Parker Drilling (PKDC) 10-Q 3 Aug 16 2016 Q2 Quarterly report Financial data

Document and Entity Information

Document and Entity Information - shares	6 Months Ended
	Jun. 30, 2016	Aug. 01, 2016
Document Document And Entity Information [Abstract]
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Jun. 30, 2016
Document Fiscal Year Focus	2,016
Document Fiscal Period Focus	Q2
Trading Symbol	PKD
Entity Registrant Name	PARKER DRILLING CO /DE/
Entity Central Index Key	76,321
Current Fiscal Year End Date	--12-31
Entity Filer Category	Accelerated Filer
Entity Common Stock, Shares Outstanding		124,695,455

CONSOLIDATED CONDENSED BALANCE

CONSOLIDATED CONDENSED BALANCE SHEETS - USD ($) $ in Thousands	Jun. 30, 2016	Dec. 31, 2015
Current assets:
Cash and cash equivalents	$ 109,034	$ 134,294
Accounts and Notes Receivable, net of allowance for bad debts of $8,192 at June 30, 2016 and $8,694 at December 31, 2015.	153,189	175,105
Rig materials and supplies	32,615	34,937
Other current assets	26,805	22,405
Total current assets	321,643	366,741
Property, plant and equipment, net of accumulated depreciation of $1,360,282 at June 30, 2016 and $1,302,380 at December 31, 2015.	747,017	805,841
Goodwill (Note 3)	6,708	6,708
Intangible assets, net (Note 3)	11,392	13,377
Deferred income taxes	87,311	139,282
Other noncurrent assets	38,700	34,753
Total assets	1,212,771	1,366,702
Current liabilities:
Accounts payable and accrued liabilities	109,091	129,703
Accrued income taxes	5,777	6,418
Total current liabilities	114,868	136,121
Long-term debt, net of unamortized debt issuance costs of $9,452 at June 30, 2016 and $10,202 at December 31, 2015.	575,548	574,798
Other long-term liabilities	15,049	18,617
Long-term deferred tax liability	76,475	68,654
Stockholders’ equity:
Common stock	20,766	20,518
Capital in excess of par value	670,419	669,120
Accumulated deficit	(254,895)	(119,238)
Accumulated other comprehensive loss	(5,459)	(1,888)
Total stockholders’ equity	430,831	568,512
Total equity	430,831	568,512
Total liabilities and stockholders’ equity	$ 1,212,771	$ 1,366,702

CONSOLIDATED CONDENSED BALANCE3

CONSOLIDATED CONDENSED BALANCE SHEETS (Parenthetical) - USD ($) $ in Thousands	Jun. 30, 2016	Dec. 31, 2015
Statement of Financial Position [Abstract]
Allowance for bad debts	$ 8,192	$ 8,694
Accumulated depreciation and amortization on property, plant and equipment	$ 1,360,990	$ 1,302,380

CONSOLIDATED CONDENSED STATEMEN

CONSOLIDATED CONDENSED STATEMENTS OF OPERATIONS (Unaudited) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Income Statement [Abstract]
Revenues	$ 105,287	$ 185,941	$ 235,790	$ 390,017
Expenses:
Operating expenses	89,195	143,569	197,312	282,839
Depreciation and amortization	36,317	38,351	72,131	78,890
Total expenses	125,512	181,920	269,443	361,729
Total operating gross margin	(20,225)	4,021	(33,653)	28,288
General and administration expense	(7,995)	(9,511)	(17,776)	(20,348)
Provision for reduction in carrying value of certain assets	0	2,316	0	2,316
Gain (loss) on disposition of assets, net	(2)	(138)	(62)	2,303
Total operating income (loss)	(28,222)	(7,944)	(51,491)	7,927
Other income and (expense):
Interest expense	(12,187)	(11,396)	(23,749)	(22,474)
Interest income	32	19	39	202
Other	(358)	(1,529)	2,127	(2,909)
Total other expense	(12,513)	(12,906)	(21,583)	(25,181)
Loss before income taxes	(40,735)	(20,850)	(73,074)	(17,254)
Income tax expense (benefit)	(913)	(6,916)	62,583	(7,098)
Net loss	(39,822)	(13,934)	(135,657)	(10,156)
Less: Net income attributable to noncontrolling interest	0	95	0	651
Net loss attributable to controlling interest	$ (39,822)	$ (14,029)	$ (135,657)	$ (10,807)
Basic loss per share	$ (0.32)	$ (0.11)	$ (1.10)	$ (0.09)
Diluted loss per share	$ (0.32)	$ (0.11)	$ (1.10)	$ (0.09)
Number of common shares used in computing earnings per share:
Basic	124,101,349	122,481,425	123,595,793	122,175,511
Diluted	124,101,349	122,481,425	123,595,793	122,175,511

CONSOLIDATED CONDENSED STATEME5

CONSOLIDATED CONDENSED STATEMENT OF COMPREHENSIVE INCOME (LOSS) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Comprehensive income:
Net loss	$ (39,822)	$ (13,934)	$ (135,657)	$ (10,156)
Other comprehensive income (loss), net of tax:
Currency translation difference on related borrowings	(307)	647	195	(1,023)
Currency translation difference on foreign currency net investments	(2,228)	1,723	(3,766)	874
Total other comprehensive income (loss), net of tax:	(2,535)	2,370	(3,571)	(149)
Comprehensive loss	(42,357)	(11,564)	(139,228)	(10,305)
Comprehensive loss attributable to noncontrolling interest	0	(95)	0	(489)
Comprehensive loss attributable to controlling interest	$ (42,357)	$ (11,659)	$ (139,228)	$ (10,794)

CONSOLIDATED CONDENSED STATEME6

CONSOLIDATED CONDENSED STATEMENTS OF CASH FLOWS (Unaudited) - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015
Cash flows from operating activities:
Net loss	$ (135,657)	$ (10,156)
Adjustments to reconcile net income to net cash flows from operating activities:
Depreciation and amortization	72,131	78,890
Accretion of contingent consideration	419	306
Loss on debt modification	(1,088)	0
Provision for reduction in carrying value of certain assets	0	2,316
(Gain) loss on disposition of assets	62	(2,303)
Deferred income tax expense (benefit)	59,305	(17,126)
Expenses not requiring cash	(5,226)	(5,308)
Accounts and notes receivable	22,319	39,683
Other assets	(2,992)	(7,352)
Accounts payable and accrued liabilities	(6,862)	14,763
Accrued income taxes	(3,985)	(1,236)
Net cash provided by operating activities	602	103,093
Cash flows from investing activities:
Capital expenditures	(16,257)	(54,605)
Proceeds from the sale of assets	1,387	288
Proceeds from insurance settlements	0	2,500
Acquisition, net of cash acquired	0	(10,431)
Net cash used in investing activities	(14,870)	(62,248)
Cash flows from financing activities:
Repayments of long-term debt	0	(30,000)
Payments of debt issuance costs	0	(1,359)
Payment for noncontrolling interest	3,375	0
Payments of contingent consideration	(6,000)	0
Excess tax (expense) from stock based compensation	(1,617)	(999)
Net cash used in financing activities	(10,992)	(32,358)
Net increase (decrease) in cash and cash equivalents	(25,260)	8,487
Cash and cash equivalents, beginning of year	134,294	108,456
Cash and cash equivalents, end of period	109,034	116,943
Supplemental cash flow information:
Interest paid	20,588	20,805
Income taxes paid	$ 9,672	$ 16,436

General

General	6 Months Ended
	Jun. 30, 2016
Accounting Policies [Abstract]
General	General The Consolidated Condensed Financial Statements as of June 30, 2016 and for the three and six months ended June 30, 2016 and 2015 are unaudited. In the opinion of Parker Drilling Company (Parker Drilling or the Company), these financial statements include all adjustments, which, unless otherwise disclosed, are of a normal recurring nature, necessary for a fair presentation of the financial position, results of operations, comprehensive income, and cash flows for the periods presented. The results for interim periods are not necessarily indicative of results for the entire year. The financial statements presented herein should be read in connection with the financial statements included in our Annual Report on Form 10-K for the year ended December 31, 2015 . Nature of Operations — Our business is comprised of two business lines: (1) Drilling Services and (2) Rental Tools Services. We report our Rental Tools Services business as one reportable segment (Rental Tools) and report our Drilling Services business as two reportable segments: (1) U.S. (Lower 48) Drilling and (2) International & Alaska Drilling. In our Drilling Services business, we drill oil and gas wells for customers in both the United States (U.S.) and international markets. We provide this service with both Company-owned rigs and customer-owned rigs. We refer to the provision of drilling services with customer-owned rigs as our operations and maintenance (O&M) service in which operators own their own drilling rigs but choose Parker Drilling to operate and maintain the rigs for them. The nature and scope of activities involved in drilling an oil and gas well are similar whether the well is drilled with a Company-owned rig (as part of a traditional drilling contract) or a customer-owned rig (as part of an O&M contract). In addition, we provide project related services, such as engineering, procurement, project management and commissioning of customer owned drilling facility projects. We have extensive experience and expertise in drilling geologically difficult wells and in managing the logistical and technological challenges of operating in remote, harsh and ecologically sensitive areas. Our U.S. (Lower 48) Drilling segment provides drilling services with our Gulf of Mexico (GOM) barge drilling fleet and markets U.S. (Lower 48) based O&M services. Our GOM barge drilling fleet operates barge rigs that drill for oil and natural gas in shallow waters in and along the inland waterways and coasts of Louisiana, Alabama and Texas. The majority of these wells are drilled in shallow water depths ranging from 6 to 12 feet. Our International & Alaska Drilling segment provides drilling services, with Company-owned rigs as well as through O&M contracts, and project related services. We strive to deploy our fleet of Company-owned rigs in markets where we expect to have opportunities to keep the rigs consistently utilized and build a sufficient presence to achieve efficient operating scale. In our Rental Tools Services business, we provide premium rental equipment and services to exploration and production (E&P) companies, drilling contractors and service companies on land and offshore in the U.S. and select international markets. Tools we provide include standard and heavy-weight drill pipe, all of which are available with standard or high-torque connections, tubing, pressure control equipment, including blow-out preventers (BOPs), drill collars and more. We also provide well construction services, which include tubular running services and downhole tools, and well intervention services, which include whipstock, fishing products and related services, as well as inspection and machine shop support. Rental tools are used during well drilling programs and are requested by the customer when they are needed, requiring us to keep a broad inventory of rental tools in stock. Rental tools are usually rented on a daily or monthly basis. Consolidation — The consolidated condensed financial statements include the accounts of the Company and subsidiaries over which we exercise control or in which we have a controlling financial interest, including entities, if any, in which the Company is allocated a majority of the entity’s losses or returns, regardless of ownership percentage. If a subsidiary of Parker Drilling has a 50 percent interest in an entity but Parker Drilling’s interest in the subsidiary or the entity does not meet the consolidation criteria, then that interest is accounted for under the equity method. Noncontrolling Interest — We apply accounting standards related to noncontrolling interests for ownership interests in our subsidiaries held by parties other than Parker Drilling. We report noncontrolling interest as equity on the consolidated balance sheets and report net income (loss) attributable to controlling interest and to noncontrolling interest separately on the consolidated condensed statements of operations. During the fourth quarter of 2015, we purchased the remaining noncontrolling interest of ITS Arabia Limited for $6.75 million , of which $3.4 million was paid in the 2015 fourth quarter. The final payment of the purchase price was made during the second quarter of 2016. At the time of purchase, the carrying value of the noncontrolling interest was $3.0 million . Reclassifications — Certain reclassifications have been made to prior period amounts to conform to the current period presentation. These reclassifications did not materially affect our consolidated financial results. Revenue Recognition — Drilling revenues and expenses, comprised of daywork drilling contracts, call-outs against master service agreements and engineering and related project services contracts, are recognized as services are performed and collection is reasonably assured. For certain contracts, we receive payments contractually designated for the mobilization of rigs and other drilling equipment. Mobilization payments received, and direct costs incurred for the mobilization, are deferred and recognized over the primary term of the related drilling contract; however, costs incurred to relocate rigs and other drilling equipment to areas in which a contract has not been secured are expensed as incurred. For contracts that are terminated prior to the specified term, early termination payments received by us are recognized as revenues when all contractual requirements are met. Revenues from rental activities are recognized ratably over the rental term, which is generally less than six months. Our project related services contracts include engineering, consulting, and project management scopes of work and revenue is typically recognized on a time and materials basis. Reimbursable Revenues — The Company recognizes reimbursements received for out-of-pocket expenses incurred as revenues and accounts for out-of-pocket expenses as direct operating costs. Such amounts totaled $18.9 million and $27.8 million for the three months ended June 30, 2016 and 2015 , respectively, and $37.9 million and $47.5 million for the six months ended June 30, 2016 and 2015 , respectively. Additionally, the Company typically receives a nominal handling fee, which is recognized as revenues in our consolidated statement of operations. Use of Estimates — The preparation of consolidated condensed financial statements in accordance with accounting policies generally accepted in the United States (U.S. GAAP) requires management to make estimates and assumptions that affect our reported amounts of assets and liabilities, our disclosure of contingent assets and liabilities at the date of the consolidated condensed financial statements, and our revenues and expenses during the periods reported. Estimates are typically used when accounting for certain significant items such as legal or contractual liability accruals, mobilization and deferred mobilization, self-insured medical/dental plans, income taxes and valuation allowance, and other items requiring the use of estimates. Estimates are based on a number of variables which may include third party valuations, historical experience, where applicable, and assumptions that we believe are reasonable under the circumstances. Due to the inherent uncertainty involved with estimates, actual results may differ from management estimates. Purchase Price Allocation — We allocate the purchase price of an acquired business to its identifiable assets and liabilities in accordance with the acquisition method based on estimated fair values at the transaction date. Transaction and integration costs associated with an acquisition are expensed as incurred. The excess of the purchase price over the amount allocated to the assets and liabilities, if any, is recorded as goodwill. We use all available information to estimate fair values, including quoted market prices, the carrying value of acquired assets, and widely accepted valuation techniques such as discounted cash flows. We typically engage third-party appraisal firms to assist in fair value determination of inventories, identifiable intangible assets, and any other significant assets or liabilities. Judgments made in determining the estimated fair value assigned to each class of assets acquired and liabilities assumed, as well as asset lives, can materially impact our results of operations. See Note 2 - Acquisitions for further discussion. Goodwill — We account for all business combinations using the acquisition method of accounting. Under this method, assets and liabilities, including any remaining noncontrolling interests, are recognized at fair value at the date of acquisition. The excess of the purchase price over the fair value of assets acquired, net of liabilities assumed, plus the value of any noncontrolling interests, is recognized as goodwill. We perform our annual goodwill impairment review as of October 1 of each year, and more frequently if negative conditions or other triggering events arise. The quantitative impairment test we perform for goodwill utilizes certain assumptions, including forecasted revenue and costs assumptions. See Note 3 - Goodwill and Intangible Assets for further discussion. Intangible Assets — Our intangible assets are related to trade names, customer relationships, and developed technology, which were acquired through acquisition and are generally amortized over a weighted average period of approximately three to six years. We assess the recoverability of the unamortized balance of our intangible assets when indicators of impairment are present based on expected future profitability and undiscounted expected cash flows and their contribution to our overall operations. Should the review indicate that the carrying value is not fully recoverable, the excess of the carrying value over the fair value of the intangible assets would be recognized as an impairment loss. See Note 3 - Goodwill and Intangible Assets for further discussion. Impairment — We evaluate the carrying amounts of long-lived assets for potential impairment when events occur or circumstances change that indicate the carrying values of such assets may not be recoverable. We evaluate recoverability by determining the undiscounted estimated future net cash flows for the respective asset groups identified. If the sum of the estimated undiscounted cash flows is less than the carrying value of the asset group, we measure the impairment as the amount by which the assets’ carrying value exceeds the fair value of such assets. Management considers a number of factors such as estimated future cash flows from the assets, appraisals and current market value analysis in determining fair value. Assets are written down to fair value if the final estimate of current fair value is below the net carrying value. The assumptions used in the impairment evaluation are inherently uncertain and require management judgment. Concentrations of Credit Risk — Financial instruments that potentially subject the Company to concentrations of credit risk consist primarily of trade receivables with a variety of national and international oil and natural gas companies. We generally do not require collateral on our trade receivables. We depend on a limited number of significant customers. Our largest customer, Exxon Neftegas Limited (ENL) , constituted approximately 39.8 percent of our consolidated revenues for the six months ended June 30, 2016 . Excluding reimbursable revenues of $36.9 million , ENL constituted approximately 28.7 percent of our total consolidated revenues for the six months ended June 30, 2016 . Our second largest customer, BP Exploration Alaska, Inc. (BP), constituted approximately 11.9 percent of our consolidated revenues for the six months ended June 30, 2016 . At June 30, 2016 and December 31, 2015 , we had deposits in domestic banks in excess of federally insured limits of approximately $69.1 million and $91.3 million , respectively. In addition, we had uninsured deposits in foreign banks as of June 30, 2016 and December 31, 2015 of $41.7 million and $44.1 million , respectively. Income Taxes — Income taxes are accounted for under the asset and liability method and have been provided for based upon tax laws and rates in effect in the countries in which operations are conducted and income or losses are generated. There is little or no expected relationship between the provision for or benefit from income taxes and income or loss before income taxes as the countries in which we operate have taxation regimes that vary not only with respect to nominal rate, but also in terms of the availability of deductions, credits, and other benefits. Deferred tax assets and liabilities are recognized for the future tax consequences attributable to differences between the financial statement carrying amounts of existing assets and liabilities and their respective tax bases and operating loss and tax credit carryforwards. Deferred tax assets and liabilities are measured using enacted tax rates in effect for the year in which the temporary differences are expected to be recovered or settled and the effect of changes in tax rates is recognized in income in the period in which the change is enacted. Valuation allowances are established to reduce deferred tax assets when it is more likely than not that some portion or all of the deferred tax assets will not be realized. In order to determine the amount of deferred tax assets or liabilities, as well as the valuation allowances, we must make estimates and assumptions regarding future taxable income, where rigs will be deployed and other matters. Changes in these estimates and assumptions, including changes in tax laws and other changes impacting our ability to recognize the underlying deferred tax assets, could require us to adjust the valuation allowances. The Company recognizes the effect of income tax positions only if those positions are more likely than not to be sustained. Recognized income tax positions are measured at the largest amount that is greater than 50 percent likely of being realized and changes in recognition or measurement are reflected in the period in which the change in judgment occurs. Legal and Investigation Matters — We accrue estimates of the probable and estimable costs for the resolution of certain legal and investigation matters. We do not accrue any amounts for other matters for which the liability is not probable and reasonably estimable. Generally, the estimate of probable costs related to these matters is developed in consultation with our legal advisors. The estimates take into consideration factors such as the complexity of the issues, litigation risks and settlement costs. If the actual settlement costs, final judgments, or fines, after appeals, differ from our estimates, our future financial results may be adversely affected.

Goodwill and Intangible Assets

Goodwill and Intangible Assets Goodwill and Intangible Assets (Notes)	6 Months Ended
	Jun. 30, 2016
Goodwill and Intangible Assets Disclosure [Abstract]
Goodwill and Intangible Assets Disclosure [Text Block]	Goodwill and Intangible Assets As part of the 2M-Tek Acquisition we recognized $6.7 million of goodwill and acquired definite-lived intangible assets with an acquisition date fair value of $13.5 million . As part of the 2013 acquisition of International Tubular Services Limited (ITS) and related assets (the ITS Acquisition), we acquired definite-lived intangible assets with an acquisition date fair value of $8.5 million . All of the Company’s goodwill and intangible assets are allocated to the Rental Tools segment. Goodwill During the 2016 second quarter, circumstances indicated that the fair value of the reporting unit may not be in excess of the carrying value of the goodwill. Therefore we performed a goodwill impairment review and determined that the fair value of the reporting unit exceeded its carrying value and therefore, no goodwill impairment was identified. Should current market conditions worsen or persist for an extended period of time, an impairment of the carrying value of our goodwill could occur. The change in the carrying amount of goodwill for the period ended June 30, 2016 is as follows: Dollars in thousands Goodwill Balance at December 31, 2015 $ 6,708 Additions — Balance at June 30, 2016 $ 6,708 Of the total amount of goodwill recognized, zero is expected to be deductible for income tax purposes. Intangible Assets Intangible Assets consist of the following: Balance at June 30, 2016 Dollars in thousands Estimated Useful Life (Years) Gross Carrying Amount Write-off Due to Sale in 2015 (1) Accumulated Amortization Net Carrying Amount Amortized intangible assets: Developed Technology 6 $ 11,630 — $ (2,423 ) $ 9,207 Customer Relationships 3 5,400 (264 ) (5,136 ) — Trade Names 5 4,940 (332 ) (2,423 ) 2,185 Total Amortized intangible assets $ 21,970 $ (596 ) $ (9,982 ) $ 11,392 (1) During the 2015 fourth quarter, we sold our controlling interest in a joint venture in Egypt resulting in the write-off of $0.6 million of intangible assets related to customer relationships and trade name acquired as part of the ITS Acquisition. Amortization expense was $2.0 million and $1.8 million for the six months ended June 30, 2016 and 2015 , respectively. Our remaining intangibles amortization expense for the next five years is presented below: Dollars in thousands Expected future intangible amortization expense 2016 $ 1,463 2017 $ 2,801 2018 $ 2,306 2019 $ 2,306 2020 $ 2,030 Beyond 2020 $ 486

Earnings per share (EPS)

Earnings per share (EPS)	6 Months Ended
	Jun. 30, 2016
Earnings Per Share [Abstract]
Earnings per share (EPS)	Earnings (Loss) Per Share (EPS) Three Months Ended June 30, 2016 Income/(Loss) (Numerator) Shares (Denominator) Per-Share Amount Basic EPS $ (39,822,000 ) 124,101,349 $ (0.32 ) Effect of dilutive securities: Restricted stock units — — — Diluted EPS $ (39,822,000 ) 124,101,349 $ (0.32 ) Six Months Ended June 30, 2016 Income/(Loss) (Numerator) Shares (Denominator) Per-Share Amount Basic EPS $ (135,657,000 ) 123,595,793 $ (1.10 ) Effect of dilutive securities: Restricted stock units — — — Diluted EPS $ (135,657,000 ) 123,595,793 $ (1.10 ) Three Months Ended June 30, 2015 Income/(Loss) (Numerator) Shares (Denominator) Per-Share Amount Basic EPS $ (14,029,000 ) 122,481,425 $ (0.11 ) Effect of dilutive securities: Restricted stock units — — — Diluted EPS $ (14,029,000 ) 122,481,425 $ (0.11 ) Six Months Ended June 30, 2015 Income/(Loss) (Numerator) Shares (Denominator) Per-Share Amount Basic EPS $ (10,807,000 ) 122,175,511 $ (0.09 ) Effect of dilutive securities: Restricted stock units — — — Diluted EPS $ (10,807,000 ) 122,175,511 $ (0.09 ) For the three and six months ended June 30, 2016 and 2015 , respectively, all common shares potentially issuable in connection with outstanding restricted stock unit awards have been excluded from the calculation of diluted EPS as the company incurred losses during the three and six month periods, therefore, inclusion of such potential common shares in the calculation would be anti-dilutive.

Accumulated Other Comprehensive

Accumulated Other Comprehensive Income	6 Months Ended
	Jun. 30, 2016
Equity [Abstract]
Accumulated Other Comprehensive Income	Accumulated Other Comprehensive Loss Accumulated other comprehensive loss consisted of the following: Dollars in thousands Foreign Currency Items December 31, 2015 $ (1,888 ) Current period other comprehensive loss (3,571 ) June 30, 2016 $ (5,459 ) There were no amounts reclassified out of accumulated other comprehensive loss for the three months ended June 30, 2016 . Amounts reclassified out of accumulated other comprehensive loss were $1.9 million for the six months ended June 30, 2016 and represent realized foreign currency translation gains.

Reportable Segments

Reportable Segments	6 Months Ended
	Jun. 30, 2016
Segment Reporting [Abstract]
Reportable Segments	Reportable Segments Our business is comprised of two business lines: (1) Drilling Services and (2) Rental Tools Services. We report our Rental Tools Services business as one reportable segment (Rental Tools) and report our Drilling Services business as two reportable segments: (1) U.S. (Lower 48) Drilling and (2) International & Alaska Drilling. Within the three reportable segments, we have aggregated our U.S. and international rental tools business units under Rental Tools, one business unit under U.S. (Lower 48) Drilling, and our Arctic, Eastern Hemisphere and Latin America business units under International & Alaska Drilling for a total of six business units. The Company has aggregated each of its business units in one of the three reporting segments based on the guidelines of ASC Topic 280, “Segment Reporting” (ASC Topic 280). We eliminate inter-segment revenues and expenses. We disclose revenues under the three reportable segments based on the similarity of the use and markets for the groups of products and services within each segment. Drilling Services Business Line In our Drilling Services business, we drill oil and gas wells for customers in both the U.S. and international markets. We provide this service with both Company-owned rigs and customer-owned rigs. We refer to the provision of drilling services with customer-owned rigs as our O&M service in which operators own their own drilling rigs but choose Parker Drilling to operate and maintain the rigs for them. The nature and scope of activities involved in drilling an oil and gas well is similar whether it is drilled with a Company-owned rig (as part of a traditional drilling contract) or a customer-owned rig (as part of an O&M contract). In addition, we provide project related services, such as engineering, procurement, project management and commissioning of customer-owned drilling facility projects. We have extensive experience and expertise in drilling geologically difficult wells and in managing the logistical and technological challenges of operating in remote, harsh and ecologically sensitive areas. U.S. (Lower 48) Drilling Our U.S. (Lower 48) Drilling segment provides drilling services with our GOM barge drilling rig fleet and markets U.S. (Lower 48) based O&M services. Our GOM barge drilling fleet operates barge rigs that drill for oil and natural gas in shallow waters in and along the inland waterways and coasts of Louisiana, Alabama and Texas. The majority of these wells are drilled in shallow water depths ranging from 6 to 12 feet. Our rigs are suitable for a variety of drilling programs, from inland coastal waters requiring shallow draft barges, to open water drilling on both state and federal water projects requiring more robust capabilities. The barge drilling industry in the GOM is characterized by cyclical activity where utilization and dayrates are typically driven by oil and gas prices and our customers’ access to project financing. Contract terms tend to be well-to-well or multi-well programs, most commonly ranging from 45 to 150 days. International & Alaska Drilling Our International & Alaska Drilling segment provides drilling services, with Company-owned rigs as well as through O&M contracts, and project related services. The drilling markets in which this segment operates have one or more of the following characteristics: • customers that typically are major, independent or national oil and natural gas companies or integrated service providers; • drilling programs in remote locations with little infrastructure, requiring a large inventory of spare parts and other ancillary equipment and self-supported service capabilities; • complex wells and/or harsh environments (such as high pressures, deep depths, hazardous or geologically challenging conditions and sensitive environments) requiring specialized equipment and considerable experience to drill; and • drilling and O&M contracts that generally cover periods of one year or more. Our Rental Tools Services Business Our Rental Tools segment provides premium rental equipment and services to E&P companies, drilling contractors and service companies on land and offshore in the U.S. and select international markets. Tools we provide include standard and heavy-weight drill pipe, tubing, pressure control equipment, including BOPs, drill collars and more. We also provide well construction services, which include tubular running services and downhole tools, and well intervention services, which include whipstock, fishing products and related services, as well as inspection and machine shop support. Our largest single market for rental tools is U.S. land drilling. Rental tools are used during well drilling programs and are usually rented on a daily or monthly basis. The following table represents the results of operations by reportable segment: Three Months Ended June 30, Six Months Ended June 30, Dollars in thousands 2016 2015 2016 2015 Revenues: (1) Drilling Services: U.S. (Lower 48) Drilling $ 1,065 $ 6,848 $ 3,150 $ 20,945 International & Alaska Drilling 71,926 114,969 160,545 228,890 Total Drilling Services 72,991 121,817 163,695 249,835 Rental Tools 32,296 64,124 72,095 140,182 Total revenues 105,287 185,941 235,790 390,017 Operating gross margin: (2) Drilling Services: U.S. (Lower 48) Drilling (9,011 ) (7,552 ) (17,571 ) (13,274 ) International & Alaska Drilling 3,196 6,844 8,274 24,208 Total Drilling Services (5,815 ) (708 ) (9,297 ) 10,934 Rental Tools (14,410 ) 4,729 (24,356 ) 17,354 Total operating gross margin (20,225 ) 4,021 (33,653 ) 28,288 General and administrative expense (7,995 ) (9,511 ) (17,776 ) (20,348 ) Provision for reduction in carrying value of certain assets — (2,316 ) — (2,316 ) Gain (loss) on disposition of assets, net (2 ) (138 ) (62 ) 2,303 Total operating income (loss) (28,222 ) (7,944 ) (51,491 ) 7,927 Interest expense (12,187 ) (11,396 ) (23,749 ) (22,474 ) Interest income 32 19 39 202 Other income (loss) (358 ) (1,529 ) 2,127 (2,909 ) Loss from continuing operations before income taxes $ (40,735 ) $ (20,850 ) $ (73,074 ) $ (17,254 ) (1) For the six months ended June 30, 2016 , our largest customer, ENL , constituted approximately 39.8 percent of our total consolidated revenues and approximately 58.4 percent of our International & Alaska Drilling segment revenues. Excluding reimbursable revenues of $36.9 million , ENL constituted approximately 28.7 percent of our total consolidated revenues and approximately 46.4 percent of our International & Alaska Drilling segment revenues. Our second largest customer, BP, constituted 11.9 percent of our total consolidated revenues and approximately 17.2 percent of our International & Alaska Drilling segment revenues. For the six months ended June 30, 2015 , our largest customer, ENL , constituted approximately 26.0 percent of our total consolidated revenues and approximately 44.3 percent of our International & Alaska Drilling segment revenues. Excluding reimbursable revenues of $39.7 million , ENL constituted approximately 18.1 percent of our total consolidated revenues and approximately 34.0 percent of our International & Alaska Drilling segment revenues. (2) Operating gross margin is calculated as revenues less direct operating expenses, including depreciation and amortization expense.

Accounting for Uncertainty in I

Accounting for Uncertainty in Income Taxes	6 Months Ended
	Jun. 30, 2016
Income Tax Disclosure [Abstract]
Accounting for Uncertainty in Income Taxes	Accounting for Uncertainty in Income Taxes We apply the accounting guidance related to accounting for uncertainty in income taxes. This guidance prescribes a recognition threshold and a measurement attribute for the financial statement recognition and measurement of tax positions taken or expected to be 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. At June 30, 2016 we had a liability for unrecognized tax benefits of $5.7 million , all of which would favorably impact our effective tax rate upon recognition, primarily related to foreign operations. At December 31, 2015 , we had a liability for unrecognized tax benefits of $7.8 million , including $3.6 million of benefits which would favorably impact our effective tax rate upon recognition, primarily related to foreign operations. In addition, we recognize interest and penalties that could be applied to uncertain tax positions in periodic income tax expense. As of June 30, 2016 and December 31, 2015 , we had approximately $1.6 million and $3.4 million , respectively, of accrued interest and penalties related to uncertain tax positions.

Income Tax Benefit_Expense

Income Tax Benefit/Expense	6 Months Ended
	Jun. 30, 2016
Income Tax Disclosure [Abstract]
Income Tax Benefit/Expense	Income Tax Benefit/Expense During the second quarter of 2016 we had income tax benefit of $0.9 million compared to income tax benefit of $6.9 million during the second quarter of 2015 . The income tax benefit in the second quarter of 2016 was primarily related to the jurisdictional mix of income and loss during the quarter, along with our continued inability to recognize the benefits associated with certain losses as a result of valuation allowances. The income tax benefit in the second quarter of 2015 was primarily related to pre-tax losses generated during that period.

Long-Term Debt

Long-Term Debt	6 Months Ended
	Jun. 30, 2016
Debt Disclosure [Abstract]
Long-Term Debt	Long-Term Debt The following table illustrates our debt portfolio as of June 30, 2016 and December 31, 2015 : Dollars in thousands June 30, December 31, 6.75% Senior Notes, due July 2022 $ 360,000 $ 360,000 7.50% Senior Notes, due August 2020 225,000 225,000 Total Principal 585,000 585,000 Less: unamortized debt issuance costs (9,452 ) (10,202 ) Total long-term debt $ 575,548 $ 574,798 6.75% Senior Notes, due July 2022 On January 22, 2014 , we issued $360.0 million aggregate principal amount of 6.75% Senior Notes due 2022 (6.75% Notes) pursuant to an Indenture between the Company and The Bank of New York Mellon Trust Company, N.A., as trustee. Net proceeds from the 6.75% Notes offering plus a $40.0 million term loan draw under the Amended and Restated Senior Secured Credit Agreement (2012 Secured Credit Agreement) and cash on hand were utilized to purchase $416.2 million aggregate principal amount of our outstanding 9.125% Senior Notes due 2018 pursuant to a tender and consent solicitation offer commenced on January 7, 2014. The 6.75% Notes are general unsecured obligations of the Company and rank equal in right of payment with all of our existing and future senior unsecured indebtedness. The 6.75% Notes are jointly and severally guaranteed by all of our subsidiaries that guarantee indebtedness under the Second Amended and Restated Senior Secured Credit Agreement, as amended from time-to-time (2015 Secured Credit Agreement) and our 7.50% Senior Notes due 2020 (7.50% Notes, and collectively with the 6.75% Notes, the Senior Notes). Interest on the 6.75% Notes is payable on January 15 and July 15 of each year, beginning July 15, 2014. Debt issuance costs related to the 6.75% Notes of approximately $7.6 million ( $5.9 million net of amortization as of June 30, 2016 ) are being amortized over the term of the notes using the effective interest rate method. At any time prior to January 15, 2017, we may redeem up to 35 percent of the aggregate principal amount of the 6.75% Notes at a redemption price of 106.75 percent of the principal amount, plus accrued and unpaid interest to the redemption date, with the net cash proceeds of certain equity offerings by us. On and after January 15, 2018, we may redeem all or a part of the 6.75% Notes upon appropriate notice, at a redemption price of 103.375 percent of the principal amount, and at redemption prices decreasing each year thereafter to par beginning January 15, 2020. If we experience certain changes in control, we must offer to repurchase the 6.75% Notes at 101.0 percent of the aggregate principal amount, plus accrued and unpaid interest and additional interest, if any, to the date of repurchase. The Indenture restricts our ability and the ability of certain subsidiaries to: (i) sell assets, (ii) pay dividends or make other distributions on capital stock or redeem or repurchase capital stock or subordinated indebtedness, (iii) make investments, (iv) incur or guarantee additional indebtedness, (v) create or incur liens, (vi) enter into sale and leaseback transactions, (vii) incur dividend or other payment restrictions affecting subsidiaries, (viii) merge or consolidate with other entities, (ix) enter into transactions with affiliates, and (x) engage in certain business activities. Additionally, the Indenture contains certain restrictive covenants designating certain events as Events of Default. These covenants are subject to a number of important exceptions and qualifications. 7.50% Senior Notes, due August 2020 On July 30, 2013 , we issued $225.0 million aggregate principal amount of the 7.50% Notes pursuant to an Indenture between the Company and The Bank of New York Mellon Trust Company, N.A., as trustee. Net proceeds from the 7.50% Notes offering were primarily used to repay the $125.0 million aggregate principal amount of a term loan used to initially finance the ITS Acquisition, to repay $45.0 million of term loan borrowings under the 2012 Secured Credit Agreement, and for general corporate purposes. The 7.50% Notes are general unsecured obligations of the Company and rank equal in right of payment with all of our existing and future senior unsecured indebtedness. The 7.50% Notes are jointly and severally guaranteed by all of our subsidiaries that guarantee indebtedness under the 2015 Secured Credit Agreement and the 6.75% Notes. Interest on the 7.50% Notes is payable on February 1 and August 1 of each year, beginning February 1, 2014. Debt issuance costs related to the 7.50% Notes of approximately $5.6 million ( $3.6 million , net of amortization as of June 30, 2016 ) are being amortized over the term of the notes using the effective interest rate method. At any time prior to August 1, 2016, we were entitled to redeem up to 35 percent of the aggregate principal amount of the 7.50% Notes at a redemption price of 107.50 percent of the principal amount, plus accrued and unpaid interest to the redemption date, with the net cash proceeds of certain equity offerings by us. On and after August 1, 2016, we may redeem all or a part of the 7.50% Notes upon appropriate notice, at a redemption price of 103.750 percent of the principal amount, and at redemption prices decreasing each year thereafter to par beginning August 1, 2018. To date we have not made any redemptions. If we experience certain changes in control, we must offer to repurchase the 7.50% Notes at 101.0 percent of the aggregate principal amount, plus accrued and unpaid interest and additional interest, if any, to the date of repurchase. The Indenture restricts our ability and the ability of certain subsidiaries to: (i) sell assets, (ii) pay dividends or make other distributions on capital stock or redeem or repurchase capital stock or subordinated indebtedness, (iii) make investments, (iv) incur or guarantee additional indebtedness, (v) create or incur liens, (vi) enter into sale and leaseback transactions, (vii) incur dividend or other payment restrictions affecting subsidiaries, (viii) merge or consolidate with other entities, (ix) enter into transactions with affiliates, and (x) engage in certain business activities. Additionally, the Indenture contains certain restrictive covenants designating certain events as Events of Default. These covenants are subject to a number of important exceptions and qualifications. 2015 Secured Credit Agreement On January 26, 2015 we entered into the 2015 Secured Credit Agreement, which amended and restated the 2012 Secured Credit Agreement. The 2015 Secured Credit Agreement was originally comprised of a $200.0 million revolving credit facility (Revolver) set to mature on January 26, 2020. On June 1, 2015, we executed the first amendment to the 2015 Secured Credit Agreement in order to amend certain provisions regarding the definition of “Change of Control.” On September 29, 2015, we executed the second amendment to the 2015 Secured Credit Agreement to, among other things, (a) amend certain covenant ratios; (b) increase the Applicable Rate for certain higher levels of consolidated leverage to a maximum of 4.00 percent per annum for Eurodollar Rate loans and to 3.00 percent per annum for Base Rate loans; (c) permit multi-year letters of credit up to an aggregate amount of $5.0 million; (d) limit payment prior to September 30, 2017 of certain restricted payments and certain prepayments of unsecured senior notes and other specified forms of indebtedness; and (e) remove the option of the Company, subject to the consent of the lenders, to increase the Credit Agreement up to an additional $75 million. On May 27, 2016, we executed the third amendment to the 2015 Secured Credit Agreement (the Third Amendment), which reduced availability under the Revolver from $200 million to $100 million . Additionally, among other things, the Third Amendment: (a) eliminates the Leverage Ratio covenant until the fourth quarter of 2018 when the covenant is reinstated with the ratio established at 4.25:1.00, and remains at 4.25:1.00 thereafter; (b) eliminates the Consolidated Interest Coverage Ratio covenant until the fourth quarter of 2017 when the covenant is reinstated with the ratio established at 1.00:1.00 and increases by 0.25 each subsequent quarter until reaching 2.00:1.00 in the fourth quarter of 2018, and remains at 2.00:1.00 thereafter; (c) immediately increases the maximum permitted Senior Secured Leverage Ratio from 1.50:1.00 to 2.80:1.00 until it decreases to 2.20:1.00 in the second quarter of 2017, to 1.75:1.00 in the third quarter of 2017, and to 1.50:1.00 in the fourth quarter of 2017 and remains at 1.50:1.00 thereafter; (d) immediately decreases the minimum permitted Asset Coverage Ratio from 1.25:1.00 to 1.10:1.00 until it increases to 1.25: 1.00 in the fourth quarter of 2017 and remains at 1.25:1.00 thereafter; (e) requires that, at any time our Consolidated Cash Balance in U.S. bank accounts is over $50 million, we repay borrowings under the 2015 Secured Credit Agreement until our Consolidated Cash balance is no more than $50 million or all borrowings have been repaid, and (f) allows up to $75 million of Junior Lien Debt. At the time the Third Amendment was executed, the remaining debt issuance costs for the 2015 Secured Credit Agreement totaled approximately $2.2 million . Since the Revolver was reduced by 50 percent, we wrote off approximately $1.1 million in May 2016. We incurred debt issuance costs relating to the Third Amendment of approximately $0.3 million , bringing total debt issuance costs to $1.4 million ( $1.3 million , net of amortization as of June 30, 2016 ) which are being amortized through January 2020, or the term of the Third Amendment, on a straight line basis. Our obligations under the 2015 Secured Credit Agreement are guaranteed by substantially all of our direct and indirect domestic subsidiaries, other than immaterial subsidiaries and subsidiaries generating revenues primarily outside the United States, each of which has executed guaranty agreements, and are secured by first priority liens on our accounts receivable, specified rigs including barge rigs in the GOM and land rigs in Alaska, certain U.S.-based rental equipment of the Company and its subsidiary guarantors and the equity interests of certain of the Company’s subsidiaries. The 2015 Secured Credit Agreement contains customary affirmative and negative covenants, such as limitations on indebtedness, liens, restrictions on entry into certain affiliate transactions and payments (including payment of dividends) and maintenance of certain ratios and coverage tests. We were in compliance with all covenants contained in the 2015 Secured Credit Agreement as of June 30, 2016 . Our Revolver is available for general corporate purposes and to support letters of credit. Interest on Revolver loans accrues at a Base Rate plus an Applicable Rate or LIBOR plus an Applicable Rate. Revolving loans are available subject to a quarterly asset coverage ratio calculation based on the Orderly Liquidation Value of certain specified rigs including barge rigs in the GOM and land rigs in Alaska, and certain U.S.-based rental equipment of the Company and its subsidiary guarantors and a percentage of eligible domestic accounts receivable. The $30.0 million draw outstanding at the closing of the 2015 Secured Credit Agreement was repaid in full during the first quarter of 2015 with cash on hand. Letters of credit outstanding against the Revolver as of June 30, 2016 totaled $11.8 million . There were no amounts drawn on the Revolver as of June 30, 2016 .

Fair Value of Financial Instrum

Fair Value of Financial Instruments	6 Months Ended
	Jun. 30, 2016
Fair Value Disclosures [Abstract]
Fair Value of Financial Instruments	Fair Value of Financial Instruments Certain of our assets and liabilities are required to be measured at fair value on a recurring basis. For purposes of recording fair value adjustments for certain financial and non-financial assets and liabilities, and determining fair value disclosures, we estimate fair value at a price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants in the principal market for the asset or liability. The fair value measurement and disclosure requirements of FASB Accounting Standards Codification Topic No. 820, Fair Value Measurement and Disclosures (ASC 820) requires inputs that we categorize using a three-level hierarchy, from highest to lowest level of observable inputs, as follows: • Level 1 — Unadjusted quoted prices for identical assets or liabilities in active markets; • Level 2 — Direct or indirect observable inputs, including quoted prices or other market data, for similar assets or liabilities in active markets or identical assets or liabilities in less active markets; and • Level 3 — Unobservable inputs that require significant judgment for which there is little or no market data. When multiple input levels are required for a valuation, we categorize the entire fair value measurement according to the lowest level of input that is significant to the entire measurement even though we may also have utilized significant inputs that are more readily observable. The amounts reported in our consolidated balance sheets for cash and cash equivalents, accounts receivable, and accounts payable approximate fair value. Fair value of our debt instruments is determined using Level 2 inputs. Fair values and related carrying values of our debt instruments were as follows for the periods indicated: June 30, 2016 December 31, 2015 Dollars in thousands Carrying Amount Fair Value Carrying Amount Fair Value Long-term Debt 6.75% Notes $ 360,000 $ 270,900 $ 360,000 $ 246,600 7.50% Notes 225,000 172,125 225,000 171,000 Total Principal $ 585,000 $ 443,025 $ 585,000 $ 417,600 The assets acquired and liabilities assumed in the 2M-Tek Acquisition were recorded at fair value in accordance with U.S. GAAP. Acquisition date fair values represent either Level 2 fair value measurements (current assets and liabilities, property, plant and equipment) or Level 3 fair value measurements (intangible assets). Market conditions could cause an instrument to be reclassified from Level 1 to Level 2, or Level 2 to Level 3. There were no transfers between levels of the fair value hierarchy or any changes in the valuation techniques used during the six months ended June 30, 2016 .

Contingencies

Contingencies	6 Months Ended
	Jun. 30, 2016
Commitments and Contingencies Disclosure [Abstract]
Contingencies	Contingencies We are a party to various lawsuits and claims arising out of the ordinary course of business. We estimate the range of our liability related to pending litigation when we believe the amount or range of loss can be estimated. We record our best estimate of a loss when the loss is considered probable. When a liability is probable and there is a range of estimated loss with no best estimate in the range, we record the minimum estimated liability related to the lawsuits or claims. As additional information becomes available, we assess the potential liability related to our pending litigation and claims and revise our estimates. Due to uncertainties related to the resolution of lawsuits and claims, the ultimate outcome may differ significantly from our estimates. In the opinion of management and based on liability accruals provided, our ultimate exposure with respect to these pending lawsuits and claims is not expected to have a material adverse effect on our consolidated financial position or cash flows, although they could have a material adverse effect on our results of operations for a particular reporting period. Customs Agent and Foreign Corrupt Practices Act (FCPA) Settlement On April 16, 2013, the Company and the Department of Justice (DOJ) entered into a deferred prosecution agreement (DPA), under which the DOJ deferred for three years prosecuting the Company for criminal violations of the anti-bribery provisions of the FCPA relating to the Company’s retention and use of an individual agent in Nigeria with respect to certain customs-related issues, in return for: (i) the Company’s acceptance of responsibility for, and agreement not to contest or contradict the truthfulness of, the statement of facts and allegations that have been filed in the United States District Court for the Eastern District of Virginia concurrently with the DPA; (ii) the Company’s payment of an approximately $11.76 million fine; (iii) the Company’s reaffirming its commitment to compliance with the FCPA and other applicable anti-corruption laws in connection with the Company’s operations, and continuing cooperation with domestic and foreign authorities in connection with the matters that are the subject of the DPA; (iv) the Company’s commitment to continue to address any identified areas for improvement in the Company’s internal controls, policies and procedures relating to compliance with the FCPA and other applicable anti-corruption laws if, and to the extent, not already addressed; and (v) the Company’s agreement to report to the DOJ in writing annually during the term of the DPA regarding remediation of the matters that are the subject of the DPA, implementation of any enhanced internal controls, and any evidence of improper payments the Company may have discovered during the term of the agreement. The DPA provided that as long as the Company remained in compliance with the terms of the DPA throughout its effective period, the charge against the Company would be dismissed with prejudice. The Company also settled a related civil complaint filed by the Securities and Exchange Commission. The third written annual report was filed with the DOJ on April 15, 2016, and the term of the DPA expired on April 23, 2016. On May 20, 2016, the DOJ filed a Motion to Dismiss the case based on its determination that the Company had complied with all of its obligations under the DPA. On the same date, the Court entered an Order dismissing with prejudice the United States’ case against the Company. With the dismissal of the case, the DPA was also terminated.

Recent Accounting Pronouncement

Recent Accounting Pronouncements	6 Months Ended
	Jun. 30, 2016
Accounting Policies [Abstract]
Recent Accounting Pronouncements	Recent Accounting Pronouncements In March 2016, the Financial Accounting Standards Board (FASB) issued Accounting Standards Update (ASU) No. 2016-09, Compensation - Stock Compensation (Topic 718). The objective of this update is to simplify several aspects of the accounting for share-based payment transactions, including the income tax consequences, classification of awards as either equity or liabilities, and classification on the statement of cash flows. The standard becomes effective for public companies for fiscal years beginning after December 15, 2016, including interim periods within those fiscal years. Early adoption is permitted. We are in the process of assessing the impact of the adoption of ASU 2016-09 on our financial position, results of operations and cash flows. In March 2016, the FASB issued ASU No. 2016-02, Leases (Topic 842). This update establishes a new lease accounting model for lessees. Upon adoption, a modified retrospective approach is required for leases that exist, or are entered into, after the beginning of the earliest comparative period presented. The standard is effective for fiscal years beginning after December 15, 2018, including interim periods within those fiscal years, although early adoption is permitted. We are in the process of assessing the impact of the adoption of ASU 2016-02 on our financial position, results of operations and cash flows. We have not yet determined the effect of the standard on our ongoing financial reporting. In May 2014, the FASB issued ASU 2014-09, Revenue from Contracts with Customers. This ASU supersedes the revenue recognition requirements in Accounting Standards Codification 605 - Revenue Recognition and most industry-specific guidance throughout the Codification. The standard requires that an entity recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the company expects to be entitled in exchange for those goods or services and should be applied retrospectively to each prior reporting period presented or retrospectively with the cumulative effect of initially applying the ASU recognized at the date of initial application. ASU 2014-09 is effective for fiscal years beginning after December 15, 2017. We are in the process of assessing the impact of the adoption of ASU 2014-09 on our financial position, results of operations and cash flows. We have not yet selected a transition method nor have we determined the effect of the standard on our ongoing financial reporting.

Parent, Guarantor, Non-Guaranto

Parent, Guarantor, Non-Guarantor Unaudited Consolidating Condensed Financial Statements	6 Months Ended
	Jun. 30, 2016
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Parent, Guarantor, Non-Guarantor Unaudited Consolidating Condensed Financial Statements	Parent, Guarantor, Non-Guarantor Unaudited Consolidating Condensed Financial Statements Set forth on the following pages are the consolidating condensed financial statements of Parker Drilling. The 2015 Secured Credit Agreement and Senior Notes are fully and unconditionally guaranteed by substantially all of our direct and indirect domestic subsidiaries, other than immaterial subsidiaries and subsidiaries generating revenues primarily outside the United States, subject to the following customary release provisions: • in connection with any sale or other disposition of all or substantially all of the assets of that guarantor (including by way of merger or consolidation) to a person that is not (either before or after giving effect to such transaction) a subsidiary of the Company; • in connection with any sale of such amount of capital stock as would result in such guarantor no longer being a subsidiary to a person that is not (either before or after giving effect to such transaction) a subsidiary of the Company; • if the Company designates any restricted subsidiary that is a guarantor as an unrestricted subsidiary; • if the guarantee by a guarantor of all other indebtedness of the Company or any other guarantor is released, terminated or discharged, except by, or as a result of, payment under such guarantee; or • upon legal defeasance or covenant defeasance (satisfaction and discharge of the indenture). 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 Rule 3-10(f) of Regulation S-X. All guarantor subsidiaries are owned 100 percent by the parent company. We are providing unaudited consolidating condensed financial information of the parent, Parker Drilling, the guarantor subsidiaries, and the non-guarantor subsidiaries as of June 30, 2016 and December 31, 2015 and for the three and six months ended June 30, 2016 and 2015 , respectively. The consolidating condensed financial statements present investments in both consolidated and unconsolidated subsidiaries using the equity method of accounting. Upon the closing of our 2015 Secured Credit Agreement, one of our subsidiaries was released as a guarantor subsidiary and is now classified as a non-guarantor subsidiary. In accordance with the guidance Topic No. 810, Consolidation (ASC 810), we have retrospectively updated the unaudited consolidating condensed financial information as of December 31, 2015 and June 30, 2015 . PARKER DRILLING COMPANY AND SUBSIDIARIES CONSOLIDATING CONDENSED BALANCE SHEET (Dollars in Thousands) (Unaudited) June 30, 2016 Parent Guarantor Non-Guarantor Eliminations Consolidated ASSETS Current assets: Cash and cash equivalents $ 55,280 $ 12,192 $ 41,562 $ — $ 109,034 Accounts and notes receivable, net — 34,853 118,336 — 153,189 Rig materials and supplies — (6,009 ) 38,624 — 32,615 Other current assets — 8,601 18,204 — 26,805 Total current assets 55,280 49,637 216,726 — 321,643 Property, plant and equipment, net (19 ) 502,191 244,845 — 747,017 Goodwill — 6,708 — — 6,708 Intangible assets, net — 10,587 805 — 11,392 Investment in subsidiaries and intercompany advances 3,032,953 2,889,755 3,498,240 (9,420,948 ) — Other noncurrent assets (151,632 ) 207,566 550,882 (480,805 ) 126,011 Total assets $ 2,936,582 $ 3,666,444 $ 4,511,498 $ (9,901,753 ) $ 1,212,771 LIABILITIES AND STOCKHOLDERS’ EQUITY Current liabilities: Accounts payable and accrued liabilities $ 114,217 $ 44,382 $ 567,968 $ (617,476 ) $ 109,091 Accrued income taxes 30,910 (15,019 ) (10,114 ) — 5,777 Total current liabilities 145,127 29,363 557,854 (617,476 ) 114,868 Long-term debt, net 575,548 — — — 575,548 Other long-term liabilities 2,867 7,708 4,474 — 15,049 Long-term deferred tax liability (29 ) 77,394 (890 ) — 76,475 Intercompany payables 1,779,740 1,417,482 2,018,050 (5,215,272 ) — Total liabilities 2,503,253 1,531,947 2,579,488 (5,832,748 ) 781,940 Total equity 433,329 2,134,497 1,932,010 (4,069,005 ) 430,831 Total liabilities and stockholders’ equity $ 2,936,582 $ 3,666,444 $ 4,511,498 $ (9,901,753 ) $ 1,212,771 PARKER DRILLING COMPANY AND SUBSIDIARIES CONSOLIDATING CONDENSED BALANCE SHEET (Dollars in Thousands) (Unaudited) December 31, 2015 Parent Guarantor Non-Guarantor Eliminations Consolidated ASSETS Current assets: Cash and cash equivalents $ 73,985 $ 13,854 $ 46,455 $ — $ 134,294 Accounts and notes receivable, net — 42,261 132,844 — 175,105 Rig materials and supplies — (4,744 ) 39,681 — 34,937 Other current assets — 5,982 16,423 — 22,405 Total current assets 73,985 57,353 235,403 — 366,741 Property, plant and equipment, net (19 ) 543,346 262,514 — 805,841 Goodwill — 6,708 — — 6,708 Intangible assets, net — 11,740 1,637 — 13,377 Investment in subsidiaries and intercompany advances 3,057,220 2,770,501 3,319,702 (9,147,423 ) — Other noncurrent assets (234,786 ) 312,790 265,995 (169,964 ) 174,035 Total assets $ 2,896,400 $ 3,702,438 $ 4,085,251 $ (9,317,387 ) $ 1,366,702 LIABILITIES AND STOCKHOLDERS’ EQUITY Current liabilities: Accounts payable and accrued liabilities $ 84,456 $ 56,382 $ 295,439 $ (306,574 ) $ 129,703 Accrued income taxes 9,900 2,111 (5,593 ) — 6,418 Total current liabilities 94,356 58,493 289,846 (306,574 ) 136,121 Long-term debt, net 574,798 — — — 574,798 Other long-term liabilities 2,868 7,446 8,303 — 18,617 Long-term deferred tax liability (29 ) 69,679 (996 ) — 68,654 Intercompany payables 1,656,968 1,401,510 1,864,671 (4,923,149 ) — Total liabilities 2,328,961 1,537,128 2,161,824 (5,229,723 ) 798,190 Total equity 567,439 2,165,310 1,923,427 (4,087,664 ) 568,512 Total liabilities and stockholders’ equity $ 2,896,400 $ 3,702,438 $ 4,085,251 $ (9,317,387 ) $ 1,366,702 PARKER DRILLING COMPANY AND SUBSIDIARIES CONSOLIDATING CONDENSED STATEMENT OF OPERATIONS (Dollars in Thousands) (Unaudited) Three Months Ended June 30, 2016 Parent Guarantor Non-Guarantor Eliminations Consolidated Total revenues $ — $ 34,586 $ 88,895 $ (18,194 ) $ 105,287 Operating expenses — 25,577 81,812 (18,194 ) 89,195 Depreciation and amortization — 23,314 13,003 — 36,317 Total operating gross margin — (14,305 ) (5,920 ) — (20,225 ) General and administration expense (1) (113 ) (7,828 ) (54 ) — (7,995 ) Gain (Loss) on disposition of assets, net — 209 (211 ) — (2 ) Total operating income (loss) (113 ) (21,924 ) (6,185 ) — (28,222 ) Other income and (expense): Interest expense (12,896 ) (44 ) (2,290 ) 3,043 (12,187 ) Interest income 191 180 2,704 (3,043 ) 32 Other — (11 ) (347 ) — (358 ) Equity in net earnings of subsidiaries (24,568 ) — — 24,568 — Total other income (expense) (37,273 ) 125 67 24,568 (12,513 ) Income (loss) before income taxes (37,386 ) (21,799 ) (6,118 ) 24,568 (40,735 ) Total income tax expense (benefit) 2,438 (5,297 ) 1,946 — (913 ) Net income (loss) attributable to controlling interest $ (39,824 ) $ (16,502 ) $ (8,064 ) $ 24,568 $ (39,822 ) (1) General and administration expenses for field operations are included in operating expenses. PARKER DRILLING COMPANY AND SUBSIDIARIES CONSOLIDATING CONDENSED STATEMENT OF OPERATIONS (Dollars in Thousands) (Unaudited) Three Months Ended June 30, 2015 Parent Guarantor Non-Guarantor Eliminations Consolidated Total revenues $ — $ 63,276 $ 162,703 $ (40,038 ) $ 185,941 Operating expenses — 35,627 147,980 (40,038 ) 143,569 Depreciation and amortization — 23,958 14,393 — 38,351 Total operating gross margin — 3,691 330 — 4,021 General and administration expense (1) (891 ) (12,924 ) 4,304 — (9,511 ) Provision for reduction in carrying value of certain assets — — (2,316 ) — (2,316 ) Gain on disposition of assets, net — (6 ) (132 ) — (138 ) Total operating income (loss) (891 ) (9,239 ) 2,186 — (7,944 ) Other income and (expense): Interest expense (11,066 ) (323 ) (3,010 ) 3,003 (11,396 ) Interest income 165 3 2,854 (3,003 ) 19 Other — 11 (1,540 ) — (1,529 ) Equity in net earnings of subsidiaries (8,392 ) — — 8,392 — Total other income (expense) (19,293 ) (309 ) (1,696 ) 8,392 (12,906 ) Income (loss) before income taxes (20,184 ) (9,548 ) 490 8,392 (20,850 ) Income tax expense (benefit) (6,155 ) (2,361 ) 1,600 — (6,916 ) Net income (loss) (14,029 ) (7,187 ) (1,110 ) 8,392 (13,934 ) Less: Net income attributable to noncontrolling interest — — 95 — 95 Net income (loss) attributable to controlling interest $ (14,029 ) $ (7,187 ) $ (1,205 ) $ 8,392 $ (14,029 ) (1) General and administration expenses for field operations are included in operating expenses. PARKER DRILLING COMPANY AND SUBSIDIARIES CONSOLIDATING CONDENSED STATEMENT OF OPERATIONS (Dollars in Thousands) (Unaudited) Six Months Ended June 30, 2016 Parent Guarantor Non-Guarantor Eliminations Consolidated Total revenues $ — $ 81,968 $ 195,372 $ (41,550 ) $ 235,790 Operating expenses — 58,413 180,449 (41,550 ) 197,312 Depreciation and amortization — 46,439 25,692 — 72,131 Total operating gross margin — (22,884 ) (10,769 ) — (33,653 ) General and administration expense (1) (200 ) (17,440 ) (136 ) — (17,776 ) Gain (Loss) on disposition of assets, net — 153 (215 ) — (62 ) Total operating income (loss) (200 ) (40,171 ) (11,120 ) — (51,491 ) Other income and (expense): Interest expense (24,752 ) (481 ) (5,150 ) 6,634 (23,749 ) Interest income 395 359 5,919 (6,634 ) 39 Other — 473 1,654 — 2,127 Equity in net earnings of subsidiaries (40,793 ) — — 40,793 — Total other income (expense) (65,150 ) 351 2,423 40,793 (21,583 ) Income (loss) before income taxes (65,350 ) (39,820 ) (8,697 ) 40,793 (73,074 ) Total income tax expense (benefit) 70,307 (9,004 ) 1,280 — 62,583 Net income (loss) attributable to controlling interest $ (135,657 ) $ (30,816 ) $ (9,977 ) $ 40,793 $ (135,657 ) (1) General and administration expenses for field operations are included in operating expenses. PARKER DRILLING COMPANY AND SUBSIDIARIES CONSOLIDATING CONDENSED STATEMENT OF OPERATIONS (Dollars in Thousands) (Unaudited) Six Months Ended June 30, 2015 Parent Guarantor Non-Guarantor Eliminations Consolidated Total revenues $ — $ 142,672 $ 313,633 $ (66,288 ) $ 390,017 Operating expenses — 79,772 269,355 (66,288 ) 282,839 Depreciation and amortization — 47,268 31,622 — 78,890 Total operating gross margin — 15,632 12,656 — 28,288 General and administration expense (1) (1,004 ) (23,039 ) 3,695 — (20,348 ) Provision for reduction in carrying value of certain assets — — (2,316 ) — (2,316 ) Gain (Loss) on disposition of assets, net — 45 2,258 — 2,303 Total operating income (loss) (1,004 ) (7,362 ) 16,293 — 7,927 Other income and (expense): Interest expense (22,125 ) (340 ) (3,338 ) 3,329 (22,474 ) Interest income 583 5 2,943 (3,329 ) 202 Other — 20 (2,929 ) — (2,909 ) Equity in net earnings of subsidiaries 597 — — (597 ) — Total other income (expense) (20,945 ) (315 ) (3,324 ) (597 ) (25,181 ) Income (loss) before income taxes (21,949 ) (7,677 ) 12,969 (597 ) (17,254 ) Total income tax expense (benefit) (11,142 ) (2,809 ) 6,853 — (7,098 ) Net income (loss) (10,807 ) (4,868 ) 6,116 (597 ) (10,156 ) Less: Net income attributable to noncontrolling interest — — 651 — 651 Net income (loss) attributable to controlling interest $ (10,807 ) $ (4,868 ) $ 5,465 $ (597 ) $ (10,807 ) (1) General and administration expenses for field operations are included in operating expenses. PARKER DRILLING COMPANY AND SUBSIDIARIES CONSOLIDATING CONDENSED STATEMENT OF COMPREHENSIVE INCOME (LOSS) (Dollars in Thousands) (Unaudited) Three Months Ended June 30, 2016 Parent Guarantor Non-Guarantor Eliminations Consolidated Comprehensive income: Net income (loss) $ (39,824 ) $ (16,502 ) $ (8,064 ) $ 24,568 $ (39,822 ) Other comprehensive income (loss), net of tax: Currency translation difference on related borrowings — — (307 ) — (307 ) Currency translation difference on foreign currency net investments — — (2,228 ) — (2,228 ) Total other comprehensive income (loss), net of tax: — — (2,535 ) — (2,535 ) Comprehensive income (loss) attributable to controlling interest $ (39,824 ) $ (16,502 ) $ (10,599 ) $ 24,568 $ (42,357 ) PARKER DRILLING COMPANY AND SUBSIDIARIES CONSOLIDATING CONDENSED STATEMENT OF COMPREHENSIVE INCOME (LOSS) (Dollars in Thousands) (Unaudited) Three Months Ended June 30, 2015 Parent Guarantor Non-Guarantor Eliminations Consolidated Comprehensive income: Net income (loss) $ (14,029 ) $ (7,187 ) $ (1,110 ) $ 8,392 $ (13,934 ) Other comprehensive income (loss), net of tax: Currency translation difference on related borrowings — — 647 — 647 Currency translation difference on foreign currency net investments — — 1,723 — 1,723 Total other comprehensive income (loss), net of tax: — — 2,370 — 2,370 Comprehensive income (loss) (14,029 ) (7,187 ) 1,260 8,392 (11,564 ) Comprehensive loss attributable to noncontrolling interest — — (95 ) — (95 ) Comprehensive income (loss) attributable to controlling interest $ (14,029 ) $ (7,187 ) $ 1,165 $ 8,392 $ (11,659 ) PARKER DRILLING COMPANY AND SUBSIDIARIES CONSOLIDATING CONDENSED STATEMENT OF COMPREHENSIVE INCOME (LOSS) (Dollars in Thousands) (Unaudited) Six Months Ended June 30, 2016 Parent Guarantor Non-Guarantor Eliminations Consolidated Comprehensive income: Net income (loss) $ (135,657 ) $ (30,816 ) $ (9,977 ) $ 40,793 $ (135,657 ) Other comprehensive income (loss), net of tax: Currency translation difference on related borrowings — — 195 — 195 Currency translation difference on foreign currency net investments — — (3,766 ) — (3,766 ) Total other comprehensive income (loss), net of tax: — — (3,571 ) — (3,571 ) Comprehensive income (loss) attributable to controlling interest $ (135,657 ) $ (30,816 ) $ (13,548 ) $ 40,793 $ (139,228 ) PARKER DRILLING COMPANY AND SUBSIDIARIES CONSOLIDATING CONDENSED STATEMENT OF COMPREHENSIVE INCOME (LOSS) (Dollars in Thousands) (Unaudited) Six Months Ended June 30, 2015 Parent Guarantor Non-Guarantor Eliminations Consolidated Comprehensive income: Net income (loss) $ (10,807 ) $ (4,868 ) $ 6,116 $ (597 ) $ (10,156 ) Other comprehensive income (loss), net of tax: Currency translation difference on related borrowings — — (1,023 ) — (1,023 ) Currency translation difference on foreign currency net investments — — 874 — 874 Total other comprehensive income (loss), net of tax: — — (149 ) — (149 ) Comprehensive income (loss) (10,807 ) (4,868 ) 5,967 (597 ) (10,305 ) Comprehensive (loss) attributable to noncontrolling interest — — (489 ) — (489 ) Comprehensive income (loss) attributable to controlling interest $ (10,807 ) $ (4,868 ) $ 5,478 $ (597 ) $ (10,794 ) PARKER DRILLING COMPANY AND SUBSIDIARIES CONSOLIDATED CONDENSED STATEMENTS OF CASH FLOWS (Dollars in Thousands) (Unaudited) Six Months Ended June 30, 2016 Parent Guarantor Non-Guarantor Eliminations Consolidated Cash flows from operating activities: Net income (loss) $ (135,657 ) $ (30,816 ) $ (9,977 ) $ 40,793 $ (135,657 ) Adjustments to reconcile net income (loss): Depreciation and amortization — 46,439 25,692 — 72,131 Accretion of contingent consideration — 419 — — 419 Loss on debt modification 1,088 — — — 1,088 Gain on disposition of assets — (153 ) 215 — 62 Deferred income tax expense 49,167 9,569 569 — 59,305 Expenses not requiring cash 2,693 (282 ) (7,637 ) — (5,226 ) Equity in net earnings of subsidiaries 40,793 — — (40,793 ) — Change in assets and liabilities: Accounts and notes receivable — 7,755 14,564 — 22,319 Other assets (103,035 ) 102,496 (2,453 ) — (2,992 ) Accounts payable and accrued liabilities 3,281 (5,737 ) (4,406 ) — (6,862 ) Accrued income taxes 21,711 (17,830 ) (7,866 ) — (3,985 ) Net cash provided by (used in) operating activities (119,959 ) 111,860 8,701 — 602 Cash flows from investing activities: Capital expenditures — (7,499 ) (8,758 ) — (16,257 ) Proceeds from the sale of assets — 121 1,266 — 1,387 Net cash provided by (used in) investing activities — (7,378 ) (7,492 ) — (14,870 ) Cash flows from financing activities: Payment for noncontrolling interest (3,375 ) — — — (3,375 ) Payment of contingent consideration — (6,000 ) — — (6,000 ) Excess tax benefit from stock-based compensation (1,617 ) — — — (1,617 ) Intercompany advances, net 106,246 (100,144 ) (6,102 ) — — Net cash provided by (used in) financing activities 101,254 (106,144 ) (6,102 ) — (10,992 ) Net change in cash and cash equivalents (18,705 ) (1,662 ) (4,893 ) — (25,260 ) Cash and cash equivalents at beginning of year 73,985 13,854 46,455 — 134,294 Cash and cash equivalents at end of year $ 55,280 $ 12,192 $ 41,562 $ — $ 109,034 PARKER DRILLING COMPANY AND SUBSIDIARIES CONSOLIDATED CONDENSED STATEMENTS OF CASH FLOWS (Dollars in Thousands) (Unaudited) Six Months Ended June 30, 2015 Parent Guarantor Non-Guarantor Eliminations Consolidated Cash flows from operating activities: Net income (loss) $ (10,807 ) $ (4,868 ) $ 6,116 $ (597 ) $ (10,156 ) Adjustments to reconcile net income (loss) Depreciation and amortization — 47,268 31,622 — 78,890 Accretion of contingent consideration — — 306 — 306 Provision for reduction in carrying value of certain assets — — 2,316 — 2,316 Gain on disposition of assets — (45 ) (2,258 ) — (2,303 ) Deferred income tax expense (22,414 ) 6,574 (1,286 ) — (17,126 ) Expenses not requiring cash 4,039 441 828 — 5,308 Equity in net earnings of subsidiaries (597 ) — — 597 — Change in assets and liabilities: Accounts and notes receivable — 27,778 11,905 — 39,683 Other assets (77,427 ) 59,964 10,111 — (7,352 ) Accounts payable and accrued liabilities 29 14,890 (156 ) — 14,763 Accrued income taxes 2,146 229 (3,611 ) — (1,236 ) Net cash provided by (used in) operating activities (105,031 ) 152,231 55,893 — 103,093 Cash flows from investing activities: Capital expenditures — (37,794 ) (16,811 ) — (54,605 ) Proceeds from the sale of assets — 82 206 — 288 Proceeds from insurance settlements — — 2,500 — 2,500 Acquisitions, net of cash acquired — (10,431 ) — — (10,431 ) Net cash provided by (used in) investing activities — (48,143 ) (14,105 ) — (62,248 ) Cash flows from financing activities: Repayments of long-term debt (30,000 ) — — — (30,000 ) Payment of debt issuance costs (1,359 ) — — — (1,359 ) Excess tax benefit from stock-based compensation (999 ) — — — (999 ) Intercompany advances, net 142,814 (97,138 ) (45,676 ) — — Net cash provided by (used in) financing activities 110,456 (97,138 ) (45,676 ) — (32,358 ) Net change in cash and cash equivalents 5,425 6,950 (3,888 ) — 8,487 Cash and cash equivalents at beginning of year 36,728 13,546 58,182 — 108,456 Cash and cash equivalents at end of year $ 42,153 $ 20,496 $ 54,294 $ — $ 116,943

General (Policies)

General (Policies) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Accounting Policies [Abstract]
Income Tax, Policy [Policy Text Block]			Income Taxes — Income taxes are accounted for under the asset and liability method and have been provided for based upon tax laws and rates in effect in the countries in which operations are conducted and income or losses are generated. There is little or no expected relationship between the provision for or benefit from income taxes and income or loss before income taxes as the countries in which we operate have taxation regimes that vary not only with respect to nominal rate, but also in terms of the availability of deductions, credits, and other benefits. Deferred tax assets and liabilities are recognized for the future tax consequences attributable to differences between the financial statement carrying amounts of existing assets and liabilities and their respective tax bases and operating loss and tax credit carryforwards. Deferred tax assets and liabilities are measured using enacted tax rates in effect for the year in which the temporary differences are expected to be recovered or settled and the effect of changes in tax rates is recognized in income in the period in which the change is enacted. Valuation allowances are established to reduce deferred tax assets when it is more likely than not that some portion or all of the deferred tax assets will not be realized. In order to determine the amount of deferred tax assets or liabilities, as well as the valuation allowances, we must make estimates and assumptions regarding future taxable income, where rigs will be deployed and other matters. Changes in these estimates and assumptions, including changes in tax laws and other changes impacting our ability to recognize the underlying deferred tax assets, could require us to adjust the valuation allowances. The Company recognizes the effect of income tax positions only if those positions are more likely than not to be sustained. Recognized income tax positions are measured at the largest amount that is greater than 50 percent likely of being realized and changes in recognition or measurement are reflected in the period in which the change in judgment occurs.
Nature of Operations			Nature of Operations — Our business is comprised of two business lines: (1) Drilling Services and (2) Rental Tools Services. We report our Rental Tools Services business as one reportable segment (Rental Tools) and report our Drilling Services business as two reportable segments: (1) U.S. (Lower 48) Drilling and (2) International & Alaska Drilling. In our Drilling Services business, we drill oil and gas wells for customers in both the United States (U.S.) and international markets. We provide this service with both Company-owned rigs and customer-owned rigs. We refer to the provision of drilling services with customer-owned rigs as our operations and maintenance (O&M) service in which operators own their own drilling rigs but choose Parker Drilling to operate and maintain the rigs for them. The nature and scope of activities involved in drilling an oil and gas well are similar whether the well is drilled with a Company-owned rig (as part of a traditional drilling contract) or a customer-owned rig (as part of an O&M contract). In addition, we provide project related services, such as engineering, procurement, project management and commissioning of customer owned drilling facility projects. We have extensive experience and expertise in drilling geologically difficult wells and in managing the logistical and technological challenges of operating in remote, harsh and ecologically sensitive areas. Our U.S. (Lower 48) Drilling segment provides drilling services with our Gulf of Mexico (GOM) barge drilling fleet and markets U.S. (Lower 48) based O&M services. Our GOM barge drilling fleet operates barge rigs that drill for oil and natural gas in shallow waters in and along the inland waterways and coasts of Louisiana, Alabama and Texas. The majority of these wells are drilled in shallow water depths ranging from 6 to 12 feet. Our International & Alaska Drilling segment provides drilling services, with Company-owned rigs as well as through O&M contracts, and project related services. We strive to deploy our fleet of Company-owned rigs in markets where we expect to have opportunities to keep the rigs consistently utilized and build a sufficient presence to achieve efficient operating scale. In our Rental Tools Services business, we provide premium rental equipment and services to exploration and production (E&P) companies, drilling contractors and service companies on land and offshore in the U.S. and select international markets. Tools we provide include standard and heavy-weight drill pipe, all of which are available with standard or high-torque connections, tubing, pressure control equipment, including blow-out preventers (BOPs), drill collars and more. We also provide well construction services, which include tubular running services and downhole tools, and well intervention services, which include whipstock, fishing products and related services, as well as inspection and machine shop support. Rental tools are used during well drilling programs and are requested by the customer when they are needed, requiring us to keep a broad inventory of rental tools in stock. Rental tools are usually rented on a daily or monthly basis.
Consolidation			Consolidation — The consolidated condensed financial statements include the accounts of the Company and subsidiaries over which we exercise control or in which we have a controlling financial interest, including entities, if any, in which the Company is allocated a majority of the entity’s losses or returns, regardless of ownership percentage. If a subsidiary of Parker Drilling has a 50 percent interest in an entity but Parker Drilling’s interest in the subsidiary or the entity does not meet the consolidation criteria, then that interest is accounted for under the equity method.
Noncontrolling Interest			Noncontrolling Interest — We apply accounting standards related to noncontrolling interests for ownership interests in our subsidiaries held by parties other than Parker Drilling. We report noncontrolling interest as equity on the consolidated balance sheets and report net income (loss) attributable to controlling interest and to noncontrolling interest separately on the consolidated condensed statements of operations. During the fourth quarter of 2015, we purchased the remaining noncontrolling interest of ITS Arabia Limited for $6.75 million , of which $3.4 million was paid in the 2015 fourth quarter. The final payment of the purchase price was made during the second quarter of 2016. At the time of purchase, the carrying value of the noncontrolling interest was $3.0 million .
Reclassifications [Text Block]			Reclassifications — Certain reclassifications have been made to prior period amounts to conform to the current period presentation. These reclassifications did not materially affect our consolidated financial results.
Revenue Recognition			Revenue Recognition — Drilling revenues and expenses, comprised of daywork drilling contracts, call-outs against master service agreements and engineering and related project services contracts, are recognized as services are performed and collection is reasonably assured. For certain contracts, we receive payments contractually designated for the mobilization of rigs and other drilling equipment. Mobilization payments received, and direct costs incurred for the mobilization, are deferred and recognized over the primary term of the related drilling contract; however, costs incurred to relocate rigs and other drilling equipment to areas in which a contract has not been secured are expensed as incurred. For contracts that are terminated prior to the specified term, early termination payments received by us are recognized as revenues when all contractual requirements are met. Revenues from rental activities are recognized ratably over the rental term, which is generally less than six months. Our project related services contracts include engineering, consulting, and project management scopes of work and revenue is typically recognized on a time and materials basis.
Reimbursable Costs Policy [Text Block]			Reimbursable Revenues — The Company recognizes reimbursements received for out-of-pocket expenses incurred as revenues and accounts for out-of-pocket expenses as direct operating costs. Such amounts totaled $18.9 million and $27.8 million for the three months ended June 30, 2016 and 2015 , respectively, and $37.9 million and $47.5 million for the six months ended June 30, 2016 and 2015 , respectively. Additionally, the Company typically receives a nominal handling fee, which is recognized as revenues in our consolidated statement of operations.
Reimbursable Costs	$ 18.9	$ 27.8	$ 37.9	$ 47.5
Use of Estimates			Use of Estimates — The preparation of consolidated condensed financial statements in accordance with accounting policies generally accepted in the United States (U.S. GAAP) requires management to make estimates and assumptions that affect our reported amounts of assets and liabilities, our disclosure of contingent assets and liabilities at the date of the consolidated condensed financial statements, and our revenues and expenses during the periods reported. Estimates are typically used when accounting for certain significant items such as legal or contractual liability accruals, mobilization and deferred mobilization, self-insured medical/dental plans, income taxes and valuation allowance, and other items requiring the use of estimates. Estimates are based on a number of variables which may include third party valuations, historical experience, where applicable, and assumptions that we believe are reasonable under the circumstances. Due to the inherent uncertainty involved with estimates, actual results may differ from management estimates.
Business Combination Disclosure [Text Block]			Purchase Price Allocation — We allocate the purchase price of an acquired business to its identifiable assets and liabilities in accordance with the acquisition method based on estimated fair values at the transaction date. Transaction and integration costs associated with an acquisition are expensed as incurred. The excess of the purchase price over the amount allocated to the assets and liabilities, if any, is recorded as goodwill. We use all available information to estimate fair values, including quoted market prices, the carrying value of acquired assets, and widely accepted valuation techniques such as discounted cash flows. We typically engage third-party appraisal firms to assist in fair value determination of inventories, identifiable intangible assets, and any other significant assets or liabilities. Judgments made in determining the estimated fair value assigned to each class of assets acquired and liabilities assumed, as well as asset lives, can materially impact our results of operations. See Note 2 - Acquisitions for further discussion. Acquisitions Acquisition of 2M-Tek On April 17, 2015 we acquired 2M-Tek, a Louisiana-based manufacturer of equipment for tubular running and related well services (the 2M-Tek Acquisition) for an initial purchase price of $10.4 million paid at the closing of the acquisition, plus $8.0 million of contingent consideration payable to the seller upon the achievement of certain milestones over the 24-month period following the closing of the 2M-Tek Acquisition. The fair value of the consideration transferred was $17.2 million , which includes the $10.4 million liability paid at closing plus the estimated fair value of the contingent consideration of $6.8 million . We paid $2.0 million of the contingent consideration upon the achievement of certain milestones during the fourth quarter of 2015 and $2.0 million during the first quarter of 2016. The remaining $4.0 million of the contingent consideration was paid in April 2016.
Goodwill Disclosure [Text Block]			Goodwill — We account for all business combinations using the acquisition method of accounting. Under this method, assets and liabilities, including any remaining noncontrolling interests, are recognized at fair value at the date of acquisition. The excess of the purchase price over the fair value of assets acquired, net of liabilities assumed, plus the value of any noncontrolling interests, is recognized as goodwill. We perform our annual goodwill impairment review as of October 1 of each year, and more frequently if negative conditions or other triggering events arise. The quantitative impairment test we perform for goodwill utilizes certain assumptions, including forecasted revenue and costs assumptions. See Note 3 - Goodwill and Intangible Assets for further discussion.
Intangible Assets			Intangible Assets — Our intangible assets are related to trade names, customer relationships, and developed technology, which were acquired through acquisition and are generally amortized over a weighted average period of approximately three to six years. We assess the recoverability of the unamortized balance of our intangible assets when indicators of impairment are present based on expected future profitability and undiscounted expected cash flows and their contribution to our overall operations. Should the review indicate that the carrying value is not fully recoverable, the excess of the carrying value over the fair value of the intangible assets would be recognized as an impairment loss. See Note 3 - Goodwill and Intangible Assets for further discussion.
Impairment or Disposal of Long-Lived Assets, Policy [Policy Text Block]			Impairment — We evaluate the carrying amounts of long-lived assets for potential impairment when events occur or circumstances change that indicate the carrying values of such assets may not be recoverable. We evaluate recoverability by determining the undiscounted estimated future net cash flows for the respective asset groups identified. If the sum of the estimated undiscounted cash flows is less than the carrying value of the asset group, we measure the impairment as the amount by which the assets’ carrying value exceeds the fair value of such assets. Management considers a number of factors such as estimated future cash flows from the assets, appraisals and current market value analysis in determining fair value. Assets are written down to fair value if the final estimate of current fair value is below the net carrying value. The assumptions used in the impairment evaluation are inherently uncertain and require management judgment
Concentrations of Credit Risk			Concentrations of Credit Risk — Financial instruments that potentially subject the Company to concentrations of credit risk consist primarily of trade receivables with a variety of national and international oil and natural gas companies. We generally do not require collateral on our trade receivables. We depend on a limited number of significant customers. Our largest customer, Exxon Neftegas Limited (ENL) , constituted approximately 39.8 percent of our consolidated revenues for the six months ended June 30, 2016 . Excluding reimbursable revenues of $36.9 million , ENL constituted approximately 28.7 percent of our total consolidated revenues for the six months ended June 30, 2016 . Our second largest customer, BP Exploration Alaska, Inc. (BP), constituted approximately 11.9 percent of our consolidated revenues for the six months ended June 30, 2016 . At June 30, 2016 and December 31, 2015 , we had deposits in domestic banks in excess of federally insured limits of approximately $69.1 million and $91.3 million , respectively. In addition, we had uninsured deposits in foreign banks as of June 30, 2016 and December 31, 2015 of $41.7 million and $44.1 million , respectively.
Recent Accounting Pronouncements			Recent Accounting Pronouncements In March 2016, the Financial Accounting Standards Board (FASB) issued Accounting Standards Update (ASU) No. 2016-09, Compensation - Stock Compensation (Topic 718). The objective of this update is to simplify several aspects of the accounting for share-based payment transactions, including the income tax consequences, classification of awards as either equity or liabilities, and classification on the statement of cash flows. The standard becomes effective for public companies for fiscal years beginning after December 15, 2016, including interim periods within those fiscal years. Early adoption is permitted. We are in the process of assessing the impact of the adoption of ASU 2016-09 on our financial position, results of operations and cash flows. In March 2016, the FASB issued ASU No. 2016-02, Leases (Topic 842). This update establishes a new lease accounting model for lessees. Upon adoption, a modified retrospective approach is required for leases that exist, or are entered into, after the beginning of the earliest comparative period presented. The standard is effective for fiscal years beginning after December 15, 2018, including interim periods within those fiscal years, although early adoption is permitted. We are in the process of assessing the impact of the adoption of ASU 2016-02 on our financial position, results of operations and cash flows. We have not yet determined the effect of the standard on our ongoing financial reporting. In May 2014, the FASB issued ASU 2014-09, Revenue from Contracts with Customers. This ASU supersedes the revenue recognition requirements in Accounting Standards Codification 605 - Revenue Recognition and most industry-specific guidance throughout the Codification. The standard requires that an entity recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the company expects to be entitled in exchange for those goods or services and should be applied retrospectively to each prior reporting period presented or retrospectively with the cumulative effect of initially applying the ASU recognized at the date of initial application. ASU 2014-09 is effective for fiscal years beginning after December 15, 2017. We are in the process of assessing the impact of the adoption of ASU 2014-09 on our financial position, results of operations and cash flows. We have not yet selected a transition method nor have we determined the effect of the standard on our ongoing financial reporting.
Legal Costs, Policy [Policy Text Block]			Legal and Investigation Matters — We accrue estimates of the probable and estimable costs for the resolution of certain legal and investigation matters. We do not accrue any amounts for other matters for which the liability is not probable and reasonably estimable. Generally, the estimate of probable costs related to these matters is developed in consultation with our legal advisors. The estimates take into consideration factors such as the complexity of the issues, litigation risks and settlement costs. If the actual settlement costs, final judgments, or fines, after appeals, differ from our estimates, our future financial results may be adversely affected.

Earnings per share (EPS) (Table

Earnings per share (EPS) (Tables)	6 Months Ended
	Jun. 30, 2016
Earnings Per Share [Abstract]
Schedule of Earnings Per Share, Basic and Diluted [Table Text Block]	Three Months Ended June 30, 2016 Income/(Loss) (Numerator) Shares (Denominator) Per-Share Amount Basic EPS $ (39,822,000 ) 124,101,349 $ (0.32 ) Effect of dilutive securities: Restricted stock units — — — Diluted EPS $ (39,822,000 ) 124,101,349 $ (0.32 ) Six Months Ended June 30, 2016 Income/(Loss) (Numerator) Shares (Denominator) Per-Share Amount Basic EPS $ (135,657,000 ) 123,595,793 $ (1.10 ) Effect of dilutive securities: Restricted stock units — — — Diluted EPS $ (135,657,000 ) 123,595,793 $ (1.10 ) Three Months Ended June 30, 2015 Income/(Loss) (Numerator) Shares (Denominator) Per-Share Amount Basic EPS $ (14,029,000 ) 122,481,425 $ (0.11 ) Effect of dilutive securities: Restricted stock units — — — Diluted EPS $ (14,029,000 ) 122,481,425 $ (0.11 ) Six Months Ended June 30, 2015 Income/(Loss) (Numerator) Shares (Denominator) Per-Share Amount Basic EPS $ (10,807,000 ) 122,175,511 $ (0.09 ) Effect of dilutive securities: Restricted stock units — — — Diluted EPS $ (10,807,000 ) 122,175,511 $ (0.09 )

Accumulated Other Comprehensi21

Accumulated Other Comprehensive Income (Tables)	6 Months Ended
	Jun. 30, 2016
Equity [Abstract]
Schedule of accumulated other comprehensive income	Accumulated other comprehensive loss consisted of the following: Dollars in thousands Foreign Currency Items December 31, 2015 $ (1,888 ) Current period other comprehensive loss (3,571 ) June 30, 2016 $ (5,459 )

Reportable Segments (Tables)

Reportable Segments (Tables)	6 Months Ended
	Jun. 30, 2016
Segment Reporting [Abstract]
Results of Operations by Reportable Segment	The following table represents the results of operations by reportable segment: Three Months Ended June 30, Six Months Ended June 30, Dollars in thousands 2016 2015 2016 2015 Revenues: (1) Drilling Services: U.S. (Lower 48) Drilling $ 1,065 $ 6,848 $ 3,150 $ 20,945 International & Alaska Drilling 71,926 114,969 160,545 228,890 Total Drilling Services 72,991 121,817 163,695 249,835 Rental Tools 32,296 64,124 72,095 140,182 Total revenues 105,287 185,941 235,790 390,017 Operating gross margin: (2) Drilling Services: U.S. (Lower 48) Drilling (9,011 ) (7,552 ) (17,571 ) (13,274 ) International & Alaska Drilling 3,196 6,844 8,274 24,208 Total Drilling Services (5,815 ) (708 ) (9,297 ) 10,934 Rental Tools (14,410 ) 4,729 (24,356 ) 17,354 Total operating gross margin (20,225 ) 4,021 (33,653 ) 28,288 General and administrative expense (7,995 ) (9,511 ) (17,776 ) (20,348 ) Provision for reduction in carrying value of certain assets — (2,316 ) — (2,316 ) Gain (loss) on disposition of assets, net (2 ) (138 ) (62 ) 2,303 Total operating income (loss) (28,222 ) (7,944 ) (51,491 ) 7,927 Interest expense (12,187 ) (11,396 ) (23,749 ) (22,474 ) Interest income 32 19 39 202 Other income (loss) (358 ) (1,529 ) 2,127 (2,909 ) Loss from continuing operations before income taxes $ (40,735 ) $ (20,850 ) $ (73,074 ) $ (17,254 ) (1) For the six months ended June 30, 2016 , our largest customer, ENL , constituted approximately 39.8 percent of our total consolidated revenues and approximately 58.4 percent of our International & Alaska Drilling segment revenues. Excluding reimbursable revenues of $36.9 million , ENL constituted approximately 28.7 percent of our total consolidated revenues and approximately 46.4 percent of our International & Alaska Drilling segment revenues. Our second largest customer, BP, constituted 11.9 percent of our total consolidated revenues and approximately 17.2 percent of our International & Alaska Drilling segment revenues. For the six months ended June 30, 2015 , our largest customer, ENL , constituted approximately 26.0 percent of our total consolidated revenues and approximately 44.3 percent of our International & Alaska Drilling segment revenues. Excluding reimbursable revenues of $39.7 million , ENL constituted approximately 18.1 percent of our total consolidated revenues and approximately 34.0 percent of our International & Alaska Drilling segment revenues. (2) Operating gross margin is calculated as revenues less direct operating expenses, including depreciation and amortization expense.

Long-Term Debt (Tables)

Long-Term Debt (Tables)	6 Months Ended
	Jun. 30, 2016
Debt Disclosure [Abstract]
Summary of Company's Current Debt Portfolio	The following table illustrates our debt portfolio as of June 30, 2016 and December 31, 2015 : Dollars in thousands June 30, December 31, 6.75% Senior Notes, due July 2022 $ 360,000 $ 360,000 7.50% Senior Notes, due August 2020 225,000 225,000 Total Principal 585,000 585,000 Less: unamortized debt issuance costs (9,452 ) (10,202 ) Total long-term debt $ 575,548 $ 574,798

Fair Value of Financial Instr24

Fair Value of Financial Instruments (Tables)	6 Months Ended
	Jun. 30, 2016
Fair Value Disclosures [Abstract]
Fair Values and Related Carrying Values of Debt Instruments	June 30, 2016 December 31, 2015 Dollars in thousands Carrying Amount Fair Value Carrying Amount Fair Value Long-term Debt 6.75% Notes $ 360,000 $ 270,900 $ 360,000 $ 246,600 7.50% Notes 225,000 172,125 225,000 171,000 Total Principal $ 585,000 $ 443,025 $ 585,000 $ 417,600

Parent, Guarantor, Non-Guaran25

Parent, Guarantor, Non-Guarantor Unaudited Consolidating Condensed Financial Statements (Tables)	6 Months Ended
	Jun. 30, 2016
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Consolidating Condensed Balance Sheet	PARKER DRILLING COMPANY AND SUBSIDIARIES CONSOLIDATING CONDENSED BALANCE SHEET (Dollars in Thousands) (Unaudited) December 31, 2015 Parent Guarantor Non-Guarantor Eliminations Consolidated ASSETS Current assets: Cash and cash equivalents $ 73,985 $ 13,854 $ 46,455 $ — $ 134,294 Accounts and notes receivable, net — 42,261 132,844 — 175,105 Rig materials and supplies — (4,744 ) 39,681 — 34,937 Other current assets — 5,982 16,423 — 22,405 Total current assets 73,985 57,353 235,403 — 366,741 Property, plant and equipment, net (19 ) 543,346 262,514 — 805,841 Goodwill — 6,708 — — 6,708 Intangible assets, net — 11,740 1,637 — 13,377 Investment in subsidiaries and intercompany advances 3,057,220 2,770,501 3,319,702 (9,147,423 ) — Other noncurrent assets (234,786 ) 312,790 265,995 (169,964 ) 174,035 Total assets $ 2,896,400 $ 3,702,438 $ 4,085,251 $ (9,317,387 ) $ 1,366,702 LIABILITIES AND STOCKHOLDERS’ EQUITY Current liabilities: Accounts payable and accrued liabilities $ 84,456 $ 56,382 $ 295,439 $ (306,574 ) $ 129,703 Accrued income taxes 9,900 2,111 (5,593 ) — 6,418 Total current liabilities 94,356 58,493 289,846 (306,574 ) 136,121 Long-term debt, net 574,798 — — — 574,798 Other long-term liabilities 2,868 7,446 8,303 — 18,617 Long-term deferred tax liability (29 ) 69,679 (996 ) — 68,654 Intercompany payables 1,656,968 1,401,510 1,864,671 (4,923,149 ) — Total liabilities 2,328,961 1,537,128 2,161,824 (5,229,723 ) 798,190 Total equity 567,439 2,165,310 1,923,427 (4,087,664 ) 568,512 Total liabilities and stockholders’ equity $ 2,896,400 $ 3,702,438 $ 4,085,251 $ (9,317,387 ) $ 1,366,702 PARKER DRILLING COMPANY AND SUBSIDIARIES CONSOLIDATING CONDENSED BALANCE SHEET (Dollars in Thousands) (Unaudited) June 30, 2016 Parent Guarantor Non-Guarantor Eliminations Consolidated ASSETS Current assets: Cash and cash equivalents $ 55,280 $ 12,192 $ 41,562 $ — $ 109,034 Accounts and notes receivable, net — 34,853 118,336 — 153,189 Rig materials and supplies — (6,009 ) 38,624 — 32,615 Other current assets — 8,601 18,204 — 26,805 Total current assets 55,280 49,637 216,726 — 321,643 Property, plant and equipment, net (19 ) 502,191 244,845 — 747,017 Goodwill — 6,708 — — 6,708 Intangible assets, net — 10,587 805 — 11,392 Investment in subsidiaries and intercompany advances 3,032,953 2,889,755 3,498,240 (9,420,948 ) — Other noncurrent assets (151,632 ) 207,566 550,882 (480,805 ) 126,011 Total assets $ 2,936,582 $ 3,666,444 $ 4,511,498 $ (9,901,753 ) $ 1,212,771 LIABILITIES AND STOCKHOLDERS’ EQUITY Current liabilities: Accounts payable and accrued liabilities $ 114,217 $ 44,382 $ 567,968 $ (617,476 ) $ 109,091 Accrued income taxes 30,910 (15,019 ) (10,114 ) — 5,777 Total current liabilities 145,127 29,363 557,854 (617,476 ) 114,868 Long-term debt, net 575,548 — — — 575,548 Other long-term liabilities 2,867 7,708 4,474 — 15,049 Long-term deferred tax liability (29 ) 77,394 (890 ) — 76,475 Intercompany payables 1,779,740 1,417,482 2,018,050 (5,215,272 ) — Total liabilities 2,503,253 1,531,947 2,579,488 (5,832,748 ) 781,940 Total equity 433,329 2,134,497 1,932,010 (4,069,005 ) 430,831 Total liabilities and stockholders’ equity $ 2,936,582 $ 3,666,444 $ 4,511,498 $ (9,901,753 ) $ 1,212,771
Consolidating Condensed Statement of Operations	Three Months Ended June 30, 2016 Parent Guarantor Non-Guarantor Eliminations Consolidated Total revenues $ — $ 34,586 $ 88,895 $ (18,194 ) $ 105,287 Operating expenses — 25,577 81,812 (18,194 ) 89,195 Depreciation and amortization — 23,314 13,003 — 36,317 Total operating gross margin — (14,305 ) (5,920 ) — (20,225 ) General and administration expense (1) (113 ) (7,828 ) (54 ) — (7,995 ) Gain (Loss) on disposition of assets, net — 209 (211 ) — (2 ) Total operating income (loss) (113 ) (21,924 ) (6,185 ) — (28,222 ) Other income and (expense): Interest expense (12,896 ) (44 ) (2,290 ) 3,043 (12,187 ) Interest income 191 180 2,704 (3,043 ) 32 Other — (11 ) (347 ) — (358 ) Equity in net earnings of subsidiaries (24,568 ) — — 24,568 — Total other income (expense) (37,273 ) 125 67 24,568 (12,513 ) Income (loss) before income taxes (37,386 ) (21,799 ) (6,118 ) 24,568 (40,735 ) Total income tax expense (benefit) 2,438 (5,297 ) 1,946 — (913 ) Net income (loss) attributable to controlling interest $ (39,824 ) $ (16,502 ) $ (8,064 ) $ 24,568 $ (39,822 ) (1) General and administration expenses for field operations are included in operating expenses.
Consolidating Condensed Statements of Comprehensive Income (Loss)	PARKER DRILLING COMPANY AND SUBSIDIARIES CONSOLIDATING CONDENSED STATEMENT OF COMPREHENSIVE INCOME (LOSS) (Dollars in Thousands) (Unaudited) Three Months Ended June 30, 2016 Parent Guarantor Non-Guarantor Eliminations Consolidated Comprehensive income: Net income (loss) $ (39,824 ) $ (16,502 ) $ (8,064 ) $ 24,568 $ (39,822 ) Other comprehensive income (loss), net of tax: Currency translation difference on related borrowings — — (307 ) — (307 ) Currency translation difference on foreign currency net investments — — (2,228 ) — (2,228 ) Total other comprehensive income (loss), net of tax: — — (2,535 ) — (2,535 ) Comprehensive income (loss) attributable to controlling interest $ (39,824 ) $ (16,502 ) $ (10,599 ) $ 24,568 $ (42,357 ) PARKER DRILLING COMPANY AND SUBSIDIARIES CONSOLIDATING CONDENSED STATEMENT OF COMPREHENSIVE INCOME (LOSS) (Dollars in Thousands) (Unaudited) Three Months Ended June 30, 2015 Parent Guarantor Non-Guarantor Eliminations Consolidated Comprehensive income: Net income (loss) $ (14,029 ) $ (7,187 ) $ (1,110 ) $ 8,392 $ (13,934 ) Other comprehensive income (loss), net of tax: Currency translation difference on related borrowings — — 647 — 647 Currency translation difference on foreign currency net investments — — 1,723 — 1,723 Total other comprehensive income (loss), net of tax: — — 2,370 — 2,370 Comprehensive income (loss) (14,029 ) (7,187 ) 1,260 8,392 (11,564 ) Comprehensive loss attributable to noncontrolling interest — — (95 ) — (95 ) Comprehensive income (loss) attributable to controlling interest $ (14,029 ) $ (7,187 ) $ 1,165 $ 8,392 $ (11,659 ) PARKER DRILLING COMPANY AND SUBSIDIARIES CONSOLIDATING CONDENSED STATEMENT OF COMPREHENSIVE INCOME (LOSS) (Dollars in Thousands) (Unaudited) Six Months Ended June 30, 2016 Parent Guarantor Non-Guarantor Eliminations Consolidated Comprehensive income: Net income (loss) $ (135,657 ) $ (30,816 ) $ (9,977 ) $ 40,793 $ (135,657 ) Other comprehensive income (loss), net of tax: Currency translation difference on related borrowings — — 195 — 195 Currency translation difference on foreign currency net investments — — (3,766 ) — (3,766 ) Total other comprehensive income (loss), net of tax: — — (3,571 ) — (3,571 ) Comprehensive income (loss) attributable to controlling interest $ (135,657 ) $ (30,816 ) $ (13,548 ) $ 40,793 $ (139,228 ) PARKER DRILLING COMPANY AND SUBSIDIARIES CONSOLIDATING CONDENSED STATEMENT OF COMPREHENSIVE INCOME (LOSS) (Dollars in Thousands) (Unaudited) Six Months Ended June 30, 2015 Parent Guarantor Non-Guarantor Eliminations Consolidated Comprehensive income: Net income (loss) $ (10,807 ) $ (4,868 ) $ 6,116 $ (597 ) $ (10,156 ) Other comprehensive income (loss), net of tax: Currency translation difference on related borrowings — — (1,023 ) — (1,023 ) Currency translation difference on foreign currency net investments — — 874 — 874 Total other comprehensive income (loss), net of tax: — — (149 ) — (149 ) Comprehensive income (loss) (10,807 ) (4,868 ) 5,967 (597 ) (10,305 ) Comprehensive (loss) attributable to noncontrolling interest — — (489 ) — (489 ) Comprehensive income (loss) attributable to controlling interest $ (10,807 ) $ (4,868 ) $ 5,478 $ (597 ) $ (10,794 )
Consolidated Condensed Statements of Cash Flows	ARKER DRILLING COMPANY AND SUBSIDIARIES CONSOLIDATED CONDENSED STATEMENTS OF CASH FLOWS (Dollars in Thousands) (Unaudited) Six Months Ended June 30, 2016 Parent Guarantor Non-Guarantor Eliminations Consolidated Cash flows from operating activities: Net income (loss) $ (135,657 ) $ (30,816 ) $ (9,977 ) $ 40,793 $ (135,657 ) Adjustments to reconcile net income (loss): Depreciation and amortization — 46,439 25,692 — 72,131 Accretion of contingent consideration — 419 — — 419 Loss on debt modification 1,088 — — — 1,088 Gain on disposition of assets — (153 ) 215 — 62 Deferred income tax expense 49,167 9,569 569 — 59,305 Expenses not requiring cash 2,693 (282 ) (7,637 ) — (5,226 ) Equity in net earnings of subsidiaries 40,793 — — (40,793 ) — Change in assets and liabilities: Accounts and notes receivable — 7,755 14,564 — 22,319 Other assets (103,035 ) 102,496 (2,453 ) — (2,992 ) Accounts payable and accrued liabilities 3,281 (5,737 ) (4,406 ) — (6,862 ) Accrued income taxes 21,711 (17,830 ) (7,866 ) — (3,985 ) Net cash provided by (used in) operating activities (119,959 ) 111,860 8,701 — 602 Cash flows from investing activities: Capital expenditures — (7,499 ) (8,758 ) — (16,257 ) Proceeds from the sale of assets — 121 1,266 — 1,387 Net cash provided by (used in) investing activities — (7,378 ) (7,492 ) — (14,870 ) Cash flows from financing activities: Payment for noncontrolling interest (3,375 ) — — — (3,375 ) Payment of contingent consideration — (6,000 ) — — (6,000 ) Excess tax benefit from stock-based compensation (1,617 ) — — — (1,617 ) Intercompany advances, net 106,246 (100,144 ) (6,102 ) — — Net cash provided by (used in) financing activities 101,254 (106,144 ) (6,102 ) — (10,992 ) Net change in cash and cash equivalents (18,705 ) (1,662 ) (4,893 ) — (25,260 ) Cash and cash equivalents at beginning of year 73,985 13,854 46,455 — 134,294 Cash and cash equivalents at end of year $ 55,280 $ 12,192 $ 41,562 $ — $ 109,034 Six Months Ended June 30, 2016 Parent Guarantor Non-Guarantor Eliminations Consolidated Cash flows from operating activities: Net income (loss) $ (135,657 ) $ (30,816 ) $ (9,977 ) $ 40,793 $ (135,657 ) Adjustments to reconcile net income (loss): Depreciation and amortization — 46,439 25,692 — 72,131 Accretion of contingent consideration — 419 — — 419 Loss on debt modification 1,088 — — — 1,088 Gain on disposition of assets — (153 ) 215 — 62 Deferred income tax expense 49,167 9,569 569 — 59,305 Expenses not requiring cash 2,693 (282 ) (7,637 ) — (5,226 ) Equity in net earnings of subsidiaries 40,793 — — (40,793 ) — Change in assets and liabilities: Accounts and notes receivable — 7,755 14,564 — 22,319 Other assets (103,035 ) 102,496 (2,453 ) — (2,992 ) Accounts payable and accrued liabilities 3,281 (5,737 ) (4,406 ) — (6,862 ) Accrued income taxes 21,711 (17,830 ) (7,866 ) — (3,985 ) Net cash provided by (used in) operating activities (119,959 ) 111,860 8,701 — 602 Cash flows from investing activities: Capital expenditures — (7,499 ) (8,758 ) — (16,257 ) Proceeds from the sale of assets — 121 1,266 — 1,387 Net cash provided by (used in) investing activities — (7,378 ) (7,492 ) — (14,870 ) Cash flows from financing activities: Payment for noncontrolling interest (3,375 ) — — — (3,375 ) Payment of contingent consideration — (6,000 ) — — (6,000 ) Excess tax benefit from stock-based compensation (1,617 ) — — — (1,617 ) Intercompany advances, net 106,246 (100,144 ) (6,102 ) — — Net cash provided by (used in) financing activities 101,254 (106,144 ) (6,102 ) — (10,992 ) Net change in cash and cash equivalents (18,705 ) (1,662 ) (4,893 ) — (25,260 ) Cash and cash equivalents at beginning of year 73,985 13,854 46,455 — 134,294 Cash and cash equivalents at end of year $ 55,280 $ 12,192 $ 41,562 $ — $ 109,034 PARKER DRILLING COMPANY AND SUBSIDIARIES CONSOLIDATED CONDENSED STATEMENTS OF CASH FLOWS (Dollars in Thousands) (Unaudited) Six Months Ended June 30, 2015 Parent Guarantor Non-Guarantor Eliminations Consolidated Cash flows from operating activities: Net income (loss) $ (10,807 ) $ (4,868 ) $ 6,116 $ (597 ) $ (10,156 ) Adjustments to reconcile net income (loss) Depreciation and amortization — 47,268 31,622 — 78,890 Accretion of contingent consideration — — 306 — 306 Provision for reduction in carrying value of certain assets — — 2,316 — 2,316 Gain on disposition of assets — (45 ) (2,258 ) — (2,303 ) Deferred income tax expense (22,414 ) 6,574 (1,286 ) — (17,126 ) Expenses not requiring cash 4,039 441 828 — 5,308 Equity in net earnings of subsidiaries (597 ) — — 597 — Change in assets and liabilities: Accounts and notes receivable — 27,778 11,905 — 39,683 Other assets (77,427 ) 59,964 10,111 — (7,352 ) Accounts payable and accrued liabilities 29 14,890 (156 ) — 14,763 Accrued income taxes 2,146 229 (3,611 ) — (1,236 ) Net cash provided by (used in) operating activities (105,031 ) 152,231 55,893 — 103,093 Cash flows from investing activities: Capital expenditures — (37,794 ) (16,811 ) — (54,605 ) Proceeds from the sale of assets — 82 206 — 288 Proceeds from insurance settlements — — 2,500 — 2,500 Acquisitions, net of cash acquired — (10,431 ) — — (10,431 ) Net cash provided by (used in) investing activities — (48,143 ) (14,105 ) — (62,248 ) Cash flows from financing activities: Repayments of long-term debt (30,000 ) — — — (30,000 ) Payment of debt issuance costs (1,359 ) — — — (1,359 ) Excess tax benefit from stock-based compensation (999 ) — — — (999 ) Intercompany advances, net 142,814 (97,138 ) (45,676 ) — — Net cash provided by (used in) financing activities 110,456 (97,138 ) (45,676 ) — (32,358 ) Net change in cash and cash equivalents 5,425 6,950 (3,888 ) — 8,487 Cash and cash equivalents at beginning of year 36,728 13,546 58,182 — 108,456 Cash and cash equivalents at end of year $ 42,153 $ 20,496 $ 54,294 $ — $ 116,943

General - Additional Informatio

General - Additional Information (Detail) - USD ($) $ in Thousands	3 Months Ended			6 Months Ended
	Jun. 30, 2016	Dec. 31, 2015	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Revenue, Major Customer [Line Items]
Payments to Acquire Property, Plant, and Equipment				$ 16,257	$ 54,605
Percentage accounted for under the equity method	50.00%			50.00%
Reimbursable Costs	$ 18,900		$ 27,800	$ 37,900	$ 47,500
Deposits in domestic bank	69,100	$ 91,300		69,100
Deposits, Foreign	$ 41,700	44,100		$ 41,700
Noncontrolling Interest, Fair Value Disclosure		6,750
Redeemable Noncontrolling Interest, Equity, Carrying Amount		3,000
Exxon Neftegas Limited [Member]
Revenue, Major Customer [Line Items]
Percentage of revenue from major customer				39.80%	26.00%
Reimbursement Revenue				$ 36,900	$ 39,700
Concentration Risk, Other Risk				0.287	0.181
BP Exploration Alaska, Inc. [Member]
Revenue, Major Customer [Line Items]
Percentage of revenue from major customer				11.90%
ITS Arabia Limited [Member]
Revenue, Major Customer [Line Items]
Purchase Price of Remaining Noncontrolling Interest		$ 3,400

Acquisitions ITS - Narrative (D

Acquisitions ITS - Narrative (Details) - April 17, 2015 Acquisition [Member] - USD ($) $ in Thousands	Apr. 18, 2015	Jun. 30, 2016	Mar. 31, 2016	Dec. 31, 2015	Apr. 17, 2015
Business Acquisition [Line Items]
Cash paid to, or on behalf of, ITS and its equity holders	$ 10,448
Business Combination, Contingent Consideration, Liability, Current					$ 8,000
Business Combination, Provisional Information, Initial Accounting Incomplete, Adjustment, Consideration Transferred	$ 17,200
Goodwill (Note 3)		$ 4,000	$ 2,000	$ 2,000	$ 6,755

Goodwill and Intangible Asset28

Goodwill and Intangible Assets Goodwill and Intangible Assets - USD ($) $ in Thousands	3 Months Ended
	Jun. 30, 2016	Dec. 31, 2015	Apr. 17, 2015	Apr. 22, 2013
Finite-Lived Intangible Assets [Line Items]
Goodwill (Note 3)	$ 6,708	$ 6,708
Goodwill, Acquired During Period	$ 0
April 17, 2015 Acquisition [Member]
Finite-Lived Intangible Assets [Line Items]
Acquired Finite-lived Intangible Asset, Residual Value			$ 13,500
ITS [Member]
Finite-Lived Intangible Assets [Line Items]
Acquired Finite-lived Intangible Asset, Residual Value				$ 8,500

Goodwill and Intangible Asset29

Goodwill and Intangible Assets Goodwill (Details) - USD ($)	3 Months Ended
	Jun. 30, 2016	Dec. 31, 2015
Goodwill [Line Items]
Business Acquisition, Goodwill, Expected Tax Deductible Amount	$ 0
Goodwill (Note 3)	6,708,000	$ 6,708,000
Goodwill, Acquired During Period	$ 0

Goodwill and Intangible Asset30

Goodwill and Intangible Assets Intangible Assets (Details) - USD ($) $ in Thousands	6 Months Ended	12 Months Ended
	Jun. 30, 2016	Dec. 31, 2015
Acquired Finite-Lived Intangible Assets [Line Items]
Indefinite-lived Intangible Assets, Written off Related to Sale of Business Unit		$ 600
Amortization of Intangible Assets	$ (596)
Intangible Assets, Gross (Excluding Goodwill)	21,970
Finite-Lived Intangible Assets, Accumulated Amortization	(9,982)
Finite-Lived Intangible Assets, Net	$ 11,392
Developed Technology Rights [Member]
Acquired Finite-Lived Intangible Assets [Line Items]
Finite-Lived Intangible Asset, Useful Life	6 years
Amortization of Intangible Assets	$ 0
Intangible Assets, Gross (Excluding Goodwill)	11,630
Finite-Lived Intangible Assets, Accumulated Amortization	(2,423)
Finite-Lived Intangible Assets, Net	$ 9,207
Customer Relationships [Member]
Acquired Finite-Lived Intangible Assets [Line Items]
Finite-Lived Intangible Asset, Useful Life	3 years
Amortization of Intangible Assets	$ (264)
Intangible Assets, Gross (Excluding Goodwill)	5,400
Finite-Lived Intangible Assets, Accumulated Amortization	(5,136)
Finite-Lived Intangible Assets, Net	$ 0
Trademarks and Trade Names [Member]
Acquired Finite-Lived Intangible Assets [Line Items]
Finite-Lived Intangible Asset, Useful Life	5 years
Amortization of Intangible Assets	$ (332)
Intangible Assets, Gross (Excluding Goodwill)	4,940
Finite-Lived Intangible Assets, Accumulated Amortization	(2,423)
Finite-Lived Intangible Assets, Net	$ 2,185

Goodwill and Intangible Asset31

Goodwill and Intangible Assets Expected Future Intangibles Amortization Expense (Details) - USD ($) $ in Thousands	3 Months Ended		12 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Dec. 31, 2015
Finite-Lived Intangible Assets [Line Items]
Indefinite-lived Intangible Assets, Written off Related to Sale of Business Unit			$ 600
Amortization of Intangible Assets	$ 2,000	$ 1,800
Finite-Lived Intangible Assets, Amortization Expense, Remainder of Fiscal Year	1
Finite-Lived Intangible Assets, Amortization Expense, Year Three	2
Finite-Lived Intangible Assets, Amortization Expense, Year Four	2
Finite-Lived Intangible Assets, Amortization Expense, Year Five	2
Finite-Lived Intangible Assets, Amortization Expense, Year Two	3
Finite-Lived Intangible Assets, Amortization Expense, after Year Five	$ 0

Earnings Per Share (EPS) - Summ

Earnings Per Share (EPS) - Summary of Earnings Per Share (EPS) (Detail) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Earnings Per Share [Abstract]
Net Income (Loss) Attributable to Parent	$ (39,822)	$ (14,029)	$ (135,657)	$ (10,807)
Basic	124,101,349	122,481,425	123,595,793	122,175,511
Basic loss per share	$ (0.32)	$ (0.11)	$ (1.10)	$ (0.09)
Diluted	124,101,349	122,481,425	123,595,793	122,175,511
Diluted loss per share	$ (0.32)	$ (0.11)	$ (1.10)	$ (0.09)
Stock Options And Restricted Stock	0	0	0	0
Stock Options and Restricted Stock, Price per Share	$ 0	$ 0	$ 0	$ 0

Accumulated Other Comprehensi33

Accumulated Other Comprehensive Income (Details) - USD ($) $ in Thousands	3 Months Ended	6 Months Ended
	Jun. 30, 2016	Jun. 30, 2016
Equity [Abstract]
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax	$ 0	$ 1,900
Accumulated Other Comprehensive Income Reclassifications [Roll Forward]
Beginning balance		(1,888)
Current period other comprehensive loss	(3,571)
Ending balance	$ (5,459)	$ (5,459)

Reportable Segments - Additiona

Reportable Segments - Additional Information (Detail) - Exxon Neftegas Limited [Member]	6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015
Segment Information [Line Items]
Percentage of revenue from major customer	39.80%	26.00%
International & Alaska Drilling [Member]
Segment Information [Line Items]
Percentage of revenue from major customer	58.40%	44.30%

Reportable Segments - Results o

Reportable Segments - Results of Operations by Reportable Segment (Detail) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Revenues:
Revenues	$ 105,287	$ 185,941	$ 235,790	$ 390,017
Operating gross margin:
Total operating gross margin	(20,225)	4,021	(33,653)	28,288
General and administration expense	(7,995)	(9,511)	(17,776)	(20,348)
Provision for reduction in carrying value of certain assets	0	(2,316)	0	(2,316)
Gain (loss) on disposition of assets, net	(2)	(138)	(62)	2,303
Total operating income (loss)	(28,222)	(7,944)	(51,491)	7,927
Interest expense	(12,187)	(11,396)	(23,749)	(22,474)
Interest income	32	19	39	202
Other	(358)	(1,529)	2,127	(2,909)
Loss before income taxes	(40,735)	(20,850)	(73,074)	(17,254)
Rental Tools [Member]
Revenues:
Revenues	32,296	64,124	72,095	140,182
Operating gross margin:
Total operating gross margin	(14,410)	4,729	(24,356)	17,354
U.S. (Lower 48) Drilling [Member]
Revenues:
Revenues	1,065	6,848	3,150	20,945
Operating gross margin:
Total operating gross margin	(9,011)	(7,552)	(17,571)	(13,274)
International & Alaska Drilling [Member]
Revenues:
Revenues	71,926	114,969	160,545	228,890
Operating gross margin:
Total operating gross margin	3,196	6,844	8,274	24,208
Drilling Services [Member]
Revenues:
Revenues	72,991	121,817	163,695	249,835
Operating gross margin:
Total operating gross margin	$ (5,815)	$ (708)	$ (9,297)	$ 10,934
Exxon Neftegas Limited [Member]
Segment Reporting Information [Line Items]
Concentration Risk, Other Risk			0.287	0.181
Percentage of revenue from major customer			39.80%	26.00%
Reimbursement Revenue			$ 36,900	$ 39,700
Exxon Neftegas Limited [Member] | International & Alaska Drilling [Member]
Segment Reporting Information [Line Items]
Concentration Risk, Other Risk			0.464	0.34
Percentage of revenue from major customer			58.40%	44.30%
BP Exploration Alaska, Inc. [Member]
Segment Reporting Information [Line Items]
Percentage of revenue from major customer			11.90%
BP Exploration Alaska, Inc. [Member] | International & Alaska Drilling [Member]
Segment Reporting Information [Line Items]
Percentage of revenue from major customer			17.20%

Accounting for Uncertainty in36

Accounting for Uncertainty in Income Taxes - Additional Information (Detail) - USD ($) $ in Millions	6 Months Ended	12 Months Ended
	Jun. 30, 2016	Dec. 31, 2015
Income Tax Disclosure [Abstract]
Liability for unrecognized tax	$ 5.7	$ 7.8
Unrecognized tax favorable impact on effective tax rate		3.6
Accrued interest and penalties applied to uncertain tax positions	$ 1.6	$ 3.4

Income Tax Benefit_Expense - Ad

Income Tax Benefit/Expense - Additional Information (Detail) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Income Tax Disclosure [Abstract]
Income tax expense (benefit)	$ (913)	$ (6,916)	$ 62,583	$ (7,098)

Long-Term Debt - Summary of Com

Long-Term Debt - Summary of Company's Current Debt Portfolio (Detail) - USD ($) $ in Thousands	Jun. 30, 2016	Dec. 31, 2015
Debt Instrument [Line Items]
Long-term Debt	$ 585,000	$ 585,000
Deferred Finance Costs, Gross	(9,452)	(10,202)
Long-term Debt, Excluding Current Maturities	575,548	574,798
6.75% Senior Notes, due July 2022 [Member]
Debt Instrument [Line Items]
Long-term Debt	360,000	360,000
7.50% Senior Notes, due August 2020 [Member]
Debt Instrument [Line Items]
Long-term Debt	$ 225,000	$ 225,000

Long-Term Debt - Additional Inf

Long-Term Debt - Additional Information (Detail) - USD ($)	Jan. 22, 2014	Jul. 30, 2013	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015	May 27, 2016	Dec. 31, 2015	Jan. 26, 2015	Apr. 18, 2013
Debt Instrument [Line Items]
Debt issuance costs			$ 2,200,000
Write off of Deferred Debt Issuance Cost			1,100,000
Payments of Debt Issuance Costs					$ 0	$ 1,359,000
Repayments of long term debt						30,000,000
Interest Expense			12,187,000	$ 11,396,000	23,749,000	$ 22,474,000
Long-term Debt			585,000,000		585,000,000			$ 585,000,000
2015 Secured Credit Agreement [Member]
Debt Instrument [Line Items]
Debt issuance costs					1,400,000
Senior secured credit facility							$ 100,000,000		$ 200,000,000
Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Letters of credit outstanding			11,800,000		11,800,000
2012 Secured Credit Agreement [Member]
Debt Instrument [Line Items]
Debt issuance costs			300,000
6.75% Senior Notes, due July 2022 [Member]
Debt Instrument [Line Items]
Aggregate principal amount	$ 360,000,000
Percentage of notes guaranteed by restricted subsidiaries	6.75%
Redemption amount percentage of principal		35.00%
Debt instrument, Redemption Price Percent		106.75%
Redemption price after year three	103.375%
Redemption price afer year five	101.00%
Debt issuance costs					7,600,000
Debt issuance cost, Net of amortization					5,900,000
Long-term Debt			$ 360,000,000		$ 360,000,000			360,000,000
9.125% Senior Notes, due April 2018 [Member]
Debt Instrument [Line Items]
Percentage of notes guaranteed by restricted subsidiaries			9.125%		9.125%
Repayments of long term debt	$ 416,200,000
Term Loan [Member]
Debt Instrument [Line Items]
Increase in the amount of term loan or revolving credit facility		$ 45,000,000
Revolving loan outstanding	$ 40,000,000
Line of Credit, Current									$ 30,000,000
7.50% Senior Notes, due August 2020 [Member]
Debt Instrument [Line Items]
Aggregate principal amount		$ 225,000,000
Percentage of notes guaranteed by restricted subsidiaries		7.50%
Deferred acquisition costs		$ 5,600,000	$ 3,600,000		$ 3,600,000
Redemption amount percentage of principal		35.00%
Debt instrument, Redemption Price Percent		107.50%
Redemption price after year three		103.75%
Redemption price afer year five		101.00%
Long-term Debt			$ 225,000,000		$ 225,000,000			$ 225,000,000
Secured Debt [Member] | Term Loan [Member]
Debt Instrument [Line Items]
Aggregate principal amount										$ 125,000,000

Fair Value of Financial Instr40

Fair Value of Financial Instruments - Fair Values and Related Carrying Values of Debt Instruments (Detail) - USD ($) $ in Thousands	Jun. 30, 2016	Dec. 31, 2015
Carrying Amount [Member]
Long-term Debt
Long term debt Fair value	$ 585,000	$ 585,000
Carrying Amount [Member] | 6.75% Senior Notes, due July 2022 [Member]
Long-term Debt
Long term debt Fair value	360,000	360,000
Carrying Amount [Member] | 7.50% Senior Notes, due August 2020 [Member]
Long-term Debt
Long term debt Fair value	225,000	225,000
Fair Value [Member]
Long-term Debt
Long term debt Fair value	443,025	417,600
Fair Value [Member] | 6.75% Senior Notes, due July 2022 [Member]
Long-term Debt
Long term debt Fair value	270,900	246,600
Fair Value [Member] | 7.50% Senior Notes, due August 2020 [Member]
Long-term Debt
Long term debt Fair value	$ 172,125	$ 171,000

Contingencies - Additional Info

Contingencies - Additional Information (Detail) $ in Thousands	Jun. 30, 2016USD ($)
Commitment And Contingencies [Line Items]
Fine paid by for retention and use of individual agent in Nigeria with respect to customs-related issues	$ 11,760

Recent Accounting Pronounceme42

Recent Accounting Pronouncements Recent Accounting Pronouncements (Details) - USD ($) $ in Thousands	Jun. 30, 2016	Dec. 31, 2015
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Long-term Debt	$ 585,000	$ 585,000
Deferred Finance Costs, Gross	$ (9,452)	$ (10,202)

Parent, Guarantor, Non-Guaran43

Parent, Guarantor, Non-Guarantor Unaudited Consolidating Condensed Financial Statements - Additional Information (Detail)	6 Months Ended
	Jun. 30, 2016	Jul. 30, 2013
Supplemental Guarantor Financial Information [Line Items]
Percentage of guaranteed subsidiaries by the parent companies	100.00%
9.125% Senior Notes, due April 2018 [Member]
Supplemental Guarantor Financial Information [Line Items]
Percentage of notes guaranteed by restricted subsidiaries	9.125%
7.50% Senior Notes, due August 2020 [Member]
Supplemental Guarantor Financial Information [Line Items]
Percentage of notes guaranteed by restricted subsidiaries		7.50%

Parent, Guarantor, Non-Guaran44

Parent, Guarantor, Non-Guarantor Unaudited Consolidating Condensed Financial Statements - Consolidating Condensed Balance Sheet (Detail) - USD ($) $ in Thousands	Jun. 30, 2016	Dec. 31, 2015	Jun. 30, 2015	Mar. 31, 2015	Dec. 31, 2014
Current assets:
Cash and cash equivalents	$ 109,034	$ 134,294	$ 116,943	$ 116,943	$ 108,456
Accounts and notes receivable, net	153,189	175,105
Rig materials and supplies	32,615	34,937
Other current assets	26,805	22,405
Total current assets	321,643	366,741
Property, plant and equipment, net	747,017	805,841
Goodwill (Note 3)	6,708	6,708
Intangible assets, net (Note 3)	11,392	13,377
Investment in subsidiaries and intercompany advances	0	0
Other Assets, Miscellaneous, Noncurrent	126,011
Deferred Income Taxes and Other Assets, Noncurrent		174,035
Total assets	1,212,771	1,366,702
Current liabilities:
Long-term deferred tax liability	76,475	68,654
Total liabilities	781,940	798,190
Total equity	430,831	568,512
Total liabilities and stockholders’ equity	1,212,771	1,366,702
Accounts payable and accrued liabilities	109,091	129,703
Accrued income taxes	5,777	6,418
Intercompany Payables	0	0
Liabilities, Current	114,868	136,121
Long-term Debt, Excluding Current Maturities	575,548	574,798
Other long-term liabilities	15,049	18,617
Common stock	20,766	20,518
Capital in excess of par value	670,419	669,120
Accumulated deficit	(254,895)	(119,238)
Accumulated other comprehensive loss	(5,459)	(1,888)
Stockholders' Equity Attributable to Parent	430,831	568,512
Parent [Member]
Current assets:
Cash and cash equivalents	55,280	73,985		42,153	36,728
Accounts and notes receivable, net	0	0
Rig materials and supplies	0	0
Other current assets	0	0
Total current assets	55,280	73,985
Property, plant and equipment, net	(19)	(19)
Goodwill (Note 3)	0	0
Intangible assets, net (Note 3)	0	0
Investment in subsidiaries and intercompany advances	3,032,953	3,057,220
Other Assets, Miscellaneous, Noncurrent	(151,632)
Deferred Income Taxes and Other Assets, Noncurrent		(234,786)
Total assets	2,936,582	2,896,400
Current liabilities:
Long-term deferred tax liability	(29)	(29)
Total liabilities	2,503,253	2,328,961
Total equity	433,329	567,439
Total liabilities and stockholders’ equity	2,936,582	2,896,400
Accounts payable and accrued liabilities	114,217	84,456
Accrued income taxes	30,910	9,900
Intercompany Payables	1,779,740	1,656,968
Liabilities, Current	145,127	94,356
Long-term Debt, Excluding Current Maturities	575,548	574,798
Other long-term liabilities	2,867	2,868
Guarantor [Member]
Current assets:
Cash and cash equivalents	12,192	13,854		20,496	13,546
Accounts and notes receivable, net	34,853	42,261
Rig materials and supplies	(6,009)	(4,744)
Other current assets	8,601	5,982
Total current assets	49,637	57,353
Property, plant and equipment, net	502,191	543,346
Goodwill (Note 3)	6,708	6,708
Intangible assets, net (Note 3)	10,587	11,740
Investment in subsidiaries and intercompany advances	2,889,755	2,770,501
Other Assets, Miscellaneous, Noncurrent	207,566
Deferred Income Taxes and Other Assets, Noncurrent		312,790
Total assets	3,666,444	3,702,438
Current liabilities:
Long-term deferred tax liability	77,394	69,679
Total liabilities	1,531,947	1,537,128
Total equity	2,134,497	2,165,310
Total liabilities and stockholders’ equity	3,666,444	3,702,438
Accounts payable and accrued liabilities	44,382	56,382
Accrued income taxes	(15,019)	2,111
Intercompany Payables	1,417,482	1,401,510
Liabilities, Current	29,363	58,493
Long-term Debt, Excluding Current Maturities	0	0
Other long-term liabilities	7,708	7,446
Non-Guarantor [Member]
Current assets:
Cash and cash equivalents	41,562	46,455		54,294	58,182
Accounts and notes receivable, net	118,336	132,844
Rig materials and supplies	38,624	39,681
Other current assets	18,204	16,423
Total current assets	216,726	235,403
Property, plant and equipment, net	244,845	262,514
Goodwill (Note 3)	0	0
Intangible assets, net (Note 3)	805	1,637
Investment in subsidiaries and intercompany advances	3,498,240	3,319,702
Other Assets, Miscellaneous, Noncurrent	550,882
Deferred Income Taxes and Other Assets, Noncurrent		265,995
Total assets	4,511,498	4,085,251
Current liabilities:
Long-term deferred tax liability	(890)	(996)
Total liabilities	2,579,488	2,161,824
Total equity	1,932,010	1,923,427
Total liabilities and stockholders’ equity	4,511,498	4,085,251
Accounts payable and accrued liabilities	567,968	295,439
Accrued income taxes	(10,114)	(5,593)
Intercompany Payables	2,018,050	1,864,671
Liabilities, Current	557,854	289,846
Long-term Debt, Excluding Current Maturities	0	0
Other long-term liabilities	4,474	8,303
Consolidation, Eliminations [Member]
Current assets:
Cash and cash equivalents	0	0		$ 0	$ 0
Accounts and notes receivable, net	0	0
Rig materials and supplies	0	0
Other current assets	0	0
Total current assets	0	0
Property, plant and equipment, net	0	0
Goodwill (Note 3)	0	0
Intangible assets, net (Note 3)	0	0
Investment in subsidiaries and intercompany advances	(9,420,948)	(9,147,423)
Other Assets, Miscellaneous, Noncurrent	(480,805)
Deferred Income Taxes and Other Assets, Noncurrent		(169,964)
Total assets	(9,901,753)	(9,317,387)
Current liabilities:
Long-term deferred tax liability	0	0
Total liabilities	(5,832,748)	(5,229,723)
Total equity	(4,069,005)	(4,087,664)
Total liabilities and stockholders’ equity	(9,901,753)	(9,317,387)
Accounts payable and accrued liabilities	(617,476)	(306,574)
Accrued income taxes	0	0
Intercompany Payables	(5,215,272)	(4,923,149)
Liabilities, Current	(617,476)	(306,574)
Long-term Debt, Excluding Current Maturities	0	0
Other long-term liabilities	$ 0	$ 0

