10-Q

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

Form 10-Q

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

For the quarterly period ended June 30, 2014

OR

☐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   ☒   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  ☒    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.

Large accelerated filer	☐	Accelerated filer	☒
Non-accelerated filer	☐  (Do not check if a smaller reporting company)	Smaller reporting company	☐

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

43,200,758shares of the registrant’s Common Stock were outstanding as of July28, 2014.  

BASIC ENERGY SERVICES, INC.

Index to Form 10-Q

Part I. FINANCIAL INFORMATION	4
Item 1. Financial Statements	4
Consolidated Balance Sheets as of June  30, 2014 (Unaudited) and December 31, 2013	4
Consolidated Statements of Operations and Comprehensive Income (Loss) for the threeand six months ended June 30, 2014 and 2013 (Unaudited)	5
Consolidated Statements of Stockholders’ Equity for the six months ended June 30, 2014 (Unaudited)	6
Consolidated Statements of Cash Flows for the six months ended June 30, 2014 and 2013 (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	28
Liquidity and Capital Resources	31
Other Matters	35
Item 3. Quantitative and Qualitative Disclosures About Market Risk	35
Item 4. Controls and Procedures	35
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	36
Item 6. Exhibits	37
Signatures	38

2

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.

3

PART I — FINANCIAL INFORMATION

ITEM 1. FINANCIAL STATEMENTS

Basic Energy Services, Inc.

Consolidated Balance Sheets

(in thousands, except share data)

	June 30,		December 31,
	2014		2013
	(Unaudited)
ASSETS
Current assets:
Cash and cash equivalents	$	98,994	$	111,532
Trade accounts receivable, net of allowance of $3,339 and $3,675, respectively		232,903		204,394
Accounts receivable - related parties		47		50
Income tax receivable		2,659		3,475
Inventories		40,960		34,240
Prepaid expenses		12,951		9,597
Other current assets		8,898		8,289
Deferred tax assets		29,804		31,436
Total current assets		427,216		403,013
Property and equipment, net		923,232		928,037
Deferred debt costs, net of amortization		14,602		16,145
Goodwill		112,283		110,914
Other intangible assets, net of amortization		73,024		77,555
Other assets		8,499		7,675
Total assets	$	1,558,856	$	1,543,339
LIABILITIES AND STOCKHOLDERS' EQUITY
Current liabilities:
Accounts payable	$	54,737	$	45,508
Accrued expenses		84,141		77,058
Current portion of long-term debt		40,577		41,394
Other current liabilities		924		688
Total current liabilities		180,379		164,648
Long-term debt, net of unamortized premium on notes of $1,341 and $1,459, respectively		838,803		846,691
Deferred tax liabilities		163,375		164,306
Other long-term liabilities		25,861		22,407
Commitments and contingencies
Stockholders' equity:
Preferred stock; $0.01 par value;  5,000,000 shares authorized; none designated or issued at June 30, 2014 and December 31, 2013		—		—
Common stock; $0.01 par value;  80,000,000 shares authorized; 43,500,032 shares issued and 43,201,279 shares outstanding at June 30, 2014; 43,500,032 shares issued and 42,226,088 shares outstanding at December 31, 2013		435		435
Additional paid-in capital		362,378		363,674
Retained deficit		(6,190)		(6,726)
Treasury stock, at cost, 298,753 and 1,273,944 shares at June 30, 2014 and  December 31, 2013, respectively		(6,185)		(12,096)
Total stockholders' equity		350,438		345,287
Total liabilities and stockholders' equity	$	1,558,856	$	1,543,339

See accompanying notes to unaudited consolidated financial statements.

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Basic Energy Services, Inc.

Consolidated Statements of Operations

(Unaudited)

(in thousands, except per share amounts)

	Three months ended June 30,				Six months ended June 30,
	2014		2013		2014		2013
	(Unaudited)				(Unaudited)
Revenues:
Completion and remedial services	$	164,366	$	132,216	$	301,851	$	250,577
Well servicing		89,629		93,921		182,541		181,596
Fluid services		90,314		85,601		183,149		169,931
Contract drilling		15,353		13,985		28,877		27,970
Total revenues		359,662		325,723		696,418		630,074
Expenses:
Completion and remedial services		102,617		85,847		189,097		164,854
Well servicing		64,748		67,600		134,508		132,603
Fluid services		65,055		59,296		131,837		117,171
Contract drilling		10,510		9,769		19,675		18,932
General and administrative, including stock-based compensation of $3,733 and $3,312 in three months and $7,121 and $6,129 in the six months ended June 30, 2014 and 2013, respectively		42,953		49,321		82,512		91,278
Depreciation and amortization		51,785		52,067		103,490		101,848
Loss on disposal of assets		916		790		237		1,879
Total expenses		338,584		324,690		661,356		628,565
Operating income		21,078		1,033		35,062		1,509
Other income (expense):
Interest expense		(16,566)		(16,806)		(33,425)		(33,614)
Interest income		13		13		26		30
Other income		107		173		473		335
Income (loss) before income taxes		4,632		(15,587)		2,136		(31,740)
Income tax benefit (expense)		(2,188)		2,790		(1,600)		10,166
Net income (loss)	$	2,444	$	(12,797)	$	536	$	(21,574)
Earnings per share of common stock:
Basic	$	0.06	$	(0.32)	$	0.01	$	(0.53)
Diluted	$	0.06	$	(0.32)	$	0.01	$	(0.53)

See accompanying notes to unaudited consolidated financial statements.

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Basic Energy Services, Inc.

Consolidated Statements of Stockholders’ Equity

(in thousands, except share data)

				Additional						Total
	Common Stock			Paid-In		Treasury		Retained		Stockholders'
	Shares	Amount		Capital		Stock		Deficit		Equity
Balance - December 31, 2013	43,500,032	$	435	$	363,674	$	(12,096)	$	(6,726)	$	345,287
Issuances of restricted stock	—		—		(9,543)		9,543		—		—
Amortization of share-based compensation	—		—		7,121		—		—		7,121
Purchase of treasury stock	—		—		—		(6,243)		—		(6,243)
Exercise of stock options	—		—		1,126		2,611		—		3,737
Net income	—		—		—		—		536		536
Balance - June 30, 2014 (unaudited)	43,500,032	$	435	$	362,378	$	(6,185)	$	(6,190)	$	350,438

See accompanying notes to unaudited consolidated financial statements.

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Basic Energy Services, Inc.

Consolidated Statements of Cash Flows

(Unaudited)

(in thousands)

	Six months ended June 30
	2014		2013
Cash flows from operating activities:
Net income (loss)	$	536	$	(21,574)
Adjustments to reconcile net loss to net cash
provided by operating activities:
Depreciation and amortization		103,490		101,848
Accretion on asset retirement obligation		64		55
Change in allowance for doubtful accounts		(336)		224
Amortization of deferred financing costs		1,605		1,512
Amortization of premium on notes		(118)		(108)
Non-cash compensation		7,121		6,129
Loss on disposal of assets		237		1,879
Deferred income taxes		701		(10,755)
Changes in operating assets and liabilities, net of acquisitions:
Accounts receivable		(28,170)		(18,346)
Inventories		(6,720)		158
Prepaid expenses and other current assets		(3,917)		(2,730)
Other assets		(824)		229
Accounts payable		9,229		(4,874)
Income tax receivable		269		(791)
Other liabilities		3,761		2,395
Accrued expenses		7,083		13,118
Net cash provided by operating activities		94,011		68,369
Cash flows from investing activities:
Purchase of property and equipment		(107,384)		(77,599)
Proceeds from sale of mutual fund		—		5,635
Proceeds from sale of assets		25,875		7,658
Payments for other long-term assets		(673)		(569)
Payments for businesses, net of cash acquired		—		(16,463)
Net cash used in investing activities		(82,182)		(81,338)
Cash flows from financing activities:
Payments of debt		(22,346)		(22,632)
Purchase of treasury stock		(6,243)		(3,528)
Tax withholding from exercise of stock options		(362)		(154)
Exercise of employee stock options		4,646		456
Deferred loan costs and other financing activities		(62)		(119)
Net cash used in financing activities		(24,367)		(25,977)
Net decrease in cash and equivalents		(12,538)		(38,946)
Cash and cash equivalents - beginning of period		111,532		134,565
Cash and cash equivalents - end of period	$	98,994	$	95,619

See accompanying notes to unaudited consolidated financial statements.

7

BASIC ENERGY SERVICES, INC.

Notes to Consolidated Financial Statements

June 30, 2014(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, 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, Kentucky, Ohio 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, 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.

8

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.

Fluid Services — Fluid services consists primarily of the sale, transportation, treatment, storage and disposal of fluids used in the 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.

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, a “footage” contract, in which an agreed upon rate is charged per the number of feet drilled, or a “turnkey” contract, in which an agreed upon single rate is charged for a drilled well.

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

Inventories

Rental and fishing tool inventories, consisting mainly of grapples, mills 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.

9

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 $23.4 million net of accumulated amortization of $8.8million, and  $23.3 million net of accumulated amortization of $7.2 million at June 30, 2014 and December 31, 2013, respectively. Amortization of deferred debt costs totaled approximately $806,000 and $759,000for the three months ended June 30, 2014 and 2013, respectively. Amortization of deferred debt cost totaled approximately $1.6 million and $1.5 million for the six months ended June 30, 2014 and 2013, respectively.

Goodwill and Other Intangible Assets

Basic had trade names of $1.9 million as of June 30, 2014 and December 31, 2013.

Additions to goodwill during the six months ended June 30, 2014 were primarily due to adjustments to the preliminary purchase price allocations for acquisitions completed in the prior year. The changes in the carrying amount of goodwill for the six months ended June 30, 2014 were as follows (in thousands):

	Completion
	And Remedial
	Services		Well Servicing		Fluid Services		Contract Drilling		Total
Balance as of December 31, 2013	$	77,697	$	6,622	$	26,595	$	—	$	110,914
Goodwill additions		—		—		1,369		—		1,369
Balance as of June 30, 2014	$	77,697	$	6,622	$	27,964	$	—	$	112,283

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$86.9 million and $87.1 million at June 30, 2014 and December 31, 2013, respectively. The gross carrying amount of non-compete agreements subject to amortization totaled approximately $12.9 million and $13.0 million at June 30, 2014 and December 31, 2013, respectively. The gross carrying amount of other intangible assets subject to amortization was $2.1 million at June 30, 2014 and December 31, 2013. Accumulated amortization related to these intangible assets totaled approximately $30.9 million and $26.6 million at June 30, 2014 and December 31, 2013, respectively. Amortization expense for the three months ended June 30, 2014 and 2013 was approximately $2.1 million and $2.2 million, respectively. Amortization expense for the six months ended June 30, 2014 and 2013 was approximately $4.3 million and $4.2 million, respectively. Other intangibles net of accumulated amortization allocated to reporting units as of June 30, 2014 were $53.1 million, $5.6 million, $10.8 million and $3.6 million for completion and remedial services, well servicing, fluid services, and contract drilling, respectively. Customer relationships are amortized over a 15-year life, non-compete agreements are amortized over a five-year life, developed technology is amortized over a 15-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.

Certain Basic share-based awards also provide for potential reissuances of unvested shares otherwise forfeited at retirement, provided the recipient also enters into required non-competition and severance agreements.  Notwithstanding these service conditions, for expense recognition we generally deem the vesting period after the retirement to be non-substantive, and treat the requisite service period from the grant date to the first date when the employee is eligible to retire. 

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

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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 six months ended June 30, 2014 or 2013.

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 April 2014, the FASB issued ASU No. 2014-08, “Presentation of Financial Statements (Topic 205) and Property, Plant, and Equipment (Topic 360): Reporting Discontinued Operations and Disclosures of Disposals of Components of an Entity." ASU 2014-08 raises the threshold for a disposal to qualify as a discontinued operation and requires new disclosures of both discontinued operations and certain other disposals that do not meet the definition of a discontinued operation. It is effective for annual periods beginning on or after December 15, 2014. Early adoption is permitted but only for disposals that have not been reported in financial statements previously issued. Basic does not believe this pronouncement will have a material impact on its consolidated financial statements.

In May 2014, the FASB issued ASU No. 2014-09, “Revenue from Contracts with Customers (Topic 606).” ASU 2014-09 provides a framework that replaces the existing revenue recognition guidance. It is effective for annual periods beginning after December 15, 2016, including interim periods within that reporting period. Basic will determine if this pronouncement will have a material impact on its consolidated financial statements.

In June 2014, the FASB issued ASU No. 2014-12,  “Compensation-Stock Compensation (Topic 718): Accounting for Share-Based Payments When the Terms of an Award Provide That a Performance Target Could Be Achieved after the Requisite Service Period.” ASU 2014-12 requires a reporting entity to treat a performance target that affects vesting and that could be achieved after the requisite service period as a performance condition. It is effective for annual periods, and interim

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periods within those annual periods, beginning after December 15, 2015. Early adoption is permitted. ASU 2014-12 may be adopted either prospectively for share-based payment awards granted or modified on or after the effective date, or retrospectively, using a modified retrospective approach. The modified retrospective approach would apply to share-based payment awards outstanding as of the beginning of the earliest annual period presented in the financial statements on adoption, and to all new or modified awards thereafter. Basic will determine if this pronouncement will have a material impact on its consolidated financial statements.

3. Acquisitions

During 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. During the six months ended June 30, 2014, Basic did not complete any acquisitions. The following table summarizes the final values for the acquisitions at the date of acquisition (in thousands):

		Total Cash Paid
	Closing Date	(net of cash acquired)
Atlas Environmental Consulting, Inc. and Atlas Oilfield Construction Company, LLC	February 19, 2013	$	12,979
Petroleum Water Solutions, LLC	February 22, 2013		3,288
Karnes Water Management, LLC	December 31, 2013		5,200
Total 2013		$	21,467

The operations of each of the acquisitions listed above are included in Basic’s statement of operations as of each respective closing date.

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4. Property and Equipment

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

	June 30, 2014		December 31, 2013
Land	$	17,316	$	17,800
Buildings and improvements		66,593		65,702
Well service units and equipment		467,651		498,846
Fluid services equipment		257,566		258,371
Brine and fresh water stations		15,007		13,496
Frac/test tanks		318,633		275,603
Pumping equipment		310,579		299,300
Construction equipment		15,908		15,677
Contract drilling equipment		106,664		104,958
Disposal facilities		149,365		143,459
Light vehicles		64,879		64,942
Rental equipment		73,150		70,738
Software		21,010		23,360
Other		19,189		16,754
		1,903,510		1,869,006
Less accumulated depreciation and amortization		980,278		940,969
Property and equipment, net	$	923,232	$	928,037

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):

	June 30, 2014		December 31, 2013
Light vehicles	$	42,551	$	39,970
Contract drilling equipment		4,223		4,223
Well service units and equipment		985		1,554
Fluid services equipment		119,870		121,051
Pumping equipment		28,445		29,080
Construction equipment		898		1,005
Software		17,120		17,120
Other		70		70
		214,162		214,073
Less accumulated amortization		87,759		77,340
	$	126,403	$	136,733

Amortization of assets held under capital leases of approximately $8.8 million and $7.6 million for the three months ended June 30, 2014 and 2013, respectively, and $17.3 million and $14.9 million for the six months ended June 30, 2013 and 2012, respectively, is included in depreciation and amortization expense in the consolidated statements of operations.

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5. Long-Term Debt

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

	June 30, 2014		December 31, 2013
Credit Facilities:
Revolver		—		—
7.75% Senior Notes due 2019	$	475,000	$	475,000
7.75% Senior Notes due 2022		300,000		300,000
Unamortized premium		1,341		1,459
Capital leases and other  notes		103,039		111,626
		879,380		888,085
Less current portion		40,577		41,394
	$	838,803	$	846,691

7.75% Senior Notes due 2019

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

The 2019 Notes and guarantees 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”).

