Edgar Filing: BASIC ENERGY SERVICES INC

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Form 10-Q

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 March 31, 2013

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

For the transition period from to

Commission File Number 001-32693

Basic Energy Services, Inc.

(Exact name of registrant as specified in its charter)


Delaware		54-2091194
(State or other jurisdiction of incorporation or organization)		(I.R.S. Employer Identification No.)

801 Cherry Street, Suite 2100 Fort Worth, Texas		76102
(Address of principal executive offices)		(Zip code)

(817) 334-4100

(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 (§ 232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files). 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.

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

42,223,893 shares of the registrant’s Common Stock were outstanding as of April 26, 2013.

BASIC ENERGY SERVICES, INC.

Index to Form 10-Q


Part I. FINANCIAL INFORMATION			4
Item 1. Financial Statements			4
Consolidated Balance Sheets as of March 31, 2013 (Unaudited) and December 31, 2012			4
Consolidated Statements of Operations and Comprehensive Income (Loss) for the three months ended March 31, 2013 and 2012 (Unaudited)			5
Consolidated Statements of Stockholders’ Equity for the three months ended March 31, 2013 (Unaudited)			6
Consolidated Statements of Cash Flows for the three months ended March 31, 2013 and 2012 (Unaudited)			7
Notes to the Unaudited Consolidated Financial Statements			8
Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations			24
Management’s Overview			24
Segment Overview			25
Operating Cost Overview			28
Critical Accounting Policies and Estimates			28
Results of Operations			30
Liquidity and Capital Resources			32
Other Matters			35
Item 3. Quantitative and Qualitative Disclosures About Market Risk			36
Item 4. Controls and Procedures			36
Part II. OTHER INFORMATION			36
Item 1. Legal Proceedings			36
Item 1A. Risk Factors			36
Item 2. Unregistered Sales of Equity Securities and Use of Proceeds			37
Item 6. Exhibits			38
Signatures			39

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 in our most recent annual report on Form 10-K and other factors, most of which are beyond our control.

The words “believe,” “may,” “estimate,” “continue,” “anticipate,” “intend,” “plan,” “expect,” “indicate” 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 or natural 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 and 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, and industry publications and surveys. Industry surveys and 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)


	March 31,			December 31,
	2013			2012
	(Unaudited)
ASSETS
Current assets:
Cash and cash equivalents	$	81,489		$	134,565
Trade accounts receivable, net of allowance of $3,041 and $2,780, respectively		219,227			209,100
Accounts receivable—related parties		69			52
Income tax receivable		2,509			2,553
Inventories		39,619			40,230
Prepaid expenses		11,612			8,796
Other current assets		12,264			13,891
Deferred tax assets		31,168			29,113

Total current assets		397,957			438,300

Property and equipment, net		951,854			943,766
Deferred debt costs, net of amortization		18,060			18,733
Goodwill		115,731			105,836
Other intangible assets, net of amortization		85,383			82,762
Other assets		6,264			6,521

Total assets	$	1,575,249		$	1,595,918

LIABILITIES AND STOCKHOLDERS’ EQUITY
Current liabilities:
Accounts payable	$	50,631		$	61,740
Accrued expenses		76,666			77,716
Current portion of long-term debt		38,755			38,235
Other current liabilities		333			306

Total current liabilities		166,385			177,997

Long-term debt, net of unamortized premium on notes of $1,630 and $1,683, respectively		847,297			844,906
Deferred tax liabilities		179,670			185,101
Other long-term liabilities		16,998			13,667
Commitments and contingencies
Stockholders’ equity:
Preferred stock; $.01 par value; 5,000,000 shares authorized; none designated or issued at March 31, 2013 and December 31, 2012		—			—
Common stock; $.01 par value; 80,000,000 shares authorized; 43,500,032 shares issued and 42,224,450 shares outstanding at March 31, 2013; 43,500,032 shares issued and 41,721,299 shares outstanding at December 31, 2012		435			435
Additional paid-in capital		364,990			355,687
Retained earnings		25,735			34,513
Treasury stock, at cost, 1,275,582 and 1,778,803 shares at March 31, 2013 and December 31, 2012, respectively		(26,261	)		(16,388	)

Total stockholders’ equity		364,899			374,247

Total liabilities and stockholders’ equity	$	1,575,249		$	1,595,918

See accompanying notes to consolidated financial statements.

Basic Energy Services, Inc.

Consolidated Statements of Operations and Comprehensive Income (Loss)

(in thousands, except per share amounts)


	Three Months Ended March 31,
	2013			2012
	(Unaudited)
Revenues:
Completion and remedial services	$	118,361		$	164,420
Fluid services		84,330			95,325
Well servicing		87,675			95,902
Contract drilling		13,985			15,250

Total revenues		304,351			370,897

Expenses:
Completion and remedial services		79,008			97,025
Fluid services		57,874			62,847
Well servicing		65,002			67,250
Contract drilling		9,164			10,206
General and administrative, including stock-based compensation of $2,817 and $2,173 in three months ended March 31, 2013 and 2012, respectively		41,957			41,358
Depreciation and amortization		49,781			43,984
Loss on disposal of assets		1,089			1,719

Total expenses		303,875			324,389

Operating income		476			46,508
Other income (expense):
Interest expense		(16,808	)		(15,223	)
Interest income		17			12
Other income		162			149

Income (loss) from continuing operations before income taxes		(16,153	)		31,446
Income tax benefit (expense)		7,375			(11,815	)

Net income (loss)	$	(8,778	)	$	19,631

Earnings per share of common stock:
Basic	$	(0.22	)	$	0.48

Diluted	$	(0.22	)	$	0.47

See accompanying notes to consolidated financial statements.

Basic Energy Services, Inc.

Consolidated Statements of Stockholders’ Equity

(in thousands, except share data)


	Common Stock				Additional Paid-In			Treasury			Retained			Total Stockholders’
	Shares		Amount		Capital			Stock			Earnings			Equity
Balance - December 31, 2012		43,500,032	$	435	$	355,687		$	(16,388	)	$	34,513		$	374,247
Issuances of restricted stock		—		—		6,712			(6,712	)		—			—
Amortization of share-based compensation		—		—		2,817			—			—			2,817
Purchase of treasury stock		—		—		—			(3,500	)		—			(3,500	)
Exercise of stock options / vesting of restricted stock		—		—		(226	)		339			—			113
Net loss		—		—		—			—			(8,778	)		(8,778	)

Balance - March 31, 2013 (unaudited)		43,500,032	$	435	$	364,990		$	(26,261	)	$	25,735		$	364,899

See accompanying notes to consolidated financial statements.

Basic Energy Services, Inc.

Consolidated Statements of Cash Flows

(in thousands)


	Three Months Ended March 31,
	2013			2012
	(Unaudited)
Cash flows from operating activities:
Net income (loss)	$	(8,778	)	$	19,631
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization		49,781			43,984
Accretion on asset retirement obligation		28			28
Change in allowance for doubtful accounts		261			382
Amortization of deferred financing costs		754			693
Amortization and retirement of discount or premium on notes		(53	)		(50	)
Non-cash compensation		2,817			2,397
Loss on disposal of assets		1,089			1,719
Deferred income taxes		(7,486	)		11,369
Changes in operating assets and liabilities, net of acquisitions:
Accounts receivable		(10,405	)		8,027
Inventories		611			(2,961	)
Prepaid expenses and other current assets		(6,729	)		(3,803	)
Other assets		257			196
Accounts payable		(11,109	)		(18,060	)
Income tax payable		44			617
Other liabilities		239			1,136
Accrued expenses		(1,837	)		(84	)

Net cash provided by operating activities		9,484			65,221

Cash flows from investing activities:
Purchase of property and equipment		(39,873	)		(46,823	)
Proceeds from sale of mutual fund		5,635			—
Proceeds from sale of assets		3,498			1,987
Payments for other long-term assets		(260	)		(171	)
Payments for businesses, net of cash acquired		(16,464	)		(18,584	)

Net cash used in investing activities		(47,464	)		(63,591	)

Cash flows from financing activities:
Payments of debt		(11,628	)		(9,644	)
Purchase of treasury stock		(3,500	)		(3,283	)
Tax withholding from exercise of stock options		(59	)		(34	)
Exercise of employee stock options		172			104
Deferred loan costs and other financing activities		(81	)		(1	)

Net cash used in financing activities		(15,096	)		(12,858	)

Net decrease in cash and equivalents		(53,076	)		(11,228	)
Cash and cash equivalents - beginning of period		134,565			78,458

Cash and cash equivalents - end of period	$	81,489		$	67,230

See accompanying notes to consolidated financial statements.

BASIC ENERGY SERVICES, INC.

Notes to Consolidated Financial Statements

March 31, 2013 (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 of America (GAAP) 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 which are of a normal recurring nature considered necessary for a fair presentation have been made in the accompanying unaudited financial statements.

Nature of Operations

Basic provides a wide range of well site services to oil and natural gas drilling and producing companies, including completion and remedial services, fluid services and well site construction services, well servicing and contract drilling. These services are primarily provided using 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, Louisiana, Wyoming, North Dakota, Colorado, Utah, Montana, West Virginia, and Pennsylvania.

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 variable interest in any other organization, entity, partnership, or contract. All intercompany transactions and balances have been eliminated.

Estimates and Uncertainties

Preparation of the accompanying consolidated financial statements in conformity with GAAP 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

•

Future cash flows

•

Stock-based compensation

•

Income taxes

•

Asset retirement obligations

•

Environmental liabilities

Revenue Recognition

Completion and Remedial Services — Completion and remedial services consists primarily of pumping services focused on cementing, acidizing and fracturing, nitrogen units, coiled tubing units, snubbing units, water treatment, thru-tubing and rental and fishing tools. 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 value of the services.

Fluid Services — Fluid services consists primarily of the sale, transportation, treatment, 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.

Well Servicing — Well servicing consists primarily of maintenance services, workover services, completion services, plugging and abandonment services and rig manufacturing and servicing. 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. Rig manufacturing revenue is recognized when the rig is accepted by the customer, based on the completed contract method by individual rig.

Contract Drilling — Contract drilling consists primarily of drilling wells to a specified depth using drilling rigs. 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 and drill bits are stated at the lower of cost or market, with cost being determined by the average cost method. Other inventories, consisting mainly of manufacturing raw materials, 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.

