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PATTERSON UTI ENERGY INC - Quarter Report: 2008 June (Form 10-Q)

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UNITED STATES SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
Form 10-Q
     
þ   QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
For the quarterly period ended June 30, 2008
or
     
o   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 0-22664
Patterson-UTI Energy, Inc.
(Exact name of registrant as specified in its charter)
     
DELAWARE   75-2504748
(State or other jurisdiction of   (I.R.S. Employer
incorporation or organization)   Identification No.)
     
450 GEARS ROAD, SUITE 500    
HOUSTON, TEXAS   77067
(Address of principal executive offices)   (Zip Code)
(281) 765-7100
(Registrant’s telephone number, including area code)
N/A
(Former name, former address and former fiscal year,
if changed since last report)
     Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. Yes þ No o
     Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, or a smaller reporting company. See the definitions of “large accelerated filer,” “accelerated filer” and “smaller reporting company” in Rule 12b-2 of the Exchange Act: (Check one)
             
Large accelerated filer þ   Accelerated filer o   Non-accelerated filer o   Smaller reporting company o
        (Do not check if a smaller reporting company)    
     Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). Yes o No þ
     Indicate the number of shares outstanding of each of the issuer’s classes of common stock, as of the latest practicable date.
     156,635,799 shares of common stock, $0.01 par value, as of July 31, 2008
 
 

 


 

PATTERSON-UTI ENERGY, INC. AND SUBSIDIARIES
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 Certification of CEO pursuant to Rule 13a-14(a)/15d-14(a)
 Certification of CFO pursuant to Rule 13a-14(a)/15d-14(a)
 Certification of CEO and CFO pursuant to 18 USC Section 1350

 


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PART I — FINANCIAL INFORMATION
ITEM 1. Financial Statements
     The following unaudited consolidated financial statements include all adjustments which are, in the opinion of management, necessary for a fair statement of the results for the interim periods presented.
PATTERSON-UTI ENERGY, INC. AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
(unaudited, in thousands, except share data)
                 
    June 30,     December 31,  
    2008     2007  
ASSETS
               
Current assets:
               
Cash and cash equivalents
  $ 62,232     $ 17,434  
Accounts receivable, net of allowance for doubtful accounts of $10,162 at June 30, 2008 and $10,014 at December 31, 2007
    391,652       373,279  
Accrued Federal and state income taxes receivable
    18,445        
Inventory
    39,888       44,416  
Deferred tax assets, net
    33,930       35,370  
Other
    63,512       52,286  
 
           
Total current assets
    609,659       522,785  
Property and equipment, net
    1,873,511       1,841,404  
Goodwill
    96,198       96,198  
Other
    4,589       4,812  
 
           
Total assets
  $ 2,583,957     $ 2,465,199  
 
           
LIABILITIES AND STOCKHOLDERS’ EQUITY
               
Current liabilities:
               
Accounts payable
  $ 151,674     $ 156,916  
Accrued Federal and state income taxes payable
          1,458  
Accrued expenses
    122,828       136,834  
 
           
Total current liabilities
    274,502       295,208  
Borrowings under line of credit
          50,000  
Deferred tax liabilities, net
    247,597       219,490  
Other
    5,569       4,471  
 
           
Total liabilities
    527,668       569,169  
 
           
Commitments and contingencies (see Note 10)
           
Stockholders’ equity:
               
Preferred stock, par value $.01; authorized 1,000,000 shares, no shares issued
           
Common stock, par value $.01; authorized 300,000,000 shares with 180,216,614 and 177,385,808 issued and 156,619,765 and 153,942,800 outstanding at June 30, 2008 and December 31, 2007, respectively
    1,802       1,773  
Additional paid-in capital
    755,124       703,581  
Retained earnings
    1,831,947       1,716,620  
Accumulated other comprehensive income
    18,126       20,207  
Treasury stock, at cost, 23,596,849 and 23,443,008 shares at June 30, 2008 and December 31, 2007, respectively
    (550,710 )     (546,151 )
 
           
Total stockholders’ equity
    2,056,289       1,896,030  
 
           
Total liabilities and stockholders’ equity
  $ 2,583,957     $ 2,465,199  
 
           
The accompanying notes are an integral part of these unaudited consolidated financial statements.

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PATTERSON-UTI ENERGY, INC. AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF INCOME
(unaudited, in thousands, except per share amounts)
                                 
    Three Months Ended     Six Months Ended  
    June 30,     June 30,  
    2008     2007     2008     2007  
Operating revenues:
                               
Contract drilling
  $ 416,835     $ 419,191     $ 836,984     $ 886,689  
Pressure pumping
    57,094       51,592       99,958       90,176  
Drilling and completion fluids
    38,745       39,667       71,295       70,427  
Oil and natural gas
    13,609       12,108       22,600       22,367  
 
                       
 
    526,283       522,558       1,030,837       1,069,659  
 
                       
Operating costs and expenses:
                               
Contract drilling
    251,381       228,297       495,748       474,451  
Pressure pumping
    32,506       25,777       61,011       46,928  
Drilling and completion fluids
    31,449       32,628       59,982       58,019  
Oil and natural gas
    3,529       2,461       5,596       5,739  
Depreciation, depletion and impairment
    65,673       59,947       129,399       115,878  
Selling, general and administrative
    17,747       16,322       34,743       30,991  
Embezzlement costs (recoveries)
          (41,935 )           (41,935 )
Gain on disposal of assets
    (2,721 )     (16,475 )     (2,535 )     (16,273 )
Other operating expenses
    300       400       600       1,000  
 
                       
 
    399,864       307,422       784,544       674,798  
 
                       
Operating income
    126,419       215,136       246,293       394,861  
 
                       
Other income (expense):
                               
Interest income
    493       457       836       826  
Interest expense
    (63 )     (831 )     (340 )     (1,594 )
Other
    353       109       737       203  
 
                       
 
    783       (265 )     1,233       (565 )
 
                       
Income before income taxes
    127,202       214,871       247,526       394,296  
 
                       
Income tax expense:
                               
Current
    29,229       56,350       57,941       109,783  
Deferred
    16,551       18,970       30,754       29,161  
 
                       
 
    45,780       75,320       88,695       138,944  
 
                       
Net income
  $ 81,422     $ 139,551     $ 158,831     $ 255,352  
 
                       
 
                               
Net income per common share:
                               
Basic
  $ 0.53     $ 0.90     $ 1.04     $ 1.64  
 
                       
Diluted
  $ 0.52     $ 0.88     $ 1.02     $ 1.62  
 
                       
 
                               
Weighted average number of common shares outstanding:
                               
Basic
    153,978       155,527       153,289       155,457  
 
                       
Diluted
    156,437       157,912       155,766       157,580  
 
                       
 
                               
Cash dividends per common share
  $ 0.16     $ 0.12     $ 0.28     $ 0.20  
 
                       
The accompanying notes are an integral part of these unaudited consolidated financial statements.

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PATTERSON-UTI ENERGY, INC. AND SUBSIDIARIES
CONSOLIDATED STATEMENT OF CHANGES IN STOCKHOLDERS’ EQUITY
(unaudited, in thousands)
                                                         
                                    Accumulated              
    Common Stock     Additional             Other              
    Number of             Paid-in     Retained     Comprehensive     Treasury        
    Shares     Amount     Capital     Earnings     Income     Stock     Total  
Balance, December 31, 2007
    177,386     $ 1,773     $ 703,581     $ 1,716,620     $ 20,207     $ (546,151 )   $ 1,896,030  
Issuance of restricted stock
    577       6       (6 )                        
Forfeitures of restricted shares
    (30 )                                    
Exercise of stock options
    2,284       23       25,344                         25,367  
Stock-based compensation
                10,137                         10,137  
Tax benefit related to stock-based compensation
                16,068                         16,068  
Foreign currency translation adjustment, net of tax of $1,206
                          (2,081 )           (2,081 )
Payment of cash dividends
                      (43,504 )                 (43,504 )
Purchase of treasury stock
                                  (4,559 )     (4,559 )
Net income
                      158,831                   158,831  
 
                                         
Balance, June 30, 2008
    180,217     $ 1,802     $ 755,124     $ 1,831,947     $ 18,126     $ (550,710 )   $ 2,056,289  
 
                                         
The accompanying notes are an integral part of these unaudited consolidated financial statements.

