PARKER DRILLING CO /DE/ - Quarter Report: 2018 June (Form 10-Q)

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 June 30, 2018



¨	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)

Securities registered pursuant to Section 12(b) of the Act:

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 every Interactive Data File required to be submitted 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 such files). Yes x No ¨

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, smaller reporting company, or an emerging growth company. See the definitions of “large accelerated filer,” “accelerated filer,” “smaller reporting company,” and “emerging growth company” in Rule 12b-2 of the Exchange Act. (Check one):



Large accelerated filer	¨	Accelerated filer	x

Non-accelerated filer	¨	Smaller reporting company	¨

		Emerging growth company	¨

If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. ¨

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). Yes ¨ No x

As of July 30, 2018 there were 9,317,754 common shares outstanding.

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TABLE OF CONTENTS



	Page
Part I. Financial Information
Item 1. Financial Statements	3
Consolidated Condensed Balance Sheets	3
Consolidated Condensed Statements of Operations	4
Consolidated Condensed Statements of Comprehensive Income (Loss)	5
Consolidated Condensed Statements of Cash Flows	6
Consolidated Condensed Statement of Stockholders’ Equity	7
Notes to the Unaudited Consolidated Condensed Financial Statements	8
Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations	34
Item 3. Quantitative and Qualitative Disclosures about Market Risk	50
Item 4. Controls and Procedures	50

Part II. Other Information
Item 1. Legal Proceedings	51
Item 1A. Risk Factors	51
Item 2. Unregistered Sales of Equity Securities and Use of Proceeds	53
Item 3. Defaults Upon Senior Securities	53
Item 4. Mine Safety Disclosures	53
Item 5. Other Information	53
Item 6. Exhibits	54
Signatures	56

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PART I. FINANCIAL INFORMATION

Item 1. Financial Statements



PARKER DRILLING COMPANY AND SUBSIDIARIES
CONSOLIDATED CONDENSED BALANCE SHEETS
(Dollars in Thousands)
(Unaudited)



	June 30, 2018			December 31, 2017
	(Unaudited)
ASSETS
Current assets:
Cash and cash equivalents	$	114,459		$	141,549
Accounts and notes receivable, net of allowance for bad debts of $7,549 at June 30, 2018 and $7,564 at December 31, 2017	122,673			122,511
Rig materials and supplies	31,921			31,415
Other current assets	23,640			22,361
Total current assets	292,693			317,836
Property, plant and equipment, net of accumulated depreciation of $1,340,963 at June 30, 2018 and $1,343,105 at December 31, 2017	602,069			625,771
Goodwill (Note 2)	6,708			6,708
Intangible assets, net (Note 2)	5,974			7,128
Deferred income taxes	2,161			1,284
Other noncurrent assets	27,614			31,552
Total assets	$	937,219		$	990,279
LIABILITIES AND STOCKHOLDERS' EQUITY
Current liabilities:
Accounts payable and accrued liabilities	$	102,797		$	99,246
Accrued income taxes	3,457			4,430
Total current liabilities	106,254			103,676
Long-term debt, net of unamortized debt issuance costs of $6,160 at June 30, 2018 and $7,029 at December 31, 2017 (Note 3)	578,840			577,971
Other long-term liabilities	10,335			12,433
Long-term deferred tax liability	60			78
Commitments and contingencies (Note 6)
Stockholders' equity:
Preferred stock, $1.00 par value, 1,942,000 shares authorized, 7.25% Series A Mandatory Convertible, 500,000 shares issued and outstanding	500			500
Common Stock, $0.16 ²/₃ par value, authorized 18,666,667 shares, issued and outstanding, 9,319,722 shares (9,262,382 shares in 2017) ⁽¹⁾	1,387			1,378
Capital in excess of par value ⁽¹⁾	766,328			766,508
Accumulated deficit	(520,426		)	(468,753		)
Accumulated other comprehensive income (loss)	(6,059		)	(3,512		)
Total stockholders' equity	241,730			296,121
Total liabilities and stockholders' equity	$	937,219		$	990,279


(1)	See Note 7 - Stockholders' Equity for details regarding the 1-for-15 reverse stock split.

