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Section 1: 10-Q (10-Q)

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UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
WASHINGTON, D.C. 20549
FORM 10-Q
 
(Mark One)
x
QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15 (d) OF THE SECURITIES EXCHANGE ACT OF 1934
For The Quarterly Period Ended September 30, 2016
OR
¨
TRANSITION REPORT PURSUANT TO SECTION 13 OR 15 (d) OF THE SECURITIES EXCHANGE ACT OF 1934
For the transition period from                      to                         
Commission File Number 1-7573 
PARKER DRILLING COMPANY
(Exact name of registrant as specified in its charter)
Delaware
 
73-0618660
(State or other jurisdiction of
incorporation or organization)
 
(I.R.S. Employer
Identification No.)
 
 
 
5 Greenway Plaza, Suite 100,
Houston, Texas
 
77046
(Address of principal executive offices)
 
(Zip code)
(281) 406-2000
(Registrant’s telephone number, including area code) 
Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.    Yes  x    No  ¨
Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files.    Yes  x    No  ¨
Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, or a smaller reporting company. See the definitions of “large accelerated filer,” “accelerated filer” and “smaller reporting company” in Rule 12b-2 of the Exchange Act. (Check one):
Large accelerated filer
 
¨
  
Accelerated filer
 
x
 
 
 
 
Non-accelerated filer
 
¨ (Do not check if a smaller reporting company)
  
Smaller reporting company
 
¨
Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).    Yes  ¨    No  x
As of October 27, 2016 there were 125,055,485 common shares outstanding.    




TABLE OF CONTENTS
 
 
Page
 
 
 
 


2



PART I. FINANCIAL INFORMATION
Item 1. Financial Statements
PARKER DRILLING COMPANY AND SUBSIDIARIES
CONSOLIDATED CONDENSED BALANCE SHEETS
(Dollars in Thousands) 
 
September 30,
2016
 
December 31,
2015
 
(Unaudited)
 
 
ASSETS
Current assets:
 
 
 
Cash and cash equivalents
$
103,613

 
$
134,294

Accounts and Notes Receivable, net of allowance for bad debts of $7,388 at September 30, 2016 and $8,694 at December 31, 2015.
130,616

 
175,105

Rig materials and supplies
32,681

 
34,937

Other current assets
22,514

 
22,405

Total current assets
289,424

 
366,741

Property, plant and equipment, net of accumulated depreciation of $1,374,409 at September 30, 2016 and $1,302,380 at December 31, 2015.
718,254

 
805,841

Goodwill
6,708

 
6,708

Intangible assets, net
10,660

 
13,377

Deferred income taxes
87,653

 
139,282

Other noncurrent assets
37,183

 
34,753

Total assets
$
1,149,882

 
$
1,366,702

LIABILITIES AND STOCKHOLDERS’ EQUITY
Current liabilities:
 
 
 
Accounts payable and accrued liabilities
86,107

 
129,703

Accrued income taxes
7,186

 
6,418

Total current liabilities
93,293

 
136,121

Long-term debt, net of unamortized debt issuance costs of $9,065 at September 30, 2016 and $10,202 at December 31, 2015.
575,935

 
574,798

Other long-term liabilities
16,161

 
18,617

Deferred tax liability
78,893

 
68,654

Commitments and contingencies (Note 11)
 
 
 
Stockholders’ equity:
 
 
 
Common stock
20,829

 
20,518

Capital in excess of par value
671,977

 
669,120

Accumulated deficit
(301,123
)
 
(119,238
)
Accumulated other comprehensive income (loss)
(6,083
)
 
(1,888
)
Total stockholders’ equity
385,600

 
568,512

Total liabilities and stockholders’ equity
$
1,149,882

 
$
1,366,702

See accompanying notes to the unaudited consolidated condensed financial statements.

3



PARKER DRILLING COMPANY AND SUBSIDIARIES
CONSOLIDATED CONDENSED STATEMENTS OF OPERATIONS
(Dollars in Thousands, Except Per Share Data)
(Unaudited)
 
 
Three Months Ended September 30,
 
Nine Months Ended September 30,
 
2016
 
2015
 
2016
 
2015
Revenues
$
97,189

 
$
173,418

 
$
332,979

 
$
563,435

Expenses:
 
 
 
 
 
 
 
Operating expenses
84,680

 
128,963

 
281,992

 
411,802

Depreciation and amortization
34,474

 
39,584

 
106,605

 
118,474

 
119,154

 
168,547

 
388,597

 
530,276

Total operating gross margin (loss)
(21,965
)
 