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. Basic received net proceeds from the issuance of the 2019 Notes of approximately $464.6 million after premiums and offering expenses. Basic used a portion of the net proceeds from the February 2011 offering to fund its tender offer and consent solicitation for its 11.625% Senior Secured Notes due 2014 and to redeem any of the Senior Secured Notes not purchased in the tender offer. Basic 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 the remainder 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, National Association, as trustee. Interest on the 2019 Notes accrues at a rate of 7.75% per year and 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 Basic’s ability and the ability of certain of its 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 Basic’s restricted subsidiaries to Basic; 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. At June 30, 2014, Basic was in compliance with the restrictive covenants under the 2019 Notes Indenture.

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Basic may, at its 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, Basic, at its option, may redeem up to 35% of the aggregate principal amount of the 2019 Notes 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 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, Basic 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, Basic 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, Basic 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 Basic’s current subsidiaries other than three immaterial subsidiaries. The 2022 Notes and the guarantees rank (i) equally in right of payment with any of Basic’s and the subsidiary guarantors’ existing and future senior indebtedness, including Basic’s existing 2019 Notes and the related guarantees, and (ii) effectively junior to all existing or future liabilities of Basic’s subsidiaries that do not guarantee the 2022 Notes and to Basic’s and the subsidiary guarantors’ existing or future secured indebtedness to the extent of the value of the collateral therefore.  

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. Basic received net proceeds from the issuance of the 2022 Notes of approximately $293.3 million after discounts and offering expenses. Basic used a portion of the net proceeds from the offering to fund its tender offer and consent solicitation for its 7.125% Senior Notes due 2016 (the “2016 Notes”) and to redeem any of the 2016 Notes not purchased in the tender offer. The remainders 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 Basic, the guarantors party thereto and Wells Fargo Bank, National Association, as trustee. Interest on the 2022 Notes accrues at a rate of 7.75% per year and 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 Basic’s ability and the ability of certain of its 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 Basic’s restricted subsidiaries to Basic; 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 June 30, 2014, Basic was in compliance with the restrictive covenants under the 2022 Notes Indenture.

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Basic may, at its 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, Basic, at its option, may redeem up to 35% of the aggregate principal amount of the 2022 Notes 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 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, Basic 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, Basic 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, Basic terminated the 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 Basic 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 Basic’s current subsidiaries, other than three immaterial subsidiaries, and are secured by substantially all of Basic’s and its subsidiary guarantors’ assets as collateral under a related Security Agreement (the “Security Agreement”). As of June 30, 2014 and December 31, 2013, the non-guarantor subsidiaries held no assets and performed no operations. On July 15, 2011, Basic exercised the accordion feature and amended the Credit Agreement to increase Basic’s total credit available from         $165.0 million to $225.0 million. On April 5, 2012, Basic amended the Credit Agreement to increase the aggregate amount of commitments thereunder to $250.0 million. On October 1, 2012, Basic further amended the Credit Agreement to permit the transactions contemplated by the offering of 2022 Notes and the tender offer and redemption of 2016 Notes. On August 29, 2013, Basic further amended the Credit Agreement to amend the required leverage ratios.

Borrowings under the Credit Agreement mature on January 15, 2016, and Basic has the ability at any time to prepay the Credit Agreement without premium or penalty. At Basic’s 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 2.50% based on Basic’s leverage ratio or (ii) Eurodollar loans, at a variable base interest rate plus a margin ranging from 2.50% to 3.50% based on Basic’s leverage ratio. Basic 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 Basic’s ability and the ability of certain of its 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;

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· 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 Basic may make and require Basic 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 as follows:

ofor the four fiscal quarters ending September 30, 2013 and December 31, 2013, a maximum consolidated leverage ratio not to exceed 4.50 to 1.00;

ofor the four fiscal quarters ending March 31, 2014 and June 30, 2014, a maximum consolidated leverage ratio not to exceed 4.25 to 1.00; and

ofor the four fiscal quarters ending September 30, 2014 and each fiscal quarter thereafter, a maximum consolidated leverage ratio not to exceed 4.00 to 1.00; and

· a maximum consolidated senior secured leverage ratio as follows:

ofor the four fiscal quarters ending September 30, 2013 through June 30, 2014, a maximum consolidated senior secured leverage ratio not to exceed 1.75 to 1.00; and

ofor the four fiscal quarters ending September 30, 2014 and each fiscal quarter thereafter, a maximum consolidated senior secured leverage ratio not to exceed 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.

Basic had no borrowings and $37.7 million of letters of credit outstanding under the Credit Agreement as of June 30, 2014, giving Basic $212.3 million of available borrowing capacity. At June 30, 2014, Basic was in compliance with the 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 June 30, 2014, Basic was in compliance with this covenant.

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

	Six Months Ended June 30,
	2014		2013
Cash payments for interest	$	30,780	$	31,612
Commitment and other fees paid		1,156		893
Amortization of debt issuance costs and discount or premium on notes		1,487		1,404
Change in accrued interest		(5)		9
Other		7		(304)
	$	33,425	$	33,614

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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

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. In the second quarter of 2014, Basic was involved in the settlement of a lawsuit related to the contractual indemnification of a customer for $4.6 million, including legal fees.

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 $5.0 million, $1.0 million, and $400,000, 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 June 30, 2014 and December 31, 2013, self-insured risk accruals totaled approximately $33.0 million net of a $42,000 receivable for medical and dental coverage and $26.1 million net of a $230,000 receivable for medical and dental coverage, respectively.

7. Stockholders’ Equity

Common Stock

At June 30, 2014 and December 31, 2013, Basic had 80,000,000 shares of common stock, par value $0.01 per share, authorized.

During the year ended 2013, Basic issued 107,250 shares of common stock from treasury stock for the exercise of stock options and no shares of newly issued common stock for the exercise of stock options.

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. The Compensation Committee of Basic’s Board of Directors approved grants of performance-based stock awards to certain members of management. In February 2014, it was determined that 283,358 shares, or approximately 106% of the target number of shares, were earned based on 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. These restricted shares remain subject to vesting over a three-year period with the first shares vesting on March 15, 2015.

In March 2014, Basic granted various employees 414,900 restricted shares of common stock that vest over a three-year period and 294,909 shares that vest over a four-year period.

During the six months ended June 30, 2014, Basic issued 250,000 shares of common stock from treasury stock for the exercise of stock options.

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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 250,461 shares through net share settlements during the first six months of 2014 and 357,714 shares through net share settlements during the first six months of 2013.

Preferred Stock

At June 30, 2014 and December 31, 2013, Basic had 5,000,000 shares of preferred stock, par value $0.01 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 10,350,000 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 June 30, 2014 and 2013, compensation expense related to share-based arrangements was approximately $3.7 million and $3.3 million, respectively. For compensation expense recognized during the three months ended June 30, 2014 and 2013, Basic recognized a tax benefit of approximately $1.8 million and  $593,000, respectively. During the six months ended June 30, 2014 and 2013, compensation expense related to share-based arrangements was approximately $7.1 million and $6.1 million, respectively. For compensation expense recognized during the six months ended June 30, 2014 and 2013, Basic recognized a tax benefit of approximately $2.8 million and $2.0 million, respectively.

As of June 30, 2014, there was approximately $32.2 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 2.5 years. The total fair value of share-based awards vested during the six months ended June 30, 2014 and 2013 was approximately $20.3 million and $11.6 million, respectively. During the three months ended June 30, 2014 and 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 approximately $4.0 million and $810,000 at June 30, 2014 and 2013, respectively.

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 June 30, 2014 and the changes during the six months then ended:

				Weighted
				Average
				Remaining	Aggregate
	Number of	Weighted		Contractual	Intrinsic
	Options	Average		Term	Value
	Granted	Exercise Price		(Years)	(000's)
Non-statutory stock options:
Outstanding, beginning of period	530,000	$	18.15
Options granted	—		—
Options forfeited	—		—
Options exercised	(250,000)		17.14
Options expired	—		—
Outstanding, end of period	280,000	$	19.05	1.40	$	2,848
Exercisable, end of period	280,000	$	19.05	1.40	$	2,848
Vested or expected  to vest, end of period	280,000	$	19.05	1.40	$	2,848

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The total intrinsic value of share options exercised during the six months ended June 30, 2014 and 2013 was approximately $2.2 million and $501,000, respectively.

Cash received from share option exercises under the Plan was approximately $4.3 million and $302,000 for the six months ended June 30, 2014 and 2013, respectively. During the six months ended June 30, 2014 and2013 there was no excess tax benefit due to the NOL. If there was no NOL, the excess tax expense would have been $57,000 for the six months ended June 30, 2014 and excess tax benefit would have been $53,000 for the six months ended June 30, 2013.

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

Restricted Stock Awards

On March 12, 2014, 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, 2014 through December 31, 2014, 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 286,518 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, 2016. As of June 30, 2014, 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 June 30, 2014 and changes during the six months ended June 30, 2014 is presented in the following table:

		Weighted Average
	Number of	Grant Date Fair
Nonvested Shares	Shares	Value Per Share
Nonvested at beginning of period	2,089,597	$	14.93
Granted during period	1,013,125		25.14
Vested during period	(843,781)		14.78
Forfeited during period	(17,515)		20.89
Nonvested at end of period	2,241,426	$	19.55

9. Related Party Transactions

Basic had receivables from employees of approximately $47,000 and $50,000 as of June 30, 2014 and December 31, 2013, respectively. During 2006, Basic entered into a lease agreement with Darle Vuelta Cattle Co., LLC, an affiliate of a director, for approximately $69,000 per year. The term of the lease 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 lease 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.

Basic entered into a joint venture agreement with a family member of an executive officer to form an entity in 2010. Basic held 80% of the equity in the joint venture, and accounted for the entity as a consolidated investment. In 2013, Basic funded approximately $2.4 million for this joint venture. The entity had only research and development activities in 2013. This joint venture agreement was terminated in November 2013, and Basic now owns 100% of the entity.

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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 unaudited basic and diluted earnings per share (in thousands, except share data):

	Three months ended June 30,				Six months ended June 30,
	2014		2013		2014		2013
	(Unaudited)				(Unaudited)
Numerator (both basic and diluted):
Net income (loss)	$	2,444	$	(12,797)	$	536	$	(21,574)
Denominator:
Denominator for basic earnings per share		41,341,888		40,336,229		40,850,970		40,411,887
Stock options		101,446		—		146,354		—
Unvested restricted stock		600,113		—		351,395		—
Denominator for diluted earnings per share		42,043,447		40,336,229		41,348,719		40,411,887
Basic earnings per common share:	$	0.06	$	(0.32)	$	0.01	$	(0.53)
Diluted earnings per common share:	$	0.06	$	(0.32)	$	0.01	$	(0.53)

Stock options and unvested restricted stock shares of approximately 979,936 and911,162 were excluded in the computation of diluted earnings per share for the three and six months ended June 30, 2013, respectively as the effect would have been anti-dilutive.

11. Business Segment Information

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

Completion and Remedial Services: This segment utilizes a fleet of pumping units, air compressor packages specially configured for underbalanced drilling operations, coiled tubing services, nitrogen services, 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.

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.

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

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.

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

	Completion
	And Remedial						Contract		Corporate and
	Services		Well Servicing		Fluid Services		Drilling		Other		Total
Three Months Ended June 30, 2014 (Unaudited)
Operating revenues	$	164,366	$	89,629	$	90,314	$	15,353	$	—	$	359,662
Direct operating costs		(102,617)		(64,748)		(65,055)		(10,510)		—		(242,930)
Segment profits	$	61,749	$	24,881	$	25,259	$	4,843	$	—	$	116,732
Depreciation and amortization	$	16,040	$	13,939	$	15,926	$	3,214	$	2,666	$	51,785
Capital expenditures (excluding acquisitions)	$	49,913	$	14,109	$	5,620	$	2,701	$	1,934	$	74,277
Three Months Ended June 30, 2013 (Unaudited)
Operating revenues	$	132,216	$	93,921	$	85,601	$	13,985	$	—	$	325,723
Direct operating costs		(85,847)		(67,600)		(59,296)		(9,769)		—		(222,512)
Segment profits	$	46,369	$	26,321	$	26,305	$	4,216	$	—	$	103,211
Depreciation and amortization	$	15,753	$	15,568	$	14,818	$	3,318	$	2,610	$	52,067
Capital expenditures (excluding acquisitions)	$	10,596	$	9,675	$	11,238	$	(42)	$	6,259	$	37,726
Six Months Ended June 30, 2014 (Unaudited)
Operating revenues	$	301,851	$	182,541	$	183,149	$	28,877	$	—	$	696,418
Direct operating costs		(189,097)		(134,508)		(131,837)		(19,675)		—		(475,117)
Segment profits	$	112,754	$	48,033	$	51,312	$	9,202	$	—	$	221,301
Depreciation and amortization	$	32,044	$	27,848	$	31,851	$	6,420	$	5,327	$	103,490
Capital expenditures (excluding acquisitions)	$	65,308	$	21,804	$	12,859	$	3,609	$	3,804	$	107,384
Identifiable assets	$	466,636	$	267,909	$	310,185	$	57,617	$	456,509	$	1,558,856
Six Months Ended June 30, 2013 (Unaudited)
Operating revenues	$	250,577	$	181,596	$	169,931	$	27,970	$	—	$	630,074
Direct operating costs		(164,854)		(132,603)		(117,171)		(18,932)		—		(433,560)
Segment profits	$	85,723	$	48,993	$	52,760	$	9,038	$	—	$	196,514
Depreciation and amortization	$	30,815	$	30,452	$	28,985	$	6,490	$	5,106	$	101,848
Capital expenditures (excluding acquisitions)	$	23,583	$	21,700	$	20,356	$	3,051	$	8,909	$	77,599
Identifiable assets	$	440,904	$	290,653	$	323,709	$	61,936	$	471,793	$	1,588,995

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

	Three months ended June 30,				Six months ended June 30,
	2014		2013		2014		2013
Segment profits	$	116,732	$	103,211	$	221,301	$	196,514
General and administrative expenses		(42,953)		(49,321)		(82,512)		(91,278)
Depreciation and amortization		(51,785)		(52,067)		(103,490)		(101,848)
Loss on disposal of assets		(916)		(790)		(237)		(1,879)
Operating income	$	21,078	$	1,033	$	35,062	$	1,509

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12. Supplemental Schedule of Cash Flow Information

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

	For The Six Months Ended June 30
	2014		2013
	(In thousands)
Capital leases issued for equipment	$	13,759	$	27,014
Asset retirement obligation additions	$	64	$	78

Basic paid no income taxes during the six months ended June 30, 2014 and 2013. Basic paid interest of approximately $30.8 million and $31.6 million during the six months ended June 30, 2014 and 2013, 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.

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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, well servicing, fluid services and contract drilling. Our results of operations reflect the impact of our acquisition strategy as a leading consolidator in the domestic land-based well services industry. Our acquisitions have increased our breadth of service offerings at the well site and expanded our market presence. In implementing our acquisition strategy, we purchased businesses and assets in three separate acquisitions from January 1, 2013 to June 30, 2014.  We also divested our inland workover barge rig fleet in March 2014. Thesetransactions, as well as market fluctuations, make our revenues, expenses and income not directly comparable between periods.

Our total hydraulic horsepower increased from 291,000 at December 31, 2012 to 351,000 atJune 30, 2014. Our weighted average number of fluid service trucks increased from 972 in the second quarter of 2013 to 1,015 in the second quarter of 2014. Our weighted average number of well servicing rigs decreased to421 in the second quarter of 2014 from 425 in the second quarter of 2013.

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

	Six Months Ended June 30,
	2014			2013
Revenues:
Completion and remedial services	$	301.9	43%	$	250.6	40%
Well servicing	$	182.5	26%	$	181.6	29%
Fluid services	$	183.1	27%	$	169.9	27%
Contract drilling	$	28.9	4%	$	28.0	4%
Total revenues	$	696.4	100%	$	630.1	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, may adversely impact the level of drilling and workover activity by our customers as well as the demand for our services and the price of our services.

