Table of Contents

 
 
UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
WASHINGTON, D.C. 20549
 
FORM 10-Q
 
(Mark One)
     
þ   QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15 (d) OF THE SECURITIES EXCHANGE ACT OF 1934
For The Quarterly Period Ended JUNE 30, 2009
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 1-7573
PARKER DRILLING COMPANY
(Exact name of registrant as specified in its charter)
     
Delaware   73-0618660
(State or other jurisdiction of
incorporation or organization)
  (I.R.S. Employer Identification No.)
5 Greenway Plaza, Suite 100, Houston, Texas 77046
(Address of principal executive offices) (Zip code)
(281) 406-2000
(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 þ No o
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 o 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
(Do not check if a smaller reporting company)
Smaller reporting Company o
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
As of July 31, 2009, 116,031,412 common shares were outstanding.
 
 

 


 

TABLE OF CONTENTS
                 
            Page  
Part I       3  
            3  
            3  
            4  
            5  
            6  
            26  
            36  
            36  
       
 
       
Part II.          
            37  
            37  
            37  
            37  
            37  
            37  
            37  
            38  
       
Officer Certifications
       
 EX-31.1
 EX-31.2
 EX-32.1
 EX-32.2

2


Table of Contents

PART I. FINANCIAL INFORMATION
ITEM 1. FINANCIAL STATEMENTS
PARKER DRILLING COMPANY AND SUBSIDIARIES
CONSOLIDATED CONDENSED BALANCE SHEETS
(Dollars in Thousands)
                 
    June 30,     December 31,  
    2009     2008  
    (Unaudited)          
ASSETS
               
Current assets:
               
Cash and cash equivalents
  $ 94,583     $ 172,298  
Accounts and notes receivable, net
    189,228       186,164  
Rig materials and supplies
    28,551       30,241  
Deferred costs
    6,472       7,804  
Deferred income taxes
    9,735       9,735  
Other tax assets
    32,957       40,924  
Other current assets
    38,577       26,125  
 
           
Total current assets
    400,103       473,291  
 
           
 
Property, plant and equipment less accumulated depreciation of $763,155 at June 30, 2009 and $712,688 at December 31, 2008
    710,843       675,548  
 
Deferred income taxes
    27,991       22,956  
 
Other noncurrent assets
    33,765       33,925  
 
           
 
Total assets
  $ 1,172,702     $ 1,205,720  
 
           
LIABILITIES AND STOCKHOLDERS’ EQUITY
               
Current liabilities:
               
Current portion of long-term debt
  $ 12,000     $ 6,000  
Accounts payable and accrued liabilities
    116,106       140,398  
Accrued income taxes
    10,614       12,130  
 
           
Total current liabilities
    138,720       158,528  
 
           
 
               
Long-term debt
    415,558       435,394  
Other long-term liabilities
    18,853       21,396  
Long-term deferred tax liability
    8,192       8,230  
Contingencies (Note 10)
           
Stockholders’ equity:
               
Noncontolling interest
           
Common stock
    19,347       18,910  
Capital in excess of par value
    621,834       619,561  
Accumulated deficit
    (49,802 )     (56,299 )
 
           
Total stockholders’ equity
    591,379       582,172  
 
           
 
Total liabilities and stockholders’ equity
  $ 1,172,702     $ 1,205,720  
 
           
See accompanying notes to the unaudited consolidated condensed financial statements.

3


Table of Contents

PARKER DRILLING COMPANY AND SUBSIDIARIES
CONSOLIDATED CONDENSED STATEMENTS OF OPERATIONS
(Dollars in Thousands Except Per Share and Weighted Average Shares Outstanding)
(Unaudited)
                                 
    Three Months Ended June 30,     Six Months Ended June 30,  
    2009     2008     2009     2008  
Revenues:
                               
International Drilling
  $ 79,279     $ 77,919     $ 156,660     $ 146,659  
U.S. Drilling
    12,889       49,368       22,745       95,256  
Project Management and Engineering Services
    23,891       28,951       55,945       48,130  
Construction Contract
    77,572       20,080       94,317       20,080  
Rental Tools
    28,160       40,412       66,049       79,883  
 
                       
Total revenues
    221,791       216,730       395,716       390,008  
 
                       
Operating expenses:
                               
International Drilling
    48,887       56,612       98,664       109,233  
U.S. Drilling
    11,628       22,130       24,764       43,652  
Project Management and Engineering Services
    18,283       24,707       44,177       40,368  
Construction Contract
    74,000       19,050       89,914       19,050  
Rental Tools
    12,752       16,030       29,206       31,848  
Depreciation and amortization
    28,951       28,166       56,075       54,332  
 
                       
Total operating expenses
    194,501       166,695       342,800       298,483  
 
                       
Total operating gross margin
    27,290       50,035       52,916       91,525  
 
                       
General and administration expense
    (11,126 )     (8,481 )     (24,186 )     (15,149 )
Provision for reduction in carrying value of certain assets
                       
Gain on disposition of assets, net
    704       636       782       1,215  
 
                       
Total operating income
    16,868       42,190       29,512       77,591  
 
                       
Other income and (expense):
                               
Interest expense
    (7,504 )     (7,045 )     (15,570 )     (13,882 )
Interest income
    174       370       460       738  
Equity in loss of unconsolidated joint venture and related charges, net of tax
                      (1,105 )
Other
    (68 )     144       (80 )     204  
 
                       
Total other income and (expense)
    (7,398 )     (6,531 )     (15,190 )     (14,045 )
 
                       
Income before income taxes
    9,470       35,659       14,322       63,546  
Income tax (benefit) expense:
                               
Current
    6,161       9,488       12,899       (1,155 )
Deferred
    (1,082 )     4,274       (5,074 )     19,602  
 
                       
Total income tax expense
    5,079       13,762       7,825       18,447  
 
                       
Net income
    4,391       21,897       6,497       45,099  
Net income attributable to noncontrolling interest
                       
 
                       
Net income attributable to Parker Drilling
  $ 4,391     $ 21,897     $ 6,497     $ 45,099  
 
                       
Basic earnings per share:
                               
Net income
  $ 0.04     $ 0.20     $ 0.06     $ 0.41  
Diluted earnings per share:
                               
Net income
  $ 0.04     $ 0.19     $ 0.06     $ 0.40  
Number of common shares used in computing earnings per share
                               
Basic
    113,180,858       111,422,969       112,723,230       110,984,640  
Diluted
    114,757,123       112,495,655       114,107,675       112,023,524  
See accompanying notes to the unaudited consolidated condensed financial statements.

4


Table of Contents

PARKER DRILLING COMPANY AND SUBSIDIARIES
CONSOLIDATED CONDENSED STATEMENTS OF CASH FLOWS
(Dollars in Thousands)
(Unaudited)
                 
    Six Months Ended June 30,  
    2009     2008  
Cash flows from operating activities:
               
Net income
  $ 6,497     $ 45,099  
Adjustments to reconcile net income to net cash provided by operating activities:
               
Depreciation and amortization
    56,075       54,332  
Gain on disposition of assets
    (782 )     (1,215 )
Equity loss in unconsolidated joint venture and related charges, net of tax
          1,105  
Deferred income tax expense
    (5,074 )     19,602  
Expenses not requiring cash
    5,947       5,929  
Change in accounts receivable
    (809 )     (10,377 )
Change in other assets
    (2,247 )     (4,393 )
Change in liabilities
    (26,582 )     (30,705 )
 
           
Net cash provided by operating activities
    33,025       79,377  
 
           
Cash flows from investing activities:
               
Capital expenditures
    (93,978 )     (89,531 )
Proceeds from the sale of assets
    950       2,487  
Proceeds from insurance settlements
          951  
Investment in unconsolidated joint venture
          (5,000 )
 
           
Net cash used in investing activities
    (93,028 )     (91,093 )
 
           
Cash flows from financing activities:
               
Proceeds from draw on term note facility
          35,000  
Proceeds from draw on revolver credit facility
    4,000       15,000  
Paydown on revolver credit facility
    (20,000 )     (35,000 )
Proceeds from stock options exercised
    101       1,861  
Excess tax cost from stock based compensation
    (1,813 )     380  
 
           
Net cash provided (used) by financing activities
    (17,712 )     17,241  
 
           
Net decrease in cash and cash equivalents
    (77,715 )     5,525  
Cash and cash equivalents at beginning of year
    172,298       60,124  
 
           
Cash and cash equivalents at end of period
  $ 94,583     $ 65,649  
 
           
Supplemental cash flow information:
               
Interest paid
  $ 15,038     $ 13,917  
Income taxes paid
  $ 13,295     $ 24,489  
See accompanying notes to the unaudited consolidated condensed financial statements.

5


Table of Contents

PARKER DRILLING COMPANY AND SUBSIDIARIES
NOTES TO THE UNAUDITED CONSOLIDATED CONDENSED FINANCIAL STATEMENTS
1.   General — In the opinion of the management of Parker Drilling Company, the accompanying unaudited consolidated condensed financial statements reflect all adjustments (of a normally recurring nature) which are necessary for a fair presentation of (1) the financial position as of June 30, 2009 and December 31, 2008, (2) the results of operations for the three and six months ended June 30, 2009 and 2008, and (3) cash flows for the six months ended June 30, 2009 and 2008. Results for the six months ended June 30, 2009 are not necessarily indicative of the results that will be realized for the year ending December 31, 2009. The financial statements should be read in conjunction with our Annual Report on Form 10-K for the year ended December 31, 2008.
 
    Stock-Based Compensation — Total stock-based compensation expense recognized under SFAS No. 123R for the three and six month periods ended June 30, 2009 and for the three and six month periods ended June 30, 2008 was $1.0 million and $2.8 million and $1.9 million and $3.9 million, respectively, all of which was related to restricted stock plan expense. Stock-based compensation expense is included in our consolidated condensed income statement in both “General and administration expense” and “operating expense.” There were no unvested stock options at June 30, 2009. The Company had 245,300 outstanding and exercisable stock options as of June 30, 2009, the aggregate intrinsic value of which was negligible, with a weighted average exercise price of $2.99. Unvested restricted stock awards at December 31, 2008 and June 30, 2009 were 1,458,716 shares and 2,616,828 shares, respectively. Total unrecognized compensation cost related to unamortized restricted stock awards was $3.8 million as of December 31, 2008 and $3.6 million as of June 30, 2009. The remaining unrecognized compensation cost related to unamortized restricted stock awards will be amortized over a weighted-average vesting period of approximately one year.
 
    For the six months ended June 30, 2009, the restricted stock vestings resulted in a tax benefit that was less than the deferred tax asset previously recognized. As a result, a shortfall of $1.8 million for the six months was offset against additional paid in capital in accordance with SFAS 123R.
 
    Convertible Senior Notes, including call options and warrants — In May 2008, the Financial Accounting Standards Board (“FASB”) issued FASB Staff Position (“FSP”) Accounting Principles Board (“APB”) 14-1, “Accounting for Convertible Debt Instruments that May Be Settled in Cash upon Conversion (Including Partial Cash Settlement),” (“FSP APB 14-1”). The FSP requires that the liability and equity components of convertible debt instruments that may be settled in cash upon conversion (including partial cash settlement), commonly referred to as Instrument C under EITF issue No. 90-19, “Convertible Bonds With Issuer Options to Settle for Cash upon Conversion,” be separated to account for the fair value of the debt and equity components as of the date of issuance to reflect the issuer’s non-convertible debt borrowing rate. The FSP is effective for financial periods beginning after December 15, 2008 and is applied retrospectively to all periods presented (retroactive restatement) pursuant to the guidance in SFAS 154, “Accounting Changes and Error Corrections.”
 
    The adoption of the FSP on January 1, 2009 impacted the treatment of the Company’s 2.125 percent convertible senior notes due 2012, by reclassifying a portion of the convertible note balances to additional paid in capital for the estimated fair value of the conversion feature at the date of issuance and creating a discount on the convertible notes that will be amortized through interest expense over the life of the convertible notes. The Company’s non-convertible debt borrowing rate at the date of issuance (July 2007) was 7.25 percent and, accordingly, adoption of the FSP resulted in a significant increase in interest expense, and reduced net income and basic earnings per share in the Company’s consolidated condensed financial statements. Upon adoption, the Company restated its “Accumulated deficit” balance by approximately $6.8 million to reflect the additional interest expense from issuance on July 5, 2007 through December 31, 2008 and reduced “Convertible senior notes” by $19.7 million, reflecting the issuance of the notes at a discount and including amortization of the discount from the transaction date through the adoption date. The Company’s “Paid in capital” balance increased by $26.5 million, reflecting the equity portion of the initial transaction. A deferred tax asset provision of $10.6 million was also established upon initial adoption of the FSP with a corresponding reduction in “Paid in capital.” This provision was then reduced by $2.7 million with the offset to “Accumulated deficit” to reflect the benefit associated with the additional interest recorded from July 2007 to December 31, 2008. See the tables below for changes to the relevant 2008 financials.