4,871

 
(55,618
)
 
33,159

General and administration expense
(7,424
)
 
(8,895
)
 
(25,200
)
 
(29,243
)
Provision for reduction in carrying value of certain assets

 
(906
)
 

 
(3,222
)
Gain (loss) on disposition of assets, net
(187
)
 
383

 
(249
)
 
2,686

Total operating income (loss)
(29,576
)
 
(4,547
)
 
(81,067
)
 
3,380

Other income (expense):
 
 
 
 
 
 
 
Interest expense
(11,015
)
 
(11,293
)
 
(34,764
)
 
(33,767
)
Interest income
9

 
7

 
48

 
209

Other
(351
)
 
(719
)
 
1,776

 
(3,628
)
Total other income (expense)
(11,357
)
 
(12,005
)
 
(32,940
)
 
(37,186
)
Income (loss) before income taxes
(40,933
)
 
(16,552
)
 
(114,007
)
 
(33,806
)
Income tax expense (benefit)
5,295

 
31,930

 
67,878

 
24,832

Net income (loss)
(46,228
)
 
(48,482
)
 
(181,885
)
 
(58,638
)
Less: Net income (loss) attributable to noncontrolling interest

 
138

 

 
789

Net income (loss) attributable to controlling interest
$
(46,228
)
 
$
(48,620
)
 
$
(181,885
)
 
$
(59,427
)
Basic income (loss) per share
$
(0.37
)
 
$
(0.40
)
 
$
(1.47
)
 
$
(0.49
)
Diluted income (loss) per share
$
(0.37
)
 
$
(0.40
)
 
$
(1.47
)
 
$
(0.49
)
 
 
 
 
 
 
 
 
Number of common shares used in computing earnings per share:
 
 
 
 
 
 
 
Basic
124,486,848

 
122,933,518

 
123,894,980

 
122,430,957

Diluted
124,486,848

 
122,933,518

 
123,894,980

 
122,430,957


See accompanying notes to the unaudited consolidated condensed financial statements.


4



PARKER DRILLING COMPANY AND SUBSIDIARIES
CONSOLIDATED CONDENSED STATEMENTS OF COMPREHENSIVE INCOME (LOSS)
(Dollars in Thousands)
(Unaudited)
 
 
Three Months Ended September 30,
 
Nine Months Ended September 30,
 
2016
 
2015
 
2016
 
2015
Comprehensive income (loss):
 
 
 
 
 
 
 
Net income (loss)
$
(46,228
)
 
$
(48,482
)
 
$
(181,885
)
 
$
(58,638
)
Other comprehensive income (loss), net of tax:
 
 
 
 
 
 
 
Currency translation difference on related borrowings
116

 
(1,285
)
 
311

 
(2,308
)
Currency translation difference on foreign currency net investments
(740
)
 
588

 
(4,506
)
 
1,462

Total other comprehensive income (loss), net of tax:
(624
)
 
(697
)
 
(4,195
)
 
(846
)
Comprehensive income (loss)
(46,852
)
 
(49,179
)
 
(186,080
)
 
(59,484
)
Comprehensive income (loss) attributable to noncontrolling interest

 
(82
)
 

 
(571
)
Comprehensive income (loss) attributable to controlling interest
$
(46,852
)
 
$
(49,261
)
 
$
(186,080
)
 
$
(60,055
)

See accompanying notes to the unaudited consolidated condensed financial statements.


5



PARKER DRILLING COMPANY AND SUBSIDIARIES
CONSOLIDATED CONDENSED STATEMENTS OF CASH FLOWS
(Dollars in Thousands)
(Unaudited)

 
Nine Months Ended September 30,
 
2016
 
2015
Cash flows from operating activities:
 
 
 
Net income (loss)
$
(181,885
)
 
$
(58,638
)
Adjustments to reconcile net income to net cash flows from operating activities:
 
 
 
Depreciation and amortization
106,605

 
118,474

Accretion of contingent consideration
419

 
547

(Gain) loss on debt modification
1,088

 

Provision for reduction in carrying value of certain assets

 
3,222

(Gain) loss on disposition of assets
249

 
(2,686
)
Deferred income tax expense (benefit)
61,199

 
10,259

Expenses not requiring cash
(4,031
)
 
8,029

Change in assets and liabilities:
 
 
 
Accounts and notes receivable
44,799

 
51,254

Other assets
3,282

 
1,486

Accounts payable and accrued liabilities
(30,590
)
 
(15,790
)
Accrued income taxes
(1,992
)
 
(7,305
)
Net cash provided by (used in) operating activities
(857
)
 