Oil prices have remained relatively stable throughout 2013 and the second quarter of 2014.  As a result of increased concentration of equipment and activity, utilization and pricing for our services hasremained competitive in our oil-based operating areas. Although natural gas prices have been depressed for a prolonged period, utilization and pricing for our services in our natural gas-based operating areas remained stable throughout the second quarter of 2014 due to slightly higher natural gas prices.

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;

· Well Servicing — rig hours, rig utilization rate, revenue per rig hour, profits per rig hour and 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; and

· Contract Drilling — rig operating days, revenue per drilling day, profits per drilling day and segment profits as a percent of revenues.

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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 and Divestitures

During 2013, we made threebusiness acquisitions that complemented our existing business segments. These included, among others:

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

OnFebruary 16, 2013, we acquired all of the assets of Atlas Environmental Consulting, Inc. and Atlas Oilfield Construction Company, LLCfor total cash consideration of$13.0 million. This acquisition has been included in our fluid services segment.

During the first six months of 2014, we made no business acquisitions.

Sale of Barges

In March 2014, we sold our four inland workover barges, and related equipment, to a private buyer for approximately $19.0 million. These assets had been included in the well servicing segment.

Segment Overview

Completion and Remedial Services

During the first six months of 2014, our completion and remedial services segment represented approximately 43% 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 and other services.  

Our pumping services concentrate on providing lower-horsepower cementing, acidizing and fracturing services in selected markets. Our total hydraulic horsepower capacity for our pumping operations was 351,000 and  292,000 at June 30, 2014 and 2013, 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 2013, the full year ended December 31, 2013 and the quarter endedJune 30, 2014 (dollars in thousands):

			Segment
	Revenues		Profits %
2013:
First Quarter	$	118,361	33%
Second Quarter	$	132,216	35%
Third Quarter	$	127,119	35%
Fourth Quarter	$	123,441	35%
Full Year	$	501,137	35%
2014:
First Quarter	$	137,485	37%
Second Quarter	$	164,366	38%

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 increase in completion and remedial services revenue to $164.4 million in the second quarter of 2014 from $137.5 million in thefirst quarter of 2014 resulted primarily from increased activity in our pumping and coil tubing services, based on an increase in activity, as well as a larger equipment base due to capital expenditures during the quarter.  Segment

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profits as a percentage of revenue increased to 38% for the second quarter of 2014 from 37% in the first quarter of 2014 primarily due to higher utilization for our pumping services operation, as well as slight rate increases in selected markets.

Well Servicing

During the first six months of 2014, our well servicing segment represented approximately 26% 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 decreased from a weighted average number of 425 rigs in the second quarter of 2013 to 421 in the second quarter of 2014, due to the divestiture of our barge rig operations.

The following is an analysis of our well servicing operations for each of the quarters in 2013, the full year ended December 31, 2013 and the quarter endedJune 30, 2014:  

	Weighted
	Average		Rig	Revenue
	Number		Utilization	Per Rig		Profits Per
	Of Rigs	Rig hours	Rate	Hour		Rig hour		Profits %
2013:
First Quarter	425	210,800	69%	$	399	$	108	26%
Second Quarter	425	223,900	74%	$	408	$	111	28%
Third Quarter	425	227,100	75%	$	404	$	118	27%
Fourth Quarter	425	199,400	66%	$	404	$	113	27%
Full Year	425	861,200	71%	$	404	$	114	27%
2014:
First Quarter	425	217,400	73%	$	417	$	106	25%
Second Quarter	421	214,200	71%	$	410	$	116	28%

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 decreased to 71% in the second quarter of 2014 compared to 73% in the first quarter of 2014. Lower utilization resulted from decreased rig hours due to the sale of our barge rigs in March 2014, and weather-related lost hours compared to the first quarter of 2014. Our segment profit percentage increased to 28% for the second quarter of 2014 from 25% in the first quarter of 2014, due to a decrease in insurance and legal costs and lower personnel expenses related to the annual reset of payroll taxes in the first quarter of 2014.

Fluid Services

During the first six months of 2014, our fluid services segment represented approximately 27% of our revenues. Revenues in our fluid services segment are earned from the sale, transportation, treatment, and recycling, 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

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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 water treatment and recycling services include the treatment, recycling and disposal of wastewater, including frac water and flowback, to reuse this water in the completion and production processes. 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 2013, the full year ended December 31, 2013, the quarter ended March 31, 2014 and the quarter endedJune 30, 2014 (dollars in thousands):

	Weighted				Segment
	Average		Revenue		Profits Per
	Number of		Per Fluid		Fluid
	Fluid Service	Trucking	Service		Service		Segment
	Trucks	Hours	Truck		Truck		Profits %
2013:
First Quarter	963	555,600	$	88	$	27	31%
Second Quarter	972	568,500	$	88	$	27	31%
Third Quarter	970	578,900	$	89	$	27	31%
Fourth Quarter	986	579,400	$	89	$	26	29%
Full Year	973	2,282,400	$	353	$	107	30%
2014:
First Quarter	1,006	607,200	$	92	$	26	28%
Second Quarter	1,015	630,900	$	89	$	25	28%

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 decreased to $89,000in the second quarter of 2014 compared to $92,000 in the first quarter of 2014 primarily due to declines in non-trucking revenue streams, such as frac heating and hot oiling operations, as well as lower disposal revenues. Segment profit percentageremained flat at 28%in both the first and second quarters of 2014.

Contract Drilling

During the first six months of 2014, 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 12 rigs during the first and second quarter of 2014.  

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The following is an analysis of our contract drilling segment for each of the quarters in 2013, the full year ended December 31, 2013 and the quarter endedJune 30, 2014:  

	Weighted
	Average	Rig
	Number of	Operating	Revenue Per		Profits Per		Segment
	Rigs	Days	Drilling Day		Drilling Day		Profits %
2013:
First Quarter	12	850	$	16,500	$	5,700	35%
Second Quarter	12	846	$	16,500	$	5,000	30%
Third Quarter	12	833	$	16,500	$	5,500	34%
Fourth Quarter	12	781	$	16,400	$	5,800	35%
Full Year	12	3,310	$	16,500	$	5,500	33%
2014:
First Quarter	12	821	$	16,500	$	5,300	32%
Second Quarter	12	942	$	16,300	$	5,100	32%

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.

Revenue per day was $16,300 in the second quarter of 2014 compared to $16,500 in the first quarter of 2014. Segment profit percentageremained flat at32% inboth the second quarters of 2014

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 significant 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. 

Results of Operations

The following is a comparison of our results of operations for the three months ended June 30, 2014 compared to the three months ended June 30, 2013. For additional segment-related information and trends, please read “Segment Overview” above.

Three Months Ended June 30, 2014 Compared to Three Months Ended June 30,2013

Revenues. Revenues increased by 10% to $359.7 million during the second quarter of 2014 from $325.7 million during the same period in 2013. This increase was primarily due to increased demand for our servicesby our customers and expansion of our fleets.

Completion and remedial services revenues increased by 24% to $164.4 million during the second quarter of 2014 compared to $132.2 million in the same period in 2013. The increase in revenue between these periods was primarily due to an increase in total hydraulic horsepower to351,000 at June 30, 2014 from 292,000 at June 30,2013.

Well servicing revenues decreased by 5% to $89.6 million during the second quarter of 2014 compared to $93.9 million during the same period in 2013. The decrease was driven by the sale of our inland workover barge rig operations in March 2014. Excluding the revenues associated with these operations, revenues increased by 1% from the second quarter of 2013. Utilization was 71% in the second quarter of 2014, compared to 74% in the comparable quarter of 2013. Excluding the

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hours associated with the divested barge rigs, utilization was 72% during the second quarter of 2013. Revenue per rig hour in the second quarter of 2014 was $410, up 1% from $408 in the comparable quarter of 2013. Our weighted average number of well servicing rigs decreased to 421 during the second quarter of 2014from 425 during the same period in2013.  

Fluid services revenues increased by 6% to $90.3 million during the second quarter of 2014 compared to $85.6 million in the same period in 2013. Our revenue per fluid service truck increased 1% to $89,000 in the second quarter of 2014 compared to $88,000 in the same period in 2013 due mainly to increases in disposal and skim oil revenues. Our weighted average number of fluid service trucks increased to 1,015 during the second quarter of 2014 from 972 in the same period in 2013.  

Contract drilling revenues increased by 10% to $15.4 million during the secondquarter of2014 compared to $14.0 million in the same period in 2013. The number of rig operating days increased to 942 in the second quarter of 2014 compared to 846 in the second quarter of 2013. The increase in revenue and rig operating days was due to an increase in vertical well drilling activity 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, increased to $242.9 million during the secondquarter of 2014 from $222.5 million in the same period in 2013.  

Direct operating expenses for the completion and remedial services segment increased by 20% to $102.6 million during the second quarter of 2014 compared to $85.8 million for the same period in 2013 due primarily to increased activity levels overall, especially in our pumping services. Segment profits increased to 38% of revenues during the second quarter of 2014 compared to 35% for the same period in 2013, due to increased completion-related activity and pricing improvements.  

Direct operating expenses for the well servicing segment decreased by 4% to $64.7 million during the second quarter of 2014 compared to $67.6 million for the same period in 2013. The decrease in direct operating expenses was primarily due to the sale of our barge rig operations in March 2014. Segment profits remained flat at28% of revenues during the second quarter of 2014 compared to the same period in 2013.

Direct operating expenses for the fluid services segment increased by 10% to $65.1 million during the second quarter of 2014 compared to $59.3 million for the same period in 2013, mainly due to increased activity levels. Segment profits were 28% of revenues during the second quarter of 2014 compared to 31% for the same period in 2013, primarily due to higher insurance costs and higher costs associated with our water recycling operations.

Direct operating expenses for the contract drilling segment increased 7% to $10.5 million during the second quarter of 2014 compared to $9.8 million for same period in 2013. Segment profits for this segment increased to 32% of revenues during the secondquarter of 2014from 30% during the second quarter of 2013 due to lower repair and maintenance charges.

General and Administrative Expenses. General and administrative expenses decreased by 13% to $43.0 million during the second quarter of 2014 from $49.3 million for the same period in 2013, due mainly to an accrual related to a sales and use tax audit in the second quarter of 2013. Additionally, the second quarter of 2014 includes $4.6 million of costs associated with our participation in the settlement of a customer lawsuit. General and administrative expenses included $3.7 million and $3.3 million of stock-based compensation expense during the second quarter of 2014 and 2013, respectively.

Depreciation and Amortization Expenses. Depreciation and amortization expenses were $51.8 million during the second quarter of 2014 compared to $52.1 million for the same period in 2013.  The decline in depreciation and amortization expense is due to the decrease in depreciation related to the divesture of our barge rig operations in March 2014, offset by capital expenditures for equipment.

Interest Expense. Interestexpense decreased to$16.6 million during the second quarter of2014 compared to $16.8 million during the second quarter of 2013.  

Income Tax Expense. There was income tax expense of $2.2 million during the second quarter of 2014 compared to an income tax benefit  of $2.8 million for the same period in 2013. Our effective tax rate during the second quarter of 2014 and 2013 was approximately 47% and 18%, respectively. The increase in our effective tax rate was primarily due to the permanent taxable differences on different amounts of pre-tax income and pre-tax loss in 2014 and 2013, respectively.

Six Months Ended June 30, 2014 Compared to Six Months Ended June 30, 2013 

Revenues. Revenues increased by 11%  to $696.4  million during  the  six months  ended  June  30, 2014  from $630.1 million during the same period in 2013. This increase was primarily due to increased demand by our customers for our services.

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Completion and remedial services revenues increased by 20% to $301.9 million during the six months ended June 30, 2014 compared to$250.6 million in the same period in 2013. The increase in revenue between these periods was primarily due to an increase in our total hydraulic horsepower to 351,000 at June 30, 2014 from 292,000 at June 30, 2013, and increased pumping and coil tubing demand by our customers.  

Well servicing revenues increased by 1% to $182.5 million during the six months ended June 30, 2014 compared to $181.6 million during the same period in 2013. The segment experienced a 1% decrease in rig hours to 431,600 during the six months ended June 30, 2014 from 434,700 during the same period in 2013, due to the sale of our inland barge rigs in March 2014. This segment also experienced an increase in revenue per rig hour to $413 during the six months ended June 30, 2014 from $404 during the same period in 2013 due to a higher ratio of plugging revenues, which are performed at a higher rate. Our average number of well servicing rigs decreased to 423 during the six months ended June 30, 2014 compared to 425 in the same period in 2013, due to the sale of our barge rigs in March 2014.  

Fluid services revenues increased by 8% to $183.1 million during the six months ended June 30, 2014 compared to$169.9 million in the same period in 2013. Our revenue per fluid service truck increased 3% to $181,000 in the six months ended June 30, 2014 compared to $176,000 in the same period in 2013 due to an increase in disposal and skim oil revenues from our salt water disposal facilities. Our weighted average number of fluid service trucks increased 4% to 1,015 during the six months ended June 30, 2014 from 972 in the same period in 2013.  

Contract drilling revenues increased by 3% to $28.9 million during the six months ended June 30, 2014 compared to $28.0 million in the same period in 2013. The number of rig operating days increased 4% to 1,763 in the six months ended June 30, 2014 compared to 1,696 in the same period in 2013. The increase in revenue and rig operating days was due to an increase 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, increased by 10% to $475.1 million during the six months ended June 30, 2014 from $433.6 million in the same period in 2013. This increase was primarily due to increased activity and revenues in each of our four business segments.

Direct operating expenses for the completion and remedial services segment increased by 15% to  $189.1 million during the six months ended June 30, 2014 compared to  $164.9 million for the same period in 2013 due primarily to increased activity levels overall. Segment profits increased to 37% of revenues during the six months ended June 30, 2014 compared to 35% for the same period in 2013, due to increased activity and rate increases in selected markets.  

Direct operating expenses for the well servicing segment increased by 1% to $134.5 million during the six months ended June 30, 2014 compared to $132.6 million for the same period in 2013. The increase in direct operating expenses was due to increased level of activity. Segment profits decreasedto26% of revenues for the six months ended June 30, 2014 compared to 27% for the same period in 2013, due to higher legal and insurance costs.

Direct operating expenses for the fluid services segment increased by 13% to $131.8 million during the six months ended June 30, 2014 compared to $117.2 million for the same period in 2013, mainly due to increased activity levels. Segment profits were 28% of revenues during the six months ended June 30, 2014 compared to 31% for the same period in 2013 due to increased competition.

Direct operating expenses for the contract drilling segment increased by 4% to $19.7 million during the six months ended June 30, 2014 from $18.9 million for the same period in 2013. Segment profits for this segment increased to 32% of revenues during the six months ended June 30, 2014 compared to 32% for the same period in 2013, primarily due  to lower repair and maintenance costs.  

       General and Administrative Expenses. General and administrative expenses decreased by 10% to $82.5 million during the six months ended June 30, 2014 from $91.3 million for the same period in 2013, due mainly to cost-cutting initiatives, as well as decreased personnel and compensation costs. General and administrative expenses included $7.1 million and $6.1 million of stock-based compensation expense during the six months ended June 30, 2014 and 2013, respectively.

Depreciation and Amortization Expenses. Depreciation and amortization expenses were $103.5 million during the six months ended June 30, 2014 compared to $101.8 million for the same period in 2013. 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 one acquisition completed since June 30, 2013.  

Interest Expense. Interest expense decreased to $33.4 million during the six months ended June 30, 2014 compared to $33.6 million during the same period of 2013.