6


Table of Contents

NOTES TO THE UNAUDITED CONSOLIDATED CONDENSED FINANCIAL STATEMENTS (continued)
1.   General (continued)
 
    Balance Sheet
                         
                    Restated  
(In thousands)   December 31, 2008     Adjustments     December 31, 2008  
ASSETS
                       
Deferred income taxes
    30,867       (7,911 )     22,956  
 
                   
 
                       
Total assets
  $ 1,213,631             $ 1,205,720  
 
                   
 
                       
LIABILITIES AND STOCKHOLDERS’ EQUITY
                       
 
                       
Long-term debt
    455,073       (19,679 )     435,394  
 
                       
Capital in excess of par
    603,731       15,830       619,561  
Accumulated deficit
    (52,237 )     (4,062 )     (56,299 )
 
                   
 
                       
Total liabilities and stockholders’ equity
  $ 1,213,631             $ 1,205,720  
 
                   
Statement of Operations
                         
                    Restated  
    Three months ended             Three months ended  
(In thousands)   June 30, 2008     Adjustments     June 30, 2008  
 
                       
Other income and (expense):
                       
Interest expense
    (5,876 )     (1,169 )     (7,045 )
 
                       
Income tax (benefit) expense:
                       
Deferred
    4,744       (470 )     4,274  
 
                   
 
                       
Net income
  $ 22,596             $ 21,897  
 
                   
                         
                    Restated  
    Six months ended             Six months ended  
    June 30, 2008     Adjustments     June 30, 2008  
 
                       
Other income and (expense):
                       
Interest expense
    (11,566 )     (2,316 )     (13,882 )
 
                       
Income tax (benefit) expense:
                       
Deferred
    20,533       (931 )     19,602  
 
                   
 
                       
Net income
  $ 46,484             $ 45,099  
 
                   

7


Table of Contents

NOTES TO THE UNAUDITED CONSOLIDATED CONDENSED FINANCIAL STATEMENTS (continued)
1.   General (continued)
 
    The maturity date of the notes (July 15, 2012) is the expected life of the liability due to the current market value of the Company’s stock which is significantly lower than the note conversion price of $13.85 per share. The 7.25 percent cost of non-convertible debt was calculated for use in our decision model at the time that the convertible notes were issued in July 2007. Using 7.25 percent, the fair value of the notes was calculated to be $98.5 million and the discount on the notes $26.5 million. Interest expense for the second quarter and first six months of 2009 was increased by $1.3 million and $2.5 million, respectively to reflect the fair value increment calculated as the amortization of the debt discount, using the effective interest rate method. In addition, $0.7 million of interest expense was recognized during the current quarter for the contractual interest coupon on these convertible notes.
 
    Property, Plant and Equipment - In the first quarter 2009, we implemented a change in accounting estimate to more accurately reflect the useful life of some of the long-lived assets in our U.S. Drilling and International Drilling segments. This resulted in an approximate $8.0 million reduction in depreciation expense in the first six months of 2009. We extended the useful lives of these long-lived assets based on our review of their service lives, technological improvements in the asset, and recent changes to our refurbishment and maintenance practices which helped to extend the lives.
 
    Non-Controlling Interest — In December 2007, the FASB issued Statement of Financial Accounting Standards No. 160, “Noncontrolling Interests in Consolidating Financial Statements” (“SFAS No. 160”). SFAS No. 160 provides enhanced guidance related to the disclosure of information regarding noncontrolling interests in a subsidiary and their effect on the company. This Statement, together with the International Accounting Standards Board’s (“IASB”) International Accounting Standards 27, “Consolidated and Separate Financial Statements,” (“IAS No. 27”) concludes a joint effort by the FASB and IASB to improve the accounting for and reporting of noncontrolling interests in consolidated financial statements and promotes international convergence of accounting standards. For the Company, SFAS No. 160 is effective January 1, 2009. The Company did not apply the disclosure provisions of SFAS No. 160 as the information regarding noncontrolling interests in a subsidiary is immaterial to the consolidated condensed financial statements.
 
    Construction Contract — Historically the Company has primarily constructed drilling rigs for its own use. In some instances, however, the Company enters into contracts to design, construct, deliver and commission a rig for a major customer. In 2008, we were awarded a cost reimbursable, fixed fee contract to construct, deliver and commission a rig for extended-reach drilling work in Alaska. Total cost of the construction phase is currently expected to be approximately $215.0 million. The Company recognizes revenues received and costs incurred related to its construction contract on a gross basis and income for the related fees on a percentage of completion basis using the cost-to-cost method. Construction costs in excess of funds received from the customer are accumulated and reported as part of other current assets. At June 30, 2009, a net asset (progress payments less construction costs) of $12.2 million is included in other current assets.
 
    Cash and Cash Equivalents — For purposes of the balance sheet and the statement of cash flows, the Company considers cash equivalents to be all highly liquid investment instruments that have a remaining maturity of three months or less at the date of purchase.
 
    Subsequent Events — In preparing these financial statements, we have evaluated subsequent events through August 7, 2009, which is the date the financial statements are being issued.

8


Table of Contents

NOTES TO THE UNAUDITED CONSOLIDATED CONDENSED FINANCIAL STATEMENTS (continued)
2.   Earnings Per Share (“EPS”)
                         
    Three Months Ended June 30, 2009  
    Income     Shares     Per-Share  
    (Numerator)     (Denominator)     Amount  
Basic EPS:
                       
Net income
  $ 4,391,000       113,180,858     $ 0.04  
 
                   
 
                       
Effect of dilutive securities:
                       
Stock options and restricted stock
            1,576,265     $  
 
                       
Diluted EPS:
                       
Net income
  $ 4,391,000       114,757,123     $ 0.04  
 
                   
                         
    Six Months Ended June 30, 2009  
    Income     Shares     Per-Share  
    (Numerator)     (Denominator)     Amount  
Basic EPS:
                       
Net income
  $ 6,497,000       112,723,230     $ 0.06  
 
                   
 
                       
Effect of dilutive securities:
                       
Stock options and restricted stock
            1,384,445     $  
 
                       
Diluted EPS:
                       
Net income
  $ 6,497,000       114,107,675     $ 0.06  
 
                   
                         
    Three Months Ended June 30, 2008  
    Income     Shares     Per-Share  
    (Numerator)     (Denominator)     Amount  
Basic EPS:
                       
Net income
  $ 21,897,000       111,422,969     $ 0.20  
 
                   
 
                       
Effect of dilutive securities:
                       
Stock options and restricted stock
            1,072,686     $ (0.01 )
 
                       
Diluted EPS:
                       
Net income
  $ 21,897,000       112,495,655     $ 0.19  
 
                   
                         
    Six Months Ended June 30, 2008  
    Income     Shares     Per-Share  
    (Numerator)     (Denominator)     Amount  
Basic EPS:
                       
Net income
  $ 45,099,000       110,984,640     $ 0.41  
 
                   
 
                       
Effect of dilutive securities:
                       
Stock options and restricted stock
            1,038,884     $ (0.01 )
 
                       
Diluted EPS:
                       
Net income
  $ 45,099,000       112,023,524     $ 0.40  
 
                   

9


Table of Contents

NOTES TO THE UNAUDITED CONSOLIDATED CONDENSED FINANCIAL STATEMENTS (continued)
2.   Earnings Per Share (“EPS”) (continued)
 
    All stock options outstanding during the three and six months ended June 30, 2008, were included in the computation of diluted EPS as the options’ exercise prices were less than the average market price of the common shares. Options to purchase 90,300 shares of common stock with exercise prices ranging from $3.78 to $4.20 per share were outstanding during the three months ended June 30, 2009, and options to purchase 105,300 shares of common stock with exercise prices ranging from $3.34 to $4.20 were outstanding during the six months ended June 30, 2009, but were not included in the computation of diluted EPS because the options’ exercise prices were greater than the average market price of the common shares and would have been anti-dilutive.
 
3.   Business Segments — The five primary services we provide are as follows: International Drilling, U.S. Drilling, Project Management and Engineering Services, Construction Contract and Rental Tools. In the first quarter of 2008, the Company created the Project Management and Engineering Services segment by combining our labor, operations and maintenance and engineering services contracts which had been previously reported in our U.S. Drilling or International Drilling segments. The segment was created in anticipation of the significant expansion of these projects and services and senior management’s resultant separate performance assessment and resource allocation for this segment. This segment’s operations, unlike our U.S. and International Drilling and Rental Tools operations, generally require little or no capital expenditures, and therefore have different performance assessment and resource needs. The Company anticipates further growth of this segment of our business and reviews and assesses its performance separately. In the second quarter of 2008, the Company created the Construction Contract segment to reflect the Company’s Engineering, Procurement, Construction and Installation contract (“EPCI”). The Construction Contract segment income (fees) is accounted for on a percentage of completion basis using the cost-to-cost method. Revenues received and costs incurred related to the contract are recorded on a gross basis.

10


Table of Contents

NOTES TO THE UNAUDITED CONSOLIDATED CONDENSED FINANCIAL STATEMENTS (continued)
3.   Business Segments (continued)
 
    Information regarding our operations by industry segment for the three and six months ended June 30, 2009 and 2008 is as follows:
                                 
    Three Months Ended June 30,     Six Months Ended June 30,  
    2009     2008     2009     2008  
            (Dollars in Thousands)          
Revenues:
                               
International Drilling
  $ 79,279     $ 77,919     $ 156,660     $ 146,659  
U.S. Drilling
    12,889       49,368       22,745       95,256  
Project Management and Engineering Services
    23,891       28,951       55,945       48,130  
Construction Contract
    77,572       20,080       94,317       20,080  
Rental Tools
    28,160       40,412       66,049       79,883  
 
                       
Total revenues
  $ 221,791     $ 216,730     $ 395,716     $ 390,008  
 
                       
Operating gross margin:
                               
International Drilling
  $ 17,163     $ 9,029     $ 33,075     $ 14,788  
U.S. Drilling
    (5,781 )     18,636       (16,239 )     34,309  
Project Management and Engineering Services
    5,608       4,244       11,768       7,762  
Construction Contract
    3,572       1,030       4,403       1,030  
Rental Tools
    6,728       17,096       19,909       33,636  
 
                       
Total operating gross margin
    27,290       50,035       52,916       91,525  
General and administration expense
    (11,126 )     (8,481 )     (24,186 )     (15,149 )
Gain on disposition of assets, net
    704       636       782       1,215  
 
                       
Total operating income
    16,868       42,190       29,512       77,591  
Interest expense
    (7,504 )     (7,045 )     (15,570 )     (13,882 )
Other
    106       514       380       (163 )
 
                       
Income before income taxes
  $ 9,470     $ 35,659     $ 14,322     $ 63,546  
 
                       
4.   Disposition of Assets — Asset dispositions in the first six months of 2008 included the sale of Rig 206 in Indonesia, which we sold at our net book value, and miscellaneous equipment that resulted in a recognized gain of $1.2 million. In the first six months of 2009 asset dispositions consisted primarily of the sale of miscellaneous equipment, resulting in a recognized gain of $0.8 million.
5.   Accounting for Uncertainty in Income Taxes — FIN 48 prescribes a recognition threshold and a measurement attribute for the financial statement recognition and measurement of tax positions taken in a tax return. For those benefits to be recognized, a tax position must be more-likely-than-not to be sustained upon examination by taxing authorities. During March 2008, the Company resolved the pending tax case with the Kazakhstan Ministry of Finance by paying the reduced interest assessment related to tax payments made in 2007 (see Note 8 - Kazakhstan Tax Case), and we accordingly reduced the previously recorded accruals based on the final resolution of this matter. During 2009, the Company recognized $0.7 million of expense related to certain intercompany transactions between our U.S. companies and foreign affiliates. As of June 30, 2009, the Company had a remaining liability for unrecognized tax benefits of $12.3 million primarily related to foreign operations.
6.   Income Tax Expense — Income tax expense was $5.1 million for the second quarter of 2009.