108,852

 
 
 
 
Cash flows from investing activities:
 
 
 
Capital expenditures
(20,994
)
 
(72,469
)
Proceeds from the sale of assets
2,296

 
731

Proceeds from insurance settlements

 
2,500

Acquisition, net of cash acquired

 
(10,431
)
Net cash provided by (used in) investing activities
(18,698
)
 
(79,669
)
 
 
 
 
Cash flows from financing activities:
 
 
 
Repayments of long-term debt

 
(30,000
)
Payments of debt issuance costs

 
(1,996
)
Payment for noncontrolling interest
(3,375
)
 

Payments of contingent consideration
(6,000
)
 

Excess tax (expense) from stock based compensation
(1,751
)
 
(992
)
Net cash provided by (used in) financing activities
(11,126
)
 
(32,988
)
 
 
 
 
Net increase (decrease) in cash and cash equivalents
(30,681
)
 
(3,805
)
Cash and cash equivalents, beginning of year
134,294

 
108,456

Cash and cash equivalents, end of period
$
103,613

 
$
104,651

 
 
 
 
Supplemental cash flow information:
 
 
 
Interest paid
$
41,175

 
$
41,393

Income taxes paid
$
12,142

 
$
21,627


See accompanying notes to the unaudited consolidated condensed financial statements.


6



PARKER DRILLING COMPANY AND SUBSIDIARIES
NOTES TO THE UNAUDITED CONSOLIDATED CONDENSED FINANCIAL STATEMENTS
Note 1 - General
The Consolidated Condensed Financial Statements as of September 30, 2016 and for the three and nine months ended September 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 Drilling Services business as two reportable segments: (1) U.S. (Lower 48) Drilling and (2) International & Alaska Drilling. Effective July 1, 2016, we report our Rental Tools Services business as two reportable segments: (1) U.S. Rental Tools and (2) International Rental Tools. We have revised our business segment reporting to reflect our current management approach and recast prior periods to conform to the current business segment presentation.
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 our 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.

7



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 $19.4 million and $20.8 million for the three months ended September 30, 2016 and 2015, respectively, and $55.8 million and $68.4 million for the nine months ended September 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 and dental plans, income taxes and related tax 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 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

8



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 39.6 percent of our consolidated revenues for the nine months ended September 30, 2016. Excluding reimbursable revenues of $54.3 million, ENL constituted approximately 28.0 percent of our total consolidated revenues for the nine months ended September 30, 2016. Our second largest customer, BP Exploration Alaska, Inc. (BP), constituted approximately 11.9 percent of our consolidated revenues for the nine months ended September 30, 2016.
At September 30, 2016 and December 31, 2015, we had deposits in domestic banks in excess of federally insured limits of approximately $69.2 million and $91.3 million, respectively. In addition, we had uninsured deposits in foreign banks as of September 30, 2016 and December 31, 2015 of $34.8 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.
Note 2 - 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.
Note 3 - 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 International Rental Tools segment.

9



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. We perform our annual impairment review during the fourth quarter, as of October 1.
The change in the carrying amount of goodwill for the period ended September 30, 2016 is as follows:
Dollars in thousands
Goodwill
Balance at December 31, 2015
$
6,708

Additions

Balance at September 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 September 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

 
$

 
$
(2,908
)
 
$
8,722

Customer relationships
3
5,400

 
(264
)
 
(5,136
)
 

Trade names
5
4,940

 
(332
)
 
(2,670
)
 
1,938

Total amortized intangible assets
 
$
21,970

 
$
(596
)
 
$
(10,714
)
 
$
10,660

(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 $2.7 million and $3.1 million for the nine months ended September 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
$
732

2017
$
2,801

2018
$
2,306

2019
$
2,306

2020
$
2,030

Beyond 2020
$
485


10



Note 4 - Earnings (Loss) Per Share (EPS)  
 
Three Months Ended September 30, 2016
 
Income/(Loss)
(Numerator)
 
Shares
(Denominator)
 
Per-Share
Amount
Basic EPS
$
(46,228,000
)
 
124,486,848

 
$
(0.37
)
Effect of dilutive securities:
 
 
 
 
 
Restricted stock units

 

 

Diluted EPS
$
(46,228,000
)
 
124,486,848

 
$
(0.37
)
 
 
 
 
 
 
 
Nine Months Ended September 30, 2016
 
Income/(Loss)
(Numerator)
 
Shares
(Denominator)
 
Per-Share
Amount
Basic EPS
$
(181,885,000
)
 
123,894,980

 
$
(1.47
)
Effect of dilutive securities:
 