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Income Tax Expense.  Income tax expense was  $1.6 million during the six months ended June 30, 2014 compared to an income tax benefit of $10.2 million for the same period in 2013. Our effective tax rate during the six months ended June 30, 2014 and 2013 was approximately 75% and 32%, respectively.The increase in our effective tax rate was primarily due to the permanent taxable differences on different amounts of pre-tax income and pre-tax loss in 2014 and 2013, respectively.

Liquidity and Capital Resources

As of June 30, 2014, our primary capital resources were net cash flows from our operations, utilization of capital leases and our $250.0 million revolving credit facility. As of June 30, 2014, we had unrestricted cash and cash equivalents of$99.0 million compared to$111.5 million as of December 31, 2013.  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 $94.0 million for the six months ended June 30, 2014 compared to cash provided by operating activities of $68.4 million during the same period in 2013. Operating cash flow in the first six months of 2014 was higher mainly due to decreased net loss in 2014 and generally higher activity levels.

Capital Expenditures

Capital expenditures are the main component of our investing activities. Cash capital expenditures (including acquisitions) during the first six months of 2014 were $107.4 million compared to $94.1 million in the same period of 2013.  We added $13.8 million of additional assets through our capital lease program during the first six months of 2014 compared to $27.0 million of additional assets in the same period in 2013.

In 2014, we currently have planned capital expenditures of approximately $285 million, including capital leases of$55 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

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 of 2019 Notes,  resulting in outstanding 2019 Notes with an aggregate principal amount of $475.0 million. 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 therefore.  

The 2019 Notes and guarantees 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”).

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 the remainder for general corporate purposes.

The 2019 Notes and guaranteeswere 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, National Association, as trustee.

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Interest on the 2019 Notes accrues at a rate of 7.75% per year and 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. At June 30, 2014, 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 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 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 therefore.  

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. 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 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 remainders 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 at a rate of 7.75% per year and 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.

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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 June 30, 2014, 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 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 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 June 30, 2014, 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 the tender offer and redemption of 2016 Notes.On August 29, 2013, we further amended the Credit Agreement to amend the required leverage ratios.

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 2.50% based on our leverage ratio or (ii) Eurodollar loans, at a variable base interest rate plus a margin ranging from 2.50% to 3.50% based

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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 as follows:

o for the four fiscal quarters ending September 30, 2013 and December 31, 2013, a maximum consolidated leverage ratio not to exceed 4.50 to 1.00;

o for the four fiscal quarters ending March 31, 2014 and June 30, 2014, a maximum consolidated leverage ratio not to exceed 4.25 to 1.00; and

o for the four fiscal quarters ending September 30, 2014 and each fiscal quarter thereafter, a maximum consolidated leverage ratio not to exceed 4.00 to 1.00; and

· a maximum consolidated senior secured leverage ratio as follows:

ofor the four fiscal quarters ending September 30, 2013 through June 30, 2014, a maximum consolidated senior secured leverage ratio not to exceed 1.75 to 1.00; and

ofor the four fiscal quarters ending September 30, 2014 and each fiscal quarter thereafter, a maximum consolidated senior secured leverage ratio not to exceed 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 $37.7 million of letters of credit outstanding under the Credit Agreement as of June 30, 2014, giving us $212.3 million of available borrowing capacity. At June 30, 2014, we were in compliance with our covenants under the Credit Agreement.

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 require us to maintain a minimum debt service coverage ratio of 1.05 to 1.00. For the six-month period endedJune 30, 2014, we were in compliance with our covenants under the agreement with Banc of America Leasing & Capital, LLC. As of June 30, 2014, we had total capital leases additions of approximately $13.8 million.

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Preferred Stock

At June 30, 2014 and December 31, 2013, we had 5,000,000 shares of $0.01 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 June 30, 2014, we had approximately $56.2 million of net operating loss carryforwards.

Recent Accounting Pronouncements

In April 2014, the FASB issued ASU No. 2014-08,“Presentation of Financial Statements (Topic 205) and Property, Plant, and Equipment (Topic 360): Reporting Discontinued Operations and Disclosures of Disposals of Components of an Entity." ASU 2014-08 raises the threshold for a disposal to qualify as a discontinued operation and requires new disclosures of both discontinued operations and certain other disposals that do not meet the definition of a discontinued operation. It is effective for annual periods beginning on or after December 15, 2014. Early adoption is permitted but only for disposals that have not been reported in financial statements previously issued. Basic will determine if this pronouncement will have a material impact on its consolidated financial statements.

In May 2014, the FASB issued ASU No. 2014-09, “Revenue from Contracts with Customers (Topic 606).” ASU 2014-09 provides a framework that replaces the existing revenue recognition guidance. It is effective for annual periods beginning after December 15, 2016, including interim periods within that reporting period. Basic will determine if this pronouncement will have a material impact on its consolidated financial statements.

In June 2014, the FASB issued ASU No. 2014-12,  “Compensation-Stock Compensation (Topic 718): Accounting for Share-Based Payments When the Terms of an Award Provide That a Performance Target Could Be Achieved after the Requisite Service Period.” ASU 2014-12 requires a reporting entity to treat a performance target that affects vesting and that could be achieved after the requisite service period as a performance condition. It is effective for annual periods, and interim periods within those annual periods, beginning after December 15, 2015. Early adoption is permitted. ASU 2014-12 may be adopted either prospectively for share-based payment awards granted or modified on or after the effective date, or retrospectively, using a modified retrospective approach. The modified retrospective approach would apply to share-based payment awards outstanding as of the beginning of the earliest annual period presented in the financial statements on adoption, and to all new or modified awards thereafter. Basic will determine if this pronouncement will have a material impact on its 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 June 30, 2014, 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, 2013.  

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

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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, we are a party to litigation or other legal proceedings that we consider to be a part of the ordinary course of business. We are not currently involved in any legal proceedings that we consider probable or reasonably possible, individually or in the aggregate, to result in a material adverse effect on our financial condition, results of operations or liquidity.

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 for the three months ended June 30, 2014 (dollars in thousands, except average price paid per share):  

	Issuer Purchases of Equity Securities
				Total Number of	Approximate Dollar
				Shares Purchased	Value of Shares
				as Part of Publicly	that May Yet be
	Total Number of	Average Price Paid		Announced	Purchased Under
Period	Shares reacquired	Per Share		Program (1)	the Program (1)
April 1 — April 30 (2)	—	$	—	—	$
May 1 — May 31 (2)	—	$	—	—	$
June 1 — June 30 (2)	—	$	—	—	$
Total	—	$	—	—	$	20,326

(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) The 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.

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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/A (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/A (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 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 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 18, 2014) (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 21, 2014)
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

37

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/ Thomas M. Patterson
Name:	Thomas M. Patterson
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: July 28, 2014

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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/A (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/A (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 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 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 18, 2014) (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 21, 2014)
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

39

EX-31.1

Exhibit 31.1

CERTIFICATION BY CHIEF EXECUTIVE OFFICER PURSUANT TO

RULE 13a-14(a) AND 15d-14(a) UNDER THE EXCHANGE ACT

I, Thomas M. Patterson, certify that:

1. I have reviewed this quarterly report on Form 10-Q of Basic Energy Services, Inc.;

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c) Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d) Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5. The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date: July 28, 2014

/s/ Thomas M. Patterson

Thomas M. Patterson

Chief Executive Officer

EX-31.2

Exhibit 31.2

CERTIFICATION BY CHIEF FINANCIAL OFFICER PURSUANT TO

RULE 13a-14(a) AND 15d-14(a) UNDER THE EXCHANGE ACT

I, Alan Krenek, certify that:

1. I have reviewed this quarterly report on Form 10-Q of Basic Energy Services, Inc.;

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c) Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d) Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5. The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date: July 28, 2014

/s/ Alan Krenek

Alan Krenek

Chief Financial Officer

EX-32.1

Exhibit 32.1

CERTIFICATION BY CHIEF EXECUTIVE OFFICER

PURSUANT TO 18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Quarterly Report of Basic Energy Services, Inc. (the “Company”) on Form 10-Q for the period ending June 30, 2014 as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Thomas M. Patterson, Chief Executive Officer of the Company, certify, pursuant to 18 U.S.C. § 1350, as adopted pursuant to § 906 of the Sarbanes-Oxley Act of 2002, to my knowledge, that:

(1)The Report fully complies with the requirements of section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2)The information contained in the Report fairly presents, in all material respects, the financial condition and result of operations of the Company.

/s/ Thomas M. Patterson

Thomas M. Patterson

Chief Executive Officer

July 28, 2014

EX-32.2

Exhibit 32.2

CERTIFICATION BY CHIEF FINANCIAL OFFICER

PURSUANT TO 18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Quarterly Report of Basic Energy Services, Inc. (the “Company”) on Form 10-Q for the period ending June 30, 2014 as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Alan Krenek, Chief Financial Officer of the Company, certify, pursuant to 18 U.S.C. § 1350, as adopted pursuant to § 906 of the Sarbanes-Oxley Act of 2002, to my knowledge, that:

(1)The Report fully complies with the requirements of section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2)The information contained in the Report fairly presents, in all material respects, the financial condition and result of operations of the Company.

/s/ Alan Krenek

Alan Krenek

Chief Financial Officer

July 28, 2014

XML

Commitments and Contingencies (Narrative) (Detail) (USD $)	3 Months Ended	6 Months Ended
	Jun. 30, 2014	Jun. 30, 2014	Dec. 31, 2013
Commitments And Contingencies [Abstract]
Litigation Settlement, Expense	$ 4,600,000
Self insurance deductible for workers compensation		5,000,000
Self insurance deductible for general liability claims		1,000,000
Self insurance deductible for medical and dental coverage		400,000
Self insured risk accruals	33,000,000	33,000,000	26,100,000
Receivable for Medical and Dental Coverage	$ 42,000	$ 42,000	$ 230,000

XML

Business Segment Information (Schedule Of Reconciliation Of Operating Profit (Loss) From Segments) (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended		6 Months Ended
	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Business Segment Information [Abstract]
Segment profits	$ 116,732	$ 103,211	$ 221,301	$ 196,514
General and administrative expenses	(42,953)	(49,321)	(82,512)	(91,278)
Depreciation and amortization	(51,785)	(52,067)	(103,490)	(101,848)
Loss on disposal of assets	(916)	(790)	(237)	(1,879)
Operating income	$ 21,078	$ 1,033	$ 35,062	$ 1,509

XML

Earnings Per Share (Computation Of Basic And Diluted Earnings Per Share) (Details) (USD $) In Thousands, except Share data, unless otherwise specified	3 Months Ended		6 Months Ended
	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Numerator (both basic and diluted):
Net income (loss)	$ 2,444	$ (12,797)	$ 536	$ (21,574)
Denominator:
Denominator for basic earnings per share	41,341,888	40,336,229	40,850,970	40,411,887
Stock options	101,446		146,354
Unvested restricted stock	600,113		351,395
Denominator for diluted earnings per share	42,043,447	40,336,229	41,348,719	40,411,887
Basic earnings per common share:	$ 0.06	$ (0.32)	$ 0.01	$ (0.53)
Diluted earnings per common share:	$ 0.06	$ (0.32)	$ 0.01	$ (0.53)

XML

Property And Equipment (Narrative) (Details) (USD $) In Millions, unless otherwise specified	3 Months Ended		6 Months Ended
	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Property Plant And Equipment [Abstract]
Lease Obligation Period			5 years
Amortization of assets held under capital leases	$ 8.8	$ 7.6	$ 17.3	$ 14.9

XML

Long-Term Debt (Tables)

6 Months Ended

Jun. 30, 2014

Long-Term Debt [Abstract]

Schedule of Long-Term Debt Instruments

	June 30, 2014		December 31, 2013
Credit Facilities:
Revolver		—		—
7.75% Senior Notes due 2019	$	475,000	$	475,000
7.75% Senior Notes due 2022		300,000		300,000
Unamortized premium		1,341		1,459
Capital leases and other  notes		103,039		111,626
		879,380		888,085
Less current portion		40,577		41,394
	$	838,803	$	846,691

Schedule of Interest Expense

	Six Months Ended June 30,
	2014		2013
Cash payments for interest	$	30,780	$	31,612
Commitment and other fees paid		1,156		893
Amortization of debt issuance costs and discount or premium on notes		1,487		1,404
Change in accrued interest		(5)		9
Other		7		(304)
	$	33,425	$	33,614

XML

Supplemental Schedule Of Cash Flow Information (Schedule Of Supplemental Cash Flow Information) (Details) (USD $) In Thousands, unless otherwise specified	6 Months Ended
	Jun. 30, 2014	Jun. 30, 2013
Supplemental Schedule Of Cash Flow Information [Abstract]
Capital leases issued for equipment	$ 13,759	$ 27,014
Asset retirement obligation additions	$ 64	$ 78

XML

Incentive Plan (Summary Of Stock Options) (Details) (USD $) In Thousands, except Share data, unless otherwise specified	6 Months Ended
	Jun. 30, 2014
Incentive Plan [Abstract]
Outstanding, beginning of period, Number of Options Granted	530,000
Options exercised, Number of Options Granted	(250,000)
Outstanding, end of period, Number of Options Granted	280,000
Exercisable, end of period, Number of Options Granted	280,000
Vested or expected to vest, end of period, Number of Options Granted	280,000
Outstanding, beginning of period, Weighted Average Exercise Price	$ 18.15
Options exercised, Weighted Average Exercise Price	$ 17.14
Outstanding, end of period, Weighted Average Exercise Price	$ 19.05
Exercisable, end of period, Weighted Average Exercise Price	$ 19.05
Vested or expected to vest, end of period, Weighted Average Exercise Price	$ 19.05
Outstanding, end of period, Weighted Average Remaining Contractual Term (Years)	1 year 4 months 24 days
Exercisable, end of period, Weighted Average Remaining Contractual Term (Years)	1 year 4 months 24 days
Vested or expected to vest, end of period, Weighted Average Remaining Contractual Term (Years)	1 year 4 months 24 days
Outstanding, end of period, Aggregate Intrinsic Value	$ 2,848
Exercisable, end of period, Aggregate Intrinsic Value	2,848
Vested or expected to vest, end of period, Aggregate Intrinsic Value	$ 2,848

XML

Long-Term Debt (Schedule Of Long-Term Debt Instruments) (Details) (USD $) In Thousands, unless otherwise specified	Jun. 30, 2014	Dec. 31, 2013
Debt Instrument [Line Items]
Revolver
Unamortized (discount) premium	1,341	1,459
Capital leases and other notes	103,039	111,626
Debt and Capital Lease Obligations, Total	879,380	888,085
Less current portion	40,577	41,394
Non Current Portion of Long Term Debt, total	838,803	846,691
7.75% Senior Notes due 2019
Debt Instrument [Line Items]
Senior Notes	475,000	475,000
7.75% Senior Notes due 2022
Debt Instrument [Line Items]
Senior Notes	$ 300,000	$ 300,000

XML

Business Segment Information (Schedule Of Reportable Segments Financial Information) (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended		6 Months Ended
	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013	Dec. 31, 2013
Segment Reporting Information [Line Items]
Operating revenues	$ 359,662	$ 325,723	$ 696,418	$ 630,074
Direct operating costs	(242,930)	(222,512)	(475,117)	(433,560)
Segment profits	116,732	103,211	221,301	196,514
Depreciation and amortization	51,785	52,067	103,490	101,848
Capital expenditures, (excluding acquisitions)	74,277	37,726	107,384	77,599
Identifiable assets	1,558,856	1,588,995	1,558,856	1,588,995	1,543,339
Completion And Remedial Services [Member]
Segment Reporting Information [Line Items]
Operating revenues	164,366	132,216	301,851	250,577
Direct operating costs	(102,617)	(85,847)	(189,097)	(164,854)
Segment profits	61,749	46,369	112,754	85,723
Depreciation and amortization	16,040	15,753	32,044	30,815
Capital expenditures, (excluding acquisitions)	49,913	10,596	65,308	23,583
Identifiable assets	466,636	440,904	466,636	440,904
Well Servicing [Member]
Segment Reporting Information [Line Items]
Operating revenues	89,629	93,921	182,541	181,596
Direct operating costs	(64,748)	(67,600)	(134,508)	(132,603)
Segment profits	24,881	26,321	48,033	48,993
Depreciation and amortization	13,939	15,568	27,848	30,452
Capital expenditures, (excluding acquisitions)	14,109	9,675	21,804	21,700
Identifiable assets	267,909	290,653	267,909	290,653
Fluid Services [Member]
Segment Reporting Information [Line Items]
Operating revenues	90,314	85,601	183,149	169,931
Direct operating costs	(65,055)	(59,296)	(131,837)	(117,171)
Segment profits	25,259	26,305	51,312	52,760
Depreciation and amortization	15,926	14,818	31,851	28,985
Capital expenditures, (excluding acquisitions)	5,620	11,238	12,859	20,356
Identifiable assets	310,185	323,709	310,185	323,709
Contract Drilling [Member]
Segment Reporting Information [Line Items]
Operating revenues	15,353	13,985	28,877	27,970
Direct operating costs	(10,510)	(9,769)	(19,675)	(18,932)
Segment profits	4,843	4,216	9,202	9,038
Depreciation and amortization	3,214	3,318	6,420	6,490
Capital expenditures, (excluding acquisitions)	2,701	(42)	3,609	3,051
Identifiable assets	57,617	61,936	57,617	61,936
Corporate And Other [Member]
Segment Reporting Information [Line Items]
Depreciation and amortization	2,666	2,610	5,327	5,106
Capital expenditures, (excluding acquisitions)	1,934	6,259	3,804	8,909
Identifiable assets	$ 456,509	$ 471,793	$ 456,509	$ 471,793

XML

Summary of Significant Accounting Policies

6 Months Ended

Jun. 30, 2014

Accounting Policies [Abstract]

Summary of Significant Accounting Policies

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, 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.  