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PATTERSON-UTI ENERGY, INC. AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CHANGES IN CASH FLOWS
(unaudited, in thousands)
                 
    Six Months Ended  
    June 30,  
    2008     2007  
Cash flows from operating activities:
               
Net income
  $ 158,831     $ 255,352  
Adjustments to reconcile net income to net cash provided by operating activities:
               
Depreciation, depletion and impairment
    129,399       115,878  
Provision for bad debts
    600       1,000  
Dry holes and abandonments
    600       786  
Deferred income tax expense
    30,754       29,161  
Stock-based compensation expense
    10,137       8,416  
Gain on disposal of assets
    (2,535 )     (16,273 )
Changes in operating assets and liabilities:
               
Accounts receivable
    (19,609 )     90,703  
Embezzlement recovery receivable
          (42,500 )
Income taxes receivable/payable
    (19,923 )     6,427  
Inventory and other current assets
    (2,912 )     14,352  
Accounts payable
    14,929       6,876  
Accrued expenses
    (13,960 )     (18,864 )
Other liabilities
    (13,035 )     (4,730 )
 
           
Net cash provided by operating activities
    273,276       446,584  
 
           
Cash flows from investing activities:
               
Purchases of property and equipment
    (176,162 )     (325,592 )
Proceeds from disposal of assets
    4,429       26,803  
 
           
Net cash used in investing activities
    (171,733 )     (298,789 )
 
           
Cash flows from financing activities:
               
Purchases of treasury stock
    (4,559 )     (415 )
Dividends paid
    (43,504 )     (31,387 )
Tax benefit related to stock-based compensation
    16,068       1,060  
Proceeds from borrowings under line of credit
          82,500  
Repayment of borrowings under line of credit
    (50,000 )     (187,500 )
Proceeds from exercise of stock options
    25,367       934  
 
           
Net cash used in financing activities
    (56,628 )     (134,808 )
 
           
Effect of foreign exchange rate changes on cash
    (117 )     1,103  
 
           
Net increase in cash and cash equivalents
    44,798       14,090  
Cash and cash equivalents at beginning of period
    17,434       13,385  
 
           
Cash and cash equivalents at end of period
  $ 62,232     $ 27,475  
 
           
Supplemental disclosure of cash flow information:
               
Net cash paid during the period for:
               
Interest expense
  $ 444     $ 1,194  
Income taxes
  $ 60,025     $ 96,759  
The accompanying notes are an integral part of these unaudited consolidated financial statements.

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PATTERSON-UTI ENERGY, INC. AND SUBSIDIARIES
NOTES TO UNAUDITED CONSOLIDATED FINANCIAL STATEMENTS
1. Basis of Consolidation and Presentation
     The interim unaudited consolidated financial statements include the accounts of Patterson-UTI Energy, Inc. (the “Company”) and its wholly-owned subsidiaries. All significant intercompany accounts and transactions have been eliminated. The Company has no controlling financial interests in any entity that is not a wholly-owned subsidiary and which would require consolidation.
     The interim consolidated financial statements have been prepared by management of the Company, without audit, pursuant to the rules and regulations of the Securities and Exchange Commission. Certain information and footnote disclosures normally included in financial statements prepared in accordance with accounting principles generally accepted in the United States of America have been omitted pursuant to such rules and regulations, although the Company believes the disclosures included either on the face of the financial statements or herein are sufficient to make the information presented not misleading. In the opinion of management, all adjustments which are of a normal recurring nature considered necessary for a fair statement of the information in conformity with accounting principles generally accepted in the United States have been included. The Unaudited Consolidated Balance Sheet as of December 31, 2007, as presented herein, was derived from the audited balance sheet of the Company, but does not include all disclosures required by accounting principles generally accepted in the United States of America. These unaudited consolidated financial statements should be read in conjunction with the consolidated financial statements and related notes included in the Company’s Annual Report on Form 10-K for the fiscal year ended December 31, 2007.
     The U.S. dollar is the functional currency for all of the Company’s operations except for its Canadian operations, which use the Canadian dollar as their functional currency. The effects of exchange rate changes are reflected in accumulated other comprehensive income, which is a separate component of stockholders’ equity.
     The Company provides a dual presentation of its net income per common share in its Unaudited Consolidated Statements of Income: Basic net income per common share (“Basic EPS”) and diluted net income per common share (“Diluted EPS”). Basic EPS excludes dilution and is computed by dividing net income by the weighted average number of common shares outstanding during the period excluding nonvested restricted stock. Diluted EPS is based on the weighted-average number of common shares outstanding plus the impact of dilutive instruments, including stock options, restricted stock and stock unit awards using the treasury stock method. The following table presents information necessary to calculate net income per share for the three and six months ended June 30, 2008 and 2007 as well as potentially dilutive securities excluded from the weighted average number of diluted common shares outstanding, as their inclusion would have been anti-dilutive during the three and six months ended June 30, 2008 and 2007 (in thousands, except per share amounts):
                                 
    Three Months Ended     Six Months Ended  
    June 30,     June 30,  
    2008     2007     2008     2007  
Net income
  $ 81,422     $ 139,551     $ 158,831     $ 255,352  
Weighted average number of common shares outstanding excluding nonvested restricted stock
    153,978       155,527       153,289       155,457  
 
                       
Basic net income per common share
  $ 0.53     $ 0.90     $ 1.04     $ 1.64  
 
                       
Weighted average number of common shares outstanding excluding nonvested restricted stock
    153,978       155,527       153,289       155,457  
Dilutive effect of stock options, restricted shares and stock unit awards
    2,459       2,385       2,477       2,123  
 
                       
Weighted average number of diluted common shares outstanding
    156,437       157,912       155,766       157,580  
 
                       
Diluted net income per common share
  $ 0.52     $ 0.88     $ 1.02     $ 1.62  
 
                       
Potentially dilutive securities excluded as anti-dilutive
    655       1,785       2,380       2,435  
 
                       
     Reclassifications — Certain reclassifications have been made to the 2007 consolidated financial statements in order for them to conform with the 2008 presentation.
     The results of operations for the three and six months ended June 30, 2008 are not necessarily indicative of the results to be expected for the full year.

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2. Stock-based Compensation
     The Company recognizes the cost of share-based awards under the fair-value method. The Company uses share-based awards to compensate employees and non-employee directors. All awards have been equity instruments in the form of stock options, restricted stock awards and stock unit awards and have included both service and, in certain cases, performance conditions. The Company issues shares of common stock when vested stock option awards are exercised, when restricted stock awards are granted and when stock unit awards vest.
     Stock Options. The Company estimates the grant date fair values of stock options using the Black-Scholes-Merton valuation model (“Black-Scholes”). Volatility assumptions are based on the historic volatility of the Company’s common stock over the most recent period equal to the expected term of the options as of the date the options are granted. The expected term assumptions are based on the Company’s experience with respect to employee stock option activity. Dividend yield assumptions are based on the expected dividends at the time the options are granted. The risk-free interest rate assumptions are determined by reference to United States Treasury yields. Weighted-average assumptions used to estimate the grant date fair values for stock options granted in the three and six-month periods ended June 30, 2008 and 2007 follow:
                                 
    Three Months Ended   Six Months Ended
    June 30,   June 30,
    2008   2007   2008   2007
Volatility
    35.74 %     36.36 %     35.73 %     36.38 %
Expected term (in years)
    4.00       4.00       4.00       4.00  
Dividend yield
    1.64 %     2.00 %     1.68 %     1.96 %
Risk-free interest rate
    2.92 %     4.56 %     2.94 %     4.56 %
     Stock option activity from January 1, 2008 to June 30, 2008 follows:
                 
            Weighted  
            Average  
    Underlying     Exercise  
    Shares     Price  
Outstanding at January 1, 2008
    7,403,084     $ 17.52  
Granted
    694,500     $ 28.75  
Exercised
    (2,284,041 )   $ 11.11  
Expired
    (134 )   $ 14.64  
 
           
Outstanding at June 30, 2008
    5,813,409     $ 21.38  
 
           
Exercisable at June 30, 2008
    4,206,407     $ 19.30  
 
           
     Restricted Stock. Under restricted stock awards to date, shares were issued when granted. Nonvested shares are subject to forfeiture for failure to fulfill service conditions and, in certain cases, performance conditions. Nonforfeitable cash dividends are paid on nonvested restricted shares.
     Restricted stock activity from January 1, 2008 to June 30, 2008 follows:
                 
            Weighted  
            Average  
            Grant Date  
    Shares     Fair Value  
Nonvested restricted stock outstanding at January 1, 2008
    1,490,150     $ 26.22  
Granted
    576,950     $ 30.31  
Vested
    (534,337 )   $ 24.36  
Forfeited
    (30,185 )   $ 26.15  
 
           
Nonvested restricted stock outstanding at June 30, 2008
    1,502,578     $ 28.45  
 
           
     Stock Units. Under stock unit awards to date, shares are not issued until the awards vest. Awards are subject to forfeiture for failure to fulfill service conditions. Nonforfeitable cash dividend equivalents are paid on nonvested stock units.