See accompanying notes to the unaudited consolidated condensed financial statements.

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PARKER DRILLING COMPANY AND SUBSIDIARIES
CONSOLIDATED CONDENSED STATEMENTS OF OPERATIONS
(Dollars in Thousands, Except Per Share Data)
(Unaudited)



	Three Months Ended June 30,						Six Months Ended June 30,
	2018			2017			2018			2017
Revenues	$	118,603		$	109,607		$	228,278		$	207,878
Expenses:
Operating expenses	91,634			89,641			183,168			175,455
Depreciation and amortization	27,136			30,982			55,685			63,184
	118,770			120,623			238,853			238,639
Total operating gross margin (loss)	(167		)	(11,016		)	(10,575		)	(30,761		)
General and administrative expense	(8,288		)	(6,503		)	(14,489		)	(13,543		)
Gain (loss) on disposition of assets, net	(478		)	(113		)	(135		)	(465		)
Total operating income (loss)	(8,933		)	(17,632		)	(25,199		)	(44,769		)
Other income (expense):
Interest expense	(11,197		)	(11,095		)	(22,437		)	(21,965		)
Interest income	30			22			53			32
Other	(1,191		)	560			(900		)	1,090
Total other income (expense)	(12,358		)	(10,513		)	(23,284		)	(20,843		)
Income (loss) before income taxes	(21,291		)	(28,145		)	(48,483		)	(65,612		)
Income tax expense (benefit)	1,586			1,743			3,190			4,085
Net income (loss)	(22,877		)	(29,888		)	(51,673		)	(69,697		)
Less: Convertible preferred stock dividend	907			1,239			1,813			1,239
Net income (loss) available to common stockholders	$	(23,784	)	$	(31,127	)	$	(53,486	)	$	(70,936	)
Basic earnings (loss) per common share: ⁽¹⁾	$	(2.56	)	$	(3.39	)	$	(5.77	)	$	(7.94	)
Diluted earnings (loss) per common share: ⁽¹⁾	$	(2.56	)	$	(3.39	)	$	(5.77	)	$	(7.94	)
Number of common shares used in computing earnings per share:
Basic ⁽¹⁾	9,292,224			9,188,888			9,271,759			8,933,945
Diluted ⁽¹⁾	9,292,224			9,188,888			9,271,759			8,933,945


(1)	See Note 7 - Stockholders' Equity for details regarding the 1-for-15 reverse stock split.

See accompanying notes to the unaudited consolidated condensed financial statements.

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PARKER DRILLING COMPANY AND SUBSIDIARIES

CONSOLIDATED CONDENSED STATEMENTS OF COMPREHENSIVE INCOME (LOSS)

(Dollars in Thousands)

(Unaudited)



	Three Months Ended June 30,						Six Months Ended June 30,
	2018			2017			2018			2017
Comprehensive income (loss):
Net income (loss)	$	(22,877	)	$	(29,888	)	$	(51,673	)	$	(69,697	)
Other comprehensive income (loss), net of tax:
Currency translation difference on related borrowings	(445		)	185			(169		)	268
Currency translation difference on foreign currency net investments	(1,802		)	686			(2,378		)	1,449
Total other comprehensive income (loss), net of tax:	(2,247		)	871			(2,547		)	1,717
Comprehensive income (loss)	$	(25,124	)	$	(29,017	)	$	(54,220	)	$	(67,980	)

See accompanying notes to the unaudited consolidated condensed financial statements.

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



	Six Months Ended June 30,
	2018			2017
Cash flows from operating activities:
Net income (loss)	$	(51,673	)	$	(69,697	)
Adjustments to reconcile net income (loss):
Depreciation and amortization	55,685			63,184
(Gain) loss on disposition of assets, net	135			465
Deferred tax expense (benefit)	(896		)	(934		)
Expenses not requiring cash	4,030			4,948
Change in assets and liabilities:
Accounts and notes receivable	(392		)	(6,853		)
Other assets	8,112			(1,722		)
Accounts payable and accrued liabilities	(6,026		)	(8,235		)
Accrued income taxes	(944		)	1,276
Net cash provided by (used in) operating activities	8,031			(17,568		)

