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 September 30, 2015 

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   ☒ 

42,612,129 shares of the registrant’s Common Stock were outstanding as of October 23,  2015.  

 

 

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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

September 30, 2015 (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. Certain information relating to our organization and footnote disclosures normally included in financial statements prepared in accordance with GAAP have been condensed or omitted in this Quarterly Report on Form 10-Q in accordance with GAAP and financial statement requirements promulgated by the U.S. Securities and Exchange Commission (“SEC”). The notes to the consolidated financial statements (unaudited) should be read in conjunction with the notes to the consolidated financial statements contained in the December 31, 2014 Form 10-K. 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, Ohio, California, Kentucky and Pennsylvania.

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. Management uses historical and other pertinent information to determine these estimates. Actual results could differ from those estimates. Areas where critical accounting estimates are made by management include:

 

 

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2. Acquisitions

In 2014 and during the first nine months of 2015, Basic acquired substantially all of the assets of the following business, which was accounted for using the purchase method of accounting. The following table summarizes the values for the acquisition at the date of acquisition (in thousands):

 

The operations of the acquisitions listed above are included in Basic’s consolidated statement of operations as of the each respective closing date. The pro forma effect of the acquisition completed in the first nine months of 2015 is not material, either individually or when aggregated, to the reported results of operations. The provisional value used with respect to Harbor Resources, LLC, Aerion Rental, LLC and Grey Rock Pressure Pumping, LLC will be finalized once the valuation of the tangible and intangible assets is complete.

3. Goodwill and Other Intangible Assets

Additions to goodwill during the nine months ended September 30, 2015 were primarily due to adjustments to the preliminary purchase price allocation for acquisitions completed in prior year.

    The Company performed a quarterly assessment of goodwill as of September 30, 2015. For step one of the impairment testing, the Company tested its reporting units for goodwill impairment. The Company’s well servicing, fluid services and contract drilling reporting units do not carry any goodwill, and were not subject to the test.

    To estimate the fair value of the reporting units, we primarily used level 1 and level 3 inputs from the fair value hierarchy, which included a weighting of the discounted cash flow method and the public company guideline method (level 3 inputs) of determining fair value of a business unit. In order to validate the reasonableness of the estimated fair values obtained for the reporting units, a reconciliation of fair value to market capitalization (level 1 inputs) was performed for each unit on a stand-alone basis. A control premium, derived from market transaction data, was used in this reconciliation to ensure that fair values were reasonably stated in conjunction with our capitalization. The measurement date for our common stock price and market capitalization was the closing price on September 30, 2015.

Based on the results of step one of the impairment test, impairment was indicated in the completion and remedial reporting unit. As such, the Company was required to perform step two assessment on the potentially impaired reporting unit. Step two requires the allocation of the estimated fair value to the tangible and intangible assets and liabilities of the respective reporting unit. This assessment indicated that goodwill of $81.9 million was considered impaired as of September 30, 2015. This non-cash charge eliminated all of the Company’s existing goodwill as of September 30, 2015. The changes in carrying amount of goodwill for the nine months ended September 30, 2015 were as follows (in thousands):

 

 

 

 

 

 

 

 

 

 

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Basic’s intangible assets were as follows (in thousands):

 

 

 

Amortization expense for the three months ended September 30, 2015 and 2014 was approximately $2.2 million and $2.1 million, respectively. Amortization expense for the nine months ended September 30, 2015 and 2014 was approximately $6.7 million and $6.4 million, respectively.

 

Intangible assets, net of accumulated amortization allocated to reporting units as of September 30, 2015 were as follows (in thousands):

 

 

Customer relationships are amortized over a 15-year life, non-compete agreements are amortized over a five-year life, and other intangible assets and trade names are amortized over a 15-year life.

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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 $10.2 million and $9.5 million for the three months ended September 30, 2015 and 2014, respectively and $31.4 million and $26.8 million for the nine months ended September 30, 2015 and 2014, respectively, is included in depreciation and amortization expense in the consolidated statements of operations.

 

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5. Long-Term Debt and Interest Expense

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

 

 

On April 21, 2015, Basic entered into an amendment to its existing $300 million Amended and Restated Credit Agreement (as so amended, the “Credit Agreement”) with a syndicate of lenders and Bank of America, N.A., as administrative agent for the lenders, that, among other things: (A) reduces the maximum aggregate commitments thereunder from $300 million to $250 million; (B) permits credit extensions under the Credit Agreement based on availability under a borrowing base comprised of eligible billed accounts receivable, eligible unbilled accounts receivable and eligible equipment of Basic; and (C) provides for the replacement of the existing financial covenants with new financial covenants, which apply only if availability under the Credit Agreement is less than the greater of (i) 25% of the aggregate commitments outstanding, or (ii) $62.5 million.  If availibilty is less than these amounts, Basic will be required to maintain (a) a consolidated senior secured leverage ratio not to exceed 2.50 to 1.00 and (b) a consolidated fixed charge coverage ratio not less than 1.00 to 1.00.