11


Table of Contents

NOTES TO THE UNAUDITED CONSOLIDATED CONDENSED FINANCIAL STATEMENTS (continued)
7.   Saudi Arabia Joint Venture — On April 9, 2008, a subsidiary of Parker executed an agreement (“Sale Agreement”) to sell its 50 percent share interest in Al-Rushaid Parker Drilling Co. Ltd. (“ARPD”) to an affiliate of the Al Rushaid subsidiary that owned the remaining 50 percent interest. The terms of the Sale Agreement provided for a $2.0 million payment to Parker’s subsidiary as consideration for the 50 percent share interest of the Parker subsidiary and partial repayment of investments and advances of the Parker subsidiary to ARPD, including a $5.0 million advance in January 2008. During the first quarter of 2008, the Parker subsidiary made the decision to terminate any future funding to ARPD, and accordingly, the Company did not record equity in losses of ARPD in the first quarter of 2008. We recognized a $1.1 million loss, net of income taxes, in the first quarter of 2008 primarily as a result of nonrecoverable costs, as per the terms of the Sale Agreement, incurred by the Parker affiliate to support ARPD operations during the current quarter. The Parker subsidiary received the $2.0 million on April 15, 2008 in full settlement of the Company’s investment in and advances to ARPD.
 
    The agreement also provides that the Parker subsidiary and its affiliates has been indemnified by ARPD for any and all claims arising out of or related to the operations of ARPD, and there are no restrictions on Parker or any of its affiliates with regard to competing with ARPD in the future, including in Saudi Arabia.
8.   Kazakhstan Tax Case — On October 12, 2005, the Kazakhstan Branch (“PKD Kazakhstan”) of Parker Drilling’s subsidiary, Parker Drilling Company International Limited (“PDCIL”), received an Act of Tax Audit from the Ministry of Finance of Kazakhstan (“MinFin”) assessing PKD Kazakhstan an amount of KZT (Kazakhstan Tenge) 14.9 billion (approximately $125.8 million). Approximately KZT7.5 billion or $63.3 million was assessed for import Value Added Tax (“VAT”), administrative fines and interest on equipment imported to perform the drilling contracts (the “VAT Assessment”) and approximately KZT7.4 billion or $62.5 million for corporate income tax, individual income tax and social tax, administrative fines and interest in connection with the reimbursements received by PDCIL from a client for the upgrade of Barge Rig 257 and other issues related to PKD Kazakhstan’s operations in the Republic of Kazakhstan (the “Income Tax Assessment”).
 
    On May 24, 2006, the Supreme Court of the Republic of Kazakhstan (“SCK”) issued a decision upholding the VAT Assessment. Consistent with its contractual obligations, on November 20, 2006, the client advanced the actual amount of the VAT Assessment and this amount has been remitted to MinFin. The administrative fines related to the VAT Assessment are being appealed by the client who is contractually responsible to reimburse PKD Kazakhstan for any administrative fines ultimately assessed. The client has also contractually agreed to reimburse PKD Kazakhstan for any incremental income taxes that PKD Kazakhstan incurs from the reimbursement of this VAT Assessment. As of June 30, 2009 the appeal of the administrative fines was still being pursued by the client.
 
    After multiple appeals to the SCK and two meetings of the U.S. Competent Authorities under the Mutual Agreement Procedure of the U.S.- Kazakhstan Tax Treaty, the SCK ultimately upheld the Income Tax Assessment and on December 12, 2007, PKD Kazakhstan paid the principal tax portion of the Income Tax Assessment, net of estimated taxes previously paid. After a further appeal against the interest portion of the notice of assessment, on February 25, 2008, the Atyrau Economic Court issued a ruling that interest on the income tax assessed should accrue from the October 12, 2005 assessment date as opposed to the original assessment in 2001, which resulted in a revised interest assessment by the Atyrau Tax Committee of approximately US$13 million, which was paid by PKD Kazakhstan on March 14, 2008, in final resolution of this matter.

12


Table of Contents

NOTES TO THE UNAUDITED CONSOLIDATED CONDENSED FINANCIAL STATEMENTS (continued)
9.   Long-Term Debt
                 
    June 30,     December 31  
    2009     2008  
    (Dollars in Thousands)  
Convertible Senior Notes payable in July 2012 with interest at 2.125% payable semi-annually in January and July, net of unamortized discount of $17,192 at June 30, 2009 and $19,679 at December 31, 2008.
  $ 107,808     $ 105,321  
Senior Notes payable in October 2013 with interest at 9.625% payable semi-annually in April and October net of unamortized premium of $2,750 at June 30, 2009 and $3,073 at December 31, 2008.
    227,750       228,073  
Term Note with amortization beginning September 30, 2009 at equal installments of $3.0 million per quarter.
    50,000       50,000  
Revolving Credit Facility with interest at prime, plus an applicable margin or LIBOR, plus an applicable margin.
    42,000       58,000  
 
           
Total debt
    427,558       441,394  
Less current portion
    12,000       6,000  
 
           
Total long-term debt
  $ 415,558     $ 435,394  
 
           
In May 2008, the Financial Accounting Standards Board (“FASB”) issued FASB Staff Position (“FSP”) Accounting Principles Board (“APB”) 14-1, “Accounting for Convertible Debt Instruments that May Be Settled in Cash upon Conversion (Including Partial Cash Settlement),” (“FSP APB 14-1”). The FSP requires that the liability and equity components of convertible debt instruments that may be settled in cash upon conversion (including partial cash settlement), commonly referred to as Instrument C under EITF issue No. 90-19, “Convertible Bonds With Issuer Options to Settle for Cash upon Conversion,” be separated to account for the fair value of the debt and equity components as of the date of issuance to reflect the issuer’s non-convertible debt borrowing rate. The FSP is effective for financial periods beginning after December 15, 2008 and is applied retrospectively to all periods presented (retroactive restatement) pursuant to the guidance in SFAS 154, “Accounting Changes and Error Corrections” (see Note 1).
On May 15, 2008 we entered into a new Credit Agreement (“2008 Credit Facility”) with a five year senior secured $80.0 million revolving credit facility (“Revolving Credit Facility) and a senior secured term loan facility (“Term Loan Facility”) of up to $50.0 million. The obligations of the Company under the 2008 Credit Facility are guaranteed by substantially all of the Company’s domestic subsidiaries, except for domestic subsidiaries owned by foreign subsidiaries and certain immaterial subsidiaries, each of which has executed a guaranty. The 2008 Credit Facility contains customary affirmative and negative covenants such as minimum ratios for consolidated leverage, consolidated interest coverage and consolidated senior secured leverage.

13


Table of Contents

NOTES TO THE UNAUDITED CONSOLIDATED CONDENSED FINANCIAL STATEMENTS (continued)
9.   Long-Term Debt (continued)
 
    The 2008 Credit Facility is available for general corporate purposes and to fund reimbursement obligations under letters of credit the banks issue on our behalf pursuant to this facility. Revolving loans are available under the 2008 Credit Facility subject to a borrowing base calculation based on a percentage of eligible accounts receivable, certain specified barge drilling rigs and eligible rental equipment of the Company and its subsidiary guarantors. As of June 30, 2009, there were $17.7 million in letters of credit outstanding, $50.0 million outstanding on the Term Loan Facility and $42.0 million outstanding on the Revolving Credit Facility. As of June 30, 2009, the amount drawn represents 75 percent of the capacity of the Revolving Credit Facility. The Term Loan will begin amortizing on September 30, 2009 at equal installments of $3.0 million per quarter. On January 30, 2009, Lehman Commercial Paper, Inc. assigned its obligations under the 2008 Credit Facility to Trustmark National Bank. Upon assignment, Trustmark National Bank fully funded Lehman Commercial Paper, Inc.’s commitment, including an additional $4.0 million that Lehman Commercial Paper, Inc. did not fund in October 2008, therefore increasing our borrowings under the Revolving Credit Facility to $62.0 million at that time. The Company expects to use the drawn amounts over the next twelve months to fund construction of two new rigs for work in Alaska. As of June 30, 2009, the Company is in compliance with all covenants.
 
    The estimated fair value of our $225.0 million principal amount of 9.625% Senior Notes due 2013, based on quoted market prices, was $211.5 million at June 30, 2009. The estimated fair value of our $125.0 million principal amount of Convertible Senior Notes due 2012 was $96.0 million on June 30, 2009.
 
10.   Contingencies
 
    Bangladesh Claim
 
    In September 2005, a subsidiary of the Company was served with a lawsuit filed in the 152nd District Court of Harris County State of Texas on behalf of numerous citizens of Bangladesh claiming $250 million in damages due to various types of property damage and personal injuries (none involving loss of life) arising as a result of two blowouts that occurred in Bangladesh in January and June 2005, although only the June 2005 blowout involved the Company. The court dismissed the case on the basis that Houston, Texas, is not the appropriate location for this suit to be filed. The plaintiffs appealed this dismissal. The Court of Appeals affirmed the dismissal which is now final because the plaintiffs failed to lodge an appeal with the Supreme Court within the required time period, which period ended April 27, 2009.
 
    Asbestos-Related Claims
 
    In August 2004, the Company was notified that certain of its subsidiaries have been named, along with other defendants, in several complaints that have been filed in the Circuit Courts of the State of Mississippi by several hundred persons that allege that they were employed by some of the named defendants between approximately 1965 and 1986. The complaints name as defendants numerous other companies that are not affiliated with the Company, including companies that allegedly manufactured drilling-related products containing asbestos that are the subject of the complaints.

14


Table of Contents

NOTES TO THE UNAUDITED CONSOLIDATED CONDENSED FINANCIAL STATEMENTS (continued)
10.   Contingencies (continued)
 
    Asbestos-Related Claims (continued)
 
    The complaints allege that the Company’s subsidiaries and other drilling contractors used asbestos-containing products in offshore drilling operations, land-based drilling operations and in drilling structures, drilling rigs, vessels and other equipment and assert claims based on, among other things, negligence and strict liability and claims under the Jones Act and that the plaintiffs are entitled to monetary damages. Based on the report of the special master, these complaints have been severed and venue of the claims transferred to the county in which the plaintiff resides or the county in which the cause of action allegedly accrued. Subsequent to the filing of amended complaints, Parker Drilling has joined with other co-defendants in filing motions to compel discovery to determine what plaintiffs have an employment relationship with which defendant, including whether or not any plaintiffs have an employment relationship with subsidiaries of Parker Drilling. Out of 668 amended single-plaintiff complaints filed to date, sixteen (16) plaintiffs have identified Parker Drilling or one of its affiliates as a defendant. Discovery is proceeding in groups of 60 and none of the plaintiff complaints naming Parker are included in the first 60 (Group I). The initial discovery of Group I resulted in certain dismissals with prejudice, two dismissals without prejudice and two withdraws from Group I, leaving only 40 plaintiffs remaining in Group I. Selection of Discovery Group II was completed on April 21, 2008. Out of the 60 plaintiffs selected, Parker Drilling was named in one suit in which the plaintiff claims that during 1973 he earned $587.40 while working for a former subsidiary of a company Parker Drilling acquired in 1996.
 
    The subsidiaries named in these asbestos-related lawsuits intend to defend themselves vigorously and, based on the information available to the Company at this time, the Company does not expect the outcome to have a material adverse effect on its financial condition, results of operations or cash flows; however, the Company is unable to predict the ultimate outcome of these lawsuits. No amounts were accrued at June 30, 2009.
 
    Gulfco Site
 
    Several years ago the Company received an information request under the Comprehensive Environmental Response, Compensation and Liability Act (“CERCLA”) designating Parker Drilling Offshore Corporation, a subsidiary of Parker Drilling as a potentially responsible party with respect to the Gulfco Marine Maintenance, Inc. Superfund Site in Freeport, Texas (EPA No. TX 055144539). The subsidiary responded to this request in 2003 with documents. In January 2008, the subsidiary received an administrative order to participate in an investigation of the site and a study of the remediation needs and alternatives. The EPA alleges that the subsidiary is successor to a party who owned the Gulfco site during the time when chemical releases took place there. Two other parties have been performing that work since mid-2005 under an earlier version of the same order. The subsidiary believes that it has a sufficient cause to decline participation under the order and has notified the EPA of that decision. Non-compliance with an EPA order absent sufficient cause for doing so can result in substantial penalties under CERCLA. The subsidiary is continuing to evaluate its relationship to the site and has conferred with the EPA and the other parties in an effort to resolve the matter. The Company has not yet estimated the amount or impact on our operations, financial position or cash flows of any costs related to the site. To date, the EPA and the other two parties have spent over $2.7 million studying and conducting initial remediation of the site. It is anticipated that an additional $1.3 million will be required to complete the remediation. Other costs (not yet quantified) such as interest and administrative overhead could be added to any action against the Company. Although we can provide no assurance as to the total amount necessary to finally resolve this matter, we currently anticipate that the total claim will not exceed $5 million and will be shared by all responsible parties. The Company does not believe it has any obligation with respect to the remediation of the property, and accordingly no accrual was made as of June 30, 2009.