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.

Fluid Services — Fluid services consists primarily of the sale, transportation, treatment, storage and disposal of fluids used in the 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.

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, a “footage” contract, in which an agreed upon rate is charged per the number of feet drilled, or a “turnkey” contract, in which an agreed upon single rate is charged for a drilled well.

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

Inventories

Rental and fishing tool inventories, consisting mainly of grapples, mills 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 $23.4 million net of accumulated amortization of $8.8million, and  $23.3 million net of accumulated amortization of $7.2 million at June 30, 2014 and December 31, 2013, respectively. Amortization of deferred debt costs totaled approximately $806,000 and $759,000for the three months ended June 30, 2014 and 2013, respectively. Amortization of deferred debt cost totaled approximately $1.6 million and $1.5 million for the six months ended June 30, 2014 and 2013, respectively.

Goodwill and Other Intangible Assets

Basic had trade names of $1.9 million as of June 30, 2014 and December 31, 2013.  

Additions to goodwill during the six months ended June 30, 2014 were primarily due to adjustments to the preliminary purchase price allocations for acquisitions completed in the prior year. The changes in the carrying amount of goodwill for the six months ended June 30, 2014 were as follows (in thousands):

	Completion
	And Remedial
	Services		Well Servicing		Fluid Services		Contract Drilling		Total
Balance as of December 31, 2013	$	77,697	$	6,622	$	26,595	$	—	$	110,914
Goodwill additions		—		—		1,369		—		1,369
Balance as of June 30, 2014	$	77,697	$	6,622	$	27,964	$	—	$	112,283

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 $86.9 million and $87.1 million at June 30, 2014 and December 31, 2013, respectively. The gross carrying amount of non-compete agreements subject to amortization totaled approximately $12.9 million and $13.0 million at June 30, 2014 and December 31, 2013, respectively. The gross carrying amount of other intangible assets subject to amortization was $2.1 million at June 30, 2014 and December 31, 2013. Accumulated amortization related to these intangible assets totaled approximately $30.9 million and $26.6 million at June 30, 2014 and December 31, 2013, respectively. Amortization expense for the three months ended June 30, 2014 and 2013 was approximately $2.1 million and $2.2 million, respectively. Amortization expense for the six months ended June 30, 2014 and 2013 was approximately $4.3 million and $4.2 million, respectively. Other intangibles net of accumulated amortization allocated to reporting units as of June 30, 2014 were $53.1 million, $5.6 million, $10.8 million and $3.6 million for completion and remedial services, well servicing, fluid services, and contract drilling, respectively. Customer relationships are amortized over a 15-year life, non-compete agreements are amortized over a five-year life, developed technology is amortized over a 15-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.

Certain Basic share-based awards also provide for potential reissuances of unvested shares otherwise forfeited at retirement, provided the recipient also enters into required non-competition and severance agreements.  Notwithstanding these service conditions, for expense recognition we generally deem the vesting period after the retirement to be non-substantive, and treat the requisite service period from the grant date to the first date when the employee is eligible to retire. 

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 six months ended June 30, 2014 or 2013.

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 April 2014, the FASB issued ASU No. 2014-08, “Presentation of Financial Statements (Topic 205) and Property, Plant, and Equipment (Topic 360): Reporting Discontinued Operations and Disclosures of Disposals of Components of an Entity." ASU 2014-08 raises the threshold for a disposal to qualify as a discontinued operation and requires new disclosures of both discontinued operations and certain other disposals that do not meet the definition of a discontinued operation. It is effective for annual periods beginning on or after December 15, 2014. Early adoption is permitted but only for disposals that have not been reported in financial statements previously issued. Basic does not believe this pronouncement will have a material impact on its consolidated financial statements.

In May 2014, the FASB issued ASU No. 2014-09, “Revenue from Contracts with Customers (Topic 606).” ASU 2014-09 provides a framework that replaces the existing revenue recognition guidance. It is effective for annual periods beginning after December 15, 2016, including interim periods within that reporting period. Basic will determine if this pronouncement will have a material impact on its consolidated financial statements.

In June 2014, the FASB issued ASU No. 2014-12,  “Compensation-Stock Compensation (Topic 718): Accounting for Share-Based Payments When the Terms of an Award Provide That a Performance Target Could Be Achieved after the Requisite Service Period.” ASU 2014-12 requires a reporting entity to treat a performance target that affects vesting and that could be achieved after the requisite service period as a performance condition. It is effective for annual periods, and interim periods within those annual periods, beginning after December 15, 2015. Early adoption is permitted. ASU 2014-12 may be adopted either prospectively for share-based payment awards granted or modified on or after the effective date, or retrospectively, using a modified retrospective approach. The modified retrospective approach would apply to share-based payment awards outstanding as of the beginning of the earliest annual period presented in the financial statements on adoption, and to all new or modified awards thereafter. Basic will determine if this pronouncement will have a material impact on its consolidated financial statements.

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Incentive Plan (Summary Of Non-Vested Shares) (Details) (USD $)	6 Months Ended
	Jun. 30, 2014
Incentive Plan [Abstract]
Nonvested at beginning of period, Number of Shares	2,089,597
Granted during period, Number of Shares	1,013,125
Vested during period, Number of Shares	(843,781)
Forfeited during period, Number of Shares	(17,515)
Nonvested at end of period, Number of Shares	2,241,426
Nonvested at beginning of period, Weighted Average Grant Date Fair Value Per Share	$ 14.93
Granted during period, Weighted Average Grant Date Fair Value Per Share	$ 25.14
Vested during period, Weighted Average Grant Date Fair Value Per Share	$ 14.78
Forfeited during period, Weighted Average Grant Date Fair Value Per Share	$ 20.89
Nonvested at end of period, Weighted Average Grant Date Fair Value Per Share	$ 19.55

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Supplemental Schedule Of Cash Flow Information (Tables)

6 Months Ended

Jun. 30, 2014

Supplemental Schedule Of Cash Flow Information [Abstract]

Schedule Of Supplemental Cash Flow Information

	For The Six Months Ended June 30
	2014		2013
	(In thousands)
Capital leases issued for equipment	$	13,759	$	27,014
Asset retirement obligation additions	$	64	$	78

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Business Segment Information (Tables)

6 Months Ended

Jun. 30, 2014

Business Segment Information [Abstract]

Schedule Of Reportable Segments Financial Information

	Completion
	And Remedial						Contract		Corporate and
	Services		Well Servicing		Fluid Services		Drilling		Other		Total
Three Months Ended June 30, 2014 (Unaudited)
Operating revenues	$	164,366	$	89,629	$	90,314	$	15,353	$	—	$	359,662
Direct operating costs		(102,617)		(64,748)		(65,055)		(10,510)		—		(242,930)
Segment profits	$	61,749	$	24,881	$	25,259	$	4,843	$	—	$	116,732
Depreciation and amortization	$	16,040	$	13,939	$	15,926	$	3,214	$	2,666	$	51,785
Capital expenditures (excluding acquisitions)	$	49,913	$	14,109	$	5,620	$	2,701	$	1,934	$	74,277
Three Months Ended June 30, 2013 (Unaudited)
Operating revenues	$	132,216	$	93,921	$	85,601	$	13,985	$	—	$	325,723
Direct operating costs		(85,847)		(67,600)		(59,296)		(9,769)		—		(222,512)
Segment profits	$	46,369	$	26,321	$	26,305	$	4,216	$	—	$	103,211
Depreciation and amortization	$	15,753	$	15,568	$	14,818	$	3,318	$	2,610	$	52,067
Capital expenditures (excluding acquisitions)	$	10,596	$	9,675	$	11,238	$	(42)	$	6,259	$	37,726
Six Months Ended June 30, 2014 (Unaudited)
Operating revenues	$	301,851	$	182,541	$	183,149	$	28,877	$	—	$	696,418
Direct operating costs		(189,097)		(134,508)		(131,837)		(19,675)		—		(475,117)
Segment profits	$	112,754	$	48,033	$	51,312	$	9,202	$	—	$	221,301
Depreciation and amortization	$	32,044	$	27,848	$	31,851	$	6,420	$	5,327	$	103,490
Capital expenditures (excluding acquisitions)	$	65,308	$	21,804	$	12,859	$	3,609	$	3,804	$	107,384
Identifiable assets	$	466,636	$	267,909	$	310,185	$	57,617	$	456,509	$	1,558,856
Six Months Ended June 30, 2013 (Unaudited)
Operating revenues	$	250,577	$	181,596	$	169,931	$	27,970	$	—	$	630,074
Direct operating costs		(164,854)		(132,603)		(117,171)		(18,932)		—		(433,560)
Segment profits	$	85,723	$	48,993	$	52,760	$	9,038	$	—	$	196,514
Depreciation and amortization	$	30,815	$	30,452	$	28,985	$	6,490	$	5,106	$	101,848
Capital expenditures (excluding acquisitions)	$	23,583	$	21,700	$	20,356	$	3,051	$	8,909	$	77,599
Identifiable assets	$	440,904	$	290,653	$	323,709	$	61,936	$	471,793	$	1,588,995

Schedule Of Reconciliation Of Operating Profit (Loss) From Segments

	Three months ended June 30,				Six months ended June 30,
	2014		2013		2014		2013
Segment profits	$	116,732	$	103,211	$	221,301	$	196,514
General and administrative expenses		(42,953)		(49,321)		(82,512)		(91,278)
Depreciation and amortization		(51,785)		(52,067)		(103,490)		(101,848)
Loss on disposal of assets		(916)		(790)		(237)		(1,879)
Operating income	$	21,078	$	1,033	$	35,062	$	1,509

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Related Party Transactions (Narrative) (Details) (USD $)				12 Months Ended
	Jun. 30, 2014	Dec. 31, 2013	Dec. 31, 2006 Chief Executive Officer [Member]	Dec. 31, 2010 Darle Vuelta Cattle Co LLC [Member] Salt Water Disposal Well [Member]
Related Party Transaction [Line Items]
Due from Employees	$ 47,000	$ 50,000
Lease agreement, amount			69,000
Price of oil and gas waste per barrel				0.10
Price of brine or fresh water per barrel				0.05
Monthly payment on leases				5,000
Percentage of ownership in joint venture	100.00%	80.00%
Funded amount for joint venture		$ 2,400,000

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Summary of Significant Accounting Policies (Narrative) (Detail) (USD $)	3 Months Ended		6 Months Ended
	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013	Dec. 31, 2013
Summary Of Significant Accounting Policies [Line Items]
Deferred debt costs, net of accumulated amortization	$ 23,400,000		$ 23,400,000		$ 23,300,000
Accumulated amortization of deferred debt costs	8,800,000		8,800,000		7,200,000
Amortization of deferred financing costs	806,000	759,000	1,605,000	1,512,000
Trade names value	1,900,000		1,900,000
Intangible assets accumulated amortization	30,900,000		30,900,000		26,600,000
Amortization expense of intangible assets	2,100,000	2,200,000	4,300,000	4,200,000
Percentage revenue from a single customer that is not exceeded			10.00%
Completion And Remedial Services [Member]
Summary Of Significant Accounting Policies [Line Items]
Other intangibles net of accumulated amortization	53,100,000		53,100,000
Well Servicing [Member]
Summary Of Significant Accounting Policies [Line Items]
Other intangibles net of accumulated amortization	5,600,000		5,600,000
Fluid Services [Member]
Summary Of Significant Accounting Policies [Line Items]
Other intangibles net of accumulated amortization	10,800,000		10,800,000
Contract Drilling
Summary Of Significant Accounting Policies [Line Items]
Other intangibles net of accumulated amortization	3,600,000		3,600,000
Customer Relationships
Summary Of Significant Accounting Policies [Line Items]
Gross carrying amount of intangible assets subject to amortization	86,900,000		86,900,000		87,100,000
Amortization period of intangible assets, in years			15 years
Noncompete Agreements
Summary Of Significant Accounting Policies [Line Items]
Gross carrying amount of intangible assets subject to amortization	12,900,000		12,900,000		13,000,000
Amortization period of intangible assets, in years			5 years
Other Intangible Assets
Summary Of Significant Accounting Policies [Line Items]
Gross carrying amount of intangible assets subject to amortization	$ 2,100,000		$ 2,100,000
Amortization period of intangible assets, in years			15 years
Rig Engineering Plans
Summary Of Significant Accounting Policies [Line Items]
Amortization period of intangible assets, in years			15 years
Well Service Units And Equipment | Minimum [Member]
Summary Of Significant Accounting Policies [Line Items]
Estimated useful lives			3 years
Well Service Units And Equipment | Maximum [Member]
Summary Of Significant Accounting Policies [Line Items]
Estimated useful lives			15 years

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Summary of Significant Accounting Policies (Changes in Carrying Amount of Goodwill) (Detail) (USD $) In Thousands, unless otherwise specified	6 Months Ended					6 Months Ended
	Jun. 30, 2014	Jun. 30, 2014 Completion And Remedial Services [Member]	Dec. 31, 2013 Completion And Remedial Services [Member]	Jun. 30, 2014 Well Servicing [Member]	Dec. 31, 2013 Well Servicing [Member]	Jun. 30, 2014 Fluid Services [Member]
Goodwill [Line Items]
Balance as of December 31, 2013	$ 110,914	$ 77,697	$ 77,697	$ 6,622	$ 6,622	$ 26,595
Goodwill adjustments	1,369					1,369
Balance as of June 30, 2014	$ 112,283	$ 77,697	$ 77,697	$ 6,622	$ 6,622	$ 27,964

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Basis of Presentation and Nature of Operations

6 Months Ended

Jun. 30, 2014

Accounting Policies [Abstract]

Basis of Presentation and Nature of Operations

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, 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, Kentucky, Ohio and Pennsylvania.