Cash flows from investing activities:
Capital expenditures	(32,549		)	(26,559		)
Proceeds from the sale of assets	851			185
Net cash provided by (used in) investing activities	(31,698		)	(26,374		)

Cash flows from financing activities:
Payments of debt issuance costs	(1,440		)	—
Convertible preferred stock dividend	(1,813		)	(1,239		)
Shares surrendered in lieu of tax	(170		)	(612		)
Proceeds from the issuance of common stock	—			25,200
Proceeds from the issuance of convertible preferred stock	—			50,000
Payment of equity issuance costs	—			(2,864		)
Net cash provided by (used in) financing activities	(3,423		)	70,485

Net increase (decrease) in cash and cash equivalents	(27,090		)	26,543
Cash and cash equivalents at beginning of period	141,549			119,691
Cash and cash equivalents at end of period	$	114,459		$	146,234

Supplemental cash flow information:
Interest paid	$	20,588		$	20,588
Income taxes paid	$	5,359		$	4,262

See accompanying notes to the unaudited consolidated condensed financial statements.

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PARKER DRILLING COMPANY AND SUBSIDIARIES

CONSOLIDATED CONDENSED STATEMENTS OF STOCKHOLDERS’ EQUITY

(Dollars and Shares in Thousands)

(Unaudited)



	Shares ⁽¹⁾	Convertible Preferred Stock		Common Stock ⁽¹⁾		Treasury Stock			Capital in Excess of Par Value ⁽¹⁾			Accumulated Deficit			Accumulated Other Comprehensive Income (Loss)			Total Stockholders’ Equity
Balances, December 31, 2017	9,762	$	500	$	1,548	$	(170	)	$	766,508		$	(468,753	)	$	(3,512	)	$	296,121
Activity in employees’ stock plans	58	—		9		—			(179		)	—			—			(170		)
Amortization of stock-based awards	—	—		—		—			1,812			—			—			1,812
Convertible preferred stock dividend	—	—		—		—			(1,813		)	—			—			(1,813		)
Comprehensive Income:
Net income (loss)	—	—		—		—			—			(51,673		)	—			(51,673		)
Other comprehensive income (loss)	—	—		—		—			—			—			(2,547		)	(2,547		)
Balances, June 30, 2018	9,820	$	500	$	1,557	$	(170	)	$	766,328		$	(520,426	)	$	(6,059	)	$	241,730


(1)	See Note 7 - Stockholders' Equity for details regarding the 1-for-15 reverse stock split.

See accompanying notes to the unaudited consolidated condensed financial statements.

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PARKER DRILLING COMPANY AND SUBSIDIARIES

NOTES TO THE UNAUDITED CONSOLIDATED CONDENSED FINANCIAL STATEMENTS

Note 1 - Summary of Significant Accounting Policies

The Consolidated Condensed Financial Statements as of June 30, 2018 and for the three and six months ended June 30, 2018 and 2017 are unaudited. In the opinion of Parker Drilling Company (Parker Drilling or the Company), these consolidated condensed financial statements include all adjustments, which, unless otherwise disclosed, are of a normal recurring nature, necessary for their fair presentation for the periods presented. The results for interim periods are not necessarily indicative of results for the entire year. The consolidated condensed financial statements presented herein should be read in connection with the consolidated financial statements included in our Annual Report on Form 10-K for the year ended December 31, 2017.

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. We report our Rental Tools Services business as two reportable segments: (1) U.S. Rental Tools and (2) International Rental Tools. For more details see Note 10 - Reportable Segments.

Consolidation — The consolidated condensed financial statements include the accounts of the Company and subsidiaries in which we exercise control or 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 described above, then that interest is accounted for under the equity method.

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.

Use of Estimates — The preparation of our 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.

Goodwill — We perform our annual goodwill impairment review during the fourth quarter, as of October 1, and more frequently if negative conditions or other triggering events arise. The quantitative impairment test we perform for goodwill utilizes certain assumptions, including forecasted revenues and costs assumptions. See Note 2 - 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 classified as definite lived intangibles, that 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 2 - 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

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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.

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 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.