 
 
 
 
Restricted stock units

 

 

Diluted EPS
$
(181,885,000
)
 
123,894,980

 
$
(1.47
)
 
 
 
 
 
 
 
Three Months Ended September 30, 2015
 
Income/(Loss)
(Numerator)
 
Shares
(Denominator)
 
Per-Share
Amount
Basic EPS
$
(48,620,000
)
 
122,933,518

 
$
(0.40
)
Effect of dilutive securities:
 
 
 
 
 
Restricted stock units

 

 

Diluted EPS
$
(48,620,000
)
 
122,933,518

 
$
(0.40
)
 
 
 
 
 
 
 
Nine Months Ended September 30, 2015
 
Income/(Loss)
(Numerator)
 
Shares
(Denominator)
 
Per-Share
Amount
Basic EPS
$
(59,427,000
)
 
122,430,957

 
$
(0.49
)
Effect of dilutive securities:
 
 
 
 
 
Restricted stock units

 

 

Diluted EPS
$
(59,427,000
)
 
122,430,957

 
$
(0.49
)
 
 
 
 
 
 
For the three and nine months ended September 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 nine month periods, therefore, inclusion of such potential common shares in the calculation would be anti-dilutive.

11



Note 5 - Accumulated Other Comprehensive Income (Loss)
Accumulated other comprehensive loss consisted of the following:
Dollars in thousands
Foreign Currency Items
December 31, 2015
$
(1,888
)
Current period other comprehensive income (loss)
(4,195
)
September 30, 2016
$
(6,083
)
There were no amounts reclassified out of accumulated other comprehensive loss for the three months ended September 30, 2016. Amounts reclassified out of accumulated other comprehensive loss were $1.9 million for the nine months ended September 30, 2016 and represent realized foreign currency translation gains.
Note 6 - Reportable Segments
Our business is comprised of two business lines: (1) Drilling Services and (2) Rental Tools Services. We report our Drilling Services business as two reportable segments: (1) U.S. (Lower 48) Drilling and (2) International & Alaska Drilling. Effective July 1, 2016, we report our Rental Tools Services business as two reportable segments: (1) U.S. Rental Tools and (2) International Rental Tools. We have revised our business segment reporting to reflect our current management approach and recast prior periods to conform to the current business segment presentation.
Within the four reportable segments, we have aggregated our Arctic, Eastern Hemisphere and Latin America business units under International & Alaska Drilling, one business unit under U.S. (Lower 48) Drilling, one business unit under U.S. Rental Tools and one business unit under International Rental Tools, for a total of six business units. The Company has aggregated each of its business units in one of the four reporting segments based on the guidelines of the Financial Accounting Standards Board (FASB) Accounting Standards Codification Topic No. 280, Segment Reporting (ASC 280). We eliminate inter-segment revenues and expenses. We disclose revenues under the four reportable segments based on the similarity of the use and markets for the groups of products and services within each segment.
Drilling Services Business
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 our 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;

12



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.
Rental Tools Services Business
In our Rental Tools Services business, our U.S. Rental Tools and International Rental Tools segments provide 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 
 September 30,
 
Nine Months Ended 
 September 30,
Dollars in thousands
2016
 
2015
 
2016
 
2015
Revenues: (1)
 
 
 
 
 
 
 
Drilling Services:
 
 
 
 
 
 
 
U.S. (Lower 48) Drilling
$
1,431

 
$
5,961

 
$
4,581

 
$
26,906

International & Alaska Drilling
65,307

 
110,661

 
225,854

 
339,551

Total Drilling Services
66,738

 
116,622

 
230,435

 
366,457

Rental Tools Services:
 
 
 
 
 
 
 
U.S. Rental Tools
14,967

 
31,905

 
55,483

 
113,155

International Rental Tools
15,484

 
24,891

 
47,061

 
83,823

Total Rental Tools Services
30,451

 
56,796

 
102,544

 
196,978

Total revenues
97,189

 
173,418

 
332,979

 
563,435

Operating gross margin: (2)
 
 
 
 
 
 
 
Drilling Services:
 
 
 
 
 
 
 
U.S. (Lower 48) Drilling
(8,686
)
 
(7,397
)
 
(26,257
)
 
(20,673
)
International & Alaska Drilling
71

 
13,212

 
8,347

 
37,428

Total Drilling Services
(8,615
)
 
5,815

 
(17,910
)
 
16,755

Rental Tools Services:
 
 
 
 
 
 
 
U.S. Rental Tools
(6,645
)
 
2,976

 
(16,069
)
 