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Acquisitions (Details) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2013
Business Acquisition [Line Items]
Total Cash Paid (net of cash acquired)	$ 21,467
Atlas Environmental Consulting, Inc. and Atlas Oilfield Construction Company, LLC
Business Acquisition [Line Items]
Closing Date	Feb. 19, 2013
Total Cash Paid (net of cash acquired)	12,979
Petroleum Water Solutions, LLC
Business Acquisition [Line Items]
Closing Date	Feb. 22, 2013
Total Cash Paid (net of cash acquired)	3,288
Karnes Water Management LLC
Business Acquisition [Line Items]
Closing Date	Dec. 31, 2013
Total Cash Paid (net of cash acquired)	$ 5,200

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Stockholders' Equity (Narrative) (Detail) (USD $)	6 Months Ended	12 Months Ended	6 Months Ended		1 Months Ended	3 Months Ended	1 Months Ended
	Jun. 30, 2014	Dec. 31, 2013	Jun. 30, 2014 Net Share Settlements	Jun. 30, 2013 Net Share Settlements	Feb. 28, 2014 Restricted Stock	Mar. 31, 2014 Restricted Stock	Mar. 31, 2014 Three-Year Period	Mar. 31, 2013 Three-Year Period	Mar. 31, 2014 Four-Year Period	Mar. 31, 2013 Four-Year Period
Class of Stock [Line Items]
Common stock, shares authorized	80,000,000	80,000,000
Common stock, par value	$ 0.01	$ 0.01
Common stock issued from treasury stock	250,000	107,250
Issued common stock for the exercise of stock options		0
Restricted shares of common stock granted							414,900	432,400	294,909	262,000
Restricted shares of common stock vesting period, (in years)						3 years	3 years	3 years	4 years	4 years
Restricted stock granted	1,013,125				283,358
Percentage of target number of shares					106.00%
Treasury shares acquired, shares			250,461	357,714
Preferred stock, shares authorized	5,000,000	5,000,000
Preferred stock, par value	$ 0.01	$ 0.01
Preferred stock, shares issued	0	0
Preferred stock, shares outstanding	0

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Consolidated Balance Sheets (USD $) In Thousands, unless otherwise specified	Jun. 30, 2014	Dec. 31, 2013
Current assets:
Cash and cash equivalents	$ 98,994	$ 111,532
Trade accounts receivable, net of allowance of $3,339 and $3,675, respectively	232,903	204,394
Accounts receivable - related parties	47	50
Income tax receivable	2,659	3,475
Inventories	40,960	34,240
Prepaid expenses	12,951	9,597
Other current assets	8,898	8,289
Deferred tax assets	29,804	31,436
Total current assets	427,216	403,013
Property and equipment, net	923,232	928,037
Deferred debt costs, net of amortization	14,602	16,145
Goodwill	112,283	110,914
Other intangible assets, net of amortization	73,024	77,555
Other assets	8,499	7,675
Total assets	1,558,856	1,543,339
Current liabilities:
Accounts payable	54,737	45,508
Accrued expenses	84,141	77,058
Current portion of long-term debt	40,577	41,394
Other current liabilities	924	688
Total current liabilities	180,379	164,648
Long-term debt, net of unamortized premium on notes of $1,341 and $1,459, respectively	838,803	846,691
Deferred tax liabilities	163,375	164,306
Other long-term liabilities	25,861	22,407
Commitments and contingencies
Stockholders' equity:
Preferred stock; $0.01 par value; 5,000,000 shares authorized; none designated or issued at June 30, 2014 and December 31, 2013
Common stock; $0.01 par value; 80,000,000 shares authorized; 43,500,032 shares issued and 43,201,279 shares outstanding at June 30, 2014; 43,500,032 shares issued and 42,26,088 shares outstanding at December 31, 2013	435	435
Additional paid-in capital	362,378	363,674
Retained deficit	(6,190)	(6,726)
Treasury stock, at cost, 298,753 and 1,273,944 shares at June 30, 2014 and December 31, 2013, respectively	(6,185)	(12,096)
Total stockholders' equity	350,438	345,287
Total liabilities and stockholders' equity	$ 1,558,856	$ 1,543,339

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Earnings Per Share (Narrative) (Details)	3 Months Ended	6 Months Ended
	Jun. 30, 2013	Jun. 30, 2013
Earnings Per Share [Abstract]
Number of anti-dilutive shares	979,936	911,162

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Consolidated Statements of Stockholders' Equity (USD $) In Thousands, except Share data	Common Stock	Additional Paid-In Capital	Treasury Stock	Retained Deficit	Total
Beginning Balance at Dec. 31, 2013	$ 435	$ 363,674	$ (12,096)	$ (6,726)	$ 345,287
Beginning Balance (in shares) at Dec. 31, 2013	43,500,032				42,226,088
Issuances of restricted stock		(9,543)	9,543
Amortization of share-based compensation		7,121			7,121
Purchase of treasury stock			(6,243)		(6,243)
Exercise of stock options		1,126	2,611		3,737
Net income				536	536
Ending Balance at Jun. 30, 2014	$ 435	$ 362,378	$ (6,185)	$ (6,190)	$ 350,438
Ending Balance (in shares) at Jun. 30, 2014	43,500,032				43,201,279

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Property And Equipment (Schedule Of Property, Plant And Equipment Under Capital Lease) (Details) (USD $) In Thousands, unless otherwise specified	Jun. 30, 2014	Dec. 31, 2013
Property, Plant And Equipment [Line Items]
Property, plant and equipment under capital lease, gross	$ 214,162	$ 214,073
Less accumulated amortization	87,759	77,340
Property, plant and equipment under capital lease, net	126,403	136,733
Light Vehicles
Property, Plant And Equipment [Line Items]
Property, plant and equipment under capital lease, gross	42,551	39,970
Contract Drilling [Member]
Property, Plant And Equipment [Line Items]
Property, plant and equipment under capital lease, gross	4,223	4,223
Well Service Units And Equipment
Property, Plant And Equipment [Line Items]
Property, plant and equipment under capital lease, gross	985	1,554
Fluid Services Equipment
Property, Plant And Equipment [Line Items]
Property, plant and equipment under capital lease, gross	119,870	121,051
Pumping Equipment
Property, Plant And Equipment [Line Items]
Property, plant and equipment under capital lease, gross	28,445	29,080
Construction Equipment
Property, Plant And Equipment [Line Items]
Property, plant and equipment under capital lease, gross	898	1,005
Software
Property, Plant And Equipment [Line Items]
Property, plant and equipment under capital lease, gross	17,120	17,120
Other
Property, Plant And Equipment [Line Items]
Property, plant and equipment under capital lease, gross	$ 70	$ 70

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Summary of Significant Accounting Policies (Tables)

6 Months Ended

Jun. 30, 2014

Accounting Policies [Abstract]

Changes in Carrying Amount of Goodwill

	Completion
	And Remedial
	Services		Well Servicing		Fluid Services		Contract Drilling		Total
Balance as of December 31, 2013	$	77,697	$	6,622	$	26,595	$	—	$	110,914
Goodwill additions		—		—		1,369		—		1,369
Balance as of June 30, 2014	$	77,697	$	6,622	$	27,964	$	—	$	112,283

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Long-Term Debt (Narrative) (Details) (USD $) In Millions, unless otherwise specified	6 Months Ended			6 Months Ended				0 Months Ended	6 Months Ended	12 Months Ended			6 Months Ended
	Jun. 30, 2014 item	Dec. 31, 2013	Jun. 15, 2011	Jun. 30, 2014 Alternate Base Rate Loans Minimum [Member]	Jun. 30, 2014 Alternate Base Rate Loans Maximum [Member]	Jun. 30, 2014 Eurodollar Loans Minimum [Member]	Jun. 30, 2014 Eurodollar Loans Maximum [Member]	Jun. 13, 2011 7.75% Senior Notes due 2019	Jun. 30, 2014 7.75% Senior Notes due 2019	Dec. 31, 2011 7.75% Senior Notes due 2019 Maverick Companies	Feb. 15, 2011 7.75% Senior Notes Due 2019 on and after February 15 2015	Feb. 15, 2011 7.75% Senior Notes Due 2019 Prior To February 15 2014	Jun. 30, 2014 7.75% Senior Notes Due 2022	Jun. 30, 2014 11.625% Senior Notes Due 2014	Jun. 30, 2014 7.125% Senior Notes Due 2016	Jun. 30, 2014 March 31, 2014 and June 30, 2014 [Member]	Jun. 30, 2014 September 30, 2013 through June 30, 2014 [Member]	Jun. 30, 2014 September 30, 2014 and each fiscal quarter thereafter [Member]
Debt Instrument [Line Items]
Issuance of senior notes								$ 200.0	$ 275.0					$ 464.6
Interest rate									7.75%				7.75%	11.625%	7.125%
Debt Instrument, Maturity Date									Feb. 15, 2019				Oct. 15, 2022
Deb tInstrument Maturity Year														2014	2016
Senior notes, aggregate principal amount								475.0					300.0
Debt instrument, purchase price as a percentage of principal amount								101.00%	100.00%
Portion of the net proceeds from the offering to be funded										186.3
Debt instrument, redemption price									100.00%				100.00%
Percent redeemable									35.00%				35.00%
Redemption price percentage of senior note									107.75%				107.75%
Minimum amount outstanding after redemption									65.00%				65.00%
Maximum period for redemption on senior note (in days)									90 days				90 days
Debt instrument, repurchase price, percentage on principal amount plus accrued and unpaid interest									101.00%				101.00%
Secured revolving credit facility	250.0		225.0								165.0	30.0
Increase in total credit	100.0
Marginal interest rate				1.50%	2.50%	2.50%	3.50%
Commitment fee	0.50%
Minimum consolidated interest coverage ratio floor	2.50
Maximum consolidated leverage ratio ceiling																4.25		4.00
Maximum consolidated senior secured leverage ratio																	1.75	2.00
Revolver
Letters of credit outstanding under the Credit Agreement	37.7
Total Available Credit under the agreement	$ 212.3
Minimum Debt service coverage ratio	1.05

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Property And Equipment (Tables)

6 Months Ended

Jun. 30, 2014

Property Plant And Equipment [Abstract]

Property And Equipment

	June 30, 2014		December 31, 2013
Land	$	17,316	$	17,800
Buildings and improvements		66,593		65,702
Well service units and equipment		467,651		498,846
Fluid services equipment		257,566		258,371
Brine and fresh water stations		15,007		13,496
Frac/test tanks		318,633		275,603
Pumping equipment		310,579		299,300
Construction equipment		15,908		15,677
Contract drilling equipment		106,664		104,958
Disposal facilities		149,365		143,459
Light vehicles		64,879		64,942
Rental equipment		73,150		70,738
Software		21,010		23,360
Other		19,189		16,754
		1,903,510		1,869,006
Less accumulated depreciation and amortization		980,278		940,969
Property and equipment, net	$	923,232	$	928,037

Schedule Of Property, Plant And Equipment Under Capital Lease

	June 30, 2014		December 31, 2013
Light vehicles	$	42,551	$	39,970
Contract drilling equipment		4,223		4,223
Well service units and equipment		985		1,554
Fluid services equipment		119,870		121,051
Pumping equipment		28,445		29,080
Construction equipment		898		1,005
Software		17,120		17,120
Other		70		70
		214,162		214,073
Less accumulated amortization		87,759		77,340
	$	126,403	$	136,733

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Consolidated Statements of Cash Flows (USD $) In Thousands, unless otherwise specified	6 Months Ended
	Jun. 30, 2014	Jun. 30, 2013
Cash flows from operating activities:
Net income (loss)	$ 536	$ (21,574)
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	103,490	101,848
Accretion on asset retirement obligation	64	55
Change in allowance for doubtful accounts	(336)	224
Amortization of deferred financing costs	1,605	1,512
Amortization of premium on notes	(118)	(108)
Non-cash compensation	7,121	6,129
Loss on disposal of assets	237	1,879
Deferred income taxes	701	(10,755)
Changes in operating assets and liabilities, net of acquisitions:
Accounts receivable	(28,170)	(18,346)
Inventories	(6,720)	158
Prepaid expenses and other current assets	(3,917)	(2,730)
Other assets	(824)	229
Accounts payable	9,229	(4,874)
Income tax receivable	269	(791)
Other liabilities	3,761	2,395
Accrued expenses	7,083	13,118
Net cash provided by operating activities	94,011	68,369
Cash flows from investing activities:
Purchase of property and equipment	(107,384)	(77,599)
Proceeds from sale of mutual fund		5,635
Proceeds from sale of assets	25,875	7,658
Payments for other long-term assets	(673)	(569)
Payments for businesses, net of cash acquired		(16,463)
Net cash used in investing activities	(82,182)	(81,338)
Cash flows from financing activities:
Payments of debt	(22,346)	(22,632)
Purchase of treasury stock	(6,243)	(3,528)
Tax withholding from exercise of stock options	(362)	(154)
Exercise of employee stock options	4,646	456
Deferred loan costs and other financing activities	(62)	(119)
Net cash used in financing activities	(24,367)	(25,977)
Net decrease in cash and equivalents	(12,538)	(38,946)
Cash and cash equivalents - beginning of period	111,532	134,565
Cash and cash equivalents - end of period	$ 98,994	$ 95,619

XML

Consolidated Balance Sheets (Parenthetical) (USD $) In Thousands, except Share data, unless otherwise specified	Jun. 30, 2014	Dec. 31, 2013
Consolidated Balance Sheets [Abstract]
Allowance for trade accounts receivable	$ 3,339	$ 3,675
Unamortized premium on notes	$ 1,341	$ 1,459
Preferred stock, par value	$ 0.01	$ 0.01
Preferred stock, shares authorized	5,000,000	5,000,000
Preferred stock, shares issued	0	0
Common stock, par value	$ 0.01	$ 0.01
Common stock, shares authorized	80,000,000	80,000,000
Common stock, shares issued	43,500,032	43,500,032
Common stock, shares outstanding	43,201,279	42,226,088
Treasury stock, shares	298,753	1,273,944

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Earnings Per Share

6 Months Ended

Jun. 30, 2014

Earnings Per Share [Abstract]

Earnings Per Share

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 unaudited basic and diluted earnings per share (in thousands, except share data):

	Three months ended June 30,				Six months ended June 30,
	2014		2013		2014		2013
	(Unaudited)				(Unaudited)
Numerator (both basic and diluted):
Net income (loss)	$	2,444	$	(12,797)	$	536	$	(21,574)
Denominator:
Denominator for basic earnings per share		41,341,888		40,336,229		40,850,970		40,411,887
Stock options		101,446		—		146,354		—
Unvested restricted stock		600,113		—		351,395		—
Denominator for diluted earnings per share		42,043,447		40,336,229		41,348,719		40,411,887
Basic earnings per common share:	$	0.06	$	(0.32)	$	0.01	$	(0.53)
Diluted earnings per common share:	$	0.06	$	(0.32)	$	0.01	$	(0.53)

Stock options and unvested restricted stock shares of approximately 979,936 and911,162 were excluded in the computation of diluted earnings per share for the three and six months ended June 30, 2013, respectively as the effect would have been anti-dilutive.

XML

Document and Entity Information	6 Months Ended
	Jun. 30, 2014	Jul. 28, 2014
Document Documentand Entity Information [Abstract]
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Jun. 30, 2014
Document Fiscal Year Focus	2014
Document Fiscal Period Focus	Q2
Entity Registrant Name	BASIC ENERGY SERVICES INC
Entity Central Index Key	0001109189
Current Fiscal Year End Date	--12-31
Entity Filer Category	Accelerated Filer
Entity Common Stock, Shares Outstanding		43,200,758
Amendment Flag	false

XML

Business Segment Information

6 Months Ended

Jun. 30, 2014

Business Segment Information [Abstract]

Business Segment Information

11. Business Segment Information

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

Completion and Remedial Services: This segment utilizes a fleet of pumping units, air compressor packages specially configured for underbalanced drilling operations, coiled tubing services, nitrogen services, 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.

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.