As of September 30, 2015, Basic had no borrowings and $50.3 million of letters of credit outstanding under its Credit Agreement,  giving Basic $111.0 million of available borrowing capacity based on its borrowing base determined as of such date.  

 

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

 

 

 

 

 

 

 

 

 

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.

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Litigation

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

 

Self-Insured Risk Accruals

Basic is self-insured up to retention limits as it relates to workers’ compensation, 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, automobile liability and medical coverage of $2.5 million, $1.0 million, $1.0 million, and $400,000, respectively. Basic maintains accruals in the accompanying consolidated balance sheets related to self-insurance retentions based upon third-party data and claims history.

At September 30, 2015 and December 31, 2014, self-insured risk accruals totaled approximately $32.2 million and $33.4 million, respectively. 

During the second quarter of 2015, Basic accrued $4.5 million related to a customer audit. This amount will be settled throughout the remainder of 2015 and 2016.

7. Stockholders’ Equity

Common Stock

In March 2015, Basic granted various employees 888,104 restricted shares of common stock that vest over a three-year period.

During the nine months ended September 30, 2015, Basic issued 103,750 shares of common stock from treasury stock for the exercise of stock options.

Treasury Stock

During the first nine months of 2015, Basic repurchased 513,600 shares for a total price of approximately $3.4 million (an average of approximately $6.67 per share), inclusive of commissions and fees. As of September 30, 2015, Basic may purchase up to an additional $10.5 million of Basic’s shares of common stock under the repurchase program.

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 216,870 shares through net share settlements during the first nine months of 2015 and 253,056 shares through net share settlements during the first nine months of 2014.

8. Incentive Plan

During the three months ended September 30, 2015 and 2014, compensation expense related to share-based arrangements was approximately $3.3 million and $3.8 million, respectively. For compensation expense recognized during the three months ended September 30, 2015 and 2014, Basic recognized a tax benefit of approximately $1.2 million and $1.5 million, respectively. During the nine months ended September 30, 2015 and 2014, compensation expense related to share-based arrangements was approximately $10.5 million and $10.9 million, respectively. For compensation expense recognized during the nine months ended September 30, 2015 and 2014, Basic recognized a tax benefit of approximately $3.8 million and $4.7 million, respectively.

 As of September 30, 2015, there was approximately $18.9 million of total unrecognized compensation related to non-vested share-based compensation arrangements granted under the Plan. That cost is expected to be recognized over a weighted-average period of 2.0 years. The total fair value of share-based awards vested during the nine months ended September 30, 2015 and 2014 was approximately $5.2 million and $20.5 million, respectively. During the  nine months ended September 30, 2015 and 2014, there was no excess tax benefit due to the net operating loss carryforwards (“NOL”). If there was no NOL, there would have been  $11,000 excess tax benefit at September 30, 2015 and there would have been an excess tax benefit of approximately $4.5 million at September 30, 2014. 

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.

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The following table reflects the summary of stock options outstanding at September 30, 2015 and the changes during the nine months then ended:

 

 

The total intrinsic value of share options exercised during the nine months ended September 30, 2015 and 2014 was approximately $37,000 and $2.2 million, respectively.

Cash received from share option exercises under the Plan was approximately $724,000 and $4.3 million for the nine months ended September 30, 2015 and 2014, respectively. During the nine months ended September 30, 2015 and 2014, there was no excess tax benefit due to the NOL. If there was no NOL, there would have been no excess tax benefit at September 30, 2015 and there would have been an excess tax benefit of approximately $534,000 at September 30, 2014. 

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

Restricted Stock Awards

 A summary of the status of Basic’s non-vested share grants at September 30, 2015 and changes during the nine months ended September 30, 2015 is presented in the following table:

 

 

Phantom Stock Awards

On March 18,  2015, the Compensation Committee of Basic’s Board of Directors approved grants of performance-based phantom stock awards to certain members of management. The performance-based phantom stock awards are tied to Basic’s achievement of total stockholder return (“TSR”) relative to the TSR of a peer group of energy services companies over the performance period (defined as the one-year calculation period starting on the 20th NYSE trading day prior to and including the last NYSE trading day of 2014 and ending on the last NYSE trading day of 2015). The number of phantom shares to be issued will range from 0% to 150% of the 704,089 target number of phantom shares, depending on the performance noted above. Any phantom shares earned at the end of the performance period will then remain subject to vesting in one-third increments on March 15, 2016, 2017 and 2018 (subject to accelerated vesting in certain circumstances). As of September 30, 2015, Basic estimated that 100% of the target number of performance-based awards will be earned.  The Compensation Committee also approved grants of phantom restricted stock awards to certain key employees. The number of phantom shares issued was 654,500. These grants remain subject to vesting over a three-year period, with the first portion vesting March 15, 2016.