Parent, Guarantor, Non-Guaran45

Parent, Guarantor, Non-Guarantor Unaudited Consolidating Condensed Financial Statements - Consolidating Condensed Statement of Operations (Detail) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Condensed Financial Statements [Line Items]
Total revenues	$ 105,287	$ 185,941	$ 235,790	$ 390,017
Operating expenses	89,195	143,569	197,312	282,839
Depreciation and amortization	36,317	38,351	72,131	78,890
Total operating gross margin	(20,225)	4,021	(33,653)	28,288
General and administration expense	(7,995)	(9,511)	(17,776)	(20,348)
Gain (loss) on disposition of assets, net	(2)	(138)	(62)	2,303
Total operating income (loss)	(28,222)	(7,944)	(51,491)	7,927
Other income and (expense):
Interest expense	(12,187)	(11,396)	(23,749)	(22,474)
Interest income	32	19	39	202
Other	(358)	(1,529)	2,127	(2,909)
Equity in net earnings of subsidiaries	0	0	0	0
Total other expense	(12,513)	(12,906)	(21,583)	(25,181)
Loss before income taxes	(40,735)	(20,850)	(73,074)	(17,254)
Income tax expense (benefit)	(913)	(6,916)	62,583	(7,098)
Deferred Income Tax Expense (Benefit)			(59,305)	17,126
Net loss	(39,822)	(13,934)	(135,657)	(10,156)
Net Income (Loss) Attributable to Noncontrolling Interest	0	95	0	651
Net loss attributable to controlling interest	(39,822)	(14,029)	(135,657)	(10,807)
Loss on debt modification			(1,088)	0
Provision for reduction in carrying value of certain assets	0	(2,316)	0	(2,316)
Parent [Member]
Condensed Financial Statements [Line Items]
Total revenues	0	0	0	0
Operating expenses	0	0	0	0
Depreciation and amortization	0	0	0	0
Total operating gross margin	0	0	0	0
General and administration expense	(113)	(891)	(200)	(1,004)
Gain (loss) on disposition of assets, net	0	0	0	0
Total operating income (loss)	(113)	(891)	(200)	(1,004)
Other income and (expense):
Interest expense	(12,896)	(11,066)	(24,752)	(22,125)
Interest income	191	165	395	583
Other	0	0	0	0
Equity in net earnings of subsidiaries	(24,568)	(8,392)	(40,793)	597
Total other expense	(37,273)	(19,293)	(65,150)	(20,945)
Loss before income taxes	(37,386)	(20,184)	(65,350)	(21,949)
Income tax expense (benefit)	2,438	(6,155)	70,307	(11,142)
Deferred Income Tax Expense (Benefit)			49,167	(22,414)
Net loss	(39,824)	(14,029)	(135,657)	(10,807)
Net Income (Loss) Attributable to Noncontrolling Interest		0		0
Net loss attributable to controlling interest	(39,824)	(14,029)	(135,657)	(10,807)
Loss on debt modification			1,088
Provision for reduction in carrying value of certain assets				0
Guarantor [Member]
Condensed Financial Statements [Line Items]
Total revenues	34,586	63,276	81,968	142,672
Operating expenses	25,577	35,627	58,413	79,772
Depreciation and amortization	23,314	23,958	46,439	47,268
Total operating gross margin	(14,305)	3,691	(22,884)	15,632
General and administration expense	(7,828)	(12,924)	(17,440)	(23,039)
Gain (loss) on disposition of assets, net	209	(6)	153	45
Total operating income (loss)	(21,924)	(9,239)	(40,171)	(7,362)
Other income and (expense):
Interest expense	(44)	(323)	(481)	(340)
Interest income	180	3	359	5
Other	(11)	11	473	20
Equity in net earnings of subsidiaries	0	0	0	0
Total other expense	125	(309)	351	(315)
Loss before income taxes	(21,799)	(9,548)	(39,820)	(7,677)
Income tax expense (benefit)	(5,297)	(2,361)	(9,004)	(2,809)
Deferred Income Tax Expense (Benefit)			9,569	6,574
Net loss	(16,502)	(7,187)	(30,816)	(4,868)
Net Income (Loss) Attributable to Noncontrolling Interest		0		0
Net loss attributable to controlling interest	(16,502)	(7,187)	(30,816)	(4,868)
Loss on debt modification			0
Provision for reduction in carrying value of certain assets				0
Non-Guarantor [Member]
Condensed Financial Statements [Line Items]
Total revenues	88,895	162,703	195,372	313,633
Operating expenses	81,812	147,980	180,449	269,355
Depreciation and amortization	13,003	14,393	25,692	31,622
Total operating gross margin	(5,920)	330	(10,769)	12,656
General and administration expense	(54)	4,304	(136)	3,695
Gain (loss) on disposition of assets, net	(211)	(132)	(215)	2,258
Total operating income (loss)	(6,185)	2,186	(11,120)	16,293
Other income and (expense):
Interest expense	(2,290)	(3,010)	(5,150)	(3,338)
Interest income	2,704	2,854	5,919	2,943
Other	(347)	(1,540)	1,654	(2,929)
Equity in net earnings of subsidiaries	0	0	0	0
Total other expense	67	(1,696)	2,423	(3,324)
Loss before income taxes	(6,118)	490	(8,697)	12,969
Income tax expense (benefit)	1,946	1,600	1,280	6,853
Deferred Income Tax Expense (Benefit)			569	(1,286)
Net loss	(8,064)	(1,110)	(9,977)	6,116
Net Income (Loss) Attributable to Noncontrolling Interest		95		651
Net loss attributable to controlling interest	(8,064)	(1,205)	(9,977)	5,465
Loss on debt modification			0
Provision for reduction in carrying value of certain assets		(2,316)		2,316
Consolidation, Eliminations [Member]
Condensed Financial Statements [Line Items]
Total revenues	(18,194)	(40,038)	(41,550)	(66,288)
Operating expenses	(18,194)	(40,038)	(41,550)	(66,288)
Depreciation and amortization	0	0	0	0
Total operating gross margin	0	0	0	0
General and administration expense	0	0	0	0
Gain (loss) on disposition of assets, net	0	0	0	0
Total operating income (loss)	0	0	0	0
Other income and (expense):
Interest expense	3,043	3,003	6,634	3,329
Interest income	(3,043)	(3,003)	(6,634)	(3,329)
Other	0	0	0	0
Equity in net earnings of subsidiaries	24,568	8,392	40,793	(597)
Total other expense	24,568	8,392	40,793	(597)
Loss before income taxes	24,568	8,392	40,793	(597)
Income tax expense (benefit)	0	0	0	0
Deferred Income Tax Expense (Benefit)			0	0
Net loss	24,568	8,392	40,793	(597)
Net Income (Loss) Attributable to Noncontrolling Interest		0		0
Net loss attributable to controlling interest	$ 24,568	$ 8,392	40,793	(597)
Loss on debt modification			$ 0
Provision for reduction in carrying value of certain assets				$ 0

Parent, Guarantor, Non-Guaran46

Parent, Guarantor, Non-Guarantor Unaudited Consolidating Condensed Financial Statements Parent, Guarantor, Non-Guarantor Unaudited Consolidating Condensed Financial Statements - Statement of Comprehensive Income (Loss) (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Schedule of Condensed Statement of Comprehensive Income [Line Items]
Net loss	$ (39,822)	$ (13,934)	$ (135,657)	$ (10,156)
Currency translation difference on related borrowings	(307)	647	195	(1,023)
Currency translation difference on foreign currency net investments	(2,228)	1,723	(3,766)	874
Total other comprehensive income (loss), net of tax:	(2,535)	2,370	(3,571)	(149)
Comprehensive Income (Loss), Net of Tax, Attributable to Parent	(42,357)	(11,659)	(139,228)	(10,794)
Comprehensive loss attributable to noncontrolling interest	0	(95)	0	(489)
Comprehensive loss	(42,357)	(11,564)	(139,228)	(10,305)
Parent [Member]
Schedule of Condensed Statement of Comprehensive Income [Line Items]
Net loss	(39,824)	(14,029)	(135,657)	(10,807)
Currency translation difference on related borrowings	0	0	0	0
Currency translation difference on foreign currency net investments	0	0	0	0
Total other comprehensive income (loss), net of tax:	0	0	0	0
Comprehensive Income (Loss), Net of Tax, Attributable to Parent	(39,824)	(14,029)	(135,657)	(10,807)
Comprehensive loss attributable to noncontrolling interest		0		0
Comprehensive loss		(14,029)		(10,807)
Guarantor [Member]
Schedule of Condensed Statement of Comprehensive Income [Line Items]
Net loss	(16,502)	(7,187)	(30,816)	(4,868)
Currency translation difference on related borrowings	0	0	0	0
Currency translation difference on foreign currency net investments	0	0	0	0
Total other comprehensive income (loss), net of tax:	0	0	0	0
Comprehensive Income (Loss), Net of Tax, Attributable to Parent	(16,502)	(7,187)	(30,816)	(4,868)
Comprehensive loss attributable to noncontrolling interest		0		0
Comprehensive loss		(7,187)		(4,868)
Non-Guarantor [Member]
Schedule of Condensed Statement of Comprehensive Income [Line Items]
Net loss	(8,064)	(1,110)	(9,977)	6,116
Currency translation difference on related borrowings	(307)	647	195	(1,023)
Currency translation difference on foreign currency net investments	(2,228)	1,723	(3,766)	874
Total other comprehensive income (loss), net of tax:	(2,535)	2,370	(3,571)	(149)
Comprehensive Income (Loss), Net of Tax, Attributable to Parent	(10,599)	1,165	(13,548)	5,478
Comprehensive loss attributable to noncontrolling interest		(95)		(489)
Comprehensive loss		1,260		5,967
Consolidation, Eliminations [Member]
Schedule of Condensed Statement of Comprehensive Income [Line Items]
Net loss	24,568	8,392	40,793	(597)
Currency translation difference on related borrowings	0	0	0	0
Currency translation difference on foreign currency net investments	0	0	0	0
Total other comprehensive income (loss), net of tax:	0	0	0	0
Comprehensive Income (Loss), Net of Tax, Attributable to Parent	$ 24,568	8,392	$ 40,793	(597)
Comprehensive loss attributable to noncontrolling interest		0		0
Comprehensive loss		$ 8,392		$ (597)

Parent, Guarantor, Non-Guaran47

Parent, Guarantor, Non-Guarantor Unaudited Consolidating Condensed Financial Statements - Consolidated Condensed Statements of Cash Flows (Detail) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Cash flows from operating activities:
Net loss	$ (39,822)	$ (13,934)	$ (135,657)	$ (10,156)
Adjustments to reconcile net income (loss)
Depreciation and amortization	36,317	38,351	72,131	78,890
Accretion of contingent consideration			419	306
(Gain) loss on disposition of assets	2	138	62	(2,303)
Deferred income tax expense (benefit)			59,305	(17,126)
Expenses not requiring cash			(5,226)	(5,308)
Equity in net earnings of subsidiaries	0	0	0	0
Accounts and notes receivable			22,319	39,683
Accrued income taxes			(3,985)	(1,236)
Other assets			(2,992)	(7,352)
Accounts payable and accrued liabilities			(6,862)	14,763
Net cash provided by operating activities			602	103,093
Cash flows from investing activities:
Capital expenditures			(16,257)	(54,605)
Proceeds from the sale of assets			1,387	288
Proceeds from insurance settlements			0	2,500
Payments to Acquire Businesses, Net of Cash Acquired			0	10,431
Net cash used in investing activities			(14,870)	(62,248)
Cash flows from financing activities:
Repayments of long-term debt				(30,000)
Paydown on term note			0	(30,000)
Payment of debt issuance costs			0	(1,359)
Payment for noncontrolling interest			3,375	0
Payments of contingent consideration			(6,000)	0
Excess tax benefit from stock-based compensation			(1,617)	(999)
Intercompany advances, net			0	0
Net cash used in financing activities			(10,992)	(32,358)
Net increase (decrease) in cash and cash equivalents			(25,260)	8,487
Cash and cash equivalents, beginning of year		116,943	134,294	108,456
Cash and cash equivalents, end of period	109,034	116,943	109,034	116,943
Provision for reduction in carrying value of certain assets	0	2,316	0	2,316
Loss on debt modification			(1,088)	0
Parent [Member]
Cash flows from operating activities:
Net loss	(39,824)	(14,029)	(135,657)	(10,807)
Adjustments to reconcile net income (loss)
Depreciation and amortization	0	0	0	0
Accretion of contingent consideration			0	0
(Gain) loss on disposition of assets	0	0	0	0
Deferred income tax expense (benefit)			(49,167)	22,414
Expenses not requiring cash			(2,693)	(4,039)
Equity in net earnings of subsidiaries	24,568	8,392	40,793	(597)
Accounts and notes receivable			0	0
Accrued income taxes			21,711	2,146
Other assets			(103,035)	(77,427)
Accounts payable and accrued liabilities			3,281	29
Net cash provided by operating activities			(119,959)	(105,031)
Cash flows from investing activities:
Capital expenditures			0	0
Proceeds from the sale of assets			0	0
Proceeds from insurance settlements				0
Payments to Acquire Businesses, Net of Cash Acquired				0
Net cash used in investing activities			0	0
Cash flows from financing activities:
Repayments of long-term debt				(30,000)
Payment of debt issuance costs				(1,359)
Payment for noncontrolling interest			3,375
Payments of contingent consideration			0
Excess tax benefit from stock-based compensation			(1,617)	(999)
Intercompany advances, net			106,246	142,814
Net cash used in financing activities			101,254	110,456
Net increase (decrease) in cash and cash equivalents			(18,705)	5,425
Cash and cash equivalents, beginning of year		42,153	73,985	36,728
Cash and cash equivalents, end of period	55,280		55,280
Provision for reduction in carrying value of certain assets				0
Loss on debt modification			1,088
Guarantor [Member]
Cash flows from operating activities:
Net loss	(16,502)	(7,187)	(30,816)	(4,868)
Adjustments to reconcile net income (loss)
Depreciation and amortization	23,314	23,958	46,439	47,268
Accretion of contingent consideration			419	0
(Gain) loss on disposition of assets	(209)	6	(153)	(45)
Deferred income tax expense (benefit)			(9,569)	(6,574)
Expenses not requiring cash			282	(441)
Equity in net earnings of subsidiaries	0	0	0	0
Accounts and notes receivable			7,755	27,778
Accrued income taxes			(17,830)	229
Other assets			102,496	59,964
Accounts payable and accrued liabilities			(5,737)	14,890
Net cash provided by operating activities			111,860	152,231
Cash flows from investing activities:
Capital expenditures			(7,499)	(37,794)
Proceeds from the sale of assets			121	82
Proceeds from insurance settlements				0
Payments to Acquire Businesses, Net of Cash Acquired				10,431
Net cash used in investing activities			(7,378)	(48,143)
Cash flows from financing activities:
Repayments of long-term debt				0
Payment of debt issuance costs				0
Payment for noncontrolling interest			0
Payments of contingent consideration			(6,000)
Excess tax benefit from stock-based compensation			0	0
Intercompany advances, net			(100,144)	(97,138)
Net cash used in financing activities			(106,144)	(97,138)
Net increase (decrease) in cash and cash equivalents			(1,662)	6,950
Cash and cash equivalents, beginning of year		20,496	13,854	13,546
Cash and cash equivalents, end of period	12,192		12,192
Provision for reduction in carrying value of certain assets				0
Loss on debt modification			0
Non-Guarantor [Member]
Cash flows from operating activities:
Net loss	(8,064)	(1,110)	(9,977)	6,116
Adjustments to reconcile net income (loss)
Depreciation and amortization	13,003	14,393	25,692	31,622
Accretion of contingent consideration			0	306
(Gain) loss on disposition of assets	211	132	215	(2,258)
Deferred income tax expense (benefit)			(569)	1,286
Expenses not requiring cash			7,637	(828)
Equity in net earnings of subsidiaries	0	0	0	0
Accounts and notes receivable			14,564	11,905
Accrued income taxes			(7,866)	(3,611)
Other assets			(2,453)	10,111
Accounts payable and accrued liabilities			(4,406)	(156)
Net cash provided by operating activities			8,701	55,893
Cash flows from investing activities:
Capital expenditures			(8,758)	(16,811)
Proceeds from the sale of assets			1,266	206
Proceeds from insurance settlements				2,500
Payments to Acquire Businesses, Net of Cash Acquired				0
Net cash used in investing activities			(7,492)	(14,105)
Cash flows from financing activities:
Repayments of long-term debt				0
Payment of debt issuance costs				0
Payment for noncontrolling interest			0
Payments of contingent consideration			0
Excess tax benefit from stock-based compensation			0	0
Intercompany advances, net			(6,102)	(45,676)
Net cash used in financing activities			(6,102)	(45,676)
Net increase (decrease) in cash and cash equivalents			(4,893)	(3,888)
Cash and cash equivalents, beginning of year		54,294	46,455	58,182
Cash and cash equivalents, end of period	41,562		41,562
Provision for reduction in carrying value of certain assets		2,316		(2,316)
Loss on debt modification			0
Consolidation, Eliminations [Member]
Cash flows from operating activities:
Net loss	24,568	8,392	40,793	(597)
Adjustments to reconcile net income (loss)
Depreciation and amortization	0	0	0	0
Accretion of contingent consideration			0	0
(Gain) loss on disposition of assets	0	0	0	0
Deferred income tax expense (benefit)			0	0
Expenses not requiring cash			0	0
Equity in net earnings of subsidiaries	(24,568)	(8,392)	(40,793)	597
Accounts and notes receivable			0	0
Accrued income taxes			0	0
Other assets			0	0
Accounts payable and accrued liabilities			0	0
Net cash provided by operating activities			0	0
Cash flows from investing activities:
Capital expenditures			0	0
Proceeds from the sale of assets			0	0
Proceeds from insurance settlements				0
Payments to Acquire Businesses, Net of Cash Acquired				0
Net cash used in investing activities			0	0
Cash flows from financing activities:
Repayments of long-term debt				0
Payment of debt issuance costs				0
Payment for noncontrolling interest			0
Payments of contingent consideration			0
Excess tax benefit from stock-based compensation			0	0
Intercompany advances, net			0	0
Net cash used in financing activities			0	0
Net increase (decrease) in cash and cash equivalents			0	0
Cash and cash equivalents, beginning of year		$ 0	0	0
Cash and cash equivalents, end of period	$ 0		0
Provision for reduction in carrying value of certain assets				$ 0
Loss on debt modification			$ 0