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     Stock unit activity from January 1, 2008 to June 30, 2008 follows:
                 
            Weighted  
            Average  
            Grant Date  
    Shares     Fair Value  
Nonvested stock units outstanding at January 1, 2008
        $  
Granted
    17,500     $ 31.60  
Vested
        $  
Forfeited
        $  
 
           
Nonvested stock units outstanding at June 30, 2008
    17,500     $ 31.60  
 
           
3. Comprehensive Income
     The following table reflects the Company’s comprehensive income after considering the effects of foreign currency translation adjustments for the three and six months ended June 30, 2008 and 2007 (in thousands):
                                 
    Three Months Ended     Six Months Ended  
    June 30,     June 30,  
    2008     2007     2008     2007  
Net income
  $ 81,422     $ 139,551     $ 158,831     $ 255,352  
Other comprehensive income (loss):
                               
Foreign currency translation adjustment related to Canadian operations, net of tax
    925       5,770       (2,081 )     6,418  
 
                       
Comprehensive income, net of tax
  $ 82,347     $ 145,321     $ 156,750     $ 261,770  
 
                       
4. Property and Equipment
     Property and equipment consisted of the following at June 30, 2008 and December 31, 2007 (in thousands):
                 
    June 30,     December 31,  
    2008     2007  
Equipment
  $ 2,811,632     $ 2,748,007  
Oil and natural gas properties
    82,625       75,732  
Buildings
    56,328       50,955  
Land
    9,827       9,991  
 
           
 
    2,960,412       2,884,685  
Less accumulated depreciation and depletion
    (1,086,901 )     (1,043,281 )
 
           
Property and equipment, net
  $ 1,873,511     $ 1,841,404  
 
           

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5. Business Segments
     The Company’s revenues, operating profits and identifiable assets are primarily attributable to four business segments: (i) contract drilling of oil and natural gas wells, (ii) pressure pumping services, (iii) drilling and completion fluid services and (iv) the investment, on a working interest basis, in oil and natural gas properties. Each of these segments represents a distinct type of business based upon the type and nature of services and products offered. These segments have separate management teams which report to the Company’s chief operating decision maker and have distinct and identifiable revenues and expenses. Separate financial data for each of our four business segments is provided in the table below (in thousands):
                                 
    Three Months Ended     Six Months Ended  
    June 30,     June 30,  
    2008     2007     2008     2007  
Revenues:
                               
Contract drilling (a)
  $ 417,874     $ 420,285     $ 838,826     $ 888,624  
Pressure pumping
    57,094       51,592       99,958       90,176  
Drilling and completion fluids (b)
    38,746       39,702       71,346       70,583  
Oil and natural gas
    13,609       12,108       22,600       22,367  
 
                       
Total segment revenues
    527,323       523,687       1,032,730       1,071,750  
Elimination of intercompany revenues (a)(b)
    (1,040 )     (1,129 )     (1,893 )     (2,091 )
 
                       
Total revenues
  $ 526,283     $ 522,558     $ 1,030,837     $ 1,069,659  
 
                       
Income before income taxes:
                               
Contract drilling
  $ 106,795     $ 137,712     $ 225,181     $ 309,417  
Pressure pumping
    14,277       17,599       18,729       27,840  
Drilling and completion fluids
    4,055       3,906       4,722       6,182  
Oil and natural gas
    7,173       5,116       11,470       7,729  
 
                       
 
    132,300       164,333       260,102       351,168  
Corporate and other
    (8,602 )     (7,607 )     (16,344 )     (14,515 )
Embezzlement (costs) recoveries (c)
          41,935             41,935  
Gain on disposal of assets (d)
    2,721       16,475       2,535       16,273  
Interest income
    493       457       836       826  
Interest expense
    (63 )     (831 )     (340 )     (1,594 )
Other
    353       109       737       203  
 
                       
Income before income taxes
  $ 127,202     $ 214,871     $ 247,526     $ 394,296  
 
                       
                 
    June 30,     December 31,  
    2008     2007  
Identifiable assets:
               
Contract drilling
  $ 2,154,535     $ 2,132,910  
Pressure pumping
    188,976       154,120  
Drilling and completion fluids
    101,154       91,989  
Oil and natural gas
    36,742       37,885  
Corporate and other (e)
    102,550       48,295  
 
           
Total assets
  $ 2,583,957     $ 2,465,199  
 
           
 
(a)   Includes contract drilling intercompany revenues of approximately $1.0 million and $1.1 million for the three months ended June 30, 2008 and 2007, respectively. Includes contract drilling intercompany revenues of approximately $1.8 million and $1.9 million for the six months ended June 30, 2008 and 2007, respectively.
 
(b)   Includes drilling and completion fluids intercompany revenues of approximately $1,000 and $35,000 for the three months ended June 30, 2008 and 2007, respectively. Includes drilling and completion fluids intercompany revenues of approximately $51,000 and $156,000 for the six months ended June 30, 2008.
 
(c)   The Company’s former CFO has pleaded guilty to criminal charges and has been sentenced and is serving a term of imprisonment arising out of his embezzlement of funds from the Company. The embezzlement recovery in 2007 includes the recognition of the recovery of assets seized by a court appointed receiver, net of professional and other costs incurred as a result of the embezzlement.
 
(d)   Gains or losses associated with the disposal of assets relate to decisions of the executive management group regarding corporate strategy. Accordingly, the related gains or losses have been separately presented and excluded from the results of specific segments.
 
(e)   Corporate and other assets primarily include cash on hand managed by the corporate group and certain tax assets.

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6. Goodwill
     Goodwill is evaluated at least annually to determine if the fair value of recorded goodwill has decreased below its carrying value. At December 31, 2007 the Company performed its annual goodwill evaluation and determined no adjustment to impair goodwill was necessary. Goodwill at both June 30, 2008 and December 31, 2007 includes $86.2 million in the Contract Drilling segment and $10.0 million in the Drilling and Completion Fluids segment.
7. Accrued Expenses
     Accrued expenses consisted of the following at June 30, 2008 and December 31, 2007 (in thousands):
                 
    June 30,     December 31,  
    2008     2007  
Salaries, wages, payroll taxes and benefits
  $ 26,656     $ 33,816  
Workers’ compensation liability
    65,596       70,989  
Sales, use and other taxes
    10,027       12,119  
Insurance, other than workers’ compensation
    16,443       16,308  
Other
    4,106       3,602  
 
           
 
  $ 122,828     $ 136,834  
 
           
8. Asset Retirement Obligation
     Statement of Financial Accounting Standards No. 143, “Accounting for Asset Retirement Obligations,” requires that the Company record a liability for the estimated costs to be incurred in connection with the abandonment of oil and natural gas properties in the future. The following table describes the changes to the Company’s asset retirement obligations during the six months ended June 30, 2008 and 2007 (in thousands):
                 
    2008     2007  
Balance at beginning of year
  $ 1,593     $ 1,829  
Liabilities incurred
    261       151  
Liabilities settled
    (207 )     (632 )
Accretion expense
    29       31  
Revision in estimated costs of plugging oil and natural gas wells
    1,025       289  
 
           
Asset retirement obligation at end of period
  $ 2,701     $ 1,668  
 
           
9. Borrowings Under Line of Credit
     The Company has an unsecured revolving line of credit (“LOC”) with a maximum borrowing capacity of $375 million. Interest is paid on outstanding LOC balances at a floating rate ranging from LIBOR plus 0.625% to 1.0% or the prime rate at the Company’s election. Any outstanding borrowings must be repaid at maturity on December 16, 2009. This arrangement includes various fees, including a commitment fee on the average daily unused amount (0.15% at June 30, 2008). There are customary restrictions and covenants associated with the LOC. Financial covenants provide for a maximum debt to capitalization ratio and a minimum interest coverage ratio. The Company does not expect that the restrictions and covenants will impact its ability to operate or react to opportunities that might arise. As of June 30, 2008, the Company had no borrowings outstanding under the LOC. However, the Company had $58.6 million in letters of credit outstanding and as a result, the Company had available borrowing capacity of approximately $316 million at June 30, 2008.
10. Commitments, Contingencies and Other Matters
     Commitments – As of June 30, 2008, the Company maintained letters of credit in the aggregate amount of $58.6 million for the benefit of various insurance companies as collateral for retrospective premiums and retained losses which could become payable under the terms of the underlying insurance contracts. These letters of credit expire at various times during the calendar year and are typically renewed annually. As of June 30, 2008, no amounts had been drawn under the letters of credit.