 

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9. Related Party Transactions

Basic had receivables from employees of approximately $44,000 and $161,000 as of September 30, 2015 and December 31, 2014, respectively.

In December 2010, Basic entered into a lease agreement with Darle Vuelta Cattle Co., LLC (“DVCC”) 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. In February 2015, Basic purchased 100 acres of vacant land outside of Midland, Texas for $1.5 million from DVCC.

 

10. Earnings Per Share

The following table sets forth the computation of unaudited basic and diluted earnings (loss) per share (in thousands, except share data):

 

 

 

Stock options and unvested restricted stock shares of approximately 395,938 and 634,541 were excluded in the computation of diluted earnings (loss) per share for the three and nine months ended September 30, 2015, respectively, as the effect would have been anti-dilutive. 

 

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11. Business Segment Information

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 (loss) 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 nine months ended September 30, 2015 and 2014, respectively. Basic paid interest of approximately $49.6 million and $49.7 million during the nine months ended September 30, 2015 and 2014, respectively.

 

13. Fair Value Measurements

The following is a summary of the carrying amounts and estimated fair values of our financial instruments as of September 30, 2015 and December 31, 2014. The fair value of our long-term notes is based upon the quoted market prices at September 30, 2015 and December 31, 2014 and is as follows:

 

The carrying amounts of cash and cash equivalents, trade accounts receivable, accounts receivable-related parties, accounts payable and accrued expenses approximate fair value due to the short maturities of these instruments. The carrying amount of our revolving credit facility in long-term debt also approximates fair value due to its variable-rate characteristics.

 

14. Recent Accounting Pronouncements

In January 2015, the FASB issued ASU 2015-01, “Simplifying Income Statement Presentation by Eliminating the Concept of Extraordinary Items.”  ASU 2015-01 eliminates from U.S. GAAP the concept of an extraordinary item. The Board released the new guidance as part of its simplification initiative, which is intended to “identify, evaluate, and improve areas of U.S. GAAP for which cost and complexity can be reduced while maintaining or improving the usefulness of the information provided to users of financial statements.” The ASU is effective for annual periods beginning after December 15, 2015, and interim periods within those annual periods. Basic does not believe this pronouncement will have a material impact on its consolidated financial statements.

In April 2015, the FASB issued ASU 2015-03, “Simplifying the Presentation of Debt Issuance Costs.” ASU 2015-03 requires that debt issuance costs related to a recognized debt liability be presented in the balance sheet as a direct deduction from the carrying amount of that debt liability, consistent with debt discounts. The ASU is effective for annual periods beginning after December 15, 2015, and interim periods within those annual periods. Basic is in the process of determining if this pronouncement will have a material impact on its consolidated financial statements.

In July 2015 the FASB issued ASU 2015-11, “Simplifying the Measurement of Inventory.” ASU 2015-11,  changes the measurement principle for entities that do not measure inventory using the last-in, first-out (LIFO) or retail inventory method from the lower of cost or market to lower of cost and net realizable value. The ASU also eliminates the requirement for these entities to consider replacement cost or net realizable value less an approximately normal profit margin when measuring inventory. The ASU is effective for annual periods beginning after December 15, 2016, and interim periods within those annual periods. Basic is in the process of determining if this pronouncement will have a material impact on its consolidated financial statements.

In August 2015 the FASB issued ASU 2015-14, “Revenue from Contracts with Customers—Deferral of the Effective Date”, that defers by one year the effective date of ASU 2014-09, “Revenue from Contracts with Customers”. The ASU is effective for annual reporting periods beginning after December 15, 2017, including interim periods within that reporting period. Basic is in the process of determining if this pronouncement will have a material impact on its consolidated financial statements.

In September 2015 the FASB issued ASU 2015-16, “Business Combinations: Simplifying the Accounting for Measurement-Period Adjustment”. ASU 2015-16 eliminates the requirement for an acquirer to retrospectively adjust the financial statements for measurement –period adjustments that occur in periods after a business combination is consummated. The ASU is effective for annual periods beginning after December 15, 2015, and interim periods within

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those annual periods. Basic does not believe this pronouncement will have a material impact on its consolidated financial statements.