Earnings (Loss) Per Share (EPS) — Basic earnings (loss) per share is computed by dividing net income (loss) available to common stockholders by the weighted average number of common shares outstanding during the period. The effects of dilutive securities, stock options, unvested restricted stock, assumed conversion of convertible stock and convertible debt are included in the diluted EPS calculation, when applicable.

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 26.3 percent of our consolidated revenues for the six months ended June 30, 2018. Excluding reimbursable revenues of $22.6 million, ENL constituted approximately 18.6 percent of our total consolidated revenues for the six months ended June 30, 2018.

We had deposits in domestic banks in excess of federally insured limits of approximately $65.6 million and $97.6 million, as of June 30, 2018 and December 31, 2017, respectively. In addition, we had uninsured deposits in foreign banks of $50.4 million and $45.6 million as of June 30, 2018 and December 31, 2017, respectively.

Legal and Investigative Matters — We accrue estimates of the probable and estimable costs for the resolution of certain legal and investigative 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.

Reverse stock split — On July 27, 2018, the Company’s 1-for-15 reverse stock split of its common stock became effective. All share and per share data have been retroactively restated for all periods presented. The reverse stock split did not affect the par value of the common stock. Shareholders who otherwise would have been entitled to receive a fractional share of common stock as a result of the reverse stock split will receive cash in lieu of such fractional share. The Company’s 7.25% Series A Mandatory Convertible Preferred Stock (“Convertible Preferred Stock”) was not subject to the reverse stock split, as proportionate adjustments were made to the minimum and maximum conversion rates of the Convertible Preferred Stock.

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Note 2 - Goodwill and Intangible Assets

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 during the fourth quarter, as of October 1, and more frequently if negative conditions or other triggering events arise. Should current market conditions worsen or persist for an extended period of time, an impairment of the carrying value of our goodwill could occur.

All of the Company’s goodwill and intangible assets are allocated to the International Rental Tools segment.

Goodwill

The change in the carrying amount of goodwill for the period ended June 30, 2018 is as follows:



Dollars in thousands	Goodwill
Balance at December 31, 2017	$	6,708
Additions	—
Balance at June 30, 2018	$	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, 2018
Dollars in thousands	Estimated Useful Life (Years)	Gross Carrying Amount		Write-off Due to Disposal			Accumulated Amortization			Net Carrying Amount
Amortized intangible assets:
Developed technology	6	$	11,630	$	—		$	(6,300	)	$	5,330
Trade names	5	4,940		(332		)	(3,964		)	644
Total amortized intangible assets		$	16,570	$	(332	)	$	(10,264	)	$	5,974

Amortization expense was $1.2 million and $1.5 million for the six months ended June 30, 2018 and 2017, respectively.

Our remaining intangibles amortization expense for the next five years is presented below:



Dollars in thousands	Expected future intangible amortization expense
2018	$	1,153
2019	$	2,306
2020	$	2,030
2021	$	485
Beyond 2021	$	—

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Note 3 - Long-term Debt

The following table illustrates the Company’s current debt portfolio as of June 30, 2018 and December 31, 2017:



Dollars in thousands	June 30, 2018			December 31, 2017
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	(6,160		)	(7,029		)
Total long-term debt	$	578,840		$	577,971

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 July 2022 (“6.75% Notes”) pursuant to an Indenture between the Company and The Bank of New York Mellon Trust Company, N.A., as trustee. 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 ($4.2 million net of amortization as of June 30, 2018) are being amortized over the term of the notes using the effective interest rate method.

We may redeem all or a part of the 6.75% Notes upon appropriate notice, at redemption prices decreasing each year after January 15, 2018 to par beginning January 15, 2020. As of June 30, 2018, the redemption price is 103.375 percent and we have not made any redemptions to date. 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 limits 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. 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 ($2.0 million, net of amortization as of June 30, 2018) are being amortized over the term of the notes using the effective interest rate method.

We may redeem all or a part of the 7.50% Notes upon appropriate notice, at redemption prices decreasing each year after August 1, 2016 to par beginning August 1, 2018. As of June 30, 2018, the redemption price is 101.875 percent and we have not made any redemptions to date. 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.

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2015 Secured Credit Agreement

On January 26