Property and Equipment

Property and equipment are stated at cost or at estimated fair value at acquisition date if acquired in a business combination. Expenditures for repairs and maintenance are charged to expense as incurred and additions and improvements that significantly extend the lives of the assets are capitalized. Upon sale or other retirement of depreciable property, the cost and accumulated depreciation and amortization are removed from the related accounts and any gain or loss is reflected in operations. All property and equipment are depreciated or amortized (to the extent of estimated salvage values) on the straight-line method. The components of a well servicing rig generally require replacement or refurbishment during the well servicing rig’s life and are depreciated over their estimated useful lives, which range from 3 to 15 years. The costs of the original components of a purchased or acquired well servicing rig are not maintained separately from the base rig.

Impairments

Long-lived assets, such as property, plant and equipment, and purchased intangibles subject to amortization, are reviewed for impairment at least 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.

Basic’s goodwill and trade name intangibles are considered to have an indefinite useful economic life and are not amortized. Basic assesses impairment of its goodwill and trade name intangibles annually as of December 31 or on an interim basis if events or circumstances indicate that the fair value of the assets has decreased below the assets’ carrying value. A qualitative assessment is allowed to determine if goodwill is potentially impaired. The qualitative assessment determines whether it is more likely than not that a reporting unit’s fair value is less than its carrying amount. If it is more likely than not that the fair value of the reporting unit is less than the carrying amount then the two-step impairment test is performed. 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.

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 amortized to interest expense using the effective interest method.

Deferred debt costs were approximately $22.9 million net of accumulated amortization of $4.9 million, and $22.6 million net of accumulated amortization of $4.1 million at March 31, 2013 and December 31, 2012, respectively. Amortization of deferred debt costs totaled approximately $754,000 and $693,000 for the three months ended March 31, 2013 and 2012, respectively.

Goodwill and Other Intangible Assets

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. Basic completes its assessment of goodwill and trade name intangible impairment as of December 31 of each year.

Basic had trade names of $1.9 million as of March 31, 2013 and December 31, 2012. Trade names have an indefinite life and are tested for impairment annually.

Additions to goodwill during the three months ended March 31, 2013 were primarily due to the purchase price allocations for acquisitions completed during 2013. These purchase price allocations were preliminary and subject to change. The changes in the carrying amount of goodwill for the three months ended March 31, 2013 were as follows (in thousands):


	Completion and Remedial Services		Fluid Services		Well Servicing		Contract Drilling		Total
Balance as of December 31, 2012	$	79,047	$	20,467	$	6,322	$	—	$	105,836
Goodwill additions		—		9,895		—		—		9,895

Balance as of March 31, 2013	$	79,047	$	30,362	$	6,322	$	—	$	115,731

Basic’s intangible assets subject to amortization consist of customer relationships, non-compete agreements and rig engineering plans. The gross carrying amount of customer relationships subject to amortization was $93.4 million at March 31, 2013 and $90.1 million at December 31, 2012. The gross carrying amount of non-compete agreements subject to amortization totaled approximately $9.2 million and $8.0 million at March 31, 2013 and December 31, 2012, respectively. The gross carrying amount of other intangible assets subject to amortization was $1.1 million at March 31, 2013 and December 31, 2012. Accumulated amortization related to these intangible assets totaled approximately $20.4 million and $18.4 million at March 31, 2013 and December 31, 2012, respectively. Amortization expense for the three months ended March 31, 2013 and 2012 was approximately $2.0 million and $1.7 million, respectively. Other intangibles net of accumulated amortization allocated to reporting units as of March 31, 2013 were $59.3 million, $15.6 million, $6.4 million and $4.1 million for completion and remedial services, fluid services, well servicing, and contract drilling, respectively. No adjustments were made to prior periods to reflect subsequent adjustments to acquisitions due to immateriality. Customer relationships are amortized over a 15-year life, non-compete agreements are amortized over a five-year life, and rig engineering plans are amortized over a 15-year life.

Stock-Based Compensation

Basic’s outstanding stock-based awards consist of stock options and restricted stock. Stock options issued are valued on the grant date using the Black-Scholes-Merton option-pricing model, and restricted stock issued is valued based on the fair value at the grant date. All stock-based awards are adjusted for an expected forfeiture rate and amortized over the vesting period. For performance based restricted stock awards, compensation expense is recognized in the Company’s financial statements based on their grant date fair value. Basic utilizes (i) the closing stock price on the date of grant to determine the fair value of vesting restricted stock awards and (ii) a Monte Carlo simulation to determine the fair value of restricted stock awards with a combination of market and service vesting criteria. The Monte Carlo simulation model utilizes multiple input variables that determine the probability of satisfying the market condition stipulated in the award grant and calculates the fair value of the award. The expected volatility utilized in the model was estimated using our historical volatility and the historical volatilities of our peer companies. The risk-free interest rate was based on the U.S. treasury rate for a term commensurate with the expected life of the grant.

Income Taxes

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. Basic 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 that represented 10% or more of consolidated revenue during the three months ended March 31, 2013 or 2012.

Asset Retirement Obligations

Basic records 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 capitalizes 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.

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, chemicals 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, its past experience with similar claims and the likelihood of the future event occurring. Basic maintains accruals on the consolidated balance sheets to cover self-insurance retentions (See note 6).

Recent Accounting Pronouncements

In December 2011, the FASB issued ASU No. 2011-11, “Balance Sheet” (“ASU 2011-11”). The standard amends and expands disclosure requirements about balance sheet offsetting and related arrangements. ASU 2011-11 became effective for Basic on January 1, 2013. The adoption of this standard did not have a material impact to Basic’s results of operations, financial position or liquidity as a result of this guidance.

In July 2012, the FASB issued ASU No. 2012-02, “Intangibles — Goodwill and Other: Testing Indefinite-Lived Intangible Assets for Impairment” (“ASU 2012-02”). ASU 2012-02 allows a qualitative assessment of whether it is more likely than not that the indefinite-lived intangible asset’s fair value is less than its carrying amount before applying the quantitative impairment test. If it is more likely than not that the fair value of an indefinite-lived intangible asset is less than its carrying amount, then the impairment test for that indefinite-lived intangible asset would be performed. ASU 2012-02 is effective for annual and interim impairment tests performed for indefinite-lived intangible assets for fiscal years beginning after September 15, 2012 and early adoption is permitted. Basic early adopted this accounting standard update and although it has changed the process Basic uses to determine if indefinite-lived intangible assets are impaired, it has not had a material impact on Basic’s consolidated financial statements.

3. Acquisitions

In 2012 and during the first three months of 2013, Basic acquired either substantially all of the assets or all of the outstanding capital stock of each of the following businesses, each of which was accounted for using the purchase method of accounting. The following table summarizes the provisional values for Salt Water Disposal of North Dakota LLC, Atlas Environmental Consulting, Inc. and Atlas Oilfield Construction Company, LLC and Petroleum Water Solutions, LLC acquisitions and the final values for the remaining acquisitions at the date of acquisition (in thousands):


	Closing Date		Total Cash Paid (net of cash acquired)
Mayo Marrs Casing Pulling, Inc.		January 13, 2012	$	6,644
SPA Victoria, LP		March 16, 2012		11,948
Surface Stac, Inc.		May 15, 2012		23,184
Salt Water Disposal of North Dakota LLC		December 19, 2012		43,190

Total 2012			$	84,966

Atlas Environmental Consulting, Inc. and Atlas Oilfield Construction Company, LLC		February, 19 2013	$	13,175
Petroleum Water Solutions, LLC		February 22, 2013	$	3,288

Total 2013			$	16,463

The operations of each of the acquisitions listed above are included in Basic’s statement of operations as of each respective closing date. The pro forma effect of the remainder of the acquisitions in the first three months of 2013 is not material, either individually or when aggregated, to the reported results of operations. The provisional values used on Salt Water Disposal of North Dakota LLC, Atlas Environmental Consulting, Inc. and Atlas Oilfield Construction Company, LLC and Petroleum Water Solutions, LLC will be finalized once the valuation of the tangible and intangible assets is completed.

4. Property and Equipment

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


	March 31,		December 31,
	2013		2012
Land	$	16,885	$	16,338
Buildings and improvements		55,115		53,831
Well service units and equipment		491,412		487,785
Fluid services equipment		229,336		218,933
Brine and fresh water stations		13,942		14,101
Frac/test tanks		275,432		274,311
Pressure pumping equipment		281,844		277,529
Construction equipment		15,653		15,657
Contract drilling equipment		104,822		105,992
Disposal facilities		137,421		119,903
Vehicles		62,904		61,802
Rental equipment		66,647		65,047
Aircraft		2,805		4,151
Software		23,313		23,921
Other		16,340		19,055

		1,793,871		1,758,357
Less accumulated depreciation and amortization		842,017		814,591

Property and equipment, net	$	951,854	$	943,766

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 consisted of the following (in thousands):


	March 31,		December 31,
	2013		2012
Light vehicles	$	32,657	$	31,180
Contract Drilling		4,223		4,223
Well service units and equipment		1,574		1,748
Fluid services equipment		109,701		105,932
Pressure pumping equipment		27,112		29,253
Construction equipment		942		974
Software		17,120		17,120
Other		99		344

		193,428		190,774
Less accumulated amortization		63,236		63,194

	$	130,192	$	127,580

Amortization of assets held under capital leases of approximately $7.3 million and $6.4 million for the three months ended March 31, 2013 and 2012, respectively, is included in depreciation and amortization expense in the consolidated statements of operations.

5. Long-Term Debt

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


	March 31,		December 31,
	2013		2012
Credit Facilities:
Revolver	$	—	$	—
7.75% Senior Notes due 2019		475,000		475,000
7.75% Senior Notes due 2022		300,000		300,000
Unamortized (discount) premium		1,630		1,683
Capital leases and other notes		109,422		106,458

		886,052		883,141
Less current portion		38,755		38,235

	$	847,297	$	844,906

7.75% Senior Notes due 2019

On February 15, 2011, we issued $275.0 million of 7.75% Senior Notes due 2019 (the “2019 Notes”). On June 13, 2011, we issued an additional $200.0 million, for an aggregate principal amount of $475.0 million of 2019 Notes. The 2019 Notes are jointly and severally, and unconditionally, guaranteed on a senior unsecured basis by all of our current subsidiaries, other than three immaterial subsidiaries. The 2019 Notes and the guarantees rank (i) equally in right of payment with any of our and the subsidiary guarantors’ existing and future senior indebtedness, including our existing 7.75% Senior Notes due 2022 and the related guarantees, and (ii) effectively junior to all existing or future liabilities of our subsidiaries that do not guarantee the 2019 Notes and to our and the subsidiary guarantors’ existing or future secured indebtedness to the extent of the value of the collateral therefor.