 

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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 made four business acquisitions from January 1, 2014 to September 30, 2015. We also divested our inland workover barge rig fleet in March 2014. These transactions, as well as market fluctuations, may make our revenues, expenses and income not directly comparable between periods.

Our total hydraulic horsepower (“hhp”) increased from 297,000 at December 31, 2013 to 444,000 at September 30, 2015. Our weighted average number of fluid service trucks decreased from 1,025 in the third quarter of 2014 to 1,012 in the third quarter of 2015. Our weighted average number of well servicing rigs remained constant at 421 during the third quarter of 2015 compared to the third quarter of 2014.

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

 

 

During the fourth quarter of 2014, oil prices declined rapidly to a level near $50 per barrel (WTI Cushing) and remained at that level during the first half of 2015.  During the third quarter of 2015, oil prices declined further to a level below $40 per barrel (WTI Cushing) and remained below $50 per barrel during the third quarter. As a result, we have seen a significant impact on our customers’ activity and for the rates we are able to charge our customers.  The third-quarter 2015 declines in oil prices have resulted in further reductions of customer capital expenditures, including maintenance and workover activities. Continued or further declines in oil prices could have a further negative impact on demand for our services if our customers further reduce their exploration, maintenance and workover plans and programs.

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. Natural gas prices have been depressed for a prolonged period and utilization and pricing for our services in our natural gas-based operating areas remained competitive during 2015.

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

 

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.

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Selected Acquisitions and Divestitures

During 2014, we made one business acquisition that complemented our existing business segments:  

Pioneer Fishing &  Rental Services, LLC 

On September 17, 2014, we acquired all of the assets of Pioneer Fishing &  Rental Services, LLC for total cash consideration of $16.1 million. This acquisition has been included in our completion and remedial services segment.

During the first nine months of 2015, we made three business acquisitions for a total acquisition price of $16.7 million. None of these transactions are considered individually material to our financial statements.

Segment Overview

Completion and Remedial Services

During the first nine months of 2015, our completion and remedial services segment represented approximately 39% of our revenues. Revenues from our completion and remedial services segment are generally derived from a variety of services designed to complete and stimulate new oil and natural gas production or place cement slurry within the wellbores. Our completion and remedial services segment includes pumping services, rental and fishing tool operations, coiled tubing services, nitrogen services, cased-hole wireline services, snubbing and other services.  

Our pumping services typically concentrate on providing mid-sized fracturing services in selected markets. Cementing and acidizing services also are included in our pumping services operations. Our total hydraulic horsepower capacity for our pumping operations was 444,000 and 413,000 at September 30, 2015 and 2014, 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 2014, the full year ended December 31, 2014 and the quarters ended March 31, 2015, June 30, 2015 and September 30, 2015 (dollars in thousands):

 

The decrease in completion and remedial services revenue to $67.2 million in the third quarter of 2015 from $69.1 million in the second quarter of 2015 resulted primarily from decreased activity and lower pricing in our pumping and coil tubing services, due to the general decline in completion activity.  Segment profits as a percentage of revenue decreased to 16% in the third quarter of 2015 from  17% in second quarter of 2015. 

Fluid Services 

During the first nine months of 2015, our fluid services segment represented approximately 31% 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

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workover activity generally enable us to generate higher segment profits. The higher segment profits for these add-on services 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 2014, the full year ended December 31, 2014, and the quarters ended March 31, 2015, June 30, 2015 and September 30, 2015 (dollars in thousands):

 

 

 

 

 

Revenue per fluid service truck decreased to $62,000 in the third quarter of 2015 compared to $63,000 in the second quarter of 2015 primarily due to decreases in customer pricing. Segment profit percentage remained constant at  24% in the second and third quarters of 2015 due to a relatively consistent utilization and pricing. 

Well Servicing

During the first nine months of 2015, our well servicing segment represented approximately 27% 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 remained constant at a weighted average number of 421 rigs.

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The following is an analysis of our well servicing operations for each of the quarters in 2014, the full year ended December 31, 2014 and the quarters ended March 31, 2015, June 30, 2015 and September 30, 2015:   

 

 

 

Rig utilization was 50% in the third quarter of 2015, down slightly from 51% in the second quarter of 2015.  The lower utilization rate in the second and third quarter of 2015 resulted from a general decline in our customers’ capital and operating budgets. Our segment profit percentage decreased to 14% for the third quarter of 2015 from 17% in the second quarter of 2015, primarily due to lower rates charged to customers in order to maintain utilization of our equipment and a higher mix of manufacturing revenues during the third quarter of 2015.