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     As of June 30, 2008, the Company had non-cancelable commitments to purchase approximately $61.7 million of equipment. In addition to commitments at June 30, 2008 the Company entered into agreements in July 2008 to purchase new drilling equipment totaling approximately $111 million.
     The Company is party to various legal proceedings arising in the normal course of its business. The Company does not believe that the outcome of these proceedings, either individually or in the aggregate, will have a material adverse effect on its financial condition, results of operations or cash flows.
11. Stockholders’ Equity
     Cash Dividends — The Company paid cash dividends during the six months ended June 30, 2008 and 2007 as follows:
                 
2008:   Per Share     Total  
            (in thousands)  
Paid on March 28, 2008
  $ 0.12     $ 18,493  
Paid on June 27, 2008
    0.16       25,011  
 
           
Total cash dividends
  $ 0.28     $ 43,504  
 
           
                 
2007:   Per Share     Total  
            (in thousands)  
Paid on March 30, 2007
  $ 0.08     $ 12,527  
Paid on June 29, 2007
    0.12       18,860  
 
           
Total cash dividends
  $ 0.20     $ 31,387  
 
           
     On July 30, 2008, the Company’s Board of Directors approved a cash dividend on its common stock in the amount of $0.16 per share to be paid on September 30, 2008 to holders of record as of September 12, 2008. The amount and timing of all future dividend payments, if any, is subject to the discretion of the Board of Directors and will depend upon business conditions, results of operations, financial condition, terms of the Company’s credit facilities and other factors.
     On August 1, 2007, the Company’s Board of Directors approved a stock buyback program (“Program”), authorizing purchases of up to $250 million of the Company’s common stock in open market or privately negotiated transactions. As of June 30, 2008, the Company had authority remaining under the Program to purchase approximately $180 million of the Company’s outstanding common stock. Shares purchased under the Program are accounted for as treasury stock.
     The Company purchased 151,794 shares of treasury stock from employees during the six months ended June 30, 2008 to provide employees with the funds necessary to satisfy payroll tax withholding obligations upon the vesting of shares of restricted stock. The purchases were made at fair market value and the total purchase price for these shares was approximately $4.5 million. These purchases were made pursuant to the terms of the Patterson-UTI Energy, Inc. 2005 Long-Term Incentive Plan and not pursuant to the Program.
12. Income Taxes
     The Company adopted Financial Accounting Standards Board (“FASB”) Interpretation No. 48, Accounting for Uncertainty in Income Taxes – an interpretation of FASB Statement No. 109 (“FIN 48”) on January 1, 2007. FIN 48 clarifies the accounting for uncertainty in income taxes recognized in an enterprise’s financial statements and prescribes a recognition threshold and measurement attribute for the financial statement recognition and measurement of a tax position taken or expected to be taken in a tax return. As of June 30, 2008, the Company had no unrecognized tax benefits. In connection with the adoption of FIN 48, the Company established a policy to account for interest and penalties with respect to income taxes as operating expenses. As of June 30, 2008, the tax years ended December 31, 2004 through December 31, 2007 are open for examination by U.S. taxing authorities. As of June 30, 2008, the tax years ended December 31, 2003 through December 31, 2007 are open for examination by Canadian taxing authorities.

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13. Recently Issued Accounting Standards
     In September 2006, the FASB issued Statement No. 157, Fair Value Measurements (“FAS 157”). FAS 157 defines fair value, establishes a framework for measuring fair value in generally accepted accounting principles, and expands disclosures about fair value measurement. The initial application of FAS 157 is limited to financial assets and liabilities and became effective on January 1, 2008 for the Company. The impact of the initial application was not material. The Company will adopt FAS 157 on a prospective basis for nonfinancial assets and liabilities that are not measured at fair value on a recurring basis on January 1, 2009. The application of FAS 157 to the Company’s nonfinancial assets and liabilities will primarily be limited to assets acquired and liabilities assumed in a business combination, asset retirement obligations and asset impairments, including goodwill and long-lived assets. This application of FAS 157 is not expected to have a material impact to the Company.
     In June 2008, the FASB issued FASB Staff Position No. EITF 03-6-1, Determining Whether Instruments Granted in Share-Based Payment Transactions Are Participating Securities (“FSP EITF 03-6-1”). FSB EITF 03-6-1 clarifies that share-based payment awards that entitle their holders to receive nonforfeitable dividends before vesting should be considered participating securities and, as such, should be included in the calculation of basic earnings-per-share using the two-class method. Certain of the Company’s share-based payment awards entitle the holders to receive nonforfeitable dividends and the application of the provisions of FSP EITF 03-6-1 may have the effect of reducing basic and diluted earnings-per-share by an immaterial amount. FSP EITF 03-6-1 is effective for financial statements issued for fiscal years beginning after December 15, 2008, as well as interim periods within those years. Once effective, all prior-period earnings-per-share data presented must be adjusted retrospectively to conform with the provisions of the FSP. The FSP will be effective for the Company beginning in the quarter ending March 31, 2009 and early application is not permitted.

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ITEM 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations
     Management Overview — We are a leading provider of contract services to the North American oil and natural gas industry. Our services primarily involve the drilling, on a contract basis, of land-based oil and natural gas wells and, to a lesser extent, we provide pressure pumping services and drilling and completion fluid services. In addition to the aforementioned contract services, we also invest, on a working interest basis, in oil and natural gas properties. For the three and six months ended June 30, 2008 and 2007, our operating revenues consisted of the following (dollars in thousands):
                                                                 
    Three Months Ended June 30,     Six Months Ended June 30,  
    2008     2007     2008     2007  
Contract drilling
  $ 416,835       79 %   $ 419,191       80 %   $ 836,984       81 %   $ 886,689       83 %
Pressure pumping
    57,094       11       51,592       10       99,958       10       90,176       8  
Drilling and completion fluids
    38,745       7       39,667       8       71,295       7       70,427       7  
Oil and natural gas
    13,609       3       12,108       2       22,600       2       22,367       2  
 
                                               
 
  $ 526,283       100 %   $ 522,558       100 %   $ 1,030,837       100 %   $ 1,069,659       100 %
 
