense recognized during the three months ended June 30, 2008 and 2007, Basic recognized a tax benefit of approximately $453,000 and $393,000 respectively. During the six months ended June 30, 2008 and 2007, compensation expense related to share-based arrangements was approximately $2.3 million and $2.2 million, respectively. For compensation expense recognized during the six months ended June 30, 2008 and 2007, Basic recognized a tax benefit of approximately $857,000 and $797,000, respectively.

     The fair value of each option award accounted for under SFAS No. 123R is estimated on the date of grant using the Black-Scholes-Merton option-pricing model that uses the assumptions noted in the following table:

		Six Months
		Ended June
		30, 2007
Risk-free interest rate			4.5	%
Expected term			6.65
Expected volatility			45.3	%
Expected dividend yield			—

     Options granted under the Plan expire 10 years from the date they are granted, and generally vest over a three-to-five year service period.

     The following table reflects the summary of stock options outstanding at June 30, 2008 and the changes during the six months then ended:

										Weighted
						Weighted				Average				Aggregate
		Number of				Average				Remaining				Instrinsic
		Options				Exercise				Contractual				Value
		Granted				Price				Term (Years)				(000’s)
Non-statutory stock options:
Outstanding,
beginning of period			2,257,355			$	9.58
Options granted			—			$	—
Options forfeited			(20,250	)		$	19.48
Options exercised			(131,250	)		$	6.05
Options expired			(5,500	)		$	22.33
Outstanding, end of period			2,100,355			$	9.67				5.76			$	45,855
Exercisable, end of period			1,403,605			$	6.32				4.98			$	35,348
Vested or expected to vest, end of period			2,081,865			$	9.52				5.74			$	45,749

     The weighted-average grant date fair value of share options granted during the six months ended June 30, 2007 was $11.85. The total intrinsic value of share options exercised during the six months ended June 30, 2008 and 2007 was approximately $2.6 million and $3.6 million, respectively.

     On March 11, 2008, the Compensation Committee of our Board of Directors approved grants of performance-based stock awards to certain members of management. The performance-based awards consist of the Company achieving certain earnings per share growth targets and certain return on capital employed performance, over the performance period from January 1, 2006 through December 31, 2008 as compared to other members of a defined peer group. The number of shares to be issued will range from 0% to 150% of the target number of shares of 101,500 depending on the performance noted above. Any shares earned at the end of the performance period will then remain subject to vesting over a three-year period, with the first shares vesting March 15, 2010.

     A summary of the status of the Company’s non-vested share grants at June 30, 2008 and changes during the six months ended June 30, 2008 is presented in the following table:

						Weighted Average
		Number of				Grant Date Fair
Nonvested Shares		Shares				Value Per Share
Nonvested at beginning of period			378,000			$	15.74
Granted during period			451,975				20.94
Vested during period			(171,500	)			7.31
Forfeited during period			(12,400	)			22.01
Nonvested at end of period			646,075			$	21.49

     As of June 30, 2008, there was approximately $14.9 million of total unrecognized compensation related to non-vested share-based compensation arrangements granted under the Plan. That cost is expected to be recognized over a weighted-average period of 3.13 years. The total fair value of share-based awards vested during the six months ended June 30, 2008 and 2007 was approximately $10.0 million and $10.8 million, respectively. The actual tax benefit realized for the tax deduction from vested share-based awards was $861,000 and $1.6 million for the six months ended June 30, 2008 and 2007, respectively.

     Cash received from share option exercises under the incentive plan was approximately $795,000 and $974,000 for the six months ended June 30, 2008 and 2007, respectively. The actual tax benefit realized for the tax deductions from options exercised was $1.0 million and $1.3 million for the six months ended June 30, 2008 and 2007, respectively.

     The Company has a history of issuing treasury and newly-issued shares to satisfy share option exercises.

9. Related Party Transactions

     Basic had receivables from employees of approximately $170,000 and $91,000 as of June 30, 2008 and December 31, 2007, respectively. During 2006, Basic entered into a lease agreement with Darle Vuelta Cattle Co., LLC, an affiliate of the Chief Executive Officer, for approximately $69,000. The term of the lease is five years and will continue on a year-to-year basis unless terminated by either party.