Contract Drilling

During the first nine months of 2015, our contract drilling segment represented approximately 3% 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 third quarter of 2015.  

The following is an analysis of our contract drilling segment for each of the quarters in 2014, the full year ended December 31, 2014 and the quarters ended March 31, 2015, June 30, 2015 and September 30, 2015:  

 

 

 

 

 

 

 

 

Revenue per day decreased to  $15,300 in the third quarter of 2015 compared to  $15,500 in the second quarter of 2015. The decrease in drilling revenue per day in the third quarter of 2015 was due to a  decrease in rig utilization and lower pricing. Segment profit percentage decreased to 17% in the third quarter of 2015 compared to 20% in the second quarter of 2015 due to the impact of decremental margins on a lower revenue base.

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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.

Results of Operations

The following is a comparison of our results of operations for the three months ended September 30, 2015 compared to the three months ended September 30, 2014. For additional segment-related information and trends, please read “Segment Overview” above.

 Three Months Ended September 30, 2015 Compared to Three Months Ended September 30, 2014 

Revenues. Revenues decreased by 52% to $189.2 million during the third quarter of 2015 from $394.0 million during the same period in 2014. This decrease was primarily due to decreased demand for our services by our customers due to a steep decline in the price of crude oil and reduced pricing as a result of the competitive market environment.

Completion and remedial services revenues decreased by 65% to $67.2 million during the third quarter of 2015 compared to $193.7 million in the same period in 2014. The decrease in revenue between these periods was primarily due to decreased demand for completion related activities and pricing for our services, particularly in our pumping services line of business. Total hydraulic horsepower increased to 444,000 at September 30, 2015 from 413,000 at September 30, 2014.

Fluid services revenues decreased by 33% to $62.6 million during the third quarter of 2015 compared to $92.9 million in the same period in 2014, due to decreases in trucking hours and lower pricing for our services. Our revenue per fluid service truck decreased 32% to $62,000 in the third quarter of 2015 compared to $91,000 in the same period in 2014 due mainly to decreases in pricing, disposal utilization and skim oil revenues. Our weighted average number of fluid service trucks decreased to 1,012 during the third quarter of 2015 compared to 1,025 in the same period in 2014.  

Well servicing revenues decreased by 39% to $55.5 million during the third quarter of 2015 compared to $91.1 million during the same period in 2014. The decrease was driven by a decrease in utilization of our equipment, primarily due to declines in customer demand and pricing. Our weighted average number of well servicing rigs remained constant at 421 during the third quarter of 2015 and 2014.  Utilization was 50% in the third quarter of 2015, compared to 71% in the comparable quarter of 2014. Revenue per rig hour in the third quarter of 2015 was $334, decreasing from $405 in the comparable quarter of 2014, due to competitive rate pressure. 

Contract drilling revenues decreased by 76% to $3.8 million during the third quarter of 2015 compared to $16.3 million in the same period in 2014. The number of rig operating days decreased 74% to  252 in the third quarter of 2015 compared to 968 in the third quarter of 2014. The decrease in revenue and rig operating days was due to a decrease in drilling activity in the Permian Basin.  

Direct Operating Expenses. Direct operating expenses, which primarily consist of labor, including workers’ compensation and health insurance, repair and maintenance, fuel and insurance, decreased to $154.9 million during the third quarter of 2015 from $264.1 million in the same period in 2014, primarily due to decreases in activity and corresponding reductions in employee headcount and wages to adapt to current activity levels.  

Direct operating expenses for the completion and remedial services segment decreased by 53% to $56.2 million during the third quarter of 2015 compared to $119.1 million for the same period in 2014 due primarily to decreased activity levels overall, especially in our pumping and coil tubing services. Segment profits decreased to 16% of revenues during the third quarter of 2015 compared to 39% for the same period in 2014, due to decremental margin impact of lower activity and increased price competition.  

Direct operating expenses for the fluid services segment decreased by 28% to $47.7 million during the third quarter of 2015 compared to $66.1 million for the same period in 2014, mainly due to decreased activity levels. Segment

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profits were 24% of revenues during the third quarter of 2015 compared to 29% for the same period in 2014 due to the decline in trucking hours and lower skim oil sales and disposal activity.

Direct operating expenses for the well servicing segment decreased by 29% to $47.9 million during the third quarter of 2015 compared to $67.6 million for the same period in 2014. The decrease in direct operating expenses corresponds to decreased workover and plugging activity levels. Segment profits decreased to 14% of revenues during the third quarter of 2015 compared to 26% of revenues during the third quarter of 2014 due to the impact of decremental margins on a lower revenue base and increased pricing competition.

