BASIC ENERGY SERVICES, INC. - Quarter Report: 2014 June (Form 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)

 

 

(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.

 

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

43,200,758 shares of the registrant’s Common Stock were outstanding as of July 28, 2014.  

 

 

 

 

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BASIC ENERGY SERVICES, INC.

Index to Form 10-Q 

 

 

 

 

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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:

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.

 

 

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PART I — FINANCIAL INFORMATION

ITEM 1. FINANCIAL STATEMENTS

Basic Energy Services, Inc.

Consolidated Balance Sheets 

(in thousands, except share data)

 

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)

 

 

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)

 

 

See accompanying notes to unaudited consolidated financial statements.

 

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Basic Energy Services, Inc.

Consolidated Statements of Cash Flows

(Unaudited)

(in thousands)

 

 

See accompanying notes to unaudited consolidated financial statements.

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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:

 

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.

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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.

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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 $8.8 million, 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 $759,000 for 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):

 

 

 

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):

 

 

 

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):

 

 

 

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):

 

 

 

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):

 

 

 

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:

 

 

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:

 

 

 

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:

 

 

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:

 

 

 

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:

 

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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:

 

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

o   for 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

o   for 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):

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

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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:

 

 

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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 and 2013 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:

 

 

 

 

 

 

 

 

 

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):

 

 

 

Stock options and unvested restricted stock shares of approximately 979,936 and 911,162 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):

 

 

 

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

 

 

 

 

 

 

 

 

 

 

 

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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:

 

 

 

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. These transactions, 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 at June 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 to 421 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):

 

 

 

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 has remained 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:

 

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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 three business acquisitions that complemented our existing business segments. These included, among others:

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

On February 16, 2013, we acquired all of the assets of Atlas Environmental Consulting, Inc. and Atlas Oilfield Construction Company, LLC for total cash consideration of $13.0 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 ended June 30, 2014 (dollars in thousands):

 

 

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 the first 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 ended June 30, 2014:   

 

 

 

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 ended June 30, 2014 (dollars in thousands):

 

 

 

 

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 $89,000 in 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 percentage remained 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 ended June 30, 2014:  

 

 

 

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 percentage remained flat at 32% in both 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 services by 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 to 351,000 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 2014 from 425 during the same period in 2013.  

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 second quarter of 2014 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 second quarter 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 at 28% 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 second quarter of 2014 from 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. Interest expense decreased to $16.6 million during the second quarter of 2014 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 decreased to 26% 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 guarantees 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.

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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:

 

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:

 

 

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:

 

 

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:

 

 

 

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:

 

 

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:

 

o   for 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

o   for 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 ended June 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):  

 

 

 

 

 

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ITEM 6.  EXHIBITS

 

 

 

 

*Incorporated by reference

#Filed with this report

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SIGNATURES

Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.

 

 

 

Date: July 28, 2014 

 

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Exhibit Index

 

*Incorporated by reference

#Filed with this report  

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