10. Earnings Per Share

     Basic presents earnings per share information in accordance with the provisions of Statement of Financial Accounting Standards No. 128, “Earnings per Share” (“SFAS No. 128”). Under SFAS No. 128, basic earnings per common share are determined by dividing net earnings applicable to common stock by the weighted average number of common shares actually outstanding during the period. Diluted earnings per common share is based on the increased number of shares that would be outstanding assuming conversion of dilutive outstanding securities using the “as if converted” method. The following table sets forth the computation of basic and diluted earnings per share (in thousands, except share data):

		Three Months Ended June 30,								Six Months Ended June 30,
		2008				2007				2008				2007
		(Unaudited)								(Unaudited)
Numerator (both basic and diluted):
Net income		$	18,713			$	21,692			$	38,369			$	43,765
Denominator:
Denominator for basic earnings per share			40,721,317				40,492,521				40,649,287				39,523,171
Stock options			827,164				864,966				810,916				885,683
Unvested restricted stock			110,114				263,080				197,915				250,504
Denominator for diluted earnings per share			41,658,595				41,620,567				41,658,118				40,659,358
Basic earnings per common share:		$	0.46			$	0.54			$	0.94			$	1.11
Diluted earnings per common share:		$	0.45			$	0.52			$	0.92			$	1.08

11. Business Segment Information

     Basic revised its reportable business segments beginning in the first quarter of 2008. The new operating segments are Well Servicing, Fluid Services, Completion and Remedial Services, and Contract Drilling. These segments have been selected based on changes in management’s resource allocation and performance assessment in making decisions regarding the Company. Contract Drilling was previously included in our Well Servicing segment. Well Site Construction Services is now consolidated with our Fluid Services segment. These changes reflect Basic’s operating focus in compliance with SFAS No. 131, “Disclosures about Segments of an Enterprise and Related Information.” The following is a description of the segments:

     Well Servicing: This business segment encompasses a full range of services performed with a mobile well servicing rig, including the installation and removal of downhole equipment and elimination of obstructions in the well bore to facilitate the flow of oil and gas. These services are performed to establish, maintain and improve production throughout the productive life of an oil and gas well and to plug and abandon a well at the end of its productive life. Basic well servicing equipment and capabilities are essential to facilitate most other services performed on a well.

     Fluid Services: This segment utilizes a fleet of trucks and related assets, including specialized tank trucks, storage tanks, water wells, disposal facilities, construction and other related equipment. Basic employs these assets to provide, transport, store and dispose of a variety of fluids. These services are required in most workover, completion and remedial projects as well as part of daily producing well operations.

     Completion and Remedial Services: This segment utilizes a fleet of pressure pumping units, air compressor packages specially configured for underbalanced drilling operations, cased-hole wireline units and an array of specialized rental equipment and fishing tools. The largest portion of this business consists of pressure pumping services focused on cementing, acidizing and fracturing services in niche markets.

     Contract Drilling: This segment utilizes shallow and medium depth rigs and associated equipment for drilling wells to a specified depth for customers on a contract basis.

     Basic’s management evaluates the performance of its operating segments based on operating revenues and segment profits. Corporate expenses include general corporate expenses associated with managing all reportable operating segments. Corporate assets consist principally of working capital and debt financing costs.

     The following table sets forth certain financial information with respect to Basic’s reportable segments (in thousands):