Direct operating expenses for the contract drilling segment decreased 72% to $3.2 million during the third quarter of 2015 compared to $11.2 million for the same period in 2014, due to decreased activity and fewer rig operating days. Segment profits decreased to 17% of revenues during the third quarter of 2015 from 31% during the third quarter of 2014 due to a significant decline in drilling projects during the third quarter of 2015.

General and Administrative Expenses. General and administrative expenses decreased by 13% to $36.0 million during the third quarter of 2015 from $41.5 million for the same period in 2014, due to cost cutting measures implemented in 2015 including reduced headcount, salary reductions and lower incentive bonus expense. General and administrative expenses included $3.3 million and $3.8 million of stock-based compensation expense during the third quarters of 2015 and 2014, respectively.

Depreciation and Amortization Expenses. Depreciation and amortization expenses were $60.3 million during the third quarter of 2015 compared to $54.5 million for the same period in 2014.  The increase in depreciation and amortization expense is due to the increase in our fleet through capital expenditures for equipment during the latter part of 2014.

Goodwill Impairment.    In the third quarter of 2015, as a result of the continued market downturn and further reduction of service activity we recorded a non-cash charge totaling $81.9 million for impairment of all of the goodwill associated with our completion and remedial services segment.

Interest Expense. Interest expense increased to $17.2 million during the third quarter of 2015 compared to $16.8 million during the third quarter of 2014.  

Income Tax Expense. There was income tax benefit of $56.5 million during the third quarter of 2015 compared to an income tax expense of $6.2 million for the same period in 2014. Our effective tax rate during the third quarter of 2015 and 2014 was approximately 35% and 39%, respectively.  Our effective tax rates for 2015 and 2014 differ from the federal tax rate due to permanent items and state income taxes. The difference in the rate from 2014 to 2015 is due to the impact of permanent items on a higher pre-tax loss amount.

 Nine Months Ended September 30, 2015 Compared to Nine Months Ended September 30, 2014 

The following is a comparison of our results of operations for the nine months ended September 30, 2015 compared to the nine months ended September 30, 2014. For additional segment-related information and trends, please read “Segment Overview” above.

Revenues. Revenues decreased by 41% to $644.6 million during the nine months ended September 30, 2015 from $1.1 billion during the same period in 2014. This decrease was primarily due to decreased demand for our services by our customers due to a steep decline in the price of crude oil and reduced pricing as a result of the competitive market environment.

Completion and remedial services revenues decreased by 50% to $249.1 million during the nine months ended September 30, 2015 compared to $495.6 million in the same period in 2014. The decrease in revenue between these periods was primarily due to decreased demand for completion related activities and pricing for our services, particularly in our pumping and coil tubing services lines of business. Additionally, we agreed to extend a $4.5 million credit to a customer as the result of an audit in the second quarter of 2015.  Total hydraulic horsepower increased to 444,000 at September 30, 2015 from 413,000 at September 30, 2014.

Fluid services revenues decreased by 27% to $200.1 million during the nine months ended September 30, 2015 compared to $276.0 million in the same period in 2014, due to decreases in trucking hours and lower pricing for our services. Our revenue per fluid service truck decreased 28% to $196,000 in the nine months ended September 30, 2015 compared to $272,000 in the same period in 2014 due mainly to decreases in pricing for our services, disposal utilization and skim oil revenues. Our weighted average number of fluid service trucks increased to 1,023 during the nine months ended September 30, 2015 compared to 1,015 in the same period in 2014.  

Well servicing revenues decreased by 36% to $175.7 million during the nine months ended September 30, 2015 compared to $273.7 million during the same period in 2014. The decrease was driven by a decrease in rig hours, primarily due to declines in utilization and pricing and the divesture of the barge rigs in the nine months ended September 30, 2014. Our weighted average number of well servicing rigs decreased to 421 during the nine months ended September 30, 2015 from 422 during the same period in 2014.  Utilization was 53% in the nine months ended September 30, 2015,  

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compared to 72% in the comparable quarter of 2014. Revenue per rig hour in the nine months ended September 30, 2015 was $354 decreasing from $411 in the comparable period of 2014 due to competitive pricing pressure.

Contract drilling revenues decreased by 56% to $19.7 million during the nine months ended September 30, 2015 compared to $45.2 million in the same period in 2014. The number of rig operating days decreased 56% to  1,206 in the nine months ended September 30, 2015 compared to 2,731 in the nine months ended September 30, 2014. The decrease in revenue and rig operating days was due to a decrease in drilling activity in the Permian Basin.  