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

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						Contract		Corporate and
	Services		Well Servicing		Fluid Services		Drilling		Other		Total
Three Months Ended June 30, 2014 (Unaudited)
Operating revenues	$	164,366	$	89,629	$	90,314	$	15,353	$	—	$	359,662
Direct operating costs		(102,617)		(64,748)		(65,055)		(10,510)		—		(242,930)
Segment profits	$	61,749	$	24,881	$	25,259	$	4,843	$	—	$	116,732
Depreciation and amortization	$	16,040	$	13,939	$	15,926	$	3,214	$	2,666	$	51,785
Capital expenditures (excluding acquisitions)	$	49,913	$	14,109	$	5,620	$	2,701	$	1,934	$	74,277
Three Months Ended June 30, 2013 (Unaudited)
Operating revenues	$	132,216	$	93,921	$	85,601	$	13,985	$	—	$	325,723
Direct operating costs		(85,847)		(67,600)		(59,296)		(9,769)		—		(222,512)
Segment profits	$	46,369	$	26,321	$	26,305	$	4,216	$	—	$	103,211
Depreciation and amortization	$	15,753	$	15,568	$	14,818	$	3,318	$	2,610	$	52,067
Capital expenditures (excluding acquisitions)	$	10,596	$	9,675	$	11,238	$	(42)	$	6,259	$	37,726
Six Months Ended June 30, 2014 (Unaudited)
Operating revenues	$	301,851	$	182,541	$	183,149	$	28,877	$	—	$	696,418
Direct operating costs		(189,097)		(134,508)		(131,837)		(19,675)		—		(475,117)
Segment profits	$	112,754	$	48,033	$	51,312	$	9,202	$	—	$	221,301
Depreciation and amortization	$	32,044	$	27,848	$	31,851	$	6,420	$	5,327	$	103,490
Capital expenditures (excluding acquisitions)	$	65,308	$	21,804	$	12,859	$	3,609	$	3,804	$	107,384
Identifiable assets	$	466,636	$	267,909	$	310,185	$	57,617	$	456,509	$	1,558,856
Six Months Ended June 30, 2013 (Unaudited)
Operating revenues	$	250,577	$	181,596	$	169,931	$	27,970	$	—	$	630,074
Direct operating costs		(164,854)		(132,603)		(117,171)		(18,932)		—		(433,560)
Segment profits	$	85,723	$	48,993	$	52,760	$	9,038	$	—	$	196,514
Depreciation and amortization	$	30,815	$	30,452	$	28,985	$	6,490	$	5,106	$	101,848
Capital expenditures (excluding acquisitions)	$	23,583	$	21,700	$	20,356	$	3,051	$	8,909	$	77,599
Identifiable assets	$	440,904	$	290,653	$	323,709	$	61,936	$	471,793	$	1,588,995

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

	Three months ended June 30,				Six months ended June 30,
	2014		2013		2014		2013
Segment profits	$	116,732	$	103,211	$	221,301	$	196,514
General and administrative expenses		(42,953)		(49,321)		(82,512)		(91,278)
Depreciation and amortization		(51,785)		(52,067)		(103,490)		(101,848)
Loss on disposal of assets		(916)		(790)		(237)		(1,879)
Operating income	$	21,078	$	1,033	$	35,062	$	1,509

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Consolidated Statements of Operations (USD $) In Thousands, except Per Share data, unless otherwise specified	3 Months Ended		6 Months Ended
	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Revenues:
Total revenues	$ 359,662	$ 325,723	$ 696,418	$ 630,074
Expenses:
General and administrative, including stock-based compensation of $3,733 and $3,312 in three months and $7,121 and $6,129 in the six months ended June 30, 2014 and 2013, respectively	42,953	49,321	82,512	91,278
Depreciation and amortization	51,785	52,067	103,490	101,848
Loss on disposal of assets	916	790	237	1,879
Total expenses	338,584	324,690	661,356	628,565
Operating income	21,078	1,033	35,062	1,509
Other income (expense):
Interest expense	(16,566)	(16,806)	(33,425)	(33,614)
Interest income	13	13	26	30
Other income	107	173	473	335
Income (loss) before income taxes	4,632	(15,587)	2,136	(31,740)
Income tax benefit (expense)	(2,188)	2,790	(1,600)	10,166
Net income (loss)	2,444	(12,797)	536	(21,574)
Earnings per share of common stock:
Basic	$ 0.06	$ (0.32)	$ 0.01	$ (0.53)
Diluted	$ 0.06	$ (0.32)	$ 0.01	$ (0.53)
Completion And Remedial Services [Member]
Revenues:
Total revenues	164,366	132,216	301,851	250,577
Expenses:
Cost of Revenue	102,617	85,847	189,097	164,854
Depreciation and amortization	16,040	15,753	32,044	30,815
Well Servicing [Member]
Revenues:
Total revenues	89,629	93,921	182,541	181,596
Expenses:
Cost of Revenue	64,748	67,600	134,508	132,603
Depreciation and amortization	13,939	15,568	27,848	30,452
Fluid Services [Member]
Revenues:
Total revenues	90,314	85,601	183,149	169,931
Expenses:
Cost of Revenue	65,055	59,296	131,837	117,171
Depreciation and amortization	15,926	14,818	31,851	28,985
Contract Drilling
Revenues:
Total revenues	15,353	13,985	28,877	27,970
Expenses:
Cost of Revenue	$ 10,510	$ 9,769	$ 19,675	$ 18,932

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Long-Term Debt

6 Months Ended

Jun. 30, 2014

Long-Term Debt [Abstract]

Long-Term Debt

5. Long-Term Debt

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

	June 30, 2014		December 31, 2013
Credit Facilities:
Revolver		—		—
7.75% Senior Notes due 2019	$	475,000	$	475,000
7.75% Senior Notes due 2022		300,000		300,000
Unamortized premium		1,341		1,459
Capital leases and other  notes		103,039		111,626
		879,380		888,085
Less current portion		40,577		41,394
	$	838,803	$	846,691

7.75% Senior Notes due 2019

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

The 2019 Notes and guarantees 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”).

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. Basic received net proceeds from the issuance of the 2019 Notes of approximately $464.6 million after premiums and offering expenses. Basic used a portion of the net proceeds from the February 2011 offering to fund its tender offer and consent solicitation for its 11.625% Senior Secured Notes due 2014 and to redeem any of the Senior Secured Notes not purchased in the tender offer. Basic 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 the remainder 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, National Association, as trustee. Interest on the 2019 Notes accrues at a rate of 7.75% per year and 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 Basic’s ability and the ability of certain of its 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 Basic’s restricted subsidiaries to Basic; 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. At June 30, 2014, Basic was in compliance with the restrictive covenants under the 2019 Notes Indenture.

Basic may, at its 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, Basic, at its option, may redeem up to 35% of the aggregate principal amount of the 2019 Notes 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 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, Basic 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, Basic 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, Basic 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 Basic’s current subsidiaries other than three immaterial subsidiaries. The 2022 Notes and the guarantees rank (i) equally in right of payment with any of Basic’s and the subsidiary guarantors’ existing and future senior indebtedness, including Basic’s existing 2019 Notes and the related guarantees, and (ii) effectively junior to all existing or future liabilities of Basic’s subsidiaries that do not guarantee the 2022 Notes and to Basic’s and the subsidiary guarantors’ existing or future secured indebtedness to the extent of the value of the collateral therefore.  

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. Basic received net proceeds from the issuance of the 2022 Notes of approximately $293.3 million after discounts and offering expenses. Basic used a portion of the net proceeds from the offering to fund its tender offer and consent solicitation for its 7.125% Senior Notes due 2016 (the “2016 Notes”) and to redeem any of the 2016 Notes not purchased in the tender offer. The remainders 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 Basic, the guarantors party thereto and Wells Fargo Bank, National Association, as trustee. Interest on the 2022 Notes accrues at a rate of 7.75% per year and 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 Basic’s ability and the ability of certain of its 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 Basic’s restricted subsidiaries to Basic; 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 June 30, 2014, Basic was in compliance with the restrictive covenants under the 2022 Notes Indenture.

Basic may, at its 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, Basic, at its option, may redeem up to 35% of the aggregate principal amount of the 2022 Notes 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 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, Basic 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, Basic 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, Basic terminated the 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 Basic 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 Basic’s current subsidiaries, other than three immaterial subsidiaries, and are secured by substantially all of Basic’s and its subsidiary guarantors’ assets as collateral under a related Security Agreement (the “Security Agreement”). As of June 30, 2014 and December 31, 2013, the non-guarantor subsidiaries held no assets and performed no operations. On July 15, 2011, Basic exercised the accordion feature and amended the Credit Agreement to increase Basic’s total credit available from         $165.0 million to $225.0 million. On April 5, 2012, Basic amended the Credit Agreement to increase the aggregate amount of commitments thereunder to $250.0 million. On October 1, 2012, Basic further amended the Credit Agreement to permit the transactions contemplated by the offering of 2022 Notes and the tender offer and redemption of 2016 Notes. On August 29, 2013, Basic further amended the Credit Agreement to amend the required leverage ratios.

Borrowings under the Credit Agreement mature on January 15, 2016, and Basic has the ability at any time to prepay the Credit Agreement without premium or penalty. At Basic’s 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 2.50% based on Basic’s leverage ratio or (ii) Eurodollar loans, at a variable base interest rate plus a margin ranging from 2.50% to 3.50% based on Basic’s leverage ratio. Basic 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 Basic’s ability and the ability of certain of its 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 Basic may make and require Basic 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 as follows:

o for the four fiscal quarters ending September 30, 2013 and December 31, 2013, a maximum consolidated leverage ratio not to exceed 4.50 to 1.00;

ofor the four fiscal quarters ending March 31, 2014 and June 30, 2014, a maximum consolidated leverage ratio not to exceed 4.25 to 1.00; and

ofor the four fiscal quarters ending September 30, 2014 and each fiscal quarter thereafter, a maximum consolidated leverage ratio not to exceed 4.00 to 1.00; and

· a maximum consolidated senior secured leverage ratio as follows:

ofor the four fiscal quarters ending September 30, 2013 through June 30, 2014, a maximum consolidated senior secured leverage ratio not to exceed 1.75 to 1.00; and

ofor the four fiscal quarters ending September 30, 2014 and each fiscal quarter thereafter, a maximum consolidated senior secured leverage ratio not to exceed 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.

Basic had no borrowings and $37.7 million of letters of credit outstanding under the Credit Agreement as of June 30, 2014, giving Basic $212.3 million of available borrowing capacity. At June 30, 2014, Basic was in compliance with the 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 June 30, 2014, Basic was in compliance with this covenant.

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

	Six Months Ended June 30,
	2014		2013
Cash payments for interest	$	30,780	$	31,612
Commitment and other fees paid		1,156		893
Amortization of debt issuance costs and discount or premium on notes		1,487		1,404
Change in accrued interest		(5)		9
Other		7		(304)
	$	33,425	$	33,614

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Property And Equipment

6 Months Ended

Jun. 30, 2014

Property Plant And Equipment [Abstract]

Property And Equipment

4. Property and Equipment

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

	June 30, 2014		December 31, 2013
Land	$	17,316	$	17,800
Buildings and improvements		66,593		65,702
Well service units and equipment		467,651		498,846
Fluid services equipment		257,566		258,371
Brine and fresh water stations		15,007		13,496
Frac/test tanks		318,633		275,603
Pumping equipment		310,579		299,300
Construction equipment		15,908		15,677
Contract drilling equipment		106,664		104,958
Disposal facilities		149,365		143,459
Light vehicles		64,879		64,942
Rental equipment		73,150		70,738
Software		21,010		23,360
Other		19,189		16,754
		1,903,510		1,869,006
Less accumulated depreciation and amortization		980,278		940,969
Property and equipment, net	$	923,232	$	928,037

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):

	June 30, 2014		December 31, 2013
Light vehicles	$	42,551	$	39,970
Contract drilling equipment		4,223		4,223
Well service units and equipment		985		1,554
Fluid services equipment		119,870		121,051
Pumping equipment		28,445		29,080
Construction equipment		898		1,005
Software		17,120		17,120
Other		70		70
		214,162		214,073
Less accumulated amortization		87,759		77,340
	$	126,403	$	136,733

Amortization of assets held under capital leases of approximately $8.8 million and $7.6 million for the three months ended June 30, 2014 and 2013, respectively, and $17.3 million and $14.9 million for the six months ended June 30, 2013 and 2012, respectively, is included in depreciation and amortization expense in the consolidated statements of operations.

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Acquisitions (Tables)

12 Months Ended

Dec. 31, 2013

Acquisitions [Abstract]

Schedule Of Values At Date Of Acquisition

		Total Cash Paid
	Closing Date	(net of cash acquired)
Atlas Environmental Consulting, Inc. and Atlas Oilfield Construction Company, LLC	February 19, 2013	$	12,979
Petroleum Water Solutions, LLC	February 22, 2013		3,288
Karnes Water Management, LLC	December 31, 2013		5,200
Total 2013		$	21,467

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Supplemental Schedule Of Cash Flow Information

6 Months Ended

Jun. 30, 2014

Supplemental Schedule Of Cash Flow Information [Abstract]

Supplemental Schedule Of Cash Flow Information

12. Supplemental Schedule of Cash Flow Information

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

	For The Six Months Ended June 30
	2014		2013
	(In thousands)
Capital leases issued for equipment	$	13,759	$	27,014
Asset retirement obligation additions	$	64	$	78

Basic paid no income taxes during the six months ended June 30, 2014 and 2013. Basic paid interest of approximately $30.8 million and $31.6 million during the six months ended June 30, 2014 and 2013, respectively.

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Incentive Plan

6 Months Ended

Jun. 30, 2014

Incentive Plan [Abstract]

Incentive Plan

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 10,350,000 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 June 30, 2014 and 2013, compensation expense related to share-based arrangements was approximately $3.7 million and $3.3 million, respectively. For compensation expense recognized during the three months ended June 30, 2014 and 2013, Basic recognized a tax benefit of approximately $1.8 million and  $593,000, respectively. During the six months ended June 30, 2014 and 2013, compensation expense related to share-based arrangements was approximately $7.1 million and $6.1 million, respectively. For compensation expense recognized during the six months ended June 30, 2014 and 2013, Basic recognized a tax benefit of approximately $2.8 million and $2.0 million, respectively.

As of June 30, 2014, there was approximately $32.2 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 2.5 years. The total fair value of share-based awards vested during the six months ended June 30, 2014 and 2013 was approximately $20.3 million and $11.6 million, respectively. During the three months ended June 30, 2014 and 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 approximately $4.0 million and $810,000 at June 30, 2014 and 2013, respectively.  

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 June 30, 2014 and the changes during the six months then ended:

				Weighted
				Average
				Remaining	Aggregate
	Number of	Weighted		Contractual	Intrinsic
	Options	Average		Term	Value
	Granted	Exercise Price		(Years)	(000's)
Non-statutory stock options:
Outstanding, beginning of period	530,000	$	18.15
Options granted	—		—
Options forfeited	—		—
Options exercised	(250,000)		17.14
Options expired	—		—
Outstanding, end of period	280,000	$	19.05	1.40	$	2,848
Exercisable, end of period	280,000	$	19.05	1.40	$	2,848
Vested or expected  to vest, end of period	280,000	$	19.05	1.40	$	2,848

The total intrinsic value of share options exercised during the six months ended June 30, 2014 and 2013 was approximately $2.2 million and $501,000, respectively.

Cash received from share option exercises under the Plan was approximately $4.3 million and $302,000 for the six months ended June 30, 2014 and 2013, respectively. During thesix months ended June 30, 2014 and2013 there was no excess tax benefit due to the NOL. If there was no NOL, the excess tax expense would have been $57,000 for the six months ended June 30, 2014 and excess tax benefit would have been $53,000 for the six months ended June 30, 2013.