										Completion and
		Well				Fluid				Remedial				Contract				Corporate
		Servicing				Services				Services				Drilling				and Other				Total
Three Months Ended June 30, 2008 (Unaudited)
Operating revenues		$	89,018			$	72,581			$	79,579			$	10,344			$	—			$	251,522
Direct operating costs			(55,293	)			(48,554	)			(42,651	)			(7,529	)			—				(154,027	)
Segment profits		$	33,725			$	24,027			$	36,928			$	2,815			$	—			$	97,495
Depreciation and amortization		$	11,492			$	7,046			$	7,041			$	1,853			$	1,300			$	28,732
Capital expenditures, (excluding acquisitions)		$	10,638			$	6,522			$	6,518			$	1,715			$	1,203			$	26,596
Three Months Ended June 30, 2007 (Unaudited)
Operating revenues		$	86,111			$	63,191			$	63,736			$	10,218			$	—			$	223,256
Direct operating costs			(52,084	)			(40,379	)			(33,374	)			(6,184	)			—				(132,021	)
Segment profits		$	34,027			$	22,812			$	30,362			$	4,034			$	—			$	91,235
Depreciation and amortization		$	9,702			$	6,329			$	5,232			$	1,916			$	828			$	24,007
Capital expenditures, (excluding acquisitions)		$	11,748			$	7,664			$	6,336			$	2,320			$	1,003			$	29,071
Six Months Ended June 30, 2008 (Unaudited)
Operating revenues		$	169,537			$	143,980			$	148,037			$	19,841			$	—			$	481,395
Direct operating costs			(103,759	)			(94,987	)			(78,439	)			(14,589	)			—				(291,774	)
Segment profits		$	65,778			$	48,993			$	69,598			$	5,252			$	—			$	189,621
Depreciation and amortization		$	22,704			$	13,921			$	13,911			$	3,661			$	2,567			$	56,764
Capital expenditures, (excluding acquisitions)		$	18,008			$	11,041			$	11,033			$	2,904			$	2,037			$	45,023
Identifiable assets		$	301,669			$	209,397			$	322,623			$	70,984			$	305,103			$	1,209,776
Six Months Ended June 30, 2007 (Unaudited)
Operating revenues		$	172,780			$	127,373			$	109,873			$	12,160			$	—			$	422,186
Direct operating costs			(102,178	)			(80,481	)			(56,509	)			(8,998	)			—				(248,166	)
Segment profits		$	70,602			$	46,892			$	53,364			$	3,162			$	—			$	174,020
Depreciation and amortization		$	17,472			$	11,397			$	9,422			$	3,450			$	1,491			$	43,232
Capital expenditures, (excluding acquisitions)		$	21,361			$	13,934			$	11,519			$	4,217			$	1,823			$	52,854
Identifiable assets		$	268,359			$	203,746			$	282,285			$	71,716			$	247,685			$	1,073,791

     The following table reconciles the segment profits reported above to the operating income as reported in the consolidated statements of operations (in thousands):

		Three Months Ended June 30,								Six Months Ended June 30,
		2008				2007				2008				2007
Segment profits		$	97,495			$	91,235			$	189,621			$	174,020
General and administrative expenses			(26,811	)			(25,592	)			(52,663	)			(48,241	)
Depreciation and amortization			(28,732	)			(24,007	)			(56,764	)			(43,232	)
Gain (loss) on disposal of assets			809				166				584				(175	)
Operating income		$	42,761			$	41,802			$	80,778			$	82,372

12. Supplemental Schedule of Cash Flow Information

     The following table reflects non-cash financing and investing activity during the following periods:

		Six Months Ended June 30,
		2008				2007
		(In thousands)
Capital leases issued for equipment		$	20,522			$	12,609
Value of Shares that may be issued		$	—			$	2,194
Contingent earnout accrual		$	1,158			$	797
Asset retirement obligation additions		$	34			$	37
Value of common stock issued in business combinations		$	—			$	51,193

     Basic paid income taxes of approximately $13.2 million and $30.6 million during the six months ended June 30, 2008 and 2007, respectively. Basic paid interest of approximately $12.9 million and $10.0 million during the six months ended June 30, 2008 and 2007, respectively.

13. Subsequent Events

     On July 15, 2008 the Agreement and Plan of Merger by and among Basic, Grey Wolf, Inc. and Horsepower Holdings, Inc. dated April 20, 2008 was terminated. The decision to terminate was made after Grey Wolf’s stockholders did not approve the merger agreement. Basic’s shareholders voted in favor of the adoption of the agreement. Basic’s merger-related expenses for the second quarter approximate up to $6.6 million, and are included in other income and expense. In accordance with Section 7.3(b) of the merger agreement, on July 15, 2008, Grey Wolf paid Basic $5 million as a result of the termination of the merger agreement. This reimbursement of merger expenses will be recognized in the third quarter of 2008. It is anticipated that up to an additional $5 million in merger costs will be recognized in the third quarter of 2008.

     On July 21, 2008, the case of Natalie Gordon, on behalf of Herself and All Others Similarly Situated v. Basic Energy Services, Inc., Steven A. Webster, Kenneth V. Huseman, James S. D’Agostino, Jr., William E. Chiles, Robert F. Fulton, Sylvester P. Johnson, IV, H.H. Wommack, III, Thomas Moore, Jr., and Grey Wolf, Inc. (Cause No. CV46465), filed in the District Court of Midland County, Texas, 238^th Judicial District, was dismissed without prejudice. The lawsuit alleged that the proposed merger consideration to be received in connection with the proposed merger among Basic, Grey Wolf and Horsepower Holdings was inadequate and that Basic and its individual directors breached fiduciary duties owed to stockholders of Basic in connection with the proposed merger.