Direct Operating Expenses. Direct operating expenses, which primarily consist of labor, including workers’ compensation and health insurance, repair and maintenance, fuel and insurance, decreased to $506.8 million during the nine months ended September 30, 2015 from $739.2 million in the same period in 2014, primarily due to decreases in activity and corresponding reductions in employee headcount and wages to adapt to current activity levels.  

Direct operating expenses for the completion and remedial services segment decreased by 37% to $195.1 million during the nine months ended September 30, 2015 compared to $308.2 million for the same period in 2014 due primarily to decreased activity levels overall, especially in our pumping and coil tubing services. Segment profits decreased to 22% of revenues during the nine months ended September 30, 2015 compared to 38% for the same period in 2014, due to decreased completion-related activity,  price competition and a $4.5 million credit given to a customer as the result of an audit in the second quarter of 2015.  

Direct operating expenses for the fluid services segment decreased by 25% to $150.2 million during the nine months ended September 30, 2015 compared to $198.0 million for the same period in 2014, mainly due to decreased activity and pricing levels. Segment profits were 25% of revenues during the nine months ended September 30, 2015 compared to 28% for the same period in 2014 due to the decline in trucking hours and lower skim oil sales and disposal activity.

Direct operating expenses for the well servicing segment decreased by 27% to $147.3 million during the nine months ended September 30, 2015 compared to $202.1 million for the same period in 2014. The decrease in direct operating expenses corresponds to decreased workover and plugging activity levels. Segment profits decreased to 16% of revenues during the nine months ended September 30, 2015 compared to 26% of revenues during the nine months ended September 30, 2014 due to decremental margins on lower revenues and expenses associated with downhole issues.

Direct operating expenses for the contract drilling segment decreased 54% to $14.2 million during the nine months ended September 30, 2015 compared to $30.9 million for the same period in 2014, due to decreased activity and fewer rig operating days. Segment profits decreased to 28% of revenues during the nine months ended September 30, 2015 from 32% during the nine months ended September 30, 2014 due to a significant decline in drilling projects.

General and Administrative Expenses. General and administrative expenses decreased by 11% to  $110.9 million during the nine months ended September 30, 2015 from  $124.0 million for the same period in 2014, due to cost cutting measures implemented in the nine months ended September 30, 2015, including headcount reductions, salary reductions and lower incentive bonus expense. General and administrative expenses included $10.5 million and $10.9 million of stock-based compensation expense during the nine months ended September 30, 2015 and 2014, respectively.

Depreciation and Amortization Expenses. Depreciation and amortization expenses were $181.5 million during the nine months ended September 30, 2015 compared to $158.0 million for the same period in 2014.  The increase in depreciation and amortization expense is due to the increase in our fleet through capital expenditures for equipment during the first nine months of 2014.

Goodwill Impairment.    In the third quarter of 2015, as a result of the continued market downturn and further reduction of service activity we recorded a non-cash charge totaling $81.9 million for impairment of all of the goodwill associated with our completion and remedial services segment.

Interest Expense. Interest expense remained relatively flat at $50.9 million during the nine months ended September 30, 2015 compared to $50.3 million during the nine months ended September 30, 2014.  

Income Tax Expense. There was income tax benefit of $101.5 million during the nine months ended September 30, 2015 compared to an income tax expense of $7.8 million for the same period in 2014. Our effective tax rate during the nine months ended September 30, 2015 and 2014 was approximately 35% and 43%, respectively. Our effective tax rates for 2015 and 2014 differ from the federal tax rate due to permanent items and state income taxes. The difference in the rate from 2014 to 2015 is due to the impact of permanent items on a higher pre-tax loss amount.

Liquidity and Capital Resources

As of September 30, 2015, 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 September 30, 2015, we had unrestricted cash and cash equivalents of $56.0 million compared to $79.9 million as of December 31, 2014. When appropriate, we will consider public or private debt and equity offerings and non-recourse transactions to meet our liquidity needs.

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On April 21, 2015, we entered into Amendment No. 2 to our Amended and Restated Credit Agreement (as amended, the “Credit Agreement”) that, among other things: (A) reduces the maximum aggregate commitments thereunder from $300 million to $250 million; (B) permits credit extensions under the Credit Agreement based on availability under a borrowing base comprised of our eligible billed accounts receivable, eligible unbilled accounts receivable and eligible equipment; and (C) provides for the replacement of the existing financial covenants with new financial covenants, which apply only if availability under the Credit Agreement is less than the greater of (i) 25% of the aggregate commitments outstanding, or (ii) $62.5 million.  If that circumstance exists, we will be required to maintain (a) a consolidated senior secured leverage ratio not to exceed 2.50 to 1.00 and (b) a consolidated fixed charge coverage ratio not less than 1.00 to 1.00.