15


Table of Contents

NOTES TO THE UNAUDITED CONSOLIDATED CONDENSED FINANCIAL STATEMENTS (continued)
10.   Contingencies (continued)
 
    Foreign Corrupt Practices Act (“FCPA”) Investigation
 
    As previously disclosed, the Company received requests from the United States Department of Justice (“DOJ”) in July 2007 and the United States Securities and Exchange Commission (“SEC”) in January 2008 relating to the Company’s utilization of the services of a customs agent. The DOJ and the SEC are conducting parallel investigations into possible violations of U.S. law by the Company, including the Foreign Corrupt Practices Act (the “FCPA”). In particular, the DOJ and the SEC are investigating the Company’s use of customs agents in certain countries in which the Company currently operates or formerly operated, including Kazakhstan and Nigeria. The Company is fully cooperating with the DOJ and SEC investigations and conducting an internal investigation into potential customs and other issues in Kazakhstan and Nigeria. At this point, we are unable to predict the duration, scope or result of the DOJ or the SEC investigation or whether either agency will commence any legal action. If we are not in compliance with the FCPA and other laws governing the conduct of business with foreign government entities (including other United States laws and regulations as well as local laws), we may be subject to criminal and civil penalties and other remedial measures, which could have an adverse impact on our business, results of operations, financial condition and liquidity.
 
    Economic Sanctions Compliance
 
    Our international operations are subject to laws and regulations restricting our international operations including activities involving restricted countries, organizations, entities and persons that have been identified as unlawful actors or that are subject to U.S. economic sanctions. Pursuant to an internal review, we have identified certain shipments of equipment and supplies that were routed through Iran as well as other activities that may have violated applicable U.S. laws and regulations. In addition, we have engaged in drilling wells in the Korpedje Field in Turkmenistan, from where natural gas may be exported by pipeline to Iran. We recently completed a review of these shipments, transactions and drilling activities to determine whether the timing, nature and extent of such activities or other conduct may have given rise to violations of these laws and regulations, and we have provided the results of our review to the appropriate U.S. government agency. We are unable to predict whether the government will initiate an investigation or any proceedings against the Company or the ultimate outcome of any such investigation or proceeding. If U.S. enforcement authorities determine that we are not in compliance with export restrictions, U.S. economic sanctions or other laws and regulations that apply to our international operations, we may be subject to civil or criminal penalties and other remedial measures, which could have an adverse impact on our business, results of operations, financial condition and liquidity.
 
11.   Recent Accounting Pronouncements — In May 2009, the FASB issued Statement of Financial Accounting Standards (SFAS) No. 165, “Subsequent Events,” which establishes general standards of accounting for and disclosures of events that occur after the balance sheet date but before the financial statements are issued or are available to be issued. It requires the disclosure of the date through which an entity has evaluated subsequent events. SFAS No. 165 is effective for interim and annual reporting periods ending after June 15, 2009. We adopted the new disclosure requirements in our June 30, 2009 condensed consolidated financial statements.
 
    In April 2009, the FASB issued FSP SFAS 107-1 and APB 28-1, “Interim Disclosures about Fair Value of Financial Instruments.” This FSP which amends SFAS No. 107, “Disclosures about Fair Value of Financial Instruments,” to require publicly-traded companies, as defined in APB Opinion No. 28, “Interim Financial Reporting,” to provide disclosures on the fair value of financial instruments in interim financial statements. FSP SFAS 107-1 and APB 28-1 is effective for interim periods ending after June 15, 2009. We have adopted the new disclosure requirements in our June 30, 2009 financial statements (see Note 9).

16


Table of Contents

NOTES TO THE UNAUDITED CONSOLIDATED CONDENSED FINANCIAL STATEMENTS (continued)
12.   Parent, Guarantor, Non-Guarantor Unaudited Consolidating Condensed Financial Statements — Set forth on the following pages are the consolidating condensed financial statements of (i) Parker Drilling, (ii) its restricted subsidiaries that are guarantors of the Senior Notes, and Convertible Senior Notes (“the Notes”) and (iii) the restricted and unrestricted subsidiaries that are not guarantors of the Notes. The Notes are guaranteed by substantially all of the domestic restricted subsidiaries of Parker Drilling. There are currently no restrictions on the ability of the restricted subsidiaries to transfer funds to Parker Drilling in the form of cash dividends, loans or advances. Parker Drilling is a holding company with no operations, other than through its subsidiaries. Separate financial statements for each guarantor company are not provided as the company complies with the exception to Rule 3-10(a)(1) of Regulation S-X, set forth in sub-paragraph (f) of such rule. All guarantor subsidiaries are directly or indirectly owned 100% by the parent company, all guarantees are full and unconditional and all guarantees are joint and several.
 
    AralParker (a Kazakhstan joint stock company, owned 100 percent by Parker Drilling (Kazakstan), LLC, Casuarina Limited (a wholly-owned captive insurance company), KDN Drilling Limited, Mallard Argentine Holdings, Ltd., Mallard Drilling of South America, Inc., Mallard Drilling of Venezuela, Inc., Parker Drilling Investment Company, Parker Drilling (Nigeria) Limited, Parker Drilling Company (Bolivia) S.A., Parker Drilling Company Kuwait Limited, Parker Drilling Company Limited (Bahamas), Parker Drilling Company of New Zealand Limited, Parker Drilling Company of Sakhalin, Parker Drilling de Mexico S. de R.L. de C.V., Parker Drilling International of New Zealand Limited, Parker Drilling Tengiz, Ltd., PD Servicios Integrales, S. de R.L. de C.V., PKD Sales Corporation, Parker SMNG Drilling Limited Liability Company (owned 50 percent by Parker Drilling Company International, LLC), Parker Drilling Kazakhstan B.V., Parker Drilling AME Limited, Parker Drilling Asia Pacific, LLC, PD International Holdings C.V.,PD Dutch Holdings C.V., PD Selective Holdings C.V., PD Offshore Holdings C.V., Parker Drilling Netherlands B.V., Parker Drilling Dutch B.V., Parker Hungary Rig Holdings Limited Liability Company, Parker Drilling Spain Rig Services, S L, Parker 3Source, LLC, Parker 5272, LLC, Parker Central Europe Rig Holdings Limited Liability Company, Parker Cyprus Leasing Limited, Parker Cyprus Ventures Limited, Parker Drilling International B.V., Parker Drilling Offshore B.V., Parker Drilling Offshore International, Inc., Parker Drilling Overseas B.V., Parker Drilling Russia B.V., Parker Drillsource, LLC, PD Labor Services, Ltd., PD Labor Sourcing, Ltd., PD Personnel Services, Ltd, SaiPar Drilling Company B.V., and Parker Enex, LLC are all non-guarantor subsidiaries. The Company is providing consolidating condensed financial information of the parent, Parker Drilling, the guarantor subsidiaries, and the non-guarantor subsidiaries as of June 30, 2009 and December 31, 2008 and for the three and six months ended June 30, 2009 and 2008. The consolidating condensed financial statements present investments in both consolidated and unconsolidated subsidiaries using the equity method of accounting.

17


Table of Contents

PARKER DRILLING COMPANY AND SUBSIDIARIES
CONSOLIDATING CONDENSED BALANCE SHEET
(Dollars in Thousands)
(Unaudited)
                                         
    June 30, 2009  
    Parent     Guarantor     Non-Guarantor     Eliminations     Consolidated  
ASSETS
                                       
Current assets:
                                       
Cash and cash equivalents
  $ 26,994     $ 4,951     $ 62,638     $     $ 94,583  
Accounts and notes receivable, net
    19,159       210,533       121,355       (161,819 )     189,228  
Rig materials and supplies
          8,769       19,782             28,551  
Deferred costs
          1,685       4,787             6,472  
Deferred income taxes
    9,735                         9,735  
Other tax assets
    82,929       (48,067 )     (1,905 )           32,957  
Other current assets
    557       23,341       20,934       (6,255 )     38,577  
 
                             
Total current assets
    139,374       201,212       227,591       (168,074 )     400,103  
 
                             
Property, plant and equipment, net
    79       507,111       203,530       123       710,843  
Investment in subsidiaries and intercompany advances
    978,657       873,028       35,366       (1,887,051 )      
Investment in and advances to unconsolidated joint venture
          4,620       (4,620 )            
Other noncurrent assets
    31,722       23,420       17,658       (11,044 )     61,756  
 
                             
Total assets
  $ 1,149,832     $ 1,609,391     $ 479,525     $ (2,066,046 )   $ 1,172,702  
 
                             
LIABILITIES AND STOCKHOLDERS’ EQUITY
                                       
Current liabilities:
                                       
Current portion of long-term debt
  $ 12,000     $     $     $     $ 12,000  
Accounts payable and accrued liabilities
    55,244       308,488       80,155       (327,781 )     116,106  
Accrued income taxes
    1,058       3,310       6,246             10,614  
 
                             
Total current liabilities
    68,302       311,798       86,401       (327,781 )     138,720  
 
                             
Long-term debt
    415,558                         415,558  
Other long-term liabilities
    10       13,046       16,841       (11,044 )     18,853  
Long-term deferred tax liability
          1,237       6,955             8,192  
Intercompany payables
    74,583       583,025       80,571       (738,179 )      
Contingencies (Note 10)
                             
Stockholders’ equity:
                                       
Common stock
    19,347       39,899       21,153       (61,052 )     19,347  
Capital in excess of par value
    621,834       997,081       208,520       (1,205,601 )     621,834  
Retained earnings (accumulated deficit)
    (49,802 )     (336,695 )     59,084       277,611       (49,802 )
 
                             
Total stockholders’ equity
    591,379       700,285       288,757       (989,042 )     591,379  
 
                             
Total liabilities and stockholders’ equity
  $ 1,149,832     $ 1,609,391     $ 479,525     $ (2,066,046 )   $ 1,172,702  
 
                             

18


Table of Contents

PARKER DRILLING COMPANY AND SUBSIDIARIES
CONSOLIDATING CONDENSED BALANCE SHEET
(Dollars in Thousands)
(Unaudited)
                                         
    December 31, 2008  
    Parent     Guarantor     Non-Guarantor     Eliminations     Consolidated  
ASSETS
                                       
Current assets:
                                       
Cash and cash equivalents
  $ 111,324     $ 9,741     $ 51,233     $     $ 172,298  
Accounts and notes receivable, net
    51,792       217,435       131,591       (214,654 )     186,164  
Rig materials and supplies
          11,518       18,723             30,241  
Deferred costs
          2,000       5,804             7,804  
Deferred income taxes
    9,735                         9,735  
Other tax assets
    83,788       (41,008 )     (1,856 )           40,924  
Other current assets
    549       13,755       11,875       (54 )     26,125  
 
                             
Total current assets
    257,188       213,441       217,370       (214,708 )     473,291  
 
                             
Property, plant and equipment, net
    79       465,659       209,686       124       675,548  
Investment in subsidiaries and intercompany advances
    867,684       1,066,216       (88,992 )     (1,844,908 )      
Investment in and advances to unconsolidated joint venture
          4,620       (4,620 )            
Other noncurrent assets
    27,607       21,215       8,059             56,881  
 
                             
Total assets
  $ 1,152,558     $ 1,771,151     $ 341,503     $ (2,059,492 )   $ 1,205,720  
 
                             
LIABILITIES AND STOCKHOLDERS’ EQUITY
                                       
Current liabilities:
                                       
Current portion of long-term debt
  $ 6,000     $     $     $     $ 6,000  
Accounts payable and accrued liabilities
    53,859       337,464       100,305       (351,230 )     140,398  
Accrued income taxes
    540       4,861       6,729             12,130  
 
                             
Total current liabilities
    60,399       342,325       107,034       (351,230 )     158,528  
 