                                               
     We provide our contract services to oil and natural gas operators in many of the oil and natural gas producing regions of North America. Our contract drilling operations are focused in various regions of Texas, New Mexico, Oklahoma, Arkansas, Louisiana, Mississippi, Alabama, Colorado, Utah, Wyoming, Montana, North Dakota, South Dakota, Pennsylvania and Western Canada, while our pressure pumping services are focused primarily in the Appalachian Basin. Our drilling and completion fluids services are provided to operators offshore in the Gulf of Mexico and on land in Texas, Southeastern New Mexico, Oklahoma and the Gulf Coast region of Louisiana. The oil and natural gas properties in which we hold working interests are primarily located in West and South Texas, Southeastern New Mexico, Utah and Mississippi.
     Our consolidated net income for the second quarter of 2008 decreased by $58.1 million or 42% as compared to the second quarter of 2007. Included in consolidated net income for the second quarter of 2007 was a pre-tax gain of approximately $41.9 million associated with the recovery of embezzled funds and approximately $16.5 million in net pre-tax gains from the disposal of certain oil and natural gas properties and other assets. Excluding the above-mentioned gains, our consolidated net income for the second quarter of 2007 would have been approximately $102 million and the decrease in net income for the second quarter of 2008 would have been approximately $20.2 million or 20%.
     Typically, the profitability of our business is most readily assessed by two primary indicators in our contract drilling segment: our average number of rigs operating and our average revenue per operating day. During the second quarter of 2008, our average number of rigs operating was 244 per day compared to 237 in the second quarter of 2007. Our average revenue per operating day was $18,740 in the second quarter of 2008 compared to $19,410 in the second quarter of 2007. The decrease in our consolidated net income was primarily due to our contract drilling segment experiencing a decrease in the average revenue per operating day and an increase in the average costs per operating day in the second quarter of 2008 as compared to the second quarter of 2007.
     Our revenues, profitability and cash flows are highly dependent upon prevailing prices for natural gas and, to a lesser extent, oil. During periods of improved commodity prices, the capital spending budgets of oil and natural gas operators tend to expand, which results in increased demand for our contract services. Conversely, in periods when these commodity prices deteriorate, the demand for our contract services generally weakens and we experience downward pressure on pricing for our services. In addition, our operations are highly impacted by competition, the availability of excess equipment, labor issues and various other factors which are more fully described as “Risk Factors” included as Item 1A in our Annual Report on Form 10-K for the fiscal year ended December 31, 2007.
     We believe that the liquidity shown on our balance sheet as of June 30, 2008, which includes approximately $335 million in working capital (including $62.2 million in cash and cash equivalents) and approximately $316 million available under a $375 million line of credit, provides us with the ability to build new equipment, make improvements to our equipment, expand into new regions, pursue acquisition opportunities, pay cash dividends and survive downturns in our industry.
     Commitments and Contingencies — As of June 30, 2008, we maintained letters of credit in the aggregate amount of $58.6 million for the benefit of various insurance companies as collateral for retrospective premiums and retained losses which could become payable under the terms of the underlying insurance contracts. These letters of credit expire at various times during each calendar year and are typically renewed annually. As of June 30, 2008, no amounts had been drawn under the letters of credit.

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     As of June 30, 2008, we had non-cancelable commitments to purchase approximately $61.7 million of equipment. In addition to commitments at June 30, 2008, we entered into agreements in July 2008 to purchase new drilling equipment totaling approximately $111 million.
     Trading and Investing — We have not engaged in trading activities that include high-risk securities, such as derivatives and non-exchange traded contracts. We invest cash primarily in highly liquid, short-term investments such as overnight deposits and money market accounts.
     Description of Business — We conduct our contract drilling operations in Texas, New Mexico, Oklahoma, Arkansas, Louisiana, Mississippi, Alabama, Colorado, Utah, Wyoming, Montana, North Dakota, South Dakota, Pennsylvania and Western Canada. As of June 30, 2008, we had approximately 350 currently marketable land-based drilling rigs. We provide pressure pumping services to oil and natural gas operators primarily in the Appalachian Basin. These services consist primarily of well stimulation and cementing for completion of new wells and remedial work on existing wells. We provide drilling fluids, completion fluids and related services to oil and natural gas operators offshore in the Gulf of Mexico and on land in Texas, Southeastern New Mexico, Oklahoma and the Gulf Coast region of Louisiana. Drilling and completion fluids are used by oil and natural gas operators during the drilling process to control pressure when drilling oil and natural gas wells. We also invest, on a working interest basis, in oil and natural gas properties.
     The North American land drilling industry has experienced periods of downturn in demand at various times during the last decade. During these periods, there have been substantially more drilling rigs available than necessary to meet demand. As a result, drilling contractors have had difficulty sustaining profit margins during the downturn periods.
     In addition to adverse effects that future declines in demand could have on us, ongoing factors which could continue to adversely affect utilization rates and pricing, even in an environment of high oil and natural gas prices and increased drilling activity, include:
    movement of drilling rigs from region to region,
 
    reactivation of land-based drilling rigs, or
 
    construction of new drilling rigs.
     As a result of an increase in drilling activity and increased prices for drilling services in 2005 and 2006, construction of new drilling rigs increased significantly in that time period. The addition of new drilling rigs to the market resulted in excess capacity compared to demand, and construction of new drilling rigs moderated in 2007. With a recent increase in demand in 2008, we believe that further construction of new drilling rigs will continue. We cannot predict either the future level of demand for our contract drilling services or future conditions in the oil and natural gas contract drilling business.
Critical Accounting Policies
     In addition to established accounting policies, our consolidated financial statements are impacted by certain estimates and assumptions made by management. No changes in our critical accounting policies have occurred since the filing of the Company’s Annual Report on Form 10-K for the fiscal year ended December 31, 2007.
Liquidity and Capital Resources
     As of June 30, 2008, we had working capital of $335 million including cash and cash equivalents of $62.2 million. For the six months ended June 30, 2008, our sources of cash flow included:
    $273 million from operating activities,
    $4.4 million in proceeds from the disposal of property and equipment, and
    $41.4 million from the exercise of stock options and tax benefits associated with stock-based compensation.
     During the six months ended June 30, 2008, we used $43.5 million to pay dividends on our common stock, $50.0 million to repay borrowings under our line of credit, $4.6 million to repurchase our common stock and $176 million:
    to build new drilling rigs,
    to make capital expenditures for the betterment and refurbishment of our drilling rigs,

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    to acquire and procure drilling equipment and facilities to support our drilling operations,
    to fund capital expenditures for our pressure pumping and drilling and completion fluids divisions, and
    to fund investments in oil and natural gas properties on a working interest basis.
     As of June 30, 2008, we had no borrowings outstanding under our $375 million revolving line of credit. However, we had $58.6 million in letters of credit outstanding and as a result, we had available borrowing capacity of approximately $316 million at June 30, 2008.
     We paid cash dividends during the six months ended June 30, 2008 as follows:
                 
    Per Share     Total  
            (in thousands)  
Paid on March 28, 2008
  $ 0.12     $ 18,493  
Paid on June 27, 2008
    0.16       25,011  
 
           
Total cash dividends
  $ 0.28     $ 43,504  
 
           
     On July 30, 2008, our Board of Directors approved a cash dividend on our common stock in the amount of $0.16 per share to be paid on September 30, 2008 to holders of record as of September 12, 2008. The amount and timing of all future dividend payments, if any, is subject to the discretion of the Board of Directors and will depend upon business conditions, results of operations, financial condition, terms of our credit facilities and other factors.
     On August 1, 2007, our Board of Directors approved a stock buyback program (“Program”), authorizing purchases of up to $250 million of our common stock in open market or privately negotiated transactions. As of June 30, 2008, we had authority remaining under the Program to purchase approximately $180 million of our outstanding common stock. Shares purchased under the Program are accounted for as treasury stock.
     We believe that the current level of cash and short-term investments, together with cash generated from operations, should be sufficient to meet our capital needs. From time to time, acquisition opportunities are evaluated. The timing, size or success of any acquisition and the associated capital commitments are unpredictable. Should opportunities for growth requiring capital arise, we believe we would be able to satisfy these needs through a combination of working capital, cash generated from operations, our existing credit facility and additional debt or equity financing. However, there can be no assurance that such capital would be available on reasonable terms, if at all.
Results of Operations
     The following tables summarize operations by business segment for the three months ended June 30, 2008 and 2007:
                         
Contract Drilling   2008   2007   % Change
    (Dollars in thousands)        
Revenues
  $ 416,835     $ 419,191       (0.6 )%
Direct operating costs
  $ 251,381     $ 228,297       10.1 %
Selling, general and administrative
  $ 1,297     $ 1,400       (7.4 )%
Depreciation
  $ 57,362     $ 51,782       10.8 %
Operating income
  $ 106,795     $ 137,712       (22.5 )%
Operating days
    22,245       21,597       3.0 %
Average revenue per operating day
  $ 18.74     $ 19.41       (3.5 )%
Average direct operating costs per operating day
  $ 11.30     $ 10.57       6.9 %
Average rigs operating
    244       237       3.0 %
Capital expenditures
  $ 67,815     $ 129,913       (47.8 )%
     Revenues in the second quarter of 2008 were relatively flat as compared to the second quarter of 2007 as a result of a slight increase in the number of operating days offset by a slight decrease in the average revenue per operating day. Direct operating costs in the second quarter of 2008 increased as compared to the second quarter of 2007 as a result of increases in operating days and average direct operating costs per operating day. The increase in average direct operating costs per operating day includes costs incurred in activating drilling rigs. Significant capital expenditures have been incurred to build new drilling rigs, to modify and upgrade our

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existing drilling rigs and to acquire additional related equipment such as drill pipe, drill collars, engines, fluid circulating systems, rig hoisting systems and safety enhancement equipment. The increase in depreciation expense was a result of the capital expenditures discussed above.
                         
Pressure Pumping   2008   2007   % Change
    (Dollars in thousands)        
Revenues
  $ 57,094     $ 51,592       10.7 %
Direct operating costs
  $ 32,506     $ 25,777       26.1 %
Selling, general and administrative
  $ 5,834     $ 4,808       21.3 %
Depreciation
  $ 4,477     $ 3,408       31.4 %
Operating income
  $ 14,277     $ 17,599       (18.9 )%
Total jobs
    3,400       3,573       (4.8 )%
Average revenue per job
  $ 16.79     $ 14.44       16.3 %
Average direct operating costs per job
  $ 9.56     $ 7.21       32.6 %
Capital expenditures
  $ 17,689     $ 14,206       24.5 %
     Revenues and direct operating costs increased as a result of an increase in the average revenue and average direct operating costs per job. Increased average revenue per job was due to increased pricing for our services and an increase in larger jobs being driven by demand for services associated with unconventional reservoirs in the Appalachian Basin. Average direct operating costs per job increased as a result of increases in compensation, maintenance and the cost of materials used in our operations, as well as an increase in larger jobs. Selling, general and administrative expense increased primarily as a result of expenses to support the expanding operations of the pressure pumping segment. Significant capital expenditures have been incurred to add capacity, expand our areas of operation and modify and upgrade existing equipment. The increase in depreciation expense is a result of the capital expenditures discussed above.
                         
Drilling and Completion Fluids   2008   2007   % Change
    (Dollars in thousands)        
Revenues
  $ 38,745     $ 39,667       (2.3 )%
Direct operating costs
  $ 31,449     $ 32,628       (3.6 )%
Selling, general and administrative
  $ 2,517     $ 2,436       3.3 %
Depreciation
  $ 724     $ 697       3.9 %
Operating income
  $ 4,055     $ 3,906       3.8 %
Capital expenditures
  $ 1,525     $ 1,023       49.1 %
     The results of operations in our drilling and completions fluids division in the second quarter of 2008 were relatively consistent with those in the second quarter of 2007.
                         
Oil and Natural Gas Production and Exploration   2008   2007   % Change
    (Dollars in thousands,        
    except sales prices)        
Revenues
  $ 13,609     $ 12,108       12.4 %
Direct operating costs
  $ 3,529     $ 2,461       43.4 %
Selling, general and administrative
  $     $ 674       (100.0 )%
Depreciation, depletion and impairment
  $ 2,907     $ 3,857       (24.6 )%
Operating income
  $ 7,173     $ 5,116       40.2 %
Capital expenditures
  $ 4,527     $ 4,619       (2.0 )%
Average net daily oil production (Bbls)
    814       1,107       (26.5 )%
Average net daily natural gas production (Mcf)
    4,126       6,444       (36.0 )%
Average oil sales price (per Bbl)
  $ 123.71     $ 63.04       96.2 %
Average natural gas sales price (per Mcf)
  $ 11.85     $ 7.84       51.1 %
     Revenues increased due to an increase in the average sales price of oil and natural gas partially offset by a decrease in the average net daily production of oil and natural gas and by the elimination of well operations revenue due to the sale in the fourth quarter of 2007 of the operating responsibilities associated with oil and natural gas wells. Average net daily oil and natural gas production decreased primarily due to production declines. The increase in direct operating costs is due to an increase of approximately $610,000 in costs associated with the abandonment of exploratory wells, as well as increased production taxes and other production costs. Selling, general and administrative expenses decreased in the second quarter of 2008 due to the sale of operating responsibilities mentioned above and the resulting elimination of headcount in our oil and natural gas production and exploration segment. Depreciation, depletion and impairment expense in the second quarter of 2008 includes approximately $79,000 incurred to impair certain oil and natural gas properties compared to approximately $534,000 incurred to impair certain oil and natural gas properties in

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the second quarter of 2007. Depletion expense decreased approximately $439,000 primarily due to the lower production of oil and natural gas.
                         
Corporate and Other   2008   2007   % Change
    (Dollars in thousands)        
Selling, general and administrative
  $ 8,099     $ 7,004       15.6 %
Depreciation
  $ 203     $ 203       0.0 %
Other operating expenses
  $ 300     $ 400       (25.0 )%
Gain on disposal of assets
  $ (2,721 )   $ (16,475 )     (83.5 )%
Embezzlement costs (recoveries)
  $     $ (41,935 )     (100.0 )%
Interest income
  $ 493     $ 457       7.9 %
Interest expense
  $ 63     $ 831       (92.4 )%
Other income
  $ 353     $ 109       223.9 %
     Selling, general and administrative expense increased primarily as a result of additional compensation expense and an increase in payroll tax expense associated with the exercise of stock options during the second quarter of 2008. The decrease in gain on disposal of assets in the second quarter of 2008 compared to the second quarter of 2007 is due to a sale in the second quarter of 2007 of certain oil and natural gas properties. Gains and losses on the disposal of assets are considered as part of our corporate activities due to the fact that such transactions relate to decisions of the executive management group regarding corporate strategy. Embezzlement costs (recoveries) in the second quarter of 2007 includes a recovery of $42.5 million, reduced by approximately $600,000 in professional and other costs incurred.
     The following tables summarize operations by business segment for the six months ended June 30, 2008 and 2007:
                         
Contract Drilling   2008   2007   % Change
    (Dollars in thousands)        
Revenues
  $ 836,984     $ 886,689       (5.6 )%
Direct operating costs
  $ 495,748     $ 474,451       4.5 %
Selling, general and administrative
  $ 2,821     $ 2,851       (1.1 )%
Depreciation
  $ 113,234     $ 99,970       13.3 %
Operating income
  $ 225,181     $ 309,417       (27.2 )%
Operating days
    44,478       44,569       (0.2 )%
Average revenue per operating day
  $ 18.82     $ 19.89       (5.4 )%
Average direct operating costs per operating day
  $ 11.15     $ 10.65       4.7 %
Average rigs operating
    244       246       (0.8 )%
Capital expenditures
  $ 135,026     $ 283,189       (52.3 )%
     Revenues in the first six months of 2008 decreased as compared to the first six months of 2007 as a result of decreases in the average revenue per operating day and in the number of operating days. Direct operating costs in the first six months of 2008 increased as compared to the first six months of 2007 as a result of the increase in average direct operating costs per operating day. The increase in average direct operating costs per operating day includes costs incurred in activating drilling rigs. The reactivation and construction of new land drilling rigs in the United States has resulted in excess capacity compared to demand. Operating days, average rigs operating and average revenue per operating day decreased in the first six months of 2008 as a result of the excess capacity of drilling rigs. Significant capital expenditures have been incurred to build new drilling rigs, to modify and upgrade our drilling rigs and to acquire additional related equipment such as drill pipe, drill collars, engines, fluid circulating systems, rig hoisting systems and safety enhancement equipment. The increase in depreciation expense was a result of the capital expenditures discussed above.
                         
Pressure Pumping   2008   2007   % Change
    (Dollars in thousands)        
Revenues
  $ 99,958     $ 90,176       10.8 %
Direct operating costs
  $ 61,011     $ 46,928       30.0 %
Selling, general and administrative
  $ 11,441     $ 8,876       28.9 %
Depreciation
  $ 8,777     $ 6,532       34.4 %
Operating income
  $ 18,729     $ 27,840       (32.7 )%
Total jobs
    6,311       6,412       (1.6 )%
Average revenue per job
  $ 15.84     $ 14.06       12.7 %
Average direct operating costs per job
  $ 9.67     $ 7.32       32.1 %
Capital expenditures
  $ 30,648     $ 30,631       0.1 %

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     Revenues and direct operating costs increased as a result of an increase in the average revenue and average direct operating costs per job. Increased average revenue per job was due to increased pricing for our services and an increase in larger jobs being driven by demand for services associated with unconventional reservoirs in the Appalachian Basin. Average direct operating costs per job increased as a result of increases in compensation, maintenance and the cost of materials used in our operations, as well as an increase in larger jobs. Selling, general and administrative expense increased primarily as a result of expenses to support the expanding operations of the pressure pumping segment. Significant capital expenditures have been incurred to add capacity, expand our areas of operation and modify and upgrade existing equipment. The increase in depreciation expense is a result of the capital expenditures discussed above.
                         
Drilling and Completion Fluids   2008   2007   % Change
    (Dollars in thousands)        
Revenues
  $ 71,295     $ 70,427       1.2 %
Direct operating costs
  $ 59,982     $ 58,019       3.4 %
Selling, general and administrative
  $ 5,143     $ 4,833       6.4 %
Depreciation
  $ 1,448     $ 1,393       3.9 %
Operating income
  $ 4,722     $ 6,182       (23.6 )%
Capital expenditures
  $ 1,533     $ 2,121       (27.7 )%
     Operating income in the first six months of 2007 included a reduction in direct operating costs of approximately $1.3 million related to a recovery received on an insurance claim. The results of operations in our drilling and completions fluids division in the first six months of 2008 were relatively consistent with those in the first six months of 2007 excluding the insurance recovery in 2007 mentioned above.
                         
Oil and Natural Gas Production and Exploration   2008   2007   % Change
    (Dollars in thousands,        
    except sales prices)        
Revenues
  $ 22,600     $ 22,367       1.0 %
Direct operating costs
  $ 5,596     $ 5,739       (2.5 )%
Selling, general and administrative
  $     $ 1,322       (100.0 )%
Depreciation, depletion and impairment
  $ 5,534     $ 7,577       (27.0 )%
Operating income
  $ 11,470     $ 7,729       48.4 %
Capital expenditures
  $ 8,955     $ 9,651       (7.2 )%
Average net daily oil production (Bbls)
    758       1,104       (31.3 )%
Average net daily natural gas production (Mcf)
    3,776       5,944       (36.5 )%
Average oil sales price (per Bbl)
  $ 111.23     $ 59.69       86.3 %
Average natural gas sales price (per Mcf)
  $ 10.57     $ 7.53       40.4 %
     Revenues increased due to an increase in the average sales price of oil and natural gas partially offset by a decrease in the average net daily production of oil and natural gas and by the elimination of well operations revenue due to the sale in the fourth quarter of 2007 of the operating responsibilities associated with oil and natural gas wells. Average net daily oil and natural gas production decreased primarily due to the sale of properties in 2007 and production declines. Selling, general and administrative expenses decreased in the first six months of 2008 due to the sale of the operating responsibilities mentioned above and the resulting elimination of headcount in our oil and natural gas production and exploration segment. Depreciation, depletion and impairment expense in the first six months of 2008 includes approximately $300,000 incurred to impair certain oil and natural gas properties compared to approximately $1.1 million incurred to impair certain oil and natural gas properties in the first six months of 2007. Depletion expense decreased approximately $1.2 million primarily due to the sale of certain properties in 2007.
                         
Corporate and Other   2008   2007   % Change
    (Dollars in thousands)        
Selling, general and administrative
  $ 15,338     $ 13,109       17.0 %
Depreciation
  $ 406     $ 406       0.0 %
Other operating expenses
  $ 600     $ 1,000       (40.0 )%
Gain on disposal of assets
  $ (2,535 )   $ (16,273 )     (84.4 )%
Embezzlement costs (recoveries)
  $     $ (41,935 )     (100.0 )%
Interest income
  $ 836     $ 826       1.2 %
Interest expense
  $ 340     $ 1,594       (78.7 )%
Other income
  $ 737     $ 203       263.1 %

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     Selling, general and administrative expense increased primarily as a result of additional compensation expense and an increase in payroll tax expense associated with the exercise of stock options during the first six months of 2008. The decrease in gain on disposal of assets in the first six months of 2008 compared to the first six months of 2007 is due to a sale in 2007 of certain oil and natural gas properties. Gains and losses on the disposal of assets are considered part of our corporate activities due to the fact that such transactions relate to decisions of the executive management group regarding corporate strategy. Embezzlement costs (recoveries) in the first six months of 2007 included a recovery of $42.5 million, reduced by approximately $600,000 in professional and other costs incurred.
Recently Issued Accounting Standards
     In September 2006, the FASB issued Statement No. 157, Fair Value Measurements (“FAS 157”). FAS 157 defines fair value, establishes a framework for measuring fair value in generally accepted accounting principles, and expands disclosures about fair value measurement. The initial application of FAS 157 is limited to financial assets and liabilities and became effective on January 1, 2008 for us. The impact of the initial application was not material. We will adopt FAS 157 on a prospective basis for nonfinancial assets and liabilities that are not measured at fair value on a recurring basis on January 1, 2009. The application of FAS 157 to our nonfinancial assets and liabilities will primarily be limited to assets acquired and liabilities assumed in a business combination, asset retirement obligations and asset impairments, including goodwill and long-lived assets. This application of FAS 157 is not expected to have a material impact to us.
     In June 2008, the FASB issued FASB Staff Position No. EITF 03-6-1, Determining Whether Instruments Granted in Share-Based Payment Transactions Are Participating Securities (“FSP EITF 03-6-1”). FSB EITF 03-6-1 clarifies that share-based payment awards that entitle their holders to receive nonforfeitable dividends before vesting should be considered participating securities and, as such, should be included in the calculation of basic earnings-per-share using the two-class method. Certain of our share-based payment awards entitle the holders to receive nonforfeitable dividends and the application of the provisions of FSP EITF 03-6-1 may have the effect of reducing basic and diluted earnings-per-share by an immaterial amount. FSP EITF 03-6-1 is effective for financial statements issued for fiscal years beginning after December 15, 2008, as well as interim periods within those years. Once effective, all prior-period earnings-per-share data presented must be adjusted retrospectively to conform with the provisions of the FSP. The FSP will be effective for us beginning in the quarter ending March 31, 2009 and early application is not permitted.
Volatility of Oil and Natural Gas Prices and its Impact on Operations
     Our revenue, profitability, and rate of growth are substantially dependent upon prevailing prices for natural gas and, to a lesser extent, oil. For many years, oil and natural gas prices and markets have been volatile. Prices are affected by market supply and demand factors as well as international military, political and economic conditions, and the ability of OPEC to set and maintain production and price targets. All of these factors are beyond our control. During 2006, the average market price of natural gas retreated from record highs that were set in 2005. The price dropped from an average of $8.98 per Mcf in 2005 to an average of $6.94 per Mcf in 2006 and an average of $7.18 per Mcf in 2007. This resulted in our customers moderating their increase in drilling activities during 2007. This moderation combined with the reactivation and construction of new land drilling rigs in the United States resulted in excess capacity. Prices have rebounded to an average of $10.33 per Mcf for the first six months of 2008 and activity has increased. We expect oil and natural gas prices to continue to be volatile and to affect our financial condition, operations and ability to access sources of capital. A significant decrease in market prices for natural gas could result in a material decrease in demand for drilling rigs and adversely affect our operating results.
     The North American land drilling industry has experienced many downturns in demand at various times during the last decade. During these periods, there have been substantially more drilling rigs available than necessary to meet demand. As a result, drilling contractors have had difficulty sustaining profit margins during the downturn periods.
ITEM 3. Quantitative and Qualitative Disclosures About Market Risk
     We currently have exposure to interest rate market risk associated with borrowings under our credit facility. The revolving credit facility calls for periodic interest payments at a floating rate ranging from LIBOR plus 0.625% to 1.0% or at the prime rate at our election. The applicable rate above LIBOR is based upon our debt to capitalization ratio. Our exposure to interest rate risk due to changes in the prime rate or LIBOR is not material due to the fact that we had no outstanding borrowings as of June 30, 2008.
     We conduct some business in Canadian dollars through our Canadian land-based drilling operations. The exchange rate between Canadian dollars and U.S. dollars has fluctuated during the last several years. If the value of the Canadian dollar against the

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U.S. dollar weakens, revenues and earnings of our Canadian operations will be reduced and the value of our Canadian net assets will decline when they are translated to U.S. dollars. This currency rate risk is not material to our results of operations or financial condition.
ITEM 4. Controls and Procedures
     Disclosure Controls and Procedures — We maintain disclosure controls and procedures (as such terms are defined in Rules 13a-15(e) and 15d-15(e) promulgated under the Securities Exchange Act of 1934, as amended (the “Exchange Act”)), designed to ensure that the information required to be disclosed in the reports that we file with the SEC under the Exchange Act is recorded, processed, summarized and reported within the time periods specified in the SEC’s rules and forms, and that such information is accumulated and communicated to our management, including our Chief Executive Officer (“CEO”) and Chief Financial Officer (“CFO”), as appropriate, to allow timely decisions regarding required disclosure.
     Under the supervision and with the participation of our management, including our CEO and CFO, we conducted an evaluation of the effectiveness of our disclosure controls and procedures as of the end of the period covered by this Quarterly Report on Form 10-Q. Based on that evaluation, our CEO and CFO concluded that our disclosure controls and procedures were effective as of June 30, 2008.
     Changes in Internal Control Over Financial Reporting —There were no changes in our internal control over financial reporting during our most recently completed fiscal quarter that have materially affected or are reasonably likely to materially affect our internal control over financial reporting, as defined in Rule 13a-15(f) under the Exchange Act.
FORWARD LOOKING STATEMENTS AND CAUTIONARY STATEMENTS FOR PURPOSES OF
THE “SAFE HARBOR” PROVISIONS OF THE PRIVATE SECURITIES
LITIGATION REFORM ACT OF 1995
     “Management’s Discussion and Analysis of Financial Condition and Results of Operations” included in Item 2 of Part I of this Quarterly Report on Form 10-Q contains forward-looking statements which are made pursuant to the “safe harbor” provisions of the Private Securities Litigation Reform Act of 1995. These statements include, without limitation, statements relating to: liquidity; financing of operations; continued volatility of oil and natural gas prices; source and sufficiency of funds required for immediate capital needs and additional rig acquisitions (if further opportunities arise); and other matters. The words “believes,” “plans,” “intends,” “expected,” “estimates” or “budgeted” and similar expressions identify forward-looking statements. The forward-looking statements are based on certain assumptions and analyses we make in light of our experience and our perception of historical trends, current conditions, expected future developments and other factors we believe are appropriate in the circumstances. We do not undertake to update, revise or correct any of the forward-looking information. Factors that could cause actual results to differ materially from our expectations expressed in the forward-looking statements include, but are not limited to, the following:
    Changes in prices and demand for oil and natural gas;
 
    Excess industry capacity of land drilling rigs resulting from the reactivation or construction of new land drilling rigs;
 
    Changes in demand for contract drilling, pressure pumping and drilling and completion fluids services;
 
    Shortages of drill pipe and other drilling equipment;
 
    Labor shortages, primarily qualified drilling personnel;
 
    Effects of competition from other drilling contractors and providers of pressure pumping and drilling and completion fluids services;
 
    Occurrence of operating hazards and uninsured losses inherent in our business operations; and
 
    Environmental and other governmental regulation.
     For a more complete explanation of these factors and others, see “Risk Factors” included as Item 1A in our Annual Report on Form 10-K for the fiscal year ended December 31, 2007.

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     You are cautioned not to place undue reliance on any of our forward-looking statements, which speak only as of the date of this Quarterly Report on Form 10-Q or, in the case of documents incorporated by reference, the date of those documents.
PART II — OTHER INFORMATION
ITEM 2. Unregistered Sales of Equity Securities and Use of Proceeds
     The table below sets forth the information with respect to purchases of our common stock made by us during the quarter ended June 30, 2008.
                                 
                            Approximate Dollar  
                    Total Number of     Value of Shares  
                    Shares (or Units)     That May yet be  
                    Purchased as Part     Purchased Under the  
    Total     Average Price     of Publicly     Plans or  
    Number of Shares     Paid per     Announced Plans     Programs (in  
Period Covered   Purchased     Share     or Programs     thousands)(1)  
April 1-30, 2008 (2)
    77,354     $ 29.00           $ 179,646  
May 1-31, 2008
        $           $ 179,646  
June 1-30, 2008 (3)
    58,626     $ 33.58       2,047     $ 179,573  
 
                       
Total
    135,980     $ 30.98       2,047     $ 179,573  
 
                       
 
(1)   On August 1, 2007, our Board of Directors approved a stock buyback program authorizing purchases of up to $250 million of our common stock in open market or privately negotiated transactions. Shares that are purchased under authority other than the approved stock buyback program do not reduce the amount remaining available under the plan.
 
(2)   During April 2008, we purchased 77,354 shares from employees to provide the funds necessary to satisfy their tax withholding obligations upon the vesting of restricted shares. The price paid was the closing price of our common stock on the last business day prior to the date the shares vested. These purchases were made pursuant to the terms of the Patterson-UTI Energy, Inc. 2005 Long-Term Incentive Plan (the “2005 Plan”) and not pursuant to the stock buyback program.
 
(3)   Includes 56,579 shares purchased during June 2008 from employees to provide the respective employees with the funds necessary to satisfy their tax withholding obligations with respect to the vesting of restricted shares. The price paid was the closing price of our common stock on the last business day prior to the date the shares vested. These purchases were made pursuant to the terms of the 2005 Plan and not pursuant to the stock buyback program.
ITEM 4. Submission of Matters to a Vote of Security Holders
     On June 5, 2008, the Company held its Annual Meeting of Stockholders. At the meeting, the stockholders voted on the following matters:
  1.   The election of seven persons to serve as directors of the Company.
 
  2.   The approval of an amendment to Patterson-UTI’s 2005 Long-Term Incentive Plan to increase the number of shares available for issuance under the plan.
 
  3.   Ratification of the appointment of PricewaterhouseCoopers LLP as the independent registered public accounting firm of the Company for the fiscal year ending December 31, 2008.

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     The seven nominees for election to the Board of Directors of the Company were elected at the meeting, and the other proposals received the affirmative votes required for approval. The voting results were as follows:
                     
1.   Election of Directors   Votes For   Votes Withheld
   
Mark S. Siegel
    114,345,500       19,066,089  
   
Kenneth N. Berns
    116,726,827       16,684,762  
   
Charles O. Buckner
    116,369,784       17,041,805  
   
Curtis W. Huff
    118,692,050       14,719,539  
   
Terry H. Hunt
    117,664,973       15,746,616  
   
Kenneth R. Peak
    115,961,923       17,449,666  
   
Cloyce A. Talbott
    113,947,789       19,463,800  
                                     
                Votes           Broker
        Votes For   Against   Abstentions   Non-votes
2.  
Approval of an amendment to Pattterson-UTI’s 2005 Long-Term Incentive Plan to increase the number of shares available for issuance under the plan
    97,484,311       18,449,578       101,790       17,375,910  
   
 
                               
3.  
Ratification of PricewaterhouseCoopers LLP as the Company’s independent registered public accounting firm
    131,861,890       1,497,893       51,806       0  
ITEM 6. Exhibits
          The following exhibits are filed herewith or incorporated by reference, as indicated:
     
3.1  
Restated Certificate of Incorporation, as amended (filed August 9, 2004 as Exhibit 3.1 to the Company’s Quarterly Report on Form 10-Q for the quarterly period ended June 30, 2004 and incorporated herein by reference).
   
 
3.2  
Amendment to Restated Certificate of Incorporation, as amended (filed August 9, 2004 as Exhibit 3.2 to the Company’s Quarterly Report on Form 10-Q for the quarterly period ended June 30, 2004 and incorporated herein by reference).
   
 
3.3  
Second Amended and Restated Bylaws (filed August 6, 2007 as Exhibit 3.3 to the Company’s Quarterly Report on Form 10-Q for the quarterly period ended June 30, 2007 and incorporated herein by reference).
   
 
31.1*  
Certification of Chief Executive Officer pursuant to Rule 13a-14(a)/15d-14(a) of the Securities Exchange Act of 1934, as amended.
   
 
31.2*  
Certification of Chief Financial Officer pursuant to Rule 13a-14(a)/15d-14(a) of the Securities Exchange Act of 1934, as amended.
   
 
32.1*  
Certification of Chief Executive Officer and Chief Financial Officer pursuant to 18 USC Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
 
*   filed herewith

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SIGNATURE
     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.
         
    PATTERSON-UTI ENERGY, INC.
 
       
 
  By:   /s/ Gregory W. Pipkin
 
       
 
      Gregory W. Pipkin
      (Principal Accounting Officer and Duly Authorized Officer)
Chief Accounting Officer and Assistant Secretary
DATED: August 1, 2008

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