As of September 30, 2015, we had no borrowings and $50.3 million of letters of credit outstanding under our Credit Agreement giving us $111.0 million of available borrowing capacity based on its borrowing base (comprised of eligible billed accounts receivable, eligible unbilled accounts receivable and eligible equipment) determined as of such date.  If borrowing capacity under our Credit Agreement decreases in the future (i.e., based on eligible billed accounts receivable, eligible unbilled accounts receivable and eligible equipment), we may pursue alternative debt financing arrangements (subject to limitations under our senior note indentures) or other sources depending on market conditions to meet future liquidity needs.

Net Cash Provided by Operating Activities

Cash provided by operating activities was $93.1 million for the nine months ended September 30, 2015 compared to cash provided by operating activities of $131.8 million during the same period in 2014. Operating cash flow in the first nine months of 2015 was lower mainly due to a net loss offset by increases in working capital.  

Capital Expenditures

Capital expenditures are the main component of our investing activities. Cash capital expenditures (including acquisitions) during the first nine months of 2015 were $64.0 million compared to $107.4 million in the same period of 2014. We added $13.7 million of additional assets through our capital lease program during the first nine months of 2015 compared to $39.9 million of additional assets in the same period in 2014.  

In 2015, we currently have planned capital expenditures of approximately $73 million, including capital leases of $20 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. 

Other Debt

For the nine months ended September 30, 2015, we had total capital lease additions of approximately $13.7 million.    

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 September 30, 2015,  we had approximately $99.3 million of net operating loss carryforwards.

Recent Accounting Pronouncements 

In January 2015, the FASB issued ASU 2015-01, “Simplifying Income Statement Presentation by Eliminating the Concept of Extraordinary Items.”  ASU 2015-01 eliminates from U.S. GAAP the concept of an extraordinary item. The Board released the new guidance as part of its simplification initiative, which is intended to “identify, evaluate, and improve areas of U.S. GAAP for which cost and complexity can be reduced while maintaining or improving the usefulness of the information provided to users of financial statements.” The ASU is effective for annual periods

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beginning after December 15, 2015, and interim periods within those annual periods. Basic does not believe this pronouncement will have a material impact on its consolidated financial statements.

In April 2015, the FASB issued ASU 2015-03, “Simplifying the Presentation of Debt Issuance Costs.” ASU 2015-03 requires that debt issuance costs related to a recognized debt liability be presented in the balance sheet as a direct deduction from the carrying amount of that debt liability, consistent with debt discounts. The ASU is effective for annual periods beginning after December 15, 2015, and interim periods within those annual periods. Basic is in the process of determining if this pronouncement will have a material impact on its consolidated financial statements.

In July 2015 the FASB issued ASU 2015-11, “Simplifying the Measurement of Inventory.” ASU 2015-11changes the measurement principle for entities that do not measure inventory using the last-in, first-out (LIFO) or retail inventory method from the lower of cost or market to lower of cost and net realizable value. The ASU also eliminates the requirement for these entities to consider replacement cost or net realizable value less an approximately normal profit margin when measuring inventory. The ASU is effective for annual periods beginning after December 15, 2016, and interim periods within those annual periods. Basic is in the process of determining if this pronouncement will have a material impact on its consolidated financial statements.

In August 2015 the FASB issued ASU 2015-14, “Revenue from Contracts with Customers—Deferral of the Effective Date”, that defers by one year the effective date of ASU 2014-09, “Revenue from Contracts with Customers”. The ASU is effective for annual reporting periods beginning after December 15, 2017, including interim periods within that reporting period. Basic is in the process of determining if this pronouncement will have a material impact on its consolidated financial statements.

In September 2015 the FASB issued ASU 2015-16, “Business Combinations: Simplifying the Accounting for Measurement-Period Adjustment”. ASU 2015-16 eliminates the requirement for an acquirer to retrospectively adjust the financial statements for measurement –period adjustments that occur in periods after a business combination is consummated. The ASU is effective for annual periods beginning after December 15, 2015, and interim periods within those annual periods. Basic does not believe 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 September 30, 2015, 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, 2014.  

ITEM 4.  CONTROLS AND PROCEDURES

Disclosure Controls and Procedures

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

Changes in Internal Control Over Financial Reporting

During the most recent fiscal quarter, there have been no changes in our internal control over financial reporting that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

PART II — OTHER INFORMATION

ITEM  1. LEGAL PROCEEDINGS

From time to time, 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.

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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 September 30, 2015:  

 

 

 

 

 

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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: October 26,  2015 

 

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Exhibit Index

 

 

 

 

 

 

*Incorporated by reference

#Filed with this report

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