ITEM 2.		MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATION

Management’s Overview

     We provide a wide range of well site services to oil and gas drilling and producing companies, including well servicing, fluid services, completion and remedial services and contract drilling. Our results of operations reflect the impact of our acquisition strategy as a leading consolidator in the domestic land-based well services industry. Our acquisitions have increased our breadth of service offerings at the well site and expanded our market presence. In implementing this strategy, we have purchased businesses and assets in 47 separate acquisitions from January 1, 2003 to June 30, 2008. Our weighted average number of well servicing rigs has increased from 126 in 2001 to 403 in the second quarter of 2008 and our weighted average number of fluid service trucks has increased from 156 to 663 in the same period. These acquisitions make changes in revenues, expenses and income not directly comparable between periods.

     Our operating revenues from each of our segments, and their relative percentages of our total revenues, consisted of the following (dollars in millions):

		Six Months Ended June 30,
		2008								2007
Revenues:
Well servicing		$	169.5				35	%		$	172.8				41	%
Fluid services			144.0				30	%			127.4				30	%
Completion and remedial services			148.0				31	%			109.9				26	%
Contract drilling			19.8				4	%			12.1				3	%
Total revenues		$	481.3				100	%		$	422.2				100	%

     Our core businesses depend on our customers’ willingness to make expenditures to produce, develop and explore for oil and gas in the United States. Industry conditions are influenced by numerous factors, such as the supply of and demand for oil and gas, domestic and worldwide economic conditions, political instability in oil producing countries and merger and divestiture activity among oil and gas producers. The volatility of the oil and gas industry, and the consequent impact on exploration and production activity, could adversely impact the level of drilling and workover activity by some of our customers. This volatility affects the demand for our services and the price of our services. In addition, the discovery rate of new oil and gas reserves in our market areas also may have an impact on our business, even in an environment of stronger oil and gas prices.

     Natural gas prices reached historical highs in 2006 which stimulated increased drilling activity by our customers. In 2007, natural gas prices declined as an excess supply of natural gas began to occur, mainly due to moderate U.S. weather patterns. Utilization for our services declined from 2006 levels as drilling activity flattened or declined in several of our markets and new equipment entered the marketplace balancing supply and demand for our services. However, pricing for our services improved in 2007 from 2006, mainly reflecting continued increases in labor costs, and offset a portion the effect of the lower utilization of our services on our total revenues. In 2008, we expect that the utilization of our services and pricing for these services will be comparable to 2007 assuming oil and gas prices and U.S. drilling activity remain at or near current levels. We are also experiencing cost inflation for fuel and fuel-based supplies and services, which is creating a negative impact on segment margins. In certain cases, we are able to mitigate this impact by charging fuel surcharges to our customers, when appropriate. We expect that activity levels in each of our business segments will increase in the second half of 2008, leading to pricing improvements which we anticipate will offset the labor and fuel cost increases that we have experienced.

     We derive a majority of our revenues from services supporting production from existing oil and gas operations. Demand for these production-related services, including well servicing and fluid services, tends to remain relatively stable, even in moderate oil and gas price environments, as ongoing maintenance spending is required to sustain production. As oil and gas prices reach higher levels, demand for all of our services generally increases as our customers engage in more well servicing activities relating to existing wells to maintain or increase oil and gas production from those wells. Because our services are required to support drilling and workover activities, we are also subject to changes in capital spending by our customers as oil and gas prices increase or decrease.

     We believe that the most important performance measures for our lines of business are as follows:

•

Well Servicing — rig hours, rig utilization rate, revenue per rig hour and segment profits as a percent of revenues;

	•		Fluid Services — revenue per truck and segment profits as a percent of revenues;
	•		Completion and Remedial Services — segment profits as a percent of revenues; and
	•		Contract Drilling — rig operating days, revenue per drilling day and segment profits as a percent of revenues.

     Segment profits are computed as segment operating revenues less direct operating costs. These measurements provide important information to us about the activity and profitability of our lines of business. For a detailed analysis of these indicators for our company, see below in “— Segment Overview.”