16,033

International Rental Tools
(6,705
)
 
(3,920
)
 
(21,639
)
 
371

Total Rental Tools Services
(13,350
)

(944
)
 
(37,708
)
 
16,404

Total operating gross margin
(21,965
)
 
4,871

 
(55,618
)
 
33,159

General and administrative expense
(7,424
)
 
(8,895
)
 
(25,200
)
 
(29,243
)
Provision for reduction in carrying value of certain assets

 
(906
)
 

 
(3,222
)
Gain (loss) on disposition of assets, net
(187
)
 
383

 
(249
)
 
2,686

Total operating income (loss)
(29,576
)
 
(4,547
)
 
(81,067
)
 
3,380

Interest expense
(11,015
)
 
(11,293
)
 
(34,764
)
 
(33,767
)
Interest income
9

 
7

 
48

 
209

Other income (loss)
(351
)
 
(719
)
 
1,776

 
(3,628
)
Loss from continuing operations before income taxes
$
(40,933
)
 
$
(16,552
)
 
$
(114,007
)
 
$
(33,806
)
 

13



(1)For the nine months ended September 30, 2016, our largest customer, ENL, constituted approximately 39.6 percent of our total consolidated revenues and approximately 58.4 percent of our International & Alaska Drilling segment revenues. Excluding reimbursable revenues of $54.3 million, ENL constituted approximately 28.0 percent of our total consolidated revenues and approximately 45.6 percent of our International & Alaska Drilling segment revenues. Our second largest customer, BP, constituted 11.9 percent of our total consolidated revenues and approximately 17.3 percent of our International & Alaska Drilling segment revenues.
For the nine months ended September 30, 2015, our largest customer, ENL, constituted approximately 27.0 percent of our total consolidated revenues and approximately 44.7 percent of our International & Alaska Drilling segment revenues. Excluding reimbursable revenues of $58.1 million, ENL constituted approximately 19.1 percent of our total consolidated revenues and approximately 34.7 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.
Note 7 - 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 September 30, 2016, we had a liability for unrecognized tax benefits of $6.0 million, primarily related to foreign operations, all of which would favorably impact our effective tax rate upon recognition. 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 September 30, 2016 and December 31, 2015, we had approximately $1.8 million and $3.4 million, respectively, of accrued interest and penalties related to uncertain tax positions.
Note 8 - Income Tax Expense (Benefit)
During the third quarter of 2016, we had income tax expense of $5.3 million compared with income tax expense of $31.9 million during the third quarter of 2015. Despite the pre-tax loss for the third quarter of 2016, we recognized income tax expense due 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. During the 2015 third quarter, we recognized income tax expense as a result of recording a valuation allowance of $36.6 million primarily on U.S. foreign tax credits and certain foreign net operating losses.
Note 9 - Long-Term Debt
The following table illustrates our debt portfolio as of September 30, 2016 and December 31, 2015:
Dollars in thousands
September 30,
2016
 
December 31,
2015
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
(9,065
)
 
(10,202
)
Total long-term debt
$
575,935

 
$
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-

14



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 ($5.7 million net of amortization as of September 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. To date we have not made any redemptions. 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 ($3.4 million, net of amortization as of September 30, 2016) are being amortized over the term of the notes using the effective interest rate method.
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) eliminated 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;

15



(b) eliminated 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 increased 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 decreased 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 September 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 September 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 September 30, 2016 totaled $9.6 million. There were no amounts drawn on the Revolver as of September 30, 2016.    
Note 10 - 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.

16



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: 
  
September 30, 2016
 
December 31, 2015
Dollars in thousands
Carrying Amount
 
Fair Value
 
Carrying Amount
 
Fair Value
Long-term debt
 
 
 
 
 
 
 
6.75% Notes
$
360,000

 
$
280,800

 
$
360,000

 
$
246,600

7.50% Notes
225,000

 
179,438

 
225,000

 
171,000

Total principal
$
585,000

 
$
460,238

 
$
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 nine months ended September 30, 2016.  
Note 11 - Commitments and 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.

17



Note 12 - Recent Accounting Pronouncements    
In August 2016, the FASB issued Accounting Standards Update (ASU) No. 2016-15, Statement of Cash Flows (Topic 230): Classification of Certain Cash Receipts and Cash Payments. The ASU is intended to reduce diversity in current practice regarding the manner in which certain cash receipts and cash payments are presented and classified in the cash flow statement. The standard becomes effective for public companies for fiscal years beginning after December 15, 2017, including interim periods within those fiscal years. Early adoption is permitted. We have assessed the impact of the adoption of ASU 2016-15 on our statement of cash flows, and we do not believe it will have a material impact.
In March 2016, the FASB issued 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 have assessed the impact of the adoption of ASU 2016-09 on our financial position, results of operations and cash flows, and we do not believe it will have a material impact.
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.    