The 2019 Notes were offered and sold in private transactions in accordance with Rule 144A and Regulation S under the Securities Act of 1933, as amended (the “Securities Act”). Under the terms of the sale of the 2019 Notes, we were required to take appropriate steps to offer to exchange other 2019 Notes with the same terms that have been registered with the Securities and Exchange Commission for the private placement 2019 Notes. We completed the exchange offer for all of the 2019 Notes on November 15, 2011.

The purchase price for the $275.0 million of 2019 Notes issued on February 15, 2011 was 100.000% of their principal amount, and the purchase price for the $200.0 million of 2019 Notes issued on June 13, 2011 was 101.000%, plus accrued interest from February 15, 2011. We received net proceeds from the issuance of the 2019 Notes of approximately $464.6 million after premiums and offering expenses. We used a portion of the net proceeds from the February 2011 offering to fund our tender offer and consent solicitation for our 11.625% Senior Secured Notes due 2014 and to redeem any of the Senior Secured Notes not purchased in the tender offer. We used a portion of the net proceeds from the June 2011 offering to fund the $186.3 million purchase price for the Maverick Companies acquisition completed in July 2011 and for general corporate purposes.

The 2019 Notes were issued pursuant to an indenture dated as of February 15, 2011 (the “2019 Notes Indenture”), by and among Basic, the guarantors party thereto and Wells Fargo Bank, N.A., as trustee. Interest on the 2019 Notes accrues at a rate of 7.75% per year. Interest on the 2019 Notes is payable semi-annually in arrears on February 15 and August 15 of each year. The 2019 Notes mature on February 15, 2019.

The 2019 Notes Indenture contains covenants that, among other things, limit our ability and the ability of certain of our subsidiaries to:

•

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 our restricted subsidiaries to us; and

•

sell assets or consolidate or merge with or into other companies.

These and other covenants that are contained in the 2019 Notes Indenture are subject to important exceptions and qualifications set forth in the 2019 Notes Indenture. At March 31, 2013, we were in compliance with the restrictive covenants under the 2019 Notes Indenture.

We may, at our option, redeem all or part of the 2019 Notes, at any time on or after February 15, 2015, at a redemption price equal to 100% of the principal amount thereof, plus a premium declining ratably to par and accrued and unpaid interest to the date of redemption.

At any time before February 15, 2014, we, at our option, may redeem up to 35% of the aggregate principal amount of the 2019 Notes issued under the 2019 Notes Indenture with the net cash proceeds of one or more qualified equity offerings at a redemption price of 107.750% of the principal amount of the 2019 Notes to be redeemed, plus accrued and unpaid interest to the date of redemption, as long as:

•

at least 65% of the aggregate principal amount of the 2019 Notes issued under the 2019 Notes Indenture remains outstanding immediately after the occurrence of such redemption; and

•

such redemption occurs within 90 days of the date of the closing of any such qualified equity offering.

In addition, at any time before February 15, 2015, we may redeem some or all of the 2019 Notes at a redemption price equal to 100% of the principal amount of the 2019 Notes, plus an applicable premium and accrued and unpaid interest to the date of redemption.

Following a change of control, as defined in the 2019 Notes Indenture, we will be required to make an offer to repurchase all or a portion of the 2019 Notes at 101% of their principal amount, plus accrued and unpaid interest to the date of repurchase.

7.75% Senior Notes due 2022

On October 16, 2012, we completed the issuance and sale of $300.0 million aggregate principal amount of 7.75% Senior Notes due 2022 (the “2022 Notes”). The 2022 Notes are jointly and severally, and unconditionally, guaranteed on a senior unsecured basis initially by all of our current subsidiaries other than three immaterial subsidiaries. The 2022 Notes and the guarantees rank (i) equally in right of payment with any of our and the subsidiary guarantors’ existing and future senior indebtedness, including our existing 2019 Notes and the related guarantees, and (ii) effectively junior to all existing or future liabilities of our subsidiaries that do not guarantee the 2022 Notes and to our and the subsidiary guarantors’ existing or future secured indebtedness to the extent of the value of the collateral therefor.

The 2022 Notes and the guarantees were offered and sold in private transactions in accordance with Rule 144A and Regulation S under the Securities Act of 1933, as amended. We received net proceeds from the issuance of the 2022 Notes of approximately $293.3 million after discounts and offering expenses. We used a portion of the net proceeds from the offering to fund our pending tender offer and consent solicitation for our 7.125% Senior Notes due 2016 (the “2016 Notes”) and to redeem any of the 2016 Notes not purchased in the tender offer. The remainder of the net proceeds were used for general corporate purposes.

The 2022 Notes and the guarantees were issued pursuant to an indenture dated as of October 16, 2012 (the “2022 Notes Indenture”), by and among us, the guarantors party thereto and Wells Fargo Bank, National Association, as trustee. Interest on the 2022 Notes accrues from and including October 16, 2012 at a rate of 7.75% per year. Interest on the 2022 Notes is payable semi-annually in arrears on April 15 and October 15 of each year, commencing on April 15, 2013. The 2022 Notes mature on October 15, 2022.

The 2022 Notes Indenture contains covenants that, among other things, limit our ability and the ability of certain of our subsidiaries to:

•

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 our restricted subsidiaries to us; and

•

sell assets or consolidate or merge with or into other companies.

These and other covenants that are contained in the 2022 Notes Indenture are subject to important exceptions and qualifications. At March 31, 2013, we were in compliance with the restrictive covenants under the 2022 Notes Indenture.

We may, at our option, redeem all or part of the 2022 Notes, at any time on or after October 15, 2017, at a redemption price equal to 100% of the principal amount thereof, plus a premium declining ratably to par and accrued and unpaid interest to the date of redemption.

At any time before October 15, 2015, we, at our option, may redeem up to 35% of the aggregate principal amount of the 2022 Notes issued under the 2022 Notes Indenture with the net cash proceeds of one or more qualified equity offerings at a redemption price of 107.750% of the principal amount of the 2022 Notes to be redeemed, plus accrued and unpaid interest to the date of redemption, as long as:

•

at least 65% of the aggregate principal amount of the 2022 Notes issued under the 2022 Notes Indenture remains outstanding immediately after the occurrence of such redemption; and

•

such redemption occurs within 90 days of the date of the closing of any such qualified equity offering.

In addition, at any time before October 15, 2017, we may redeem some or all of the 2022 Notes at a redemption price equal to 100% of the principal amount of the 2022 Notes, plus an applicable premium and accrued and unpaid interest to the date of redemption.

Following a change of control, as defined in the 2022 Notes Indenture, we will be required to make an offer to repurchase all or a portion of the 2022 Notes at 101% of their principal amount, plus accrued and unpaid interest to the date of repurchase.

Revolving Credit Facility

On February 15, 2011, in connection with the initial offering of 2019 Notes, we terminated our previous $30.0 million secured revolving credit facility with Capital One, National Association, and entered into a credit agreement (the “Credit Agreement”) providing for a new $165.0 million Revolving Credit Facility with Merrill Lynch, Pierce, Fenner & Smith Incorporated and Capital One, National Association, as joint lead arrangers and joint book managers, the lenders party thereto and Bank of America, N.A., as administrative agent. The Credit Agreement includes an accordion feature whereby the total credit available to us can be increased by up to $100.0 million under certain circumstances, subject to additional lender commitments. The obligations under the Credit Agreement are guaranteed on a joint and several basis by each of our current subsidiaries, other than three immaterial subsidiaries, and are secured by substantially all of our and our subsidiary guarantors’ assets as collateral under a related Security Agreement (the “Security Agreement”). As of March 31, 2013 and December 31, 2012, the non-guarantor subsidiaries held no assets and performed no operations. On July 15, 2011, we exercised the accordion feature and amended the Credit Agreement to increase our total credit available from $165.0 million to $225.0 million. On April 5, 2012, we amended the Credit Agreement to increase the aggregate amount of commitments thereunder to $250.0 million. On October 1, 2012, we further amended the Credit Agreement to permit the transactions contemplated by the offering of 2022 Notes and tender offer and redemption of 2016 Notes.

Borrowings under the Credit Agreement mature on January 15, 2016, and we have the ability at any time to prepay the Credit Agreement without premium or penalty. At our option, advances under the Credit Agreement may be comprised of (i) alternate base rate loans, at a variable base interest rate plus a margin ranging from 1.50% to 2.25% based on our leverage ratio or (ii) Eurodollar loans, at a variable base interest rate plus a margin ranging from 2.50% to 3.25% based on our leverage ratio. We will pay a commitment fee equal to 0.50% on the daily unused amount of the commitments under the Credit Agreement.

The Credit Agreement contains various covenants that, subject to agreed upon exceptions, limit our ability and the ability of certain of our subsidiaries to:

•

incur indebtedness;

•

grant liens;

•

enter into sale and leaseback transactions;

•

make loans, capital expenditures, acquisitions and investments;

•

change the nature of business;

•

acquire or sell assets or consolidate or merge with or into other companies;

•

declare or pay dividends;

•

enter into transactions with affiliates;

•

enter into burdensome agreements;

•

prepay, redeem or modify or terminate other indebtedness;

•

change accounting policies and reporting practices; and

•

amend organizational documents.

The Credit Agreement also contains covenants that, among other things, limit the amount of capital contributions we may make and require us to maintain specified ratios or conditions as follows:

•

a minimum consolidated interest coverage ratio of not less than 2.50 to 1.00;

•

a maximum consolidated leverage ratio not to exceed 4.00 to 1.00; and

•

a maximum consolidated senior secured leverage ratio of 2.00 to 1.00.

If an event of default occurs under the Credit Agreement, then the lenders may (i) terminate their commitments under the Credit Agreement, (ii) declare any outstanding loans under the Credit Agreement to be immediately due and payable after applicable grace periods and (iii) foreclose on the collateral secured by the Security Agreement.

We had no borrowings and $22.5 million of letters of credit outstanding under the Credit Agreement as of March 31, 2013, giving us $227.5 million of available borrowing capacity. At March 31, 2013, we were in compliance with our covenants under the Credit Agreement.

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 leases with Banc of America Leasing & Capital, LLC require it to maintain a minimum debt service coverage ratio of 1.05 to 1.00. At March 31, 2013, Basic was in compliance with this covenant.

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


	Three Months Ended March 31,
	2013			2012
Cash payments for interest	$	19,266		$	19,375
Commitment and other fees paid		455			408
Amortization of debt issuance costs and discount or premium on notes		700			643
Change in accrued interest		(3,402	)		(5,214	)
Other		(211	)		11

	$	16,808		$	15,223

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 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

Self-Insured Risk Accruals

Basic is self-insured up to retention limits as it relates to workers’ compensation, general liability claims, 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, general liability claims, and medical and dental coverage of $1.0 million, $1.0 million, and $300,000, respectively. Basic has lower deductibles per occurrence for automobile liability. Basic maintains accruals in the accompanying consolidated balance sheets related to self-insurance retentions based upon third-party data and claims history.

At March 31, 2013 and December 31, 2012, self-insured risk accruals totaled approximately $24.2 million net of a $355,000 receivable for medical and dental coverage and $22.9 million net of a $205,000 receivable for medical and dental coverage, respectively.

7. Stockholders’ Equity

Common Stock

At March 31, 2013 and December 31, 2012, Basic had 80,000,000 shares of common stock, par value $.01 per share, authorized.

During the year ended 2012, Basic issued 133,200 shares of common stock from treasury stock for the exercise of stock options and 0 shares of newly-issued common stock for the exercise of stock options.

In March 2012, Basic granted various employees 646,438 restricted shares of common stock that vest over a three-year period and 179,000 shares that vest over a four-year period. The Compensation Committee of Basic’s Board of Directors approved grants of performance-based stock awards to certain members of management. In January 2013, it was determined that 42,513 shares, or 25% of the target number of shares, were earned based on Basic’s achievement of total stockholder return over the performance period from January 1, 2012 through December 31, 2012, as compared to other members of a defined peer group. These restricted shares remain subject to vesting over a three-year period, with the first shares vesting on March 15, 2014.

In March 2013, Basic granted various employees 432,400 restricted shares of common stock that vest over a three-year period and 262,000 shares that vest over a four-year period.

During the three months ended March 31, 2013, Basic issued 34,175 shares of common stock from treasury stock for the exercise of stock options.

Treasury Stock

Basic has acquired treasury shares through net share settlements for payment of payroll taxes upon the vesting of restricted stock. Basic acquired a total of 357,714 shares through net share settlements during 2012 and 251,519 shares through net share settlements during the first three months of 2013.

Preferred Stock

At March 31, 2013 and December 31, 2012, Basic had 5,000,000 shares of preferred stock, par value $.01 per share, authorized, of which none was designated, issued or outstanding.

8. Incentive Plan

In May 2003, Basic’s board of directors and stockholders approved the Basic Energy Services, Inc. 2003 Incentive Plan (as amended, 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 predecessors that were awarded and remained outstanding prior to adoption of the Plan. The Plan provides for the issuance of 8,350,000 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.

During the three months ended March 31, 2013 and 2012, compensation expense related to share-based arrangements was approximately $2.8 million and $2.2 million, respectively. For compensation expense recognized during the three months ended March 31, 2013 and 2012, Basic recognized a tax benefit of approximately $1.3 million and $816,000, respectively.

As of March 31, 2013, there was approximately $28.1 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 2.6 years. The total fair value of share-based awards vested during the three months ended March 31, 2013 and 2012 was approximately $11.5 million and $11.6 million, respectively. There was no actual tax benefit realized for the tax deduction from vested share-based awards for the three months ended March 31, 2012. During the three months ended March 31, 2013, there was no excess tax benefit due to the net operating loss carryforwards (“NOL”). If there was no NOL, the excess tax benefit would have been $800,000.

Stock Option Awards

The fair value of each option award is estimated on the date of grant using the Black-Scholes-Merton option-pricing model. 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 March 31, 2013 and the changes during the three months then ended:


	Number of Options Granted			Weighted Average Exercise Price		Weighted Average Remaining Contractual Term (Years)		Aggregate Instrinsic Value (000’s)
Non-statutory stock options:
Outstanding, beginning of period		642,250		$	16.09
Options granted		—		$	—
Options forfeited		—		$	—
Options exercised		(34,175	)	$	5.37
Options expired		—		$	—

Outstanding, end of period		608,075		$	16.69		2.46	$	2,040

Exercisable, end of period		608,075		$	16.69		2.46	$	2,040

Vested or expected to vest, end of period		608,075		$	16.69		2.46	$	2,040

The total intrinsic value of share options exercised during the three months ended March 31, 2013 and 2012 was approximately $293,000 and $130,000, respectively.

Cash received from share option exercises under the Plan was approximately $183,000 and $70,000 for the three months ended March 31, 2013 and 2012, respectively. There was no actual tax benefit realized for the tax deductions from options exercised for the three months ended March 31, 2012. During the three months ended March 31, 2013, there was no excess tax benefit due to the NOL. If there was no NOL, the excess tax benefit would have been $14,000.

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

Restricted Stock Awards

On March 12, 2013, the Compensation Committee of Basic’s Board of Directors approved grants of performance-based stock awards to certain members of management. The performance-based awards are tied to Basic’s achievement of total stockholder return over the performance period from January 1, 2013 through December 31, 2013, 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 347,084 target number of shares 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, 2015. As of March 31, 2013, Basic estimated that 100% of the target number of performance-based awards will be earned.

A summary of the status of Basic’s non-vested share grants at March 31, 2013 and changes during the three months ended March 31, 2013 is presented in the following table:


				Weighted Average
	Number of			Grant Date Fair
Nonvested Shares	Shares			Value Per Share
Nonvested at beginning of period		1,986,059		$	15.10
Granted during period		1,042,281			14.35
Vested during period		(751,878	)		14.74
Forfeited during period		(16,348	)		15.09

Nonvested at end of period		2,260,114		$	14.89

9. Related Party Transactions

Basic had receivables from employees of approximately $69,000 and $52,000 as of March 31, 2013 and December 31, 2012, 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 per year. The term of the lease is five years and will continue on a year-to-year basis unless terminated by either party. In December 2010, Basic entered into a lease agreement with Darle Vuelta Cattle Co., LLC for the right to operate a salt water disposal well, brine well and fresh water well. The term of the leases is two years and will continue until the salt water disposal well and brine well are plugged and no fresh water is being sold. The lease payments are the greater of (i) the sum of $0.10 per barrel of disposed oil and gas waste and $0.05 per barrel of brine or fresh water sold or (ii) $5,000 per month. In April 2012, Basic purchased approximately 22 acres of land for approximately $215,000 from Darle Vuelta Cattle Co., LLC.

Basic entered into a joint venture agreement with a family member of an executive officer to form an entity in 2010. Basic holds 80 percent of the equity in the joint venture, and consolidates the financial results. For the three months ended March 31, 2013 and 2012, Basic funded approximately $587,000 and $345,000, respectively, for this joint venture. The entity had only research and development activities for the three months ended March 31, 2012 and 2013.

10. Earnings Per Share

Basic’s 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 March 31,
	2013			2012
	(Unaudited)
Numerator (both basic and diluted):
Net income (loss)	$	(8,778	)	$	19,631
Denominator:
Denominator for basic earnings per share		39,885,111			40,758,074
Stock options		284,115			233,344
Unvested restricted stock		140,605			637,482

Denominator for diluted earnings per share		40,309,831			41,628,900

Basic earnings per common share:	$	(0.22	)	$	0.48

Diluted earnings per common share:	$	(0.22	)	$	0.47

Stock options and unvested shares of restricted stock of approximately 221,384 were excluded in the computation of diluted earnings per share for the three months ended March 31, 2013 and 69,000 were excluded in the computation of diluted earnings per share for the three months ended March 31, 2012, as the effect would have been anti-dilutive due to the net loss in the period.

11. Business Segment Information

Basic’s reportable business segments are Completion and Remedial Services, Fluid Services, Well Servicing, and Contract Drilling. The following is a description of the segments:

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

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, treat, store and dispose of a variety of fluids, as well as provide well site construction and maintenance services. These services are required in most workover, completion and remedial projects and are routinely used in daily producing well operations.

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 natural gas. These services are performed to establish, maintain and improve production throughout the productive life of an oil and natural gas well and to plug and abandon a well at the end of its productive life. Well servicing equipment and capabilities such as Basic’s are essential to facilitate most other services performed on a well. This segment also includes the manufacturing, refurbishment and servicing of mobile well servicing rigs and associated equipment.

Contract Drilling: This segment utilizes drilling 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 Remedial Services			Fluid Services			Well Servicing			Contract Drilling			Corporate and Other		Total
*Three Months Ended March 31, 2013 (Unaudited)*
Operating revenues	$	118,361		$	84,330		$	87,675		$	13,985		$	—	$	304,351
Direct operating costs		(79,008	)		(57,874	)		(65,002	)		(9,164	)		—	$	(211,048	)

Segment profits	$	39,353		$	26,456		$	22,673		$	4,821		$	—	$	93,303

Depreciation and amortization	$	14,932		$	14,311		$	14,787		$	3,196		$	2,555	$	49,781
Capital expenditures, (excluding acquisitions)	$	12,987		$	9,118		$	12,026		$	3,093		$	2,649	$	39,873
Identifiable assets	$	442,241		$	308,943		$	303,136		$	63,426		$	457,503	$	1,575,249
*Three Months Ended March 31, 2012 (Unaudited)*
Operating revenues	$	164,420		$	95,325		$	95,902		$	15,250		$	—	$	370,897
Direct operating costs		(97,025	)		(62,847	)		(67,250	)		(10,206	)		—		(237,328	)

Segment profits	$	67,395		$	32,478		$	28,652		$	5,044		$	—	$	133,569

Depreciation and amortization	$	12,851		$	11,796		$	14,341		$	2,748		$	2,248	$	43,984
Capital expenditures, (excluding acquisitions)	$	17,013		$	9,052		$	13,521		$	4,607		$	2,630	$	46,823
Identifiable assets	$	412,206		$	245,063		$	301,996		$	62,029		$	436,403	$	1,457,697

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 March 31,
	2013			2012
Segment profits	$	93,303		$	133,569
General and administrative expenses		(41,957	)		(41,358	)
Depreciation and amortization		(49,781	)		(43,984	)
Loss on disposal of assets		(1,089	)		(1,719	)

Operating income	$	476		$	46,508

12. Supplemental Schedule of Cash Flow Information

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


	Three Months Ended March 31,
	2013		2012
	(In thousands)
Capital leases issued for equipment	$	14,592	$	8,339
Asset retirement obligation additions	$	78	$	11

Basic paid no income taxes during the three months ended March 31, 2013 or for the same period in 2012. Basic paid interest of approximately $19.3 million and $19.4 million during the three months ended March 31, 2013 and 2012, respectively.

13. Fair Value Measurements

Fair value is the price that would be received to sell an asset or the amount paid to transfer a liability in an orderly transaction between market participants (an exit price) at the measurement date. Fair value is a market based measurement considered from the perspective of a market participant. Basic uses market data or assumptions that market participants would use in pricing the asset or liability, including assumptions about risk and the risks inherent in the inputs to the valuation. These inputs can be readily observable, market corroborated, or unobservable. If observable prices or inputs are not available, unobservable prices or inputs are used to estimate the current fair value, often using an internal valuation model. These valuation techniques involve some level of management estimation and judgment, the degree of which is dependent on the item being valued. Basic primarily applies a market approach for recurring fair value measurements using the best available information while utilizing valuation techniques that maximize the use of observable inputs and minimize the use of unobservable inputs.

There is a fair value hierarchy that prioritizes the inputs used to measure fair value. The hierarchy gives the highest priority to quoted prices in active markets for identical assets or liabilities (Level 1 measurement) and the lowest priority to unobservable inputs (Level 3 measurement). Basic classifies fair value balances based on the observability of those inputs. The three levels of the fair value hierarchy are as follows:

Level 1—Quoted prices in active markets for identical assets or liabilities that Basic has the ability to access. Active markets are those in which transactions for the asset or liability occur in sufficient frequency and volume to provide pricing information on an ongoing basis.

Level 2—Inputs are other than quoted prices in active markets included in Level 1, which are either directly or indirectly observable. These inputs are either directly observable in the marketplace or indirectly observable through corroboration with market data for substantially the full contractual term of the asset or liability being measured.

Level 3—Inputs reflect management’s best estimate of what market participants would use in pricing the asset or liability at the measurement date. Consideration is given to the risk inherent in the valuation technique and the risk inherent in the inputs to the model.

In valuing certain assets and liabilities, the inputs used to measure fair value may fall into different levels of the fair value hierarchy. For disclosure purposes, assets and liabilities are classified in their entirety in the fair value hierarchy level based on the lowest level of input that is significant to the overall fair value measurement. Basic’s assessment of the significance of a particular input to the fair value measurement requires judgment and may affect the placement within the fair value hierarchy levels.

Basic does not have any assets or liabilities that are remeasured at fair value on a recurring basis.

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

Management’s Overview

We provide a wide range of well site services to oil and natural gas drilling and producing companies, including completion and remedial services, fluid services and well site construction services, well servicing 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 our acquisition strategy, we purchased businesses and assets in six separate acquisitions from January 1, 2012 to March 31, 2013. Our total hydraulic horsepower increased from 271,000 at December 31, 2011 to 292,000 at March 31, 2013. Our weighted average number of fluid service trucks increased from 900 in the first quarter of 2012 to 964 in the first quarter of 2013. Our weighted average number of well servicing rigs increased from 423 in the first quarter of 2012 to 425 in the first quarter of 2013. These acquisitions, as well as market fluctuations, make our 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):


	Three Months Ended March 31,
	2013				2012
Revenues:
Completion and remedial services	$	118.4	39	%	$	164.4	40	%
Fluid services	$	84.3	28	%	$	95.3	29	%
Well servicing	$	87.7	29	%	$	95.9	28	%
Contract drilling	$	14.0	4	%	$	15.3	3	%

Total revenues	$	304.4	100	%	$	370.9	100	%

Our core businesses depend on our customers’ willingness to make expenditures to produce, develop and explore for oil and natural gas in the United States. Industry conditions are influenced by numerous factors, such as the supply of and demand for oil and natural gas, domestic and worldwide economic conditions, political instability in oil producing countries and merger and divestiture activity among oil and natural gas producers. The volatility of the oil and natural gas industry, and the consequent impact on exploration and production activity, has adversely impacted, and could continue to 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.

During 2010, oil prices remained relatively stable following the increase in prices experienced during 2009. Oil prices increased during the first half of 2011 primarily due to political and economic instability in several oil producing countries and remained relatively stable during the last months of 2011 and throughout 2012 and the first quarter of 2013. This trend in oil prices has caused utilization and pricing for our services to stabilize in our oil-based operating areas, while utilization and pricing for our services in our natural gas-based operating areas remained depressed throughout the first quarter of 2013 due to low natural gas prices. Our outlook for 2013 continues to be based on the assumption that upstream spending and oilfield activity will be similar to the levels in 2012. We expect to see activity increase through the summer and into the fall with the second half of 2013 substantially busier than the first half.

We will continue to evaluate opportunities to expand our business through selective acquisitions and internal growth initiatives. Our capital investment decisions are determined by an analysis of the projected return on capital employed of 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 natural 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.

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

•

Completion and Remedial Services — segment profits as a percent of revenues;

•

Fluid Services — trucking hours, revenue per truck, segment profits per truck and segment profits as a percent of revenues;

•

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

•

Contract Drilling — rig operating days, revenue per drilling day, profits 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 “Segment Overview” below.

Selected Acquisitions

During 2012, we made four acquisitions that complemented our existing business segments. These included, among others:

Surface Stac, Inc.

On May 15, 2012, we acquired substantially all of the assets of Surface Stac, Inc for total consideration of $23.2 million in cash. This acquisition has been included in our completion and remedial servicing segment.

Salt Water Disposal of North Dakota LLC

On December 19, 2012, we acquired substantially all of the assets of Salt Water Disposal of North Dakota LLC for total consideration of $43.2 million in cash. This acquisition has been included in our fluid services segment.

During the first three months of 2013, we made two acquisitions that complemented our existing business segments including:

Atlas Environmental Consulting, Inc. and Atlas Oilfield Construction Company, LLC

On February 16, 2013, we acquired all of the assets of Atlas Environmental Consulting, Inc. and Atlas Oilfield Construction Company, LLC, for total cash consideration of $13.2 million. This acquisition operates in our fluid services segment.

Petroleum Water Solutions, LLC

On February 22, 2013, we acquired all of the assets of Petroleum Water Solutions, LLC for total cash consideration of $3.3 million. This acquisition operates in our fluid services segment.

Segment Overview

Completion and Remedial Services

During the first three months of 2013, our completion and remedial services segment represented approximately 39% of our revenues. Revenues from our completion and remedial services segment are generally derived from a variety of services designed to complete and stimulate new oil and natural gas production or place cement slurry within the wellbores. Our completion and remedial services segment includes pumping services, rental and fishing tool operations, coiled tubing services, nitrogen services, cased-hole wireline services, snubbing, water treatment and underbalanced drilling.

Our pumping services concentrate on providing single truck, lower-horsepower cementing, acidizing and fracturing services in selected markets. Our total hydraulic horsepower capacity for our pressure pumping operations was 292,000 and 276,000 at March 31, 2013 and March 31, 2012, 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 in 2012, the full year ended December 31, 2012 and the quarter ended March 31, 2013 (dollars in thousands):


	Revenues		Segment Profits %
2012:
First Quarter	$	164,420		41	%
Second Quarter	$	156,560		41	%
Third Quarter	$	143,348		39	%


	Revenues		Segment Profits %
Fourth Quarter	$	121,742		34	%
Full Year	$	586,070		39	%
2013:
First Quarter	$	118,361		33	%

We gauge the performance of our completion and remedial services segment based on the segment’s operating revenues and segment profits as a percent of revenues.

The decrease in completion and remedial services revenue to $118.4 million in the first quarter of 2013 from $121.7 million in the fourth quarter of 2012 resulted primarily from decreased revenue from our pumping equipment, due to relatively low drilling rig count and significant weather issues during the first quarter. The decrease in segment profits as a percentage of revenue from 34% in the fourth quarter of 2012 to 33% in the first quarter of 2013 was primarily due to lower utilization.

Fluid Services

During the first three months of 2013, our fluid services segment represented approximately 28% of our revenues. Revenues in our fluid services segment are earned from the sale, transportation, treatment, storage and disposal of fluids used in the drilling, production and maintenance of oil and natural gas wells. Revenues also include 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 natural 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. 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. 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 natural gas facilities. 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 in 2012, the full year ended December 31, 2012 and the quarter ended March 31, 2013 (dollars in thousands):


	Weighted Average Number of Fluid Service Trucks		Trucking Hours		Revenue Per Fluid Service Truck		Segment Profits Per Fluid Service Truck		Segment Profits %
2012:
First Quarter		900		580,700	$	106	$	36		34	%
Second Quarter		918		552,400	$	99	$	35		36	%
Third Quarter		931		551,600	$	91	$	29		32	%
Fourth Quarter		954		555,200	$	86	$	25		29	%
Full Year		926		2,239,900	$	380	$	125		33	%
2013:
First Quarter		963		555,600	$	88	$	27		31	%

We gauge activity levels in our fluid services segment based on trucking hours, revenue and segment profits per fluid service truck, and segment profits as a percent of revenues.

Revenue per fluid service truck increased to $88,000 in the first quarter of 2013 compared to the fourth quarter of 2012, primarily due to increases in disposal revenue associated with a full quarter impact of the Salt Water Disposal of North Dakota acquisition. Segment profit percentage increased to 31% for the first quarter of 2013 compared to 29% for the fourth quarter of 2012, primarily due to the holiday impact of the fourth quarter, along with lower repair and maintenance costs.

Well Servicing

During the first three months of 2013, our well servicing segment represented approximately 29% of our revenues. Revenue in our well servicing segment is derived from maintenance, workover, completion, manufacturing and plugging and abandonment services. We provide maintenance-related services as part of the normal, periodic upkeep of producing oil and natural 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 also have a rig manufacturing and servicing facility that builds new workover rigs, performs large-scale refurbishments of used workover rigs and provides maintenance services on previously manufactured rigs.

We typically charge our well servicing rig 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 the activity levels of our well servicing rigs on a weekly basis by calculating a rig utilization rate based on a 55-hour work week per rig. Our fleet increased from a weighted average number of 423 rigs in the first quarter of 2012 to 425 in the first quarter of 2013.

The following is an analysis of our well servicing operations for each of the quarters in 2012, the full year ended December 31, 2012 and the quarter ended March 31, 2013:


	Weighted Average Number of Rigs		Rig Hours		Rig Utilization Rate			Revenue Per Rig Hour		Profits Per Rig Hour		Segment Profits %
2012:
First Quarter		423		231,300		76.5	%	$	393	$	117		30	%
Second Quarter		431		232,500		75.4	%	$	399	$	111		27	%
Third Quarter		431		226,400		73.5	%	$	402	$	124		30	%
Fourth Quarter		429		203,000		66.2	%	$	393	$	108		28	%
Full Year		429		893,200		72.9	%	$	397	$	115		29	%
2013:
First Quarter		425		210,800		69.4	%	$	399	$	108		26	%

We gauge activity levels in our well servicing segment based on rig hours, rig utilization rate, revenue per rig hour, segment profits per rig hour and segment profits as a percent of revenues. Revenue per rig hour and profits per rig hour in the table above do not include revenues and profits from the rig manufacturing and maintenance division of this business segment.

Rig utilization increased to 69% in the first quarter of 2013 compared to 66% in the fourth quarter of 2012. Higher utilization resulted from increased rig hours due to the absence of the holiday impact in the first quarter of 2013. Our segment profit percentage decreased to 26% during the first quarter of 2013 from 28% during the fourth quarter of 2012 due to the reset of unemployment taxes at the beginning of the year.

Contract Drilling

During the first three months of 2013, our contract drilling segment represented approximately 4% of our revenues. Revenues from our contract drilling segment are derived primarily from the drilling of new wells.

Within this segment, we typically charge our drilling rig customers at a “daywork” daily rate, or “footage” at an established rate per number of feet drilled. We measure the activity level of our drilling rigs on a weekly basis by calculating a rig utilization rate based on a seven-day work week per rig. Our contract drilling rig fleet had a weighted average of twelve rigs during the first quarter of 2012 and 2013.

The following is an analysis of our contract drilling segment for each of the quarters in 2012, the full year ended December 31, 2012 and the quarter ended March 31, 2013:


	Weighted Average Number of Rigs		Rig Operating Days		Revenue Per Drilling Day		Profits Per Drilling Day		Segment Profits %
2012:
First Quarter		12		967	$	15,800	$	5,200		33	%
Second Quarter		12		1,007	$	15,500	$	5,800		37	%
Third Quarter		12		957	$	15,800	$	5,300		34	%
Fourth Quarter		12		892	$	16,000	$	5,100		32	%
Full Year		12		3,823	$	15,800	$	5,300		34	%
2013:
First Quarter		12		850	$	16,500	$	5,700		35	%

We gauge activity levels in our drilling operations based on rig operating days, revenue per drilling day, profits per drilling day and segment profits as a percent of revenues.

The increase in revenue per day to $16,500 in the first quarter of 2013 from $16,000 in the fourth quarter of 2012 was due primarily to higher utilization from our greater depth, higher rate rigs. Segment profit percentage increased to 35% in the first quarter of 2013 from 32% in the fourth quarter of 2012 due to higher day rates and lower repairs and maintenance expense.

Operating Cost Overview

Our operating costs are comprised primarily of labor, including workers’ compensation and health insurance, repair and maintenance, fuel and insurance. The majority of our employees are paid on an hourly basis. We also incur costs to employ personnel to sell and supervise our services and perform maintenance on our fleet. These costs are not directly tied to our level of business activity. Compensation for our administrative personnel in local operating yards and in our corporate office is accounted for as general and administrative expenses. Repair and maintenance is performed by our crews, company maintenance personnel and outside service providers. Insurance is generally a fixed cost regardless of utilization and relates to the number of rigs, trucks and other equipment in our fleet, employee payroll and safety record.

Critical Accounting Policies and Estimates

Our unaudited consolidated financial statements are impacted by the accounting policies used and the estimates and assumptions made by management during their preparation. A complete summary of our critical accounting policies is included in Note 2 of the notes to our historical audited consolidated financial statements in our most recent annual report on Form 10-K. The following is a discussion of our critical accounting policies and estimates.

Critical Accounting Policies

We have identified below certain accounting policies that are of particular importance in the presentation of our financial position, results of operations and cash flows and that require the application of significant judgment by management.

Property and Equipment. Property and equipment are stated at cost or at estimated fair value at acquisition date if acquired in a business combination. Expenditures for repairs and maintenance are charged to expenses as incurred. We also review the capitalization of refurbishment of workover rigs as described in Note 2 of the notes to our unaudited consolidated financial statements.

Impairments. We review our assets for impairment at least annually, or whenever, in management’s judgment, events or changes in circumstances indicate that the carrying amount of a long-lived asset may not be recovered over its remaining service life. Provisions for asset impairment are charged to income when the sum of the estimated future cash flows, on an undiscounted basis, is less than the asset’s carrying amount. When impairment is indicated, an impairment charge is recorded based on an estimate of future cash flows on a discounted basis.

Self-Insured Risk Accruals. We are self-insured up to retention limits with regard to workers’ compensation, general liability claims, and medical and dental coverage of our employees. We generally maintain no physical property damage coverage on our workover rig fleet, with the exception of certain of our 24-hour workover rigs and newly

manufactured rigs. We have deductibles per occurrence for workers’ compensation, general liability claims, and medical and dental coverage of $1.0 million, $1.0 million and $300,000, respectively. We have lower deductibles per occurrence for automobile liability. We maintain accruals in our consolidated balance sheets related to self-insurance retentions based upon third-party actuarial data and claims history.

Revenue Recognition. We recognize revenues when the services are performed, collection of the relevant receivables is probable, persuasive evidence of the arrangement exists and the price is fixed and determinable.

Income Taxes. We recognize deferred tax assets and liabilities 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.

Critical Accounting Estimates

The preparation of our consolidated financial statements in conformity with accounting principles generally accepted in the United States of America (GAAP) requires management to make certain estimates and assumptions. These estimates and assumptions affect the reported amounts of assets and liabilities, the disclosure of contingent assets and liabilities at the balance sheet date and the amounts of revenues and expenses recognized during the reporting period. We analyze our estimates based on historical experience and various other assumptions that we believe to be reasonable under the circumstances. However, actual results could differ from such estimates. The following is a discussion of our critical accounting estimates.

Depreciation and Amortization. In order to depreciate and amortize our property and equipment and our intangible assets with finite lives, we estimate the useful lives and salvage values of these items. Our estimates may be affected by such factors as changing market conditions, technological advances in the industry or changes in regulations governing the industry.

Impairment of Property and Equipment. Our analysis for potential impairment of property and equipment requires us to estimate undiscounted future cash flows. Actual impairment charges are recorded using an estimate of discounted future cash flows. The determination of future cash flows requires us to estimate rates and utilization in future periods and such estimates can change based on market conditions, technological advances in the industry or changes in regulations governing the industry.

Impairment of Goodwill. Our goodwill is considered to have an indefinite useful economic life and is not amortized. We assess impairment of our goodwill annually as of December 31 or on an interim basis if events or circumstances indicate that the fair value of the asset has decreased below its carrying value. A qualitative assessment of whether it is more likely than not that the fair value of the reporting unit is less than its carrying value is allowed but not required. If it is more likely than not that the fair value of the reporting unit is less than its carrying amount, then the two-step impairment test is performed. In the two-step test, 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.

Allowance for Doubtful Accounts. We estimate our allowance for doubtful accounts based on an analysis of historical collection activity and specific identification of overdue accounts. Factors that may affect this estimate include (1) changes in the financial positions of our significant customers and (2) a decline in commodity prices that could affect our entire customer base.

Litigation and Self-Insured Risk Reserves. We estimate our reserves related to litigation and self-insured risk based on the facts and circumstances specific to the litigation and self-insured risk claims and our past experience with similar claims. The actual outcome of litigation and self-insured claims could differ significantly from estimated amounts. As discussed in “Self-Insured Risk Accruals” above with respect to our critical accounting policies, we maintain accruals on our balance sheet to cover self-insured retentions. These accruals are based on certain assumptions developed based upon third-party actuarial data and historical data to project future losses. Loss estimates in the calculation of these accruals are adjusted based upon actual claim settlements and reported claims.

Fair Value of Assets Acquired and Liabilities Assumed. We estimate the fair value of assets acquired and liabilities assumed in business combinations, which involves the use of various assumptions. These estimates may be affected by such factors as changing market conditions, technological advances in the industry or changes in regulations governing the industry. The most significant assumptions, and the ones requiring the most judgment, involve the estimated fair value of property and equipment, intangible assets and the resulting amount of goodwill, if any. We test annually for impairment of the goodwill and intangible assets with indefinite useful lives recorded in business combinations. This requires us to estimate the fair values of our own assets and liabilities at the reporting unit level. Therefore, considerable judgment, similar to that described above in connection with our estimation of the fair value of an acquired company, is required to assess goodwill and certain intangible assets for impairment.

Cash Flow Estimates. Our estimates of future cash flows are based on the most recent available market and operating data for the applicable asset or reporting unit at the time the estimate is made. Our cash flow estimates are used for asset impairment analyses.

Stock-Based Compensation. We have historically compensated our directors, executives and employees through the awarding of stock options and restricted stock. We accounted for restricted stock awards issued in 2012 and 2013 using a grant date fair-value based method, resulting in compensation expense for stock-based awards being recorded in our consolidated statements of income. For performance based restricted stock awards, compensation expense is recognized in our financial statements based on their grant date fair value. We utilize (i) the closing stock price on the date of the grant to determine the fair value of vesting restricted stock awards and (ii) a Monte Carlo simulation to determine the fair value of restricted stock awards with a combination of market and service vesting criteria. The Monte Carlo simulation model utilizes multiple input variables that determine the probability of satisfying the market condition stipulated in the award grant and calculates the fair value of the award. The expected volatility utilized in the model was estimated using our historical volatility and the historical volatilities of our peer companies. The risk free interest rate was based on the U.S. treasury rate for a term commensurate with the expected life of the grant. Stock options have not been issued since 2007 but are valued on the grant date using Black-Scholes-Merton option pricing model, and restricted stock issued is valued based on the fair value of our common stock at the grant date. In addition, judgment is required in estimating the amount of stock-based awards that are expected to be forfeited. Because the determination of these various assumptions is subject to significant management judgment and different assumptions could result in material differences in amounts recorded in our consolidated financial statements, management believes that accounting estimates related to the valuation of stock-based awards are critical.

Income Taxes. The amount and availability of our loss carryforwards (and certain other tax attributes) are subject to a variety of interpretations and restrictive tests. The utilization of such carryforwards could be limited or lost upon certain changes in ownership and the passage of time. Accordingly, although we believe substantial loss carryforwards are available to us, no assurance can be given concerning the realization of such loss carryforwards, or whether or not such loss carryforwards will be available in the future.

Asset Retirement Obligations. We record the fair value of an asset retirement obligation as a liability in the period in which we incur 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 settlement of obligations.

Results of Operations

The following is a comparison of our results of operations for the three months ended March 31, 2013 compared to the three months ended March 31, 2012. For additional segment-related information and trends, please read “Segment Overview” above.

Three Months Ended March 31, 2013 Compared to Three Months Ended March 31, 2012

Revenues. Revenues decreased by 18% to $304.4 million during the first quarter of 2013 from $370.9 million during the same period in 2012. This decrease was primarily due to decreased demand by our customers for our services and increased competition, which affected the rates we can charge for our services.

Completion and remedial services revenues decreased by 28% to $118.4 million during the first quarter of 2013 compared to $164.4 million in the same period in 2012. The decrease in revenue between these periods was primarily due to lower completion revenues driven by a general decline in new well completions and lower pricing for our services. Total hydraulic horsepower increased to 292,000 at March 31, 2013 from 276,000 at March 31, 2012 due to two additional frac units acquired in the first quarter of 2012.

Fluid services revenues decreased by 12% to $84.3 million during the first quarter of 2013 compared to $95.3 million in the same period in 2012. Our revenue per fluid service truck decreased 19% to $88,000 in the first quarter of 2013 compared to $106,000 in the same period in 2012 due to increased competition in our geographic footprint, which caused pressure on the rates charged for our services. Our weighted average number of fluid service trucks increased 1% to 964 during the first quarter of 2013 from 954 in the same period in 2012.

Well servicing revenues decreased by 9% to $87.7 million during the first quarter of 2013 compared to $95.9 million during the same period in 2012. The lower revenues were due to the 9% decrease in rig hours to 210,800 during the first quarter of 2013 from 231,300 during the first quarter of 2012, which was driven by a general decline in production spending through the first quarter of 2013. This segment experienced an increase in revenue per rig hour to $399 during the first quarter of 2013 from $393 during the first quarter of 2012 due to a higher ratio of barge and plugging revenues, which are performed at a higher rate. Our average number of well servicing rigs increased to 425 during the first quarter of 2013 compared to 423 in the same period in 2012.

Contract drilling revenues decreased by 8% to $14.0 million during the first quarter of 2013 compared to $15.3 million in the same period in 2012. The number of rig operating days decreased 12% to 850 in the first quarter of 2013 compared to 967 in the first quarter of 2012. The decrease in revenue and rig operating days was due to a decrease in new well starts in the Permian Basin, where all of our drilling rigs operate.

Direct Operating Expenses. Direct operating expenses, which primarily consist of labor, including workers’ compensation and health insurance, repair and maintenance, fuel and insurance, decreased by 11% to $211.0 million during the first quarter of 2013 from $237.3 million in the same period in 2012. This decrease was primarily due to decreased activity in each of our four business segments.

Direct operating expenses for the completion and remedial services segment decreased by 19% to $79.0 million during the first quarter of 2013 compared to $97.0 million for the same period in 2012 due primarily to decreased activity levels overall, especially in our pumping services line. Segment profits decreased to 33% of revenues during the first quarter of 2013 compared to 41% for the same period in 2012, due to higher material costs and reduced activity.

Direct operating expenses for the fluid services segment decreased by 8% to $57.9 million during the first quarter of 2013 compared to $62.8 million for the same period in 2012, mainly due to decreased activity levels. Segment profits were 31% of revenues during the first quarter of 2013 compared to 34% for the same period in 2012 due to reduced activity.

Direct operating expenses for the well servicing segment decreased by 3% to $65.0 million during the first quarter of 2013 compared to $67.3 million for the same period in 2012. The decrease in direct operating expenses was due to decreased level of activity. Segment profits decreased to 26% of revenues during the first quarter of 2013 compared to 30% for the same period in 2012 due to reduced activity.

Direct operating expenses for the contract drilling segment decreased by 11% to $9.1 million during the first quarter of 2013 from $10.2 million for the same period in 2012. Segment profits for this segment increased to 35% of revenues during the first quarter of 2013 compared to 33% for the same period in 2012, primarily due to lower personnel costs.

General and Administrative Expenses. General and administrative expenses increased by 1% to $42.0 million during the first quarter of 2013 from $41.4 million for the same period in 2012, due mainly to increased personnel costs, including incentive compensation, and increased costs from acquisitions completed during 2012. General and administrative expenses included $2.8 million and $2.2 million of stock-based compensation expense during the first quarter of 2013 and 2012, respectively.

Depreciation and Amortization Expenses. Depreciation and amortization expenses were $49.8 million during the first quarter of 2013 compared to $44.0 million for the same period in 2012. The increase in depreciation expense was due to the increased capital expenditures for property and equipment over the past year through internal growth and through the six acquisitions completed since March 31, 2012.

Interest Expense. Interest expense increased to $16.8 million during the first quarter of 2013 compared to $15.2 million during the first quarter of 2012. The increased expense was due to the issuance of an aggregate of $300.0 million of 7.75% senior notes in 2012.

Income Tax Expense. There was income tax benefit of $7.4 million during the first quarter of 2013 compared to an income tax expense of $11.8 million for the same period in 2012. Our effective tax rate during the first quarter of 2013 and 2012 was approximately 46% and 38%, respectively. The increase in our effective tax rate was primarily due to an increased impact of the Texas gross margin tax.

Liquidity and Capital Resources

As of March 31, 2013, our primary capital resources were net cash flows from our operations, utilization of capital leases and our $225.0 million revolving credit facility. As of March 31, 2013, we had unrestricted cash and cash equivalents of $81.5 million compared to $134.6 million as of December 31, 2012. The decrease in cash balances from December 31, 2012 to March 31, 2013 is primarily due to the capital expenditures and two cash acquisitions completed during the first quarter. When appropriate, we will consider public or private debt and equity offerings and non-recourse transactions to meet our liquidity needs.

Net Cash Provided by Operating Activities

Cash provided by operating activities was $21.7 million for the three months ended March 31, 2013 compared to cash provided by operating activities of $65.2 million during the same period in 2012. Operating cash flow in the first three months of 2012 was higher mainly due to the increase in profitability resulting from higher revenues offset by the increase in accounts receivable.

Capital Expenditures

Capital expenditures are the main component of our investing activities. Cash capital expenditures (including acquisitions) during the first three months of 2013 were $39.9 million compared to $65.4 million in the same period of 2012. We added $14.6 million of additional assets through our capital lease program during the first three months of 2013 compared to $8.3 million of additional assets in the same period in 2012.

In 2013, we currently have planned capital expenditures of approximately $145.0 million and capital leases of $40.0 million. We do not budget acquisitions in the normal course of business, and we regularly engage in discussions related to potential acquisitions related to the well services industry.

Capital Resources and Financing

We currently believe that our operating cash flows, available funds from our revolving credit facility, and cash on hand will be sufficient to fund our near term liquidity requirements.

Our ability to access additional sources of financing will be dependent on our operating cash flows and demand for our services, which could be negatively impacted due to the extreme volatility of commodity prices and declines in capital and debt markets.

7.75% Senior Notes due 2019

The 2019 Notes Indenture contains covenants that, among other things, limit our ability and the ability of certain of our subsidiaries to:

•

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 our restricted subsidiaries to us; and

•

sell assets or consolidate or merge with or into other companies.

These and other covenants that are contained in the 2019 Notes Indenture are subject to important exceptions and qualifications set forth in the 2019 Notes Indenture. At March 31, 2013 and December 31, 2012, we were in compliance with the restrictive covenants under the 2019 Notes Indenture.

•

at least 65% of the aggregate principal amount of the 2019 Notes issued under the 2019 Notes Indenture remains outstanding immediately after the occurrence of such redemption; and

•

such redemption occurs within 90 days of the date of the closing of any such qualified equity offering.

7.75% Senior Notes due 2022

The 2022 Notes Indenture contains covenants that, among other things, limit our ability and the ability of certain of our subsidiaries to:

•

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 our restricted subsidiaries to us; and

•

sell assets or consolidate or merge with or into other companies.

These and other covenants that are contained in the 2022 Notes Indenture are subject to important exceptions and qualifications. At March 31, 2013 and December 31, 2012, we were in compliance with the restrictive covenants under the 2022 Notes Indenture.

•

at least 65% of the aggregate principal amount of the 2022 Notes issued under the 2022 Notes Indenture remains outstanding immediately after the occurrence of such redemption; and

•

such redemption occurs within 90 days of the date of the closing of any such qualified equity offering.

Revolving Credit Facility

The Credit Agreement contains various covenants that, subject to agreed upon exceptions, limit our ability and the ability of certain of our subsidiaries to:

•

incur indebtedness;

•

grant liens;

•

enter into sale and leaseback transactions;

•

make loans, capital expenditures, acquisitions and investments;

•

change the nature of business;

•

acquire or sell assets or consolidate or merge with or into other companies;

•

declare or pay dividends;

•

enter into transactions with affiliates;

•

enter into burdensome agreements;

•

prepay, redeem or modify or terminate other indebtedness;

•

change accounting policies and reporting practices; and

•

amend organizational documents.

The Credit Agreement also contains covenants that, among other things, limit the amount of capital contributions we may make and require us to maintain specified ratios or conditions as follows:

•

a minimum consolidated interest coverage ratio of not less than 2.50 to 1.00;

•

a maximum consolidated leverage ratio not to exceed 4.00 to 1.00; and

•

a maximum consolidated senior secured leverage ratio of 2.00 to 1.00.

Other Debt

We have a variety of other capital leases and notes payable outstanding that is generally customary in our business. None of these debt instruments is material individually. Our capital leases with Banc of America Leasing & Capital, LLC requires us to maintain a minimum debt service coverage ratio of 1.05 to 1.00. At March 31, 2013, we were in compliance with our covenants under the agreement with Banc of America Leasing & Capital, LLC. As of March 31, 2013, we had total capital leases of approximately $14.6 million.

Preferred Stock

At March 31, 2013 and December 31, 2012, we had 5,000,000 shares of $.01 par value preferred stock authorized, of which none was designated, issued or outstanding.

Other Matters

Off-Balance Sheet Arrangements

We have no off-balance sheet arrangements that have or are reasonably likely to have a current or future effect on our financial condition, changes in financial condition, revenues or expenses, results of operations, liquidity, capital expenditures or capital resources that is material to investors.

Net Operating Losses

As of March 31, 2013, we had approximately $49.1 million of net operating loss carryforwards.

Recent Accounting Pronouncements

In December 2011, the FASB issued ASU No. 2011-11, “Balance Sheet” (“ASU 2011-11”). The standard amends and expands disclosure requirements about balance sheet offsetting and related arrangements. ASU 2011-11 became effective for Basic on January 1, 2013. The adoption of this standard did not have a material impact to its results of operations, financial position or liquidity as a result of this guidance.

In July 2012, the FASB issued ASU No. 2012-02, “Intangibles — Goodwill and Other: Testing Indefinite-Lived Intangible Assets for Impairment” (“ASU 2012-02”). ASU 2012-02 allows a qualitative assessment of whether it is more likely than not that the indefinite-lived intangible asset’s fair value is less than its carrying amount before applying the quantitative impairment test. If it is more likely than not that the fair value of an indefinite-lived intangible asset is less than its carrying amount, then the impairment test for that indefinite-lived intangible asset would be performed. ASU 2012-02 is effective for annual and interim impairment tests performed for indefinite-lived intangible assets for fiscal years beginning after September 15, 2012 and early adoption is permitted. Basic adopted this accounting standard update early, and although it has changed the process Basic uses to determine if indefinite-lived intangible assets are impaired, it has not had a material impact on Basic’s consolidated financial statements.

Impact of Inflation on Operations

Management is of the opinion that inflation has not had a significant impact on our business.

ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

As of March 31, 2013, we had no material changes to the disclosure on this matter made in our Annual Report on Form 10-K for the year ended December 31, 2012.

ITEM 4. CONTROLS AND PROCEDURES

Disclosure Controls and Procedures

Based on their evaluation as of the end of the period covered by this report, our principal executive officer and principal financial officer have concluded that our disclosure controls and procedures (as defined in Rules 13a-15(e) and 15d-15(e) under the Exchange Act) are effective to ensure that information required to be disclosed in reports that we file or submit under the Exchange Act is recorded, processed, summarized and reported within the time periods specified in the SEC’s rules and forms and effective to ensure that information required to be disclosed in such reports is accumulated and communicated to our management, including our principal executive officer and principal financial officer, to allow timely decisions regarding required disclosure.

Changes in Internal Control Over Financial Reporting

During the most recent fiscal quarter, there have been no changes in our internal control over financial reporting 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

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. The information regarding litigation and environmental matters described in note 6 of the notes to our unaudited consolidated financial statements included in this Quarterly Report on Form 10-Q is incorporated herein by reference.

ITEM 1A. RISK FACTORS

For information regarding risks that may affect our business, see the risk factors included in our most recent annual report on Form 10-K under the heading “Risk Factors.”

ITEM 2. UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS

Purchase of Equity Securities by the Issuer and Affiliated Purchasers

The following table summarizes stock repurchase activity for the three months ended March 31, 2013:


	Issuer Purchases of Equity Securities
Period	Total Number of Shares Purchased (1)		Average Price Paid per Share		Total Number of Shares Purchased as Part of Publicly Announced Program(2)		Approximate Dollar Value of Shares that May Yet be Purchased Under the Program
January 1 — January 31		3,302	$	12.05		—	$	—
February 1 — February 28		—	$	—		—	$	—
March 1 — March 31		248,217	$	13.94		—	$	—
Total		251,519	$	13.92		—	$	—

(1)

On May 24, 2012, we announced that our Board of Directors had reauthorized the repurchase of up to approximately $35.2 million of shares of our common stock from time to time in open market or private transactions, at our discretion, as a continuation of our prior $50.0 million stock repurchase program announced in 2008 (of which $14.8 million was purchased prior to such reauthorization). The stock repurchase program may be suspended or discontinued at any time.

(2)

These shares were repurchased from various employees to provide such employees the cash amounts necessary to pay certain tax liabilities associated with the vesting of restricted shares owned by them. The shares were repurchased on various dates based on the closing price per share on the date of repurchase.

ITEM 6. EXHIBITS


Exhibit No.		Description

3.1*		Amended and Restated Certificate of Incorporation of the Company, dated September 22, 2005. (Incorporated by reference to Exhibit 3.1 of the Company’s Registration Statement on Form S-1 (SEC File No. 333-127517), filed on September 28, 2005)

3.2*		Amended and Restated Bylaws of the Company, effective as of March 9, 2010. (Incorporated by reference to Exhibit 3.1 of the Company’s Current Report on Form 8-K (SEC File No. 001-32693), filed on March 15, 2010)

4.1*		Specimen Stock Certificate representing common stock of the Company. (Incorporated by reference to Exhibit 4.1 of the Company’s Registration Statement on Form S-1 (SEC File No. 333-127517), filed on November 4, 2005)

4.2*		Indenture dated as of February 15, 2011, among Basic Energy Services, Inc. as Issuer, the Subsidiary Guarantors named therein and Wells Fargo Bank, N.A., as trustee. (Incorporated by reference to Exhibit 4.2 of the Company’s Current Report on Form 8-K (SEC File No. 001-32693), filed on February 18, 2011)

4.3*		Form of 7.75% Senior Note due 2019. (Included as Exhibit A to Exhibit 4.2 of the Company’s Current Report on Form 8-K (SEC File No. 001-32693), filed on February 18, 2011)

4.4*		First Supplemental Indenture dated as of August 5, 2011 to Indenture dated as of February 15, 2011 among Basic Energy Services, Inc. as Issuer, the Subsidiary Guarantors named therein and Wells Fargo Bank, N.A., as trustee. (Incorporated by reference to Exhibit 10.2 of the Company’s Current Report on Form 8-K (SEC File No. 001-32693), filed on August 10, 2011)

4.5*		Indenture dated as of October 16, 2012, among Basic Energy Services, Inc. as Issuer, the Guarantors named therein and Wells Fargo Bank, National Association, as trustee. (Incorporated by reference to Exhibit 4.1 of the Company’s Current Report on Form 8-K/A (SEC File No. 001-32693), filed on October 26, 2012)

4.6*		Form of 7.75% Senior Note due 2022. (Included as Exhibit A to Exhibit 4.1 of the Company’s Current Report on Form 8-K/A (SEC File No. 001-32693), filed on October 26, 2012)

10.1*		Form of Performance-Based Award Agreement (Executive and Senior Management) (effective March 2013). (Incorporated by reference to Exhibit 10.1 of the Company’s Current Report on Form 8-K (SEC File No. 001-32693), filed on March 18, 2013)

10.2*		Fifth Amended and Restated Basic Energy Services, Inc. 2003 Incentive Plan. (Incorporated by reference to Exhibit 10.2 of the Company’s Current Report on Form 8-K (SEC File No. 001-32693), filed on March 18, 2013)

31.1#		Certification by Chief Executive Officer required by Rule 13a-14(a) and 15d-14(a) under the Exchange Act

31.2#		Certification by Chief Financial Officer required by Rule 13a-14(a) and 15d-14(a) under the Exchange Act

32.1#		Certification of Chief Executive Officer pursuant to 18 U.S.C Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002

32.2#		Certification of Chief Financial Officer pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002

101.CAL#		XBRL Calculation Linkbase Document

101.DEF#		XBRL Definition Linkbase Document

101.INS#		XBRL Instance Document

101.LAB#		XBRL Labels Linkbase Document

101.PRE#		XBRL Presentation Linkbase Document

101.SCH#		XBRL Schema Document

*	Incorporated by reference

#	Filed with 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.


BASIC ENERGY SERVICES, INC.

By:	/s/ Kenneth V. Huseman

	Name:	Kenneth V. Huseman
	Title:	President, Chief Executive Officer and Director (Principal Executive Officer)

By:	/s/ Alan Krenek

	Name:	Alan Krenek
	Title:	Senior Vice President, Chief Financial Officer, Treasurer and Secretary (Principal Financial Officer)

By:	/s/ John Cody Bissett

	Name:	John Cody Bissett
	Title:	Vice President, Controller and Chief Accounting Officer (Principal Accounting Officer)

Date: April 26, 2013

Exhibit Index


Exhibit No.		Description

3.1*		Amended and Restated Certificate of Incorporation of the Company, dated September 22, 2005. (Incorporated by reference to Exhibit 3.1 of the Company’s Registration Statement on Form S-1 (SEC File No. 333-127517), filed on September 28, 2005)

3.2*		Amended and Restated Bylaws of the Company, effective as of March 9, 2010. (Incorporated by reference to Exhibit 3.1 of the Company’s Current Report on Form 8-K (SEC File No. 001-32693), filed on March 15, 2010)

4.1*		Specimen Stock Certificate representing common stock of the Company. (Incorporated by reference to Exhibit 4.1 of the Company’s Registration Statement on Form S-1 (SEC File No. 333-127517), filed on November 4, 2005)

4.2*		Indenture dated as of February 15, 2011, among Basic Energy Services, Inc. as Issuer, the Subsidiary Guarantors named therein and Wells Fargo Bank, N.A., as trustee. (Incorporated by reference to Exhibit 4.2 of the Company’s Current Report on Form 8-K (SEC File No. 001-32693), filed on February 18, 2011)

4.3*		Form of 7.75% Senior Note due 2019. (Included as Exhibit A to Exhibit 4.2 of the Company’s Current Report on Form 8-K (SEC File No. 001-32693), filed on February 18, 2011)

4.4*		First Supplemental Indenture dated as of August 5, 2011 to Indenture dated as of February 15, 2011 among Basic Energy Services, Inc. as Issuer, the Subsidiary Guarantors named therein and Wells Fargo Bank, N.A., as trustee. (Incorporated by reference to Exhibit 10.2 of the Company’s Current Report on Form 8-K (SEC File No. 001-32693), filed on August 10, 2011)

4.5*		Indenture dated as of October 16, 2012, among Basic Energy Services, Inc. as Issuer, the Guarantors named therein and Wells Fargo Bank, National Association, as trustee. (Incorporated by reference to Exhibit 4.1 of the Company’s Current Report on Form 8-K/A (SEC File No. 001-32693), filed on October 26, 2012)

4.6*		Form of 7.75% Senior Note due 2022. (Included as Exhibit A to Exhibit 4.1 of the Company’s Current Report on Form 8-K/A (SEC File No. 001-32693), filed on October 26, 2012)

10.1*		Form of Performance-Based Award Agreement (Executive and Senior Management) (effective March 2013). (Incorporated by reference to Exhibit 10.1 of the Company’s Current Report on Form 8-K (SEC File No. 001-32693), filed on March 18, 2013)

10.2*		Fifth Amended and Restated Basic Energy Services, Inc. 2003 Incentive Plan. (Incorporated by reference to Exhibit 10.2 of the Company’s Current Report on Form 8-K (SEC File No. 001-32693), filed on March 18, 2013)

31.1#		Certification by Chief Executive Officer required by Rule 13a-14(a) and 15d-14(a) under the Exchange Act

31.2#		Certification by Chief Financial Officer required by Rule 13a-14(a) and 15d-14(a) under the Exchange Act

32.1#		Certification of Chief Executive Officer pursuant to 18 U.S.C Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002

32.2#		Certification of Chief Financial Officer pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002

101.CAL# XBRL Calculation Linkbase Document

101.DEF# XBRL Definition Linkbase Document

101.INS# XBRL Instance Document

101.LAB# XBRL Labels Linkbase Document

101.PRE# XBRL Presentation Linkbase Document

101.SCH# XBRL Schema Document

*	Incorporated by reference

#	Filed with this report

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