     We intend to continue growing our business through selective acquisitions, continuing a newbuild program and/or upgrading our existing assets. Our capital investment decisions are determined by an analysis of the projected return on capital employed for each of those alternatives, which is substantially driven by the cost to acquire existing assets from a third party, the capital required to build new equipment and the point in the oil and gas commodity price cycle. Based on these factors, we make capital investment decisions that we believe will support our long-term growth strategy. While we believe our costs of integration for prior acquisitions have been reflected in our historical results of operations, integration of acquisitions may result in unforeseen operational difficulties or require a disproportionate amount of our management’s attention. As discussed below in “— Liquidity and Capital Resources,” we also must meet certain financial covenants in order to borrow money under our existing credit agreement to fund future acquisitions

Selected 2007 Acquisitions

     During 2007, we made several acquisitions that complemented our existing lines of business and increased our presence in the rental tool business. These included, among others:

Parker Drilling Offshore USA, LLC

     On January 3, 2007, we acquired two barge-mounted workover rigs and related equipment from Parker Drilling Offshore USA, LLC for total consideration of $20.5 million cash. The acquired rigs operate in the inland waters of Louisiana and Texas as a part of Basic Marine Services.

JetStar Consolidated Holdings, Inc.

     On March 6, 2007, we acquired all of the outstanding capital stock of JetStar Consolidated Holdings, Inc. (“JetStar”) for an aggregate purchase price of approximately $128.7 million, including $87.7 million in cash, of which approximately $37.6 million was used for the retirement of JetStar’s outstanding debt. As part of the purchase price, we issued 1,794,759 shares of common stock, at a fair value of $22.86 per share for a total fair value of approximately $41 million. This acquisition operates in our completion and remedial services line of business.

Sledge Drilling Holding Corp.

     On April 2, 2007, we acquired all of the outstanding capital stock of Sledge Drilling Holding Corp. (“Sledge”) for an aggregate purchase price of approximately $60.8 million, including $50.6 million in cash, of which approximately $19 million was used for the repayment of Sledge’s outstanding debt. As part of the purchase price, we issued 430,191 shares of common stock at a fair value of $23.63 per share for a total fair value of approximately $10.2 million. This acquisition allowed us to expand our drilling operations in the Permian Basin and operates in our contract drilling line of business.

Selected 2008 Acquisitions

     During the first six months of 2008, we made several acquisitions that complemented our existing lines of business. These included among others:

Xterra Fishing and Rental Tools Co

     On January 28, 2008, we acquired all of the outstanding capital stock of Xterra Fishing and Rental Tools Co. (“Xterra”) for total consideration of $21.1 million cash. This acquisition operates in our completion and remedial services line of business.

Segment Overview

Well Servicing

     During the first six months of 2008, our well servicing segment represented 35% of our revenues. Revenue in our well servicing segment is derived from maintenance, workover, completion, and plugging and abandonment services. We provide maintenance-related services as part of the normal, periodic upkeep of producing oil and gas wells. Maintenance-related services represent a relatively consistent component of our business. Workover and completion services generate more revenue per hour than maintenance work, due to the use of auxiliary equipment, but demand for workover and completion services fluctuates more with the overall activity level in the industry.

     We typically charge our customers for services on an hourly basis at rates that are determined by the type of service and equipment required, market conditions in the region in which the rig operates, the ancillary equipment provided on the rig and the necessary personnel. Depending on the type of job, we may also charge by the project or by the day. We measure our activity levels by the total number of hours worked by all of the rigs in our fleet. We monitor our fleet utilization levels, with full utilization deemed to be 55 hours per week per rig. Our fleet has increased from a weighted average number of 364 rigs in the first quarter of 2007 to 403 in the second quarter of 2008 through a combination of newbuild purchases and the remainder through acquisitions and other individual equipment purchases.

     The following is an analysis of our well servicing operations for each of the quarters and year ended December 31, 2007 and the quarters ended March 31, 2008 and June 30, 2008:

		Weighted
		Average								Rig								Profits
		Number of				Rig				Utilization				Revenue Per				Per Rig				Segment
		Rigs				Hours				Rate				Rig Hour				Hour				Profits%
2007:
First Quarter			364				210,800				81.0	%		$	411			$	174				42.2	%
Second Quarter			371				207,700				78.3	%		$	415			$	163				39.5	%
Third Quarter			383				212,100				77.7	%		$	414			$	166				40.0	%
Fourth Quarter			386				200,600				72.7	%		$	409			$	159				38.8	%
Full Year			376				831,200				77.3	%		$	412			$	166				40.1	%
2008:
First Quarter			392				202,500				72.2	%		$	398			$	158				39.8	%
Second Quarter			403				222,300				77.1	%		$	400			$	152				37.9	%

     We gauge activity levels in our well servicing segment based on rig utilization rate, revenue per rig hour and segment profits per rig hour.

     The decrease in our revenue per rig hour from $415 in the second quarter of 2007 to $400 in the second quarter of 2008 is the result of a change in weighting of our work from higher rate workover markets to the lower rate service markets and increased competition.