18



Note 13 - 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 September 30, 2016 and December 31, 2015 and for the three and nine months ended September 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 of FASB Accounting Standards Codification Topic No. 810, Consolidation (ASC 810), we have retrospectively updated the unaudited consolidating condensed financial information as of December 31, 2015 and September 30, 2015.

19



  
PARKER DRILLING COMPANY AND SUBSIDIARIES
CONSOLIDATING CONDENSED BALANCE SHEET
(Dollars in Thousands)
(Unaudited)
 
 
September 30, 2016
 
Parent
 
Guarantor
 
Non-Guarantor
 
Eliminations
 
Consolidated
ASSETS
Current assets:
 
 
 
 
 
 
 
 
 
Cash and cash equivalents
$
54,042

 
$
13,684

 
$
35,887

 
$

 
$
103,613

Accounts and notes receivable, net

 
15,637

 
114,979

 

 
130,616

Rig materials and supplies

 
(6,210
)
 
38,891

 

 
32,681

Other current assets

 
7,142

 
15,372

 

 
22,514

Total current assets
54,042

 
30,253

 
205,129

 

 
289,424

Property, plant and equipment, net
(19
)
 
483,513

 
234,760

 

 
718,254

Goodwill

 
6,708

 

 

 
6,708

Intangible assets, net

 
10,010

 
650

 

 
10,660

Investment in subsidiaries and intercompany advances
3,016,378

 
2,917,336

 
3,605,766

 
(9,539,480
)
 

Other noncurrent assets
(137,690
)
 
191,518

 
551,820

 
(480,812
)
 
124,836

Total assets
$
2,932,711

 
$
3,639,338

 
$
4,598,125

 
$
(10,020,292
)
 
$
1,149,882

 
 
 
 
 
 
 
 
 
 
LIABILITIES AND STOCKHOLDERS’ EQUITY
Current liabilities:
 
 
 
 
 
 
 
 
 
Accounts payable and accrued liabilities
$
103,855

 
$
33,848

 
$
565,881

 
$
(617,477
)
 
$
86,107

Accrued income taxes
43,043

 
(24,909
)
 
(10,948
)
 

 
7,186

Total current liabilities
146,898

 
8,939

 
554,933

 
(617,477
)
 
93,293

Long-term debt, net
575,935

 

 

 

 
575,935

Other long-term liabilities
2,867

 
8,418

 
4,876

 

 
16,161

Deferred tax liability
(29
)
 
80,545

 
(1,623
)
 

 
78,893

Intercompany payables
1,818,320

 
1,425,349

 
2,112,278

 
(5,355,947
)
 

Total liabilities
2,543,991

 
1,523,251

 
2,670,464

 
(5,973,424
)
 
764,282

Total equity
388,720

 
2,116,087

 
1,927,661

 
(4,046,868
)
 
385,600

Total liabilities and stockholders’ equity
$
2,932,711

 
$
3,639,338

 
$
4,598,125

 
$
(10,020,292
)
 
$
1,149,882


20




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

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



21




PARKER DRILLING COMPANY AND SUBSIDIARIES
CONSOLIDATING CONDENSED STATEMENT OF OPERATIONS
(Dollars in Thousands)
(Unaudited)

 
Three Months Ended September 30, 2016
 
Parent
 
Guarantor
 
Non-Guarantor
 
Eliminations
 
Consolidated
Total revenues
$

 
$
25,399

 
$
96,663

 
$
(24,873
)
 
$
97,189

Operating expenses

 
25,505

 
84,048

 
(24,873
)
 
84,680

Depreciation and amortization

 
22,300

 
12,174

 

 
34,474

Total operating gross margin (loss)

 
(22,406
)
 
441

 

 
(21,965
)
General and administration expense (1)
(92
)
 
(2,759
)
 
(4,573
)
 

 
(7,424
)
Provision for reduction in carrying value of certain assets

 

 

 

 

Gain (loss) on disposition of assets, net

 
(12
)
 
(175
)
 

 
(187
)
Total operating income (loss)
(92
)
 
(25,177
)
 
(4,307
)
 

 
(29,576
)
Other income (expense):
 
 
 
 
 
 
 
 
 
Interest expense
(11,700
)
 
(56
)
 