                             
Long-term debt
    435,394                         435,394  
Other long-term liabilities
    10       14,351       7,035             21,396  
Long-term deferred tax liability
          1,237       6,993             8,230  
Intercompany payables
    74,583       583,027       71,299       (728,909 )      
Contingencies (Note 10)
                             
Stockholders’ equity:
                                       
Common stock
    18,910       39,899       21,153       (61,052 )     18,910  
Capital in excess of par value
    619,561       1,045,727       141,112       (1,186,839 )     619,561  
Retained earnings (accumulated deficit)
    (56,299 )     (255,415 )     (13,123 )     268,538       (56,299 )
 
                             
Total stockholders’ equity
    582,172       830,211       149,142       (979,353 )     582,172  
 
                             
Total liabilities and stockholders’ equity
  $ 1,152,558     $ 1,771,151     $ 341,503     $ (2,059,492 )   $ 1,205,720  
 
                             

19


Table of Contents

PARKER DRILLING COMPANY AND SUBSIDIARIES
CONSOLIDATING CONDENSED STATEMENT OF OPERATIONS
(Dollars in Thousands)
(Unaudited)
                                         
    Three months ended June 30, 2009  
    Parent     Guarantor     Non-Guarantor     Eliminations     Consolidated  
Total revenues
  $     $ 170,794     $ 70,742     $ (19,745 )   $ 221,791  
Operating expenses
          133,568       51,727       (19,745 )     165,550  
Depreciation and amortization
          20,956       7,995             28,951  
 
                             
Total operating gross margin
          16,270       11,020             27,290  
 
                             
General and administration expense (1)
    (42 )     (11,074 )     (10 )           (11,126 )
Gain on disposition of assets, net
          595       109             704  
 
                             
Total operating income (loss)
    (42 )     5,791       11,119             16,868  
 
                             
Other income and (expense):
                                       
Interest expense
    (8,517 )     (11,620 )     (60 )     12,693       (7,504 )
Interest income
    10,519       2,017       6,692       (19,054 )     174  
Other
          (69 )     1             (68 )
Equity in net earnings of subsidiaries
    (802 )                 802        
 
                             
Total other income and (expense)
    1,200       (9,672 )     6,633       (5,559 )     (7,398 )
 
                             
Income (loss) before income taxes
    1,158       (3,881 )     17,752       (5,559 )     9,470  
Income tax expense (benefit):
                                       
Current
    (5,185 )     8,257       3,089             6,161  
Deferred
    1,952       (2,943 )     (91 )           (1,082 )
 
                             
Total income tax expense (benefit)
    (3,233 )     5,314       2,998             5,079  
 
                             
Net income (loss)
  $ 4,391     $ (9,195 )   $ 14,754     $ (5,559 )   $ 4,391  
 
                             
 
(1)   All field operations general and administration expenses are included in operating expenses.

20


Table of Contents

PARKER DRILLING COMPANY AND SUBSIDIARIES
CONSOLIDATING CONDENSED STATEMENT OF OPERATIONS
(Dollars in Thousands)
(Unaudited)
                                         
    Three months ended June 30, 2008  
    Parent     Guarantor     Non-Guarantor     Eliminations     Consolidated  
Total revenues
  $     $ 163,721     $ 78,298     $ (25,289 )   $ 216,730  
Operating expenses
    (4 )     102,686       61,136       (25,289 )     138,529  
Depreciation and amortization
          21,025       7,141             28,166  
 
                             
Total operating gross margin
    4       40,010       10,021             50,035  
 
                             
General and administration expense (1)
    (41 )     (8,412 )     (28 )           (8,481 )
Gain on disposition of assets, net
          350       286             636  
 
                             
Total operating income (loss)
    (37 )     31,948       10,279             42,190  
 
                             
Other income and (expense):
                                       
Interest expense
    (8,232 )     (11,792 )     (66 )     13,045       (7,045 )
Interest income
    10,572       1,885       958       (13,045 )     370  
Other
    2       (4 )     146             144  
Equity in net earnings of subsidiaries
    15,164                   (15,164 )      
 
                             
Total other income and (expense)
    17,506       (9,911 )     1,038       (15,164 )     (6,531 )
 
                             
Income (loss) before income taxes
    17,469       22,037       11,317       (15,164 )     35,659  
Income tax (benefit) expense:
                                       
Current
    (4,697 )     10,182       4,003             9,488  
Deferred
    269       3,826       179             4,274  
 
                             
Total income tax (benefit) expense
    (4,428 )     14,008       4,182             13,762  
 
                             
Net income (loss)
  $ 21,897     $ 8,029     $ 7,135     $ (15,164 )   $ 21,897  
 
                             
 
(1)   All field operations general and administration expenses are included in operating expenses.

21


Table of Contents

PARKER DRILLING COMPANY AND SUBSIDIARIES
CONSOLIDATING CONDENSED STATEMENT OF OPERATIONS
(Dollars in Thousands)
(Unaudited)
                                         
    Six months ended June 30, 2009  
    Parent     Guarantor     Non-Guarantor     Eliminations     Consolidated  
Total revenues
  $     $ 293,116     $ 150,971     $ (48,371 )   $ 395,716  
Operating expenses
          220,451       114,645       (48,371 )     286,725  
Depreciation and amortization
          41,010       15,065             56,075  
 
                             
Total operating gross margin
          31,655       21,261             52,916  
 
                             
General and administration expense (1)
    (83 )     (24,069 )     (34 )           (24,186 )
Gain on disposition of assets, net
          608       174             782  
 
                             
Total operating income (loss)
    (83 )     8,194       21,401             29,512  
 
                             
Other income and (expense):
                                       
Interest expense
    (17,399 )     (23,395 )     (163 )     25,387       (15,570 )
Interest income
    21,224       3,674       7,310       (31,748 )     460  
Other
    (3 )     (90 )     13             (80 )
Equity in net earnings of subsidiaries
    (9,073 )                 9,073        
 
                             
Total other income and (expense)
    (5,251 )     (19,811 )     7,160       2,712       (15,190 )
 
                             
Income (loss) before income taxes
    (5,334 )     (11,617 )     28,561       2,712       14,322  
Income tax expense (benefit):
                                       
Current
    (5,689 )     11,418       7,170             12,899  
Deferred
    (6,142 )     1,108       (40 )           (5,074 )
 
                             
Total income tax expense (benefit)
    (11,831 )     12,526       7,130             7,825  
 
                             
Net income (loss)
  $ 6,497     $ (24,143 )   $ 21,431     $ 2,712     $ 6,497  
 
                             
 
(1)   All field operations general and administration expenses are included in operating expenses.

22


Table of Contents

PARKER DRILLING COMPANY AND SUBSIDIARIES
CONSOLIDATING CONDENSED STATEMENT OF OPERATIONS
(Dollars in Thousands)
(Unaudited)
                                         
    Six months ended June 30, 2008  
    Parent     Guarantor     Non-Guarantor     Eliminations     Consolidated  
 
                                       
Total revenues
  $     $ 292,403     $ 144,203     $ (46,598 )   $ 390,008  
 
                                       
Operating expenses
    (3 )     177,049       113,703       (46,598 )     244,151  
Depreciation and amortization
          41,538       12,794             54,332  
 
                             
 
                                       
Total operating gross margin
    3       73,816       17,706             91,525  
 
                             
General and administration expense (1)
    (121 )     (14,996 )     (32 )           (15,149 )
Gain on disposition of assets, net
          932       283             1,215  
 
                             
 
                                       
Total operating income (loss)
    (118 )     59,752       17,957             77,591  
 
                             
 
                                       
Other income and (expense):
                                       
Interest expense
    (16,253 )     (23,578 )     (146 )     26,095       (13,882 )
Changes in fair value of derivative positions
                             
Interest income
    21,261       3,810       1,762       (26,095 )     738  
Equity in loss of unconsolidated joint venture, net of taxes
          (1,105 )                 (1,105 )
Other
    2       6       196             204  
Equity in net earnings of subsidiaries
    47,387                   (47,387 )      
 
                             
 
                                       
Total other income and (expense)
    52,397       (20,867 )     1,812       (47,387 )     (14,045 )
 
                             
 
                                       
Income (loss) before income taxes
    52,279       38,885       19,769       (47,387 )     63,546  
 
                                       
Income tax (benefit) expense:
                                       
Current
    (7,265 )     (1,009 )     7,119             (1,155 )
Deferred
    14,445       4,664       493             19,602  
 
                             
 
                                       
Total income tax expense
    7,180       3,655       7,612             18,447  
 
                             
 
                                       
Net income (loss)
  $ 45,099     $ 35,230     $ 12,157     $ (47,387 )   $ 45,099  
 
                             
 
(1)   All field operations general and administration expenses are included in operating expenses.

23


Table of Contents

PARKER DRILLING COMPANY AND SUBSIDIARIES
CONSOLIDATING CONDENSED STATEMENT OF CASH FLOWS
(Dollars in Thousands)
(Unaudited)
                                         
    Six months ending June 30, 2009  
    Parent     Guarantor     Non-Guarantor     Eliminations     Consolidated  
Cash flows from operating activities:
                                       
Net income (loss)
  $ 6,497     $ (24,143 )   $ 21,431     $ 2,712     $ 6,497  
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
                                       
Depreciation and amortization
          41,010       15,065             56,075  
Gain on disposition of assets
          (608 )     (174 )           (782 )
Deferred tax expense (benefit)
    (6,142 )     1,108       (40 )           (5,074 )
Expenses not requiring cash
    5,947                         5,947  
Equity in net earnings of subsidiaries
    9,073                   (9,073 )      
Change in accounts receivable
    32,634       (43,679 )     10,236             (809 )
Change in other assets
    3,703       12,566       (18,516 )           (2,247 )
Change in liabilities
    1,717       (17,698 )     (10,601 )           (26,582 )
 
                             
 
                                       
Net cash provided by (used in) operating activities
    53,429       (31,444 )     17,401       (6,361 )     33,025  
 
                             
 
                                       
Cash flows from investing activities:
                                       
Capital expenditures
          (84,460 )     (9,518 )           (93,978 )
Proceeds from the sale of assets
          636       314             950  
Intercompany dividend payments
                (6,361 )     6,361        
 
                             
 
                                       
Net cash provided by (used in) investing activities
          (83,824 )     (15,565 )     6,361       (93,028 )
 
                             
 
                                       
Cash flows from financing activities:
                                       
Proceeds from draw on revolver credit facility
    4,000                         4,000  
Paydown on revolver credit facility
    (20,000 )                       (20,000 )
Proceeds from stock options exercised
    101                         101  
Excess tax cost from stock-based compensation
    (1,813 )                       (1,813 )
Intercompany advances, net
    (120,047 )     110,479       9,568              
 
                             
 
                                       
Net cash provided by (used in) financing activities
    (137,759 )     110,479       9,568             (17,712 )
 
                             
 
                                       
Net increase (decrease) in cash and cash equivalents
    (84,330 )     (4,789 )     11,404             (77,715 )
 
                                       
Cash and cash equivalents at beginning of year
    111,324       9,741       51,233             172,298  
 
                             
 
                                       
Cash and cash equivalents at end of period
  $ 26,994     $ 4,951     $ 62,638     $     $ 94,583  
 
                             

24


Table of Contents

PARKER DRILLING COMPANY AND SUBSIDIARIES
CONSOLIDATING CONDENSED STATEMENT OF CASH FLOWS
(Dollars in Thousands)
(Unaudited)
                                         
    Six months ending June 30, 2008  
    Parent     Guarantor     Non-Guarantor     Eliminations     Consolidated  
Cash flows from operating activities:
                                       
Net income (loss)
  $ 45,099     $ 35,230     $ 12,157     $ (47,387 )   $ 45,099  
Adjustments to reconcile net income (loss) to net cash provided by (used in) operating activities:
                                       
Depreciation and amortization
          41,538       12,794             54,332  
Gain on disposition of assets
          (932 )     (283 )           (1,215 )
Equity in loss of unconsolidated joint venture
          1,105                   1,105  
Deferred income tax expense
    14,445       4,664       493             19,602  
Expenses not requiring cash
    5,929                         5,929  
Equity in net earnings of subsidiaries
    (47,387 )                 47,387        
Change in accounts receivable
    8,853       27,542       (46,772 )           (10,377 )
Change in other assets
    (6,762 )     (7,329 )     9,698             (4,393 )
Change in liabilities
    (538 )     (57,855 )     27,688             (30,705 )
 
                             
 
                                       
Net cash provided by operating activities
    19,639       43,963       15,775             79,377  
 
                             
 