Fluid Services

     During the first six months of 2008, our fluid services segment represented 30% of our revenues. Revenues in our fluid services segment are earned from the sale, transportation, storage and disposal of fluids used in the drilling, production and maintenance of oil and gas wells, and well site construction and maintenance services. The fluid services segment has a base level of business consisting of transporting and disposing of salt water produced as a by-product of the production of oil and gas. These services are necessary for our customers and generally have a stable demand but typically produce lower relative segment profits than other parts of our fluid services segment. Fluid services for completion and workover projects typically require fresh or brine water for making drilling mud, circulating fluids or frac fluids used during a job, and all of these fluids require storage tanks and hauling and disposal. Because we can provide a full complement of fluid sales, trucking,

storage and disposal required on most drilling and workover projects, the add-on services associated with drilling and workover activity enable us to generate higher segment profits contributions. Revenues from our well site construction services are derived primarily from preparing and maintaining access roads and well locations, installing small diameter gathering lines and pipelines, constructing foundations to support drilling rigs and providing maintenance services for oil and gas facilities. The higher segment profits are due to the relatively small incremental labor costs associated with providing these services in addition to our base fluid services segment. We typically price fluid services by the job, by the hour or by the quantities sold, disposed of or hauled.

     The following is an analysis of our fluid services operations for each of the quarters and year ended December 31, 2007 and the quarters ended March 31, 2008 and June 30, 2008 (dollars in thousands):

										Segment
										Profits
		Weighted								Per
		Average Number of				Revenue Per				Fluid
		Fluid Service				Fluid Service				Service				Segment
		Trucks				Truck				Truck				Profits%
2007:
First Quarter			652			$	98			$	37				37.5	%
Second Quarter			657			$	96			$	35				36.1	%
Third Quarter			653			$	97			$	35				35.7	%
Fourth Quarter			656			$	104			$	37				35.7	%
Full Year			655			$	396			$	144				36.2	%
2008:
First Quarter			644			$	111			$	39				35.0	%
Second Quarter			663			$	109			$	36				33.1	%

     We gauge activity levels in our fluid services segment based on revenue and segment profits per fluid service truck.

     The increase in revenue per fluid service truck from $96,000 in the second quarter of 2007 to $109,000 in the second quarter of 2008 is primarily due to the retirement of less efficient and underutilized trucks in the fourth quarter of 2007, as well as the addition of 17 trucks from the B&S Equipment, Ltd. acquisition. There has also been an increase in revenue from higher fuel surcharges and other services which are not directly correlated with trucking volume. The decrease in segment profits from 36.1% in the second quarter of 2007 to 33.1% in the second quarter of 2008 is due primarily to increased fuel, personnel costs and repair and maintenance.

Completion and Remedial Services

     During the first six months of 2008, our completion and remedial services segment represented 31% of our revenues. Revenues from our completion and remedial services segment are generally derived from a variety of services designed to stimulate oil and gas production or place cement slurry within the wellbores. Our completion and remedial services segment includes pressure pumping, cased-hole wireline services, underbalanced drilling and rental and fishing tool operations.

     Our pressure pumping operations concentrate on providing single truck, lower-horsepower cementing, acidizing and fracturing services in selected markets. In March 2007, we acquired all of the outstanding capital stock of JetStar Consolidated Holdings, Inc. This acquisition allowed us to enter into the Kansas market and increased our presence in North Texas. Our total hydraulic horsepower capacity for our pressure pumping operations was 128,000 and 119,000 at June 30, 2008 and June 30, 2007, respectively.

     In this segment, we generally derive our revenues on a project-by-project basis in a competitive bidding process. Our bids are generally based on the amount and type of equipment and personnel required, with the materials consumed billed separately. During

periods of decreased spending by oil and gas companies, we may be required to discount our rates to remain competitive, which would cause lower segment profits.

     The following is an analysis of our completion and remedial services segment for each of the quarters and year ended December 31, 2007 and the quarters ended March 31, 2008 and June 30, 2008 (dollars in thousands):

						Segment
		Revenues				Profits%
2007:
First Quarter		$	46,137				49.9	%
Second Quarter		$	63,735				47.6	%
Third Quarter		$	66,304				47.6	%
Fourth Quarter		$	64,515				46.2	%
Full Year		$	240,692				47.7	%
2008:
First Quarter		$	68,458				47.7	%
Second Quarter		$	79,579				46.4	%