504

 
237

 
(11,015
)
Interest income
189

 
157

 
(100
)
 
(237
)
 
9

Other

 
15

 
(366
)
 

 
(351
)
Equity in net earnings of subsidiaries
(24,887
)
 

 

 
24,887

 

Total other income (expense)
(36,398
)
 
116

 
38

 
24,887

 
(11,357
)
Income (loss) before income taxes
(36,490
)
 
(25,061
)
 
(4,269
)
 
24,887

 
(40,933
)
Total income tax expense (benefit)
9,738

 
(6,652
)
 
2,209

 

 
5,295

Net income (loss) attributable to controlling interest
$
(46,228
)
 
$
(18,409
)
 
$
(6,478
)
 
$
24,887

 
$
(46,228
)

(1) General and administration expenses for field operations are included in operating expenses.

22




PARKER DRILLING COMPANY AND SUBSIDIARIES
CONSOLIDATING CONDENSED STATEMENT OF OPERATIONS
(Dollars in Thousands)
(Unaudited)
 
Three Months Ended September 30, 2015
 
Parent
 
Guarantor
 
Non-Guarantor
 
Eliminations
 
Consolidated
Total revenues
$

 
$
59,252

 
$
138,564

 
$
(24,398
)
 
$
173,418

Operating expenses

 
32,457

 
120,904

 
(24,398
)
 
128,963

Depreciation and amortization

 
24,002

 
15,582

 

 
39,584

Total operating gross margin (loss)

 
2,793

 
2,078

 

 
4,871

General and administration expense (1)
(148
)
 
(8,857
)
 
110

 

 
(8,895
)
Provision for reduction in carrying value of certain assets

 
(920
)
 
14

 

 
(906
)
Gain (loss) on disposition of assets, net

 
407

 
(24
)
 

 
383

Total operating income (loss)
(148
)
 
(6,577
)
 
2,178

 

 
(4,547
)
Other income (expense):
 
 
 
 
 
 
 
 
 
Interest expense
(11,020
)
 
(268
)
 
(2,618
)
 
2,613

 
(11,293
)
Interest income
173

 
(18
)
 
2,465

 
(2,613
)
 
7

Other

 
(102
)
 
(617
)
 

 
(719
)
Equity in net earnings of subsidiaries
(29,913
)
 

 

 
29,913

 

Total other income (expense)
(40,760
)
 
(388
)
 
(770
)
 
29,913

 
(12,005
)
Income (loss) before income taxes
(40,908
)
 
(6,965
)
 
1,408

 
29,913

 
(16,552
)
Income tax expense (benefit)
7,712

 
(2,846
)
 
27,064

 

 
31,930

Net income (loss)
(48,620
)
 
(4,119
)
 
(25,656
)
 
29,913

 
(48,482
)
Less: Net income (loss) attributable to noncontrolling interest

 

 
138

 

 
138

Net income (loss) attributable to controlling interest
$
(48,620
)
 
$
(4,119
)
 
$
(25,794
)
 
$
29,913

 
$
(48,620
)

(1) General and administration expenses for field operations are included in operating expenses.
























23





PARKER DRILLING COMPANY AND SUBSIDIARIES
CONSOLIDATING CONDENSED STATEMENT OF OPERATIONS
(Dollars in Thousands)
(Unaudited)

 
Nine Months Ended September 30, 2016
 
Parent
 
Guarantor
 
Non-Guarantor
 
Eliminations
 
Consolidated
Total revenues
$

 
$
107,368

 
$
292,034

 
$
(66,423
)
 
$
332,979

Operating expenses

 
83,917

 
264,498

 
(66,423
)
 
281,992

Depreciation and amortization

 
68,739

 
37,866

 

 
106,605

Total operating gross margin (loss)

 
(45,288
)
 
(10,330
)
 

 
(55,618
)
General and administration expense (1)
(291
)
 
(20,199
)
 
(4,710
)
 

 
(25,200
)
Gain (loss) on disposition of assets, net

 
141

 
(390
)
 

 
(249
)
Total operating income (loss)
(291
)
 
(65,346
)
 
(15,430
)
 

 
(81,067
)
Other income (expense):
 
 
 
 
 
 
 
 
 
Interest expense
(36,452
)
 
(537
)
 
(4,646
)
 
6,871

 
(34,764
)
Interest income
584

 
515

 
5,820

 
(6,871
)
 
48

Other

 
488

 
1,288

 

 
1,776

Equity in net earnings of subsidiaries
(65,679
)
 

 

 
65,679

 

Total other income (expense)
(101,547
)
 
466

 
2,462

 
65,679

 
(32,940
)
Income (loss) before income taxes
(101,838
)
 
(64,880
)
 
(12,968
)
 
65,679

 
(114,007
)
Total income tax expense (benefit)
80,047

 
(15,656
)
 
3,487

 

 
67,878

Net income (loss) attributable to controlling interest
$
(181,885
)
 
$
(49,224
)
 
$
(16,455
)
 
$
65,679

 
$
(181,885
)

(1) General and administration expenses for field operations are included in operating expenses.


