                                       
Cash flows from investing activities:
                                       
Capital expenditures
          (72,080 )     (17,451 )           (89,531 )
Proceeds from the sale of assets
          2,487       (0 )           2,487  
Proceeds from insurance claims
                951             951  
Investment in unconslidated joint venture
          (5,000 )                 (5,000 )
 
                             
 
                                       
Net cash used in investing activities
          (74,593 )     (16,500 )           (91,093 )
 
                             
 
                                       
Cash flows from financing activities:
                                       
Proceeds from draw on term note facility
    35,000                         35,000  
Paydown on revolver credit facility
    (35,000 )                       (35,000 )
Proceeds from draw on revolver credit facility
    15,000                         15,000  
Proceeds from stock options exercised
    1,861                         1,861  
Excess tax benefit from stock based compensation
    380                         380  
Intercompany advances, net
    (47,604 )     29,315       18,289              
 
                             
 
                                       
Net cash provided by (used in) financing activities
    (30,363 )     29,315       18,289             17,241  
 
                             
 
                                       
Net increase (decrease) in cash and cash equivalents
    (10,724 )     (1,315 )     17,564             5,525  
 
                                       
Cash and cash equivalents at beginning of year
    31,326       8,314       20,484             60,124  
 
                             
 
                                       
Cash and cash equivalents at end of period
  $ 20,602     $ 6,999     $ 38,048     $     $ 65,649  
 
                             

25


Table of Contents

ITEM 2.   MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS
DISCLOSURE NOTE REGARDING FORWARD-LOOKING STATEMENTS
     This Form 10-Q contains statements that are “forward-looking statements” within the meaning of Section 27A of the Securities Act of 1933, as amended, or the Securities Act, and Section 21E of the Securities Exchange Act of 1934, as amended, or the Exchange Act. All statements contained in this Form 10-Q, other than statements of historical facts, are “forward-looking statements” for purposes of these provisions, including any statements regarding:
    stability of prices and demand for oil and natural gas;
 
    levels of oil and natural gas exploration and production activities;
 
    demand for contract drilling and drilling related services and demand for rental tools;
 
    our future operating results and profitability;
 
    our future rig utilization, dayrates and rental tools activity;
 
    entering into new, or extending existing, drilling contracts and our expectations concerning when our rigs will commence operations under such contracts;
 
    growth through acquisitions of companies or assets;
 
    construction or upgrades of rigs and expectations regarding when these rigs will commence operations;
 
    capital expenditures for acquisition of rigs, construction of new rigs or major upgrades to existing rigs;
 
    entering into joint venture agreements;
 
    our future liquidity;
 
    availability and sources of funds to reduce our debt and expectations of when debt will be reduced;
 
    the outcome of pending or future legal proceedings, tax assessments and other claims;
 
    the availability of insurance coverage for pending or future claims;
 
    the enforceability of contractual indemnification in relation to pending or future claims;
 
    compliance with covenants under our senior credit facility and indentures for our senior notes; and
 
    organic growth of our operations.
     In some cases, you can identify these statements by forward-looking words such as “anticipate,” “believe,” “could,” “estimate,” “expect,” “intend,” “outlook,” “may,” “should,” “will” and “would” or similar words. Forward-looking statements are based on certain assumptions and analyses made by our management in light of their experience and perception of historical trends, current conditions, expected future developments and other factors they believe are relevant. Although our management believes that their assumptions are reasonable based on information currently available, those assumptions are subject to significant risks and uncertainties, many of which are outside of our control. The following factors, as well as any other cautionary language included in this Form 10-Q, provide examples of risks, uncertainties and events that may cause our actual results to differ materially from the expectations we describe in our “forward-looking statements:”
    worldwide economic and business conditions that adversely affect market conditions and/or the cost of doing business;
 
    inability of the Company to access the credit markets;
 
    the U.S. economy and the demand for natural gas;
 
    worldwide demand for oil;
 
    fluctuations in the market prices of oil and natural gas;
 
    imposition of unanticipated trade restrictions;
 
    unanticipated operating hazards and uninsured risks;
 
    political instability, terrorism or war;
 
    governmental regulations, including changes in accounting rules or tax laws or ability to remit funds to the U.S., that adversely affect the cost of doing business;
 
    changes in the tax laws that would allow double taxation on foreign sourced income;
 
    the outcome of our investigation and the parallel investigations by the Securities and Exchange Commission and the Department of Justice into possible violations of U.S. law, including the Foreign Corrupt Practices Act;
 
    adverse environmental events;

26


Table of Contents

DISCLOSURE NOTE REGARDING FORWARD-LOOKING STATEMENTS (continued)
    adverse weather conditions;
 
    global health concerns;
 
    changes in the concentration of customer and supplier relationships;
 
    ability of our customers and suppliers to obtain financing for their operations;
 
    unexpected cost increases for new construction and upgrade and refurbishment projects;
 
    delays in obtaining components for capital projects and ongoing operational maintenance;
 
    shortages of skilled labor;
 
    unanticipated cancellation of contracts by operators;
 
    breakdown of equipment;
 
    other operational problems including delays in start-up of operations;
 
    changes in competition;
 
    the effect of litigation and contingencies; and
 
    other similar factors (some of which are discussed in documents referred to in this Form 10-Q, including the risk factors described in our 2008 Annual Report on Form 10-K and our other reports and filings with the Securities and Exchange Commission).
     Each “forward-looking statement” speaks only as of the date of this Form 10-Q, and we undertake no obligation to publicly update or revise any forward-looking statements, whether as a result of new information, future events or otherwise. Before you decide to invest in our securities, you should be aware that the occurrence of the events described in these risk factors and elsewhere in this Form 10-Q could have a material adverse effect on our business, results of operations, financial condition and cash flows.
OVERVIEW AND OUTLOOK
Summary
     Despite pressures worldwide on contractors and service providers to the energy exploration and development markets, we delivered reasonable results for the second quarter 2009. Our international drilling and project management operations increased their profitability, while slowing demand and increased discounting in the U.S. drilling market reduced the contribution of both our rental tools and Gulf of Mexico barge drilling segments. However, the Gulf of Mexico barge drilling business did return to a positive gross margin in the quarter as compared to the first quarter of 2009, benefiting from a reduced cost structure and stabilizing demand.
     The accumulating weight of global economic conditions and the slowdown in exploration have led us to pare back our expectations of near-term revenue trends for the Company. We have implemented actions to reduce our cost structure while maintaining service to our customers in an effort to sustain profitable operations for the remainder of the year.
Overview
     Revenues for the second quarter of 2009 were $221.8 million, a 2 percent increase over revenues achieved in the second quarter of 2008, attributable to a significant increase in Construction Contract revenue and stability in our International Drilling segment offsetting declines elsewhere. Construction Contract revenues reflect the increased construction content on the BP-owned Liberty rig achieved in the second quarter of 2009 compared to the second quarter of 2008 when the rig was in its early phases. The Liberty rig is approximately 60% complete at this time with a completion date sometime in early 2010. As such, the remaining revenues associated with this project will be recognized over this time frame. International Drilling segment’s revenue increase was driven by a higher average dayrate offset by a moderate decline in utilization. Revenues for the U.S. Drilling segment were lower due to market-driven declines in dayrates and utilization in the Gulf of Mexico barge market. Rental Tools revenues fell primarily because of the decline in U.S. drilling activity and industry discounting.

27


Table of Contents

OVERVIEW AND OUTLOOK (continued)
Overview (continued)
     Operating margin was $27.3 million for the second quarter of 2009 as compared to $50.0 million for the second quarter of 2008, driven primarily by a $24.4 million decline in the U.S. Drilling operating margin and a $10.4 million decline in Rental Tool operating margin resulting from a downturn in drilling activity in their respective markets. This was partially offset by increases in the International Drilling, Project Management and Engineering Services and Construction Contract segments. The increased operating margin for International Drilling is primarily the result of a higher dayrate for our Caspian Sea Barge Rig 257 and further operating cost efficiencies. The increase in operating margin for Project Management and Engineering Services was due to operational improvements. The higher operating margin for Construction Contract reflects the increased construction activity on the BP-owned Liberty rig.
Outlook
     We remain cautious in our outlook for the remainder of 2009, expecting that recent soft market conditions will continue through the rest of the year. We remain confident in the ability of our businesses to manage through these conditions. We believe our strategy, execution abilities, diversification, leaner operating structure and strengthened balance sheet will sustain our performance through the cycle and position us favorably for a recovery. We expect to sustain profitable operations through the rest of the year. Based on current market conditions and our potential business opportunities, we anticipate the third quarter will be the low point for the year to be followed by moderate improvements.
     There was a modest second quarter uptick in the Gulf of Mexico barge market and we were able to capture much of the work available to our U.S. Drilling segment by keeping most of our rig fleet warm-stacked and work-ready during this period. Looking forward, we expect downward pressure on rig utilization and dayrates in the Gulf of Mexico barge market, including an expectation of a typical industry slowdown during the hurricane season. In addition to the seasonal disruption, we expect that the uncertain commodity price outlook, particularly for natural gas, will contribute to further pressure on this market.
     In our International Drilling segment, we believe that the longer terms of contracts covering the majority of our fleet, our strategic position in oil and gas regions experiencing the most activity, and our strong customer relationships with some of the world’s largest exploration companies, position us well to manage through current market conditions. We expect some market pressure on dayrates reflecting declining costs in other areas of the industry and softer market conditions. In addition, we anticipate our Caspian Sea barge drilling rig will be on reduced dayrate in the fourth quarter as it undergoes a scheduled overhaul and upgrade. We are encouraged by the current pace of rig tenders and project discussions and believe that we could see opportunities to improve our rig fleet utilization later in the year.
     Results for our Rental Tools business are expected to decline further in the near term as the result of lower utilization and increased discounts driven primarily by the reduced level of U.S. drilling. We anticipate our presence in the active U.S. shale plays and, later in the year, added deepwater and international rentals will partially offset the effects of the slower pace of U.S. drilling activity.
     Based on the current level of work in our Project Management and Engineering Services segment we anticipate results for this business through the remainder of the year to be similar to those of the second quarter. Construction Contract revenues and gross margin will reflect progress on the BP-owned Liberty rig which has been successfully sea-lifted to its satellite drilling island in Alaska with completion of this contract anticipated to occur in early 2010.

28


Table of Contents

RESULTS OF OPERATIONS
Three Months Ended June 30, 2009 Compared with Three Months Ended June 30, 2008
     We recorded net income of $4.4 million for the three months ended June 30, 2009, as compared to net income of $21.9 million for the three months ended June 30, 2008. Gross margin was $27.3 million for the three months ended June 30, 2009 as compared to $50.0 million for the three months ended June 30, 2008.
     In the first quarter of 2008, we began separate presentation of our project management and engineering services segment. As part of our long-term strategic growth plan, we have begun to separately monitor the results of this non-capital intensive segment of operations. We also created a new segment in the second quarter of 2008 to separately reflect results of our extended-reach rig construction contract.
     The following is an analysis of our operating results for the comparable quarters:
                                 
    Three Months Ended June 30,  
    2009     2008  
    (Dollars in Thousands)  
Revenues:
                               
International Drilling
  $ 79,279       36 %   $ 77,919       36 %
U.S. Drilling
    12,889       6 %     49,368       23 %
Project Management and Engineering Services
    23,891       11 %     28,951       13 %
Construction Contract
    77,572       35 %     20,080       9 %
Rental Tools
    28,160       12 %     40,412       19 %
 
                       
Total revenues
  $ 221,791       100 %   $ 216,730       100 %
 
                       
 
                               
Operating gross margin:
                               
International Drilling gross margin excluding depreciation and amortization (1)
  $ 30,392       38 %   $ 21,307       27 %
U.S. Drilling gross margin excluding depreciation and amortization (1)
    1,261       10 %     27,238       55 %
Project Management and Engineering Services gross margin excluding depreciation and amortization (1)
    5,608       23 %     4,244       15 %
Construction Contract excluding depreciation and amortization (1)
    3,572       5 %     1,030       5 %
Rental Tools gross margin excluding depreciation and amortization (1)
    15,408       55 %     24,382       60 %
Depreciation and amortization
    (28,951 )             (28,166 )        
 
                           
Total operating gross margin (2)
    27,290               50,035          
 
                               
General and administration expense
    (11,126 )             (8,481 )        
Gain on disposition of assets, net
    704               636          
 
                           
Total operating income
  $ 16,868             $ 42,190          
 
                           
 
(1)   Gross margins, excluding depreciation and amortization, are computed as revenues less direct operating expenses, excluding depreciation and amortization expense; gross margin percentages are computed as gross margin, excluding depreciation and amortization, as a percent of revenues. The gross margin amounts, excluding depreciation and amortization, and gross margin percentages should not be used as a substitute for those amounts reported under accounting principles generally accepted in the United States (“GAAP”). However, we monitor our business segments based on several criteria, including gross margin. Management believes that this information is useful to our investors because it more accurately reflects cash generated by segment. Such gross margin amounts are reconciled to our most comparable GAAP measure as follows:
                                         
                    Project              
                    Management              
                    and              
    International             Engineering     Construction        
    Drilling     U.S. Drilling     Services     Contract     Rental Tools  
    (Dollars in Thousands)  
Three Months Ended June 30, 2009
                                       
Operating gross margin (2)
  $ 17,163     $ (5,781 )   $ 5,608     $ 3,572     $ 6,728  
Depreciation and amortization
    13,229       7,042                   8,680  
 
                             
Drilling and rental gross margin excluding depreciation and amortization
  $ 30,392     $ 1,261     $ 5,608     $ 3,572     $ 15,408  
 
                             
 
                                       
Three Months Ended June 30, 2008
                                       
Operating gross margin (2)
  $ 9,029     $ 18,636     $ 4,244     $ 1,030     $ 17,096  
Depreciation and amortization
    12,278       8,602                   7,286  
 
                             
Drilling and rental gross margin excluding depreciation and amortization
  $ 21,307     $ 27,238     $ 4,244     $ 1,030     $ 24,382  
 
                             
 
(2)   Gross margin (operating) — revenues less direct operating expenses, including depreciation and amortization expense.

29


Table of Contents

RESULTS OF OPERATIONS (continued)
International Drilling Segment
     This segment’s revenues increased $1.4 million to $79.3 million during the current quarter when compared to the second quarter of 2008.
     Revenues in our Americas region increased by $5.7 million mainly due to Rig 121 in Mexico and Rig 268 in Colombia being fully operational during the current quarter as they did not become operational until later in 2008. Revenues in our CIS region decreased by $2.4 million primarily due to equipment change out in Western Kazakstan being partially offset by a higher dayrate for our barge rig operating in the Caspian Sea. In our Asia Pacific region, revenues decreased $3.8 million due to lower utilization.
     International operating gross margin, excluding depreciation and amortization, increased $9.1 million to $30.4 million during the current quarter of 2009 as compared to the second quarter of 2008. The improved margins are attributable to the above mentioned increase in revenues and lower operating expenses in our Africa-Middle East and Asia-Pacific regions being partially offset by decreased margin due to the change out of equipment in Western Kazakhstan.
U.S. Drilling Segment
     Revenues for this segment decreased $36.5 million to $12.9 million for the quarter ended June 30, 2009 as compared to the quarter ended June 30, 2008. The decrease in revenues was primarily due to the market downturn which caused utilization for the U.S. barges to drop to 30 percent for the current quarter as compared to 91 percent in the same period in 2008.
     As a result of the above mentioned factors, gross margin, excluding depreciation and amortization, decreased $26.0 million to $1.3 million when compared to the second quarter of 2008.
Project Management and Engineering Services Segment
     Revenues for this segment decreased $5.1 million during the current period as compared to the comparable period of 2008. This decrease was primarily the result of lower reimbursable revenues partially offset by higher revenues related to a Front End Engineering Design (“FEED”) study for our Arkutun Dagi project. Project management and engineering services do not incur depreciation and amortization, and as such, operating gross margin for this segment increased $1.4 million in the current period.
Construction Contract Segment
     Revenues from the construction of the extended-reach drilling rig for use in the Alaskan Beaufort Sea were $77.6 million for the second quarter of 2009. This project is a cost plus fixed fee contract. Operating gross margin for the EPCI project was $3.6 million based on the percentage of completion of the contract.
Rental Tools Segment
     Rental tools revenues decreased $12.3 million to $28.2 million during the current quarter as compared to the second quarter of 2008. Lower overall demand has led to increased discounting, impacting both revenues and gross margin. Rental tools operating gross margins, excluding depreciation and amortization, decreased $9.0 million to $15.4 million for the current quarter as compared to the second quarter of 2008.

30


Table of Contents

RESULTS OF OPERATIONS (continued)
Other Financial Data
     Gain on disposition of assets for the second quarters of 2009 and 2008 was insignificant as a result of minor asset sales during each period. Interest expense increased $0.5 million during the current quarter as compared to the second quarter of 2008 as additional borrowings during 2008 and 2009 led to a higher level of outstanding debt. Interest income remained relatively unchanged on a comparative basis. General and administration expense increased $2.6 million as compared to the second quarter of 2008 due primarily to higher legal and professional fees associated with the ongoing DOJ and SEC investigations into the customs agent discussed in Note 10 in the notes to the unaudited consolidated condensed financial statements.
     Income tax expense was $5.1 million for the second quarter of 2009, as compared to income tax expense of $13.8 million for the second quarter of 2008 which includes the reversal of a $3.1 million reserve for 2007 foreign tax credits. The decrease in income tax expense in the second quarter of 2009, compared to the second quarter of 2008, was primarily due to lower pre-tax income in the second quarter of 2009, as a result of the factors described above as well.
     Depreciation expense benefited by $4.0 million due to a change in accounting estimate to extend the useful life of certain long-lived assets for depreciation purposes. We extended useful lives of these long-lived assets based on our review of their service lives, technological improvements in the asset, and recent changes to our refurbishment and maintenance practices which helped to extend the lives.
Six Months Ended June 30, 2009 Compared with Six Months Ended June 30, 2008
     We recorded net income of $6.5 million for the six months ended June 30, 2009, as compared to net income of $45.1 million for the six months ended June 30, 2008. Gross margin was $52.9 million for the six months ended June 30, 2009 as compared to $91.5 million for the six months ended June 30, 2008.
     In the first quarter of 2008, we began separate presentation of our project management and engineering services segment. As part of our long-term strategic growth plan, we continue to separately monitor the results of this non-capital intensive group of operations. We also created a new segment in the second quarter of 2008 to separately reflect results of our rig construction contract and we continue to separately monitor the results of that segment as well.

31


Table of Contents

RESULTS OF OPERATIONS (continued)
     The following is an analysis of our operating results for the comparable periods:
                                 
    Six Months Ended June 30,  
    2009     2008  
    (Dollars in Thousands)  
Revenues:
                               
International Drilling
  $ 156,660       40 %   $ 146,659       38 %
U.S. Drilling
    22,745       6 %     95,256       25 %
Project Management and Engineering Services
    55,945       14 %     48,130       12 %
Construction Contract
    94,317       24 %     20,080       5 %
Rental Tools
    66,049       16 %     79,883       20 %
 
                       
Total revenues
  $ 395,716       100 %   $ 390,008       100 %
 
                       
 
                               
Operating gross margin:
                               
International Drilling gross margin excluding depreciation and amortization (1)
  $ 57,996       37 %   $ 37,426       26 %
U.S. Drilling gross margin excluding depreciation and amortization (1)
    (2,019 )     -9 %     51,604       54 %
Project Management and Engineering Services gross margin excluding depreciation and amortization (1)
    11,768       21 %     7,762       16 %
Construction Contract excluding depreciation and amortization (1)
    4,403       5 %     1,030       5 %
Rental Tools gross margin excluding depreciation and amortization (1)
    36,843       56 %     48,035       60 %
Depreciation and amortization
    (56,075 )             (54,332 )        
 
                       
Total operating gross margin (2)
    52,916               91,525          
 
                               
General and administration expense
    (24,186 )             (15,149 )        
Gain on disposition of assets, net
    782               1,215          
 
                           
Total operating income
  $ 29,512             $ 77,591          
 
                           
 
(1)   Gross margins, excluding depreciation and amortization, are computed as revenues less direct operating expenses, excluding depreciation and amortization expense; gross margin percentages are computed as gross margin, excluding depreciation and amortization, as a percent of revenues. The gross margin amounts, excluding depreciation and amortization, and gross margin percentages should not be used as a substitute for those amounts reported under accounting principles generally accepted in the United States (“GAAP”). However, we monitor our business segments based on several criteria, including gross margin. Management believes that this information is useful to our investors because it more accurately reflects cash generated by segment. Such gross margin amounts are reconciled to our most comparable GAAP measure as follows:
                                         
                    Project              
                    Management              
                    and              
    International             Engineering     Construction        
    Drilling     U.S. Drilling     Services     Contract     Rental Tools  
    (Dollars in Thousands)  
Six Months Ended June 30, 2009
                                       
Operating gross margin (2)
  $ 33,075     $ (16,239 )   $ 11,768     $ 4,403     $ 19,909  
Depreciation and amortization
    24,921       14,220                   16,934  
 
                             
Drilling and rental gross margin excluding depreciation and amortization
  $ 57,996     $ (2,019 )   $ 11,768     $ 4,403     $ 36,843  
 
                             
 
                                       
Six Months Ended June 30, 2008
                                       
Operating gross margin (2)
  $ 14,788     $ 34,309     $ 7,762     $ 1,030     $ 33,636  
Depreciation and amortization
    22,638       17,295                   14,399  
 
                             
Drilling and rental gross margin excluding depreciation and amortization
  $ 37,426     $ 51,604     $ 7,762     $ 1,030     $ 48,035  
 
                             
 
(2)   Gross margin (operating) — revenues less direct operating expenses, including depreciation and amortization expense.

32


Table of Contents

RESULTS OF OPERATIONS (continued)
International Drilling Segment
     This segment’s revenues increased $10.0 million to $156.7 million during the current period when compared to the same period of 2008.
     Revenues in our Americas region increased by $11.0 million mainly due to an additional three rigs being fully operational during the current period as two were rigging up during the comparable period and one other became operational later in 2008. Revenues in our CIS region increased by $4.9 million primarily attributable to a higher dayrate for our barge rig operating in the Caspian Sea. In our Asia Pacific region, revenues decreased $7.4 million due to lower utilization.
     International operating gross margin, excluding depreciation and amortization, increased $20.6 million to $58.0 million during the current period of 2009 as compared to the same period of 2008. The improved margins are attributable to the above mentioned increase in revenues and lower operating expenses in our Africa-Middle East and Asia-Pacific regions being partially offset by decreased revenue due to the change out of equipment in Western Kazakhstan.
U.S. Drilling Segment
     Revenues for this segment decreased $72.5 million to $22.7 million for the period ended June 30, 2009 as compared to the period ended June 30, 2008. The decrease in revenues was primarily due to the market downturn which caused utilization for the U.S. barges to drop to 28 percent for the current period as compared 83 percent in the same period in 2008. As a result of the above mentioned factors, gross margin, excluding depreciation and amortization, decreased $53.6 million to a negative $2.0 million when compared to the same period of 2008.
Project Management and Engineering Services Segment
     Revenues for this segment increased $7.8 million during the current period as compared to the same period of 2008. This increase was primarily the result of higher reimbursable revenues and revenues related to a Front End Engineering Design (“FEED”) study for our Arkutun Dagi project. Project management and engineering services do not incur depreciation and amortization, and as such, operating gross margin for this segment increased $4.0 million in the current period.
Construction Contract Segment
     Revenues from the construction of the extended-reach drilling rig for use in the Alaskan Beaufort Sea were $94.3 million for the six months ended June 30, 2009. This project is a cost plus fixed fee contract. Operating gross margin for the EPCI project was $4.4 million in the current period based on the percentage of completion of the contract.
Rental Tools Segment
     Rental tools revenues decreased $13.8 million to $66.0 million during the current period as compared to the same period of 2008. Lower overall demand has led to increased discounting, impacting both revenues and gross margin. Rental tools operating gross margins, excluding depreciation and amortization, decreased $11.2 million to $36.8 million for the current period as compared to the same period of 2008.
Other Financial Data
     Gain on dispositions of assets for the first six months of 2009 and 2008 was insignificant as a result of minor asset sales during each period. Interest expense increased $1.7 million during the current period as compared to the same period of 2008 as additional borrowings during the second half of 2008 led to a higher level of outstanding debt. Interest income remained relatively unchanged on a comparative basis. General and administration expense increased $9.0 million as compared to the same period of 2008 due primarily to higher legal and professional fees associated with the ongoing DOJ and SEC investigations into the customs agent discussed in Note 10 in the notes to the unaudited consolidated condensed financial statements.

33


Table of Contents

RESULTS OF OPERATIONS (continued)
Other Financial Data (continued)
     Income tax expense was $7.8 million for the six months ended June 30, 2009, as compared to income tax expense of $18.4 million for the comparable period of 2008. The decrease in income tax expense in the current period of 2009, compared to the same period of 2008, was primarily due to lower pre-tax income in the second quarter of 2009. Income tax for the comparable period of 2008 includes a benefit of $13.4 million of FIN 48 interest and foreign currency exchange rate fluctuations related to our settlement of interest related to our Kazakhstan tax case (see Note 8 — Kazakhstan Tax Case), a valuation allowance of $4.1 million related to a Papua New Guinea deferred tax asset and the reversal of a $3.1 million reserve relating to 2007 foreign tax credits.
     Depreciation expense benefited by $8.0 million due to a change in accounting estimate to extend the useful life of certain long-lived assets for depreciation purposes. We extended useful lives of these long-lived assets based on our review of their service lives, technological improvements in the assets and recent changes to our refurbishment and maintenance practices which helped to extend the lives.
LIQUIDITY AND CAPITAL RESOURCES
Cash Flows
     As of June 30, 2009, we had cash and cash equivalents of $94.6 million, a decrease of $77.7 million from December 31, 2008. The primary source of cash for the six-month period ended June 30, 2009 as reflected on the consolidated condensed statements of cash flows was $33.0 million provided by operating activities. The primary uses of cash were $94.0 million for capital expenditures and a net pay down of $16.0 million on our revolver credit facility. Major capital expenditures for the period included $31.0 million on the construction of two new Alaska rigs and $25.5 million for tubulars and other tools for Rental Tools.
     As of June 30, 2008, we had cash and cash equivalents of $65.6 million, an increase of $5.5 million from December 31, 2007. The primary sources of cash for the six month period ended June 30, 2008 as reflected on the consolidated condensed statements of cash flows were $79.4 million provided by operating activities, net proceeds of $15.0 million from draws on our credit facilities and net proceeds of $3.4 million from the sale of assets and insurance proceeds. The primary uses of cash were $89.5 million for capital expenditures and a $5.0 million investment in our unconsolidated joint venture. Major capital expenditures for the period included $24.0 million on construction of new international land rigs, $12.9 million on the construction of two new Alaska rigs and $24.4 million for tubulars and other rental tools for Quail Tools.
Financing Activity
     On July 5, 2007, we issued $125.0 million aggregate principal amount of 2.125 percent Convertible Senior Notes due July 15, 2012. Interest is payable semiannually on July 15th and January 15th. The initial conversion price is approximately $13.85 per share and is subject to adjustment for the occurrence of certain events stated within the indenture. Proceeds from the transaction were used to call our outstanding Senior Floating Rate notes, to pay the net cost of hedge and warrant transactions and for general corporate purposes. Effectively, the hedge and warrant transactions increase the conversion price to approximately $18.29 per share.
     On September 20, 2007, we replaced our existing $40.0 million Credit Agreement with a new $60.0 million Amended and Restated Credit Agreement (“2007 Credit Facility”) which expires in September 2012. The 2007 Credit Facility was secured by rental tools equipment, accounts receivable and the stock of substantially all of our domestic subsidiaries, other than domestic subsidiaries owned by a foreign subsidiary, and contains customary affirmative and negative covenants such as minimum ratios for consolidated leverage, consolidated interest coverage and consolidated senior secured leverage.

34


Table of Contents

LIQUIDITY AND CAPITAL RESOURCES (continued)
Financing Activity (continued)
     On May 15, 2008 we entered into a new Credit Agreement (“2008 Credit Facility”) with a five year senior secured $80.0 million revolving credit facility (“Revolving Credit Facility) and a senior secured term loan facility (“Term Loan Facility”) of up to $50.0 million. The obligations of the Company under the 2008 Credit Facility are guaranteed by substantially all of the Company’s domestic subsidiaries, except for domestic subsidiaries owned by foreign subsidiaries and certain immaterial subsidiaries, each of which has executed a guaranty. The 2008 Credit Facility contains customary affirmative and negative covenants such as minimum ratios for consolidated leverage, consolidated interest coverage and consolidated senior secured leverage.
     The 2008 Credit Facility is available for general corporate purposes and to fund reimbursement obligations under letters of credit the banks issue on our behalf pursuant to this facility. Revolving loans are available under the 2008 Credit Facility subject to a borrowing base calculation based on a percentage of eligible accounts receivable, certain specified barge drilling rigs and eligible rental equipment of the Company and its subsidiary guarantors. As of June 30, 2009, there were $17.7 million in letters of credit outstanding, $50.0 million outstanding on the Term Loan Facility and $42.0 million outstanding on the Revolving Credit Facility. As of June 30, 2009, the amount drawn represents nearly 75 percent of the capacity of the Revolving Credit Facility. The Term Loan will begin amortizing on September 30, 2009 at equal installments of $3.0 million per quarter. On January 30, 2009, Lehman Commercial Paper, Inc. assigned its obligations under the 2008 Credit Facility to Trustmark National Bank. Upon assignment, Trustmark National Bank fully funded Lehman Commercial Paper, Inc.’s commitment, including an additional $4.0 million that Lehman Commercial Paper, Inc. did not fund in October 2008, therefore increasing our borrowings under the Revolving Credit Facility to $62.0 million at that time. On June 3, 2009, the Company repaid $20.0 million of the Revolving Credit Facility, reducing the amount drawn to $42.0 million at June 30, 2009. The Company expects to use the drawn amounts over the next twelve months to fund construction of two new rigs for work in Alaska. Although the credit crisis may affect certain customers’ ability to pay, the Company has not experienced significant delays in payments from customers as a result of the current credit crisis. The Company anticipates it has sufficient liquidity to meet its expected capital expenditures and manage any delays in collection of receivables, should they occur.
     We had total long-term debt, including current portion, of $427.6 million as of June 30, 2009, which consists of:
    $125.0 million aggregate principal amount of Convertible Senior Notes at a coupon rate of 2.125 percent, which are due July 15, 2012 net of $17.2 million in unamortized debt discount;
 
    $225.0 million aggregate principal amount of 9.625 percent Senior Notes, which are due October 1, 2013 plus an associated $2.8 million in unamortized debt premium; and
 
    $92.0 million drawn against our 2008 Credit Facility, including $42.0 million on our Revolving Credit Facility and $50.0 million on our Term Loan Facility, $12.0 million of which is classified as short term.
     As of June 30, 2009, we had approximately $114.9 million of liquidity which consisted of $94.6 million of cash and cash equivalents on hand and $20.3 million of availability under the Revolving Credit Facility. We do not have any unconsolidated special-purpose entities, off-balance sheet financing arrangements nor guarantees of third-party financial obligations. We have no energy or commodity contracts.

35


Table of Contents

LIQUIDITY AND CAPITAL RESOURCES (continued)
     The following table summarizes our future contractual cash obligations as of June 30, 2009:
                                         
            Less than                     More than  
    Total     1 Year     Years 2 - 3     Years 4 - 5     5 Years  
    (Dollars in Thousands)  
Contractual cash obligations:
                                       
Long-term debt — principal (1)
  $ 400,000     $ 12,000     $ 21,000     $ 367,000     $  
Long-term debt — interest (1)
    109,008       27,215       53,150       28,643        
Operating leases (2)
    26,833       5,042       5,419       3,955       12,417  
Purchase commitments (3)
    61,552       61,552                    
 
                             
 
                                       
Total contractual obligations
  $ 597,393     $ 105,809     $ 79,569     $ 399,598     $ 12,417  
 
                             
 
                                       
Commercial commitments:
                                       
Long-term debt —
                                       
Revolving credit facility (4)
  $ 42,000     $     $     $ 42,000     $  
Standby letters of credit (4)
    17,734       17,734                    
 
                             
 
                                       
Total commercial commitments
  $ 59,734     $ 17,734     $     $ 42,000     $  
 
                             
 
(1)   Long-term debt includes the principal and interest cash obligations of the 9.625 percent Senior Notes and the 2.125 percent Convertible Senior Notes as well as $50.0 million of term loans drawn on our Credit Facility. The remaining unamortized premium of $2.8 million on the 9.625 percent Senior Notes and unamortized discount of $17.2 million on the 2.125% Convertible Senior Notes are not included in the contractual cash obligations schedule.
 
(2)   Operating leases consist of lease agreements in excess of one year for office space, equipment, vehicles and personal property.
 
(3)   We have purchase commitments outstanding as of June 30, 2009, related to rig upgrade projects and new rig construction.
 
(4)   We have a $130.0 million credit agreement of which $80.0 million is a revolving credit facility. As of June 30, 2009, we had drawn down $42.0 million under the revolving credit facility and $17.7 million of availability has been used to support letters of credit that have been issued. The revolving credit facility expires May 14, 2013.
ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK
     There have been no material changes in market risk faced by us from those reported in our 2008 Annual Report on Form 10-K filed with the SEC. For more information on market risk, see Part II, Items 7 and 7A in our 2008 Annual Report on Form 10-K.
ITEM 4. CONTROLS AND PROCEDURES
     Evaluation of Disclosure Controls and Procedures — We maintain disclosure controls and procedures that are designed to ensure that information required to be disclosed in our Securities Exchange Act reports 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 and chief financial officer, as appropriate, to allow timely decisions regarding required disclosure based on the definition of “disclosure controls and procedures” in Rule 13a-15(e). In designing and evaluating the disclosure controls and procedures, management recognized that disclosure controls and procedures, no matter how well designed and operated, can provide only reasonable assurance of achieving the desired control objectives, and management necessarily was required to apply its judgment in evaluating the cost-benefit relationship of possible disclosure controls and procedures. We performed evaluations under the supervision and with the participation of our management, including our chief executive officer and our chief financial officer, of the effectiveness of the design and operation of our disclosure controls and procedures as of June 30, 2009. Based on the foregoing, our chief executive officer and chief financial officer concluded that our disclosure controls and procedures were effective at the reasonable assurance level at June 30, 2009.
     Changes in Internal Control Over Financial Reporting There have been no changes in our internal control over financial reporting during the quarter ended June 30, 2009 covered by this report that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

36


Table of Contents

PART II. OTHER INFORMATION
ITEM 1. LEGAL PROCEEDINGS
     For information regarding legal proceedings, see Note 10, “Contingencies,” in Item 1 of Part I of this quarterly report on Form 10-Q, which information is incorporated herein by reference into this item.
ITEM 1A. RISK FACTORS
     There have been no material changes in risk factors involving the Company or its subsidiaries from those previously disclosed in the Company’s Annual Report on Form 10-K for the fiscal year ended December 31, 2008.
ITEM 2. UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS
Issuer Purchases of Equity Securities
         
    Total Number of   Average Price
Date   Shares Purchased   Paid Per Share
April 1, 2009
  23,917   $1.88
April 6, 2009   41,720   $2.01
May 27, 2009   36,361   $4.27
ITEM 3. DEFAULTS UPON SENIOR SECURITIES
     None.
ITEM 4. SUBMISSION OF MATTERS TO A VOTE OF SECURITY HOLDERS
     None.
ITEM 5. OTHER INFORMATION
     None.
ITEM 6. EXHIBITS
     (a) Exhibits: The following exhibits are filed or furnished as a part of this report:
     
Exhibit    
Number   Description
31.1
  Section 302 Certification — Chairman and Chief Executive Officer
31.2
  Section 302 Certification — Senior Vice President and Chief Financial Officer
32.1
  Section 906 Certification — Chairman and Chief Executive Officer
32.2
  Section 906 Certification — Senior Vice President and Chief Financial Officer

37


Table of Contents

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.
         
  PARKER DRILLING COMPANY
 
 
Date: August 7, 2009  By:   /s/ Robert L. Parker Jr.    
    Robert L. Parker Jr.   
    Chairman and Chief Executive Officer   
 
     
  By:   /s/ W. Kirk Brassfield    
    W. Kirk Brassfield   
    Senior Vice President and Chief Financial Officer   

38


Table of Contents

         
INDEX TO EXHIBITS
     
Exhibit    
Number   Description
31.1
  Section 302 Certification — Chairman and Chief Executive Officer
31.2
  Section 302 Certification — Senior Vice President and Chief Financial Officer
32.1
  Section 906 Certification — Chairman and Chief Executive Officer
32.2
  Section 906 Certification — Senior Vice President and Chief Financial Officer

39