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

Restricted Stock Awards

On March 12, 2014, 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, 2014 through December 31, 2014, 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 286,518 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, 2016. As of June 30, 2014, 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 June 30, 2014 and changes during the six months ended June 30, 2014 is presented in the following table:

		Weighted Average
	Number of	Grant Date Fair
Nonvested Shares	Shares	Value Per Share
Nonvested at beginning of period	2,089,597	$	14.93
Granted during period	1,013,125		25.14
Vested during period	(843,781)		14.78
Forfeited during period	(17,515)		20.89
Nonvested at end of period	2,241,426	$	19.55

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Commitments and Contingencies

6 Months Ended

Jun. 30, 2014

Commitments And Contingencies [Abstract]

Commitments and Contingencies

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

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. In the second quarter of 2014, Basic was involved in the settlement of a lawsuit related to the contractual indemnification of a customer for $4.6 million, including legal fees.

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 $5.0 million, $1.0 million, and $400,000, 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 June 30, 2014 and December 31, 2013, self-insured risk accruals totaled approximately $33.0 million net of a $42,000 receivable for medical and dental coverage and $26.1 million net of a $230,000 receivable for medical and dental coverage, respectively.

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Stockholders' Equity

6 Months Ended

Jun. 30, 2014

Stockholders' Equity [Abstract]

Stockholders' Equity

7. Stockholders’ Equity

Common Stock

At June 30, 2014 and December 31, 2013, Basic had 80,000,000 shares of common stock, par value $0.01 per share, authorized.

During the year ended 2013, Basic issued 107,250 shares of common stock from treasury stock for the exercise of stock options and no shares of newly issued common stock for the exercise of stock options.

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. The Compensation Committee of Basic’s Board of Directors approved grants of performance-based stock awards to certain members of management. In February 2014, it was determined that 283,358 shares, or approximately 106% of the target number of shares, were earned based on 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. These restricted shares remain subject to vesting over a three-year period with the first shares vesting on March 15, 2015.

In March 2014, Basic granted various employees 414,900 restricted shares of common stock that vest over a three-year period and 294,909 shares that vest over a four-year period.

During the six months ended June 30, 2014, Basic issued 250,000 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 250,461 shares through net share settlements during the first six months of 2014 and 357,714 shares through net share settlements during the first six months of 2013.

Preferred Stock

At June 30, 2014 and December 31, 2013, Basic had 5,000,000 shares of preferred stock, par value $0.01 per share, authorized, of which none was designated, issued or outstanding.

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Related Party Transactions

6 Months Ended

Jun. 30, 2014

Related Party Transactions [Abstract]

Related Party Transactions

9. Related Party Transactions

Basic had receivables from employees of approximately $47,000 and $50,000 as of June 30, 2014 and December 31, 2013, respectively. During 2006, Basic entered into a lease agreement with Darle Vuelta Cattle Co., LLC, an affiliate of a director, for approximately $69,000 per year. The term of the lease 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 lease 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.

Basic entered into a joint venture agreement with a family member of an executive officer to form an entity in 2010. Basic held 80% of the equity in the joint venture, and accounted for the entity as a consolidated investment. In 2013, Basic funded approximately $2.4 million for this joint venture. The entity had only research and development activities in 2013. This joint venture agreement was terminated in November 2013, and Basic now owns 100% of the entity.

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Property And Equipment (Property And Equipment) (Details) (USD $) In Thousands, unless otherwise specified	Jun. 30, 2014	Dec. 31, 2013
Property, Plant And Equipment [Line Items]
Property and equipment, gross	$ 1,903,510	$ 1,869,006
Less accumulated depreciation and amortization	980,278	940,969
Property and equipment, net	923,232	928,037
Land
Property, Plant And Equipment [Line Items]
Property and equipment, gross	17,316	17,800
Buildings And Improvements
Property, Plant And Equipment [Line Items]
Property and equipment, gross	66,593	65,702
Well Service Units And Equipment
Property, Plant And Equipment [Line Items]
Property and equipment, gross	467,651	498,846
Fluid Services Equipment
Property, Plant And Equipment [Line Items]
Property and equipment, gross	257,566	258,371
Brine And Fresh Water Stations
Property, Plant And Equipment [Line Items]
Property and equipment, gross	15,007	13,496
Frac/Test Tanks
Property, Plant And Equipment [Line Items]
Property and equipment, gross	318,633	275,603
Pumping Equipment
Property, Plant And Equipment [Line Items]
Property and equipment, gross	310,579	299,300
Construction Equipment
Property, Plant And Equipment [Line Items]
Property and equipment, gross	15,908	15,677
Contract Drilling Equipment
Property, Plant And Equipment [Line Items]
Property and equipment, gross	106,664	104,958
Disposal Facilities
Property, Plant And Equipment [Line Items]
Property and equipment, gross	149,365	143,459
Light Vehicles
Property, Plant And Equipment [Line Items]
Property and equipment, gross	64,879	64,942
Rental Equipment
Property, Plant And Equipment [Line Items]
Property and equipment, gross	73,150	70,738
Software
Property, Plant And Equipment [Line Items]
Property and equipment, gross	21,010	23,360
Other
Property, Plant And Equipment [Line Items]
Property and equipment, gross	$ 19,189	$ 16,754

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Summary of Significant Accounting Policies (Policies)

6 Months Ended

Jun. 30, 2014

Accounting Policies [Abstract]

Principles of Consolidation

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

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

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, 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.  

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.

Fluid Services — Fluid services consists primarily of the sale, transportation, treatment, storage and disposal of fluids used in the 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.

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, a “footage” contract, in which an agreed upon rate is charged per the number of feet drilled, or a “turnkey” contract, in which an agreed upon single rate is charged for a drilled well.

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

Inventories

Inventories

Rental and fishing tool inventories, consisting mainly of grapples, mills 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

   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

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

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 $23.4 million net of accumulated amortization of $8.8million, and  $23.3 million net of accumulated amortization of $7.2 million at June 30, 2014 and December 31, 2013, respectively. Amortization of deferred debt costs totaled approximately $806,000 and $759,000for the three months ended June 30, 2014 and 2013, respectively. Amortization of deferred debt cost totaled approximately $1.6 million and $1.5 million for the six months ended June 30, 2014 and 2013, respectively.

Goodwill and Other Intangible Assets

Goodwill and Other Intangible Assets

Basic had trade names of $1.9 million as of June 30, 2014 and December 31, 2013.  

Additions to goodwill during the six months ended June 30, 2014 were primarily due to adjustments to the preliminary purchase price allocations for acquisitions completed in the prior year. The changes in the carrying amount of goodwill for the six months ended June 30, 2014 were as follows (in thousands):

	Completion
	And Remedial
	Services		Well Servicing		Fluid Services		Contract Drilling		Total
Balance as of December 31, 2013	$	77,697	$	6,622	$	26,595	$	—	$	110,914
Goodwill additions		—		—		1,369		—		1,369
Balance as of June 30, 2014	$	77,697	$	6,622	$	27,964	$	—	$	112,283

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 $86.9 million and $87.1 million at June 30, 2014 and December 31, 2013, respectively. The gross carrying amount of non-compete agreements subject to amortization totaled approximately $12.9 million and $13.0 million at June 30, 2014 and December 31, 2013, respectively. The gross carrying amount of other intangible assets subject to amortization was $2.1 million at June 30, 2014 and December 31, 2013. Accumulated amortization related to these intangible assets totaled approximately $30.9 million and $26.6 million at June 30, 2014 and December 31, 2013, respectively. Amortization expense for the three months ended June 30, 2014 and 2013 was approximately $2.1 million and $2.2 million, respectively. Amortization expense for the six months ended June 30, 2014 and 2013 was approximately $4.3 million and $4.2 million, respectively. Other intangibles net of accumulated amortization allocated to reporting units as of June 30, 2014 were $53.1 million, $5.6 million, $10.8 million and $3.6 million for completion and remedial services, well servicing, fluid services, and contract drilling, respectively. Customer relationships are amortized over a 15-year life, non-compete agreements are amortized over a five-year life, developed technology is amortized over a 15-year life and rig engineering plans are amortized over a 15-year life.

Stock-Based Compensation

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.

Certain Basic share-based awards also provide for potential reissuances of unvested shares otherwise forfeited at retirement, provided the recipient also enters into required non-competition and severance agreements.  Notwithstanding these service conditions, for expense recognition we generally deem the vesting period after the retirement to be non-substantive, and treat the requisite service period from the grant date to the first date when the employee is eligible to retire. 

Income Taxes

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

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 six months ended June 30, 2014 or 2013.

Asset Retirement Obligations

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

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

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

Recent Accounting Pronouncements

In April 2014, the FASB issued ASU No. 2014-08, “Presentation of Financial Statements (Topic 205) and Property, Plant, and Equipment (Topic 360): Reporting Discontinued Operations and Disclosures of Disposals of Components of an Entity." ASU 2014-08 raises the threshold for a disposal to qualify as a discontinued operation and requires new disclosures of both discontinued operations and certain other disposals that do not meet the definition of a discontinued operation. It is effective for annual periods beginning on or after December 15, 2014. Early adoption is permitted but only for disposals that have not been reported in financial statements previously issued. Basic does not believe this pronouncement will have a material impact on its consolidated financial statements.

In May 2014, the FASB issued ASU No. 2014-09, “Revenue from Contracts with Customers (Topic 606).” ASU 2014-09 provides a framework that replaces the existing revenue recognition guidance. It is effective for annual periods beginning after December 15, 2016, including interim periods within that reporting period. Basic will determine if this pronouncement will have a material impact on its consolidated financial statements.

In June 2014, the FASB issued ASU No. 2014-12,  “Compensation-Stock Compensation (Topic 718): Accounting for Share-Based Payments When the Terms of an Award Provide That a Performance Target Could Be Achieved after the Requisite Service Period.” ASU 2014-12 requires a reporting entity to treat a performance target that affects vesting and that could be achieved after the requisite service period as a performance condition. It is effective for annual periods, and interim periods within those annual periods, beginning after December 15, 2015. Early adoption is permitted. ASU 2014-12 may be adopted either prospectively for share-based payment awards granted or modified on or after the effective date, or retrospectively, using a modified retrospective approach. The modified retrospective approach would apply to share-based payment awards outstanding as of the beginning of the earliest annual period presented in the financial statements on adoption, and to all new or modified awards thereafter. Basic will determine if this pronouncement will have a material impact on its consolidated financial statements.

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Incentive Plan (Tables)

6 Months Ended

Jun. 30, 2014

Incentive Plan [Abstract]

Summary Of Stock Options

				Weighted
				Average
				Remaining	Aggregate
	Number of	Weighted		Contractual	Intrinsic
	Options	Average		Term	Value
	Granted	Exercise Price		(Years)	(000's)
Non-statutory stock options:
Outstanding, beginning of period	530,000	$	18.15
Options granted	—		—
Options forfeited	—		—
Options exercised	(250,000)		17.14
Options expired	—		—
Outstanding, end of period	280,000	$	19.05	1.40	$	2,848
Exercisable, end of period	280,000	$	19.05	1.40	$	2,848
Vested or expected  to vest, end of period	280,000	$	19.05	1.40	$	2,848

Summary Of Non-Vested Shares

		Weighted Average
	Number of	Grant Date Fair
Nonvested Shares	Shares	Value Per Share
Nonvested at beginning of period	2,089,597	$	14.93
Granted during period	1,013,125		25.14
Vested during period	(843,781)		14.78
Forfeited during period	(17,515)		20.89
Nonvested at end of period	2,241,426	$	19.55

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Supplemental Schedule Of Cash Flow Information (Narrative) (Details) (USD $)	6 Months Ended
	Jun. 30, 2014	Jun. 30, 2013
Supplemental Schedule Of Cash Flow Information [Abstract]
Interest paid	$ (30,780,000)	$ (31,612,000)
Income Taxes Paid	$ 0	$ 0

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Incentive Plan (Narrative) (Details) (USD $)	0 Months Ended	3 Months Ended		6 Months Ended
	Mar. 12, 2014	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Shares available for issuance		10,350,000		10,350,000
Share Based Compensation Expenses		$ 3,700,000	$ 3,300,000	$ 7,100,000	$ 6,100,000
Tax benefit		1,800,000	593,000	2,800,000	2,000,000
Unrecognized compensation related to non-vested share-based compensation arrangements		32,200,000		32,200,000
Weighted-average period over which unrecognized compensation cost related to non-vested share-based compensation arrangements is expected to be recognized, in years				2 years 6 months
Total fair value of share-based awards vested				20,300,000	11,600,000
Excess tax benefit due to carryforward loss				0
Total intrinsic value of options exercised				2,200,000	501,000
Cash received from option exercises				4,646,000	456,000
Target number of shares to be issued	286,518
Percentage of target number of performance-based awards will be earned				100.00%
Minimum [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Percentage of target number of shares to be issued				0.00%
Maximum [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Percentage of target number of shares to be issued				150.00%
Stock Options [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Excess tax benefit if there was no net operating loss carry forwards				57,000	53,000
Options expiration period, (in years)				10 years
Cash received from option exercises				4,300,000	302,000
Stock Options [Member] | Minimum [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Vesting periods				3 years
Stock Options [Member] | Maximum [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Vesting periods				5 years
Restricted Stock Awards [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Excess tax benefit if there was no net operating loss carry forwards				$ 4,000,000	$ 810,000
Vesting periods				3 years

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Consolidated Statements of Operations (Parenthetical) (USD $) In Thousands, unless otherwise specified	3 Months Ended		6 Months Ended
	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Consolidated Statements of Operations [Abstract]
Stock-based compensation included in general and administrative expense	$ 3,733	$ 3,312	$ 7,121	$ 6,129

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Acquisitions

6 Months Ended

Jun. 30, 2014

Acquisitions [Abstract]

Acquisitions

3. Acquisitions

During 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. During the six months ended June 30, 2014, Basic did not complete any acquisitions. The following table summarizes the final values for the acquisitions at the date of acquisition (in thousands):

		Total Cash Paid
	Closing Date	(net of cash acquired)
Atlas Environmental Consulting, Inc. and Atlas Oilfield Construction Company, LLC	February 19, 2013	$	12,979
Petroleum Water Solutions, LLC	February 22, 2013		3,288
Karnes Water Management, LLC	December 31, 2013		5,200
Total 2013		$	21,467

The operations of each of the acquisitions listed above are included in Basic’s statement of operations as of each respective closing date.

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Earnings Per Share (Tables)

6 Months Ended

Jun. 30, 2014

Earnings Per Share [Abstract]

Computation Of Basic And Diluted Earnings Per Share

	Three months ended June 30,				Six months ended June 30,
	2014		2013		2014		2013
	(Unaudited)				(Unaudited)
Numerator (both basic and diluted):
Net income (loss)	$	2,444	$	(12,797)	$	536	$	(21,574)
Denominator:
Denominator for basic earnings per share		41,341,888		40,336,229		40,850,970		40,411,887
Stock options		101,446		—		146,354		—
Unvested restricted stock		600,113		—		351,395		—
Denominator for diluted earnings per share		42,043,447		40,336,229		41,348,719		40,411,887
Basic earnings per common share:	$	0.06	$	(0.32)	$	0.01	$	(0.53)
Diluted earnings per common share:	$	0.06	$	(0.32)	$	0.01	$	(0.53)

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Long-Term Debt (Schedule Of Interest Expense) (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended		6 Months Ended
	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Long-Term Debt [Abstract]
Cash payments for interest			$ (30,780)	$ (31,612)
Commitment and other fees paid			1,156	893
Amortization of debt issuance costs and discount or premium on notes			1,487	1,404
Change in accrued interest			(5)	9
Other			7	(304)
Total interest expense	$ 16,566	$ 16,806	$ 33,425	$ 33,614

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Fair Value Measurements

6 Months Ended

Jun. 30, 2014

Fair Value Measurements [Abstract]

Fair Value Measurements

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.