24



PARKER DRILLING COMPANY AND SUBSIDIARIES
CONSOLIDATING CONDENSED STATEMENT OF OPERATIONS
(Dollars in Thousands)
(Unaudited)

 
Nine Months Ended September 30, 2015
 
Parent
 
Guarantor
 
Non-Guarantor
 
Eliminations
 
Consolidated
Total revenues
$

 
$
201,924

 
$
452,197

 
$
(90,686
)
 
$
563,435

Operating expenses

 
112,229

 
390,259

 
(90,686
)
 
411,802

Depreciation and amortization

 
71,270

 
47,204

 

 
118,474

Total operating gross margin (loss)

 
18,425

 
14,734

 

 
33,159

General and administration expense (1)
(1,152
)
 
(31,896
)
 
3,805

 

 
(29,243
)
Provision for reduction in carrying value of certain assets

 
(920
)
 
(2,302
)
 

 
(3,222
)
Gain on disposition of assets, net

 
452

 
2,234

 

 
2,686

Total operating income (loss)
(1,152
)
 
(13,939
)
 
18,471

 

 
3,380

Other income (expense):
 
 
 
 
 
 
 
 
 
Interest expense
(33,145
)
 
(608
)
 
(5,956
)
 
5,942

 
(33,767
)
Interest income
756

 
(12
)
 
5,407

 
(5,942
)
 
209

Other

 
(81
)
 
(3,547
)
 

 
(3,628
)
Equity in net earnings of subsidiaries
(29,316
)
 

 

 
29,316

 

Total other income (expense)
(61,705
)
 
(701
)
 
(4,096
)
 
29,316

 
(37,186
)
Income (loss) before income taxes
(62,857
)
 
(14,640
)
 
14,375

 
29,316

 
(33,806
)
Total income tax expense (benefit)
(3,430
)
 
(5,656
)
 
33,918

 

 
24,832

Net income (loss)
(59,427
)
 
(8,984
)
 
(19,543
)
 
29,316

 
(58,638
)
Less: Net income (loss) attributable to noncontrolling interest

 

 
789

 

 
789

Net income (loss) attributable to controlling interest
$
(59,427
)
 
$
(8,984
)
 
$
(20,332
)
 
$
29,316

 
$
(59,427
)

(1) General and administration expenses for field operations are included in operating expenses.


25




PARKER DRILLING COMPANY AND SUBSIDIARIES
CONSOLIDATING CONDENSED STATEMENT OF COMPREHENSIVE INCOME (LOSS)
(Dollars in Thousands)
(Unaudited)

 
Three Months Ended September 30, 2016
 
Parent
 
Guarantor
 
Non-Guarantor
 
Eliminations
 
Consolidated
Comprehensive income (loss):
 
 
 
 
 
 
 
 
 
Net income (loss)
$
(46,228
)
 
$
(18,409
)
 
$
(6,478
)
 
$
24,887

 
$
(46,228
)
Other comprehensive income (loss), net of tax:
 
 
 
 
 
 
 
 
 
Currency translation difference on related borrowings

 

 
116

 

 
116

Currency translation difference on foreign currency net investments

 

 
(740
)
 

 
(740
)
Total other comprehensive income (loss), net of tax:

 

 
(624
)
 

 
(624
)
Comprehensive income (loss) attributable to controlling interest
$
(46,228
)
 
$
(18,409
)
 
$
(7,102
)
 
$
24,887

 
$
(46,852
)



PARKER DRILLING COMPANY AND SUBSIDIARIES
CONSOLIDATING CONDENSED STATEMENT OF COMPREHENSIVE INCOME (LOSS)
(Dollars in Thousands)
(Unaudited)

 
Three Months Ended September 30, 2015
 
Parent
 
Guarantor
 
Non-Guarantor
 
Eliminations
 
Consolidated
Comprehensive income (loss):
 
 
 
 
 
 
 
 
 
Net income (loss)
$
(48,620
)
 
$
(4,119
)
 
$
(25,656
)
 
$
29,913

 
$
(48,482
)
Other comprehensive income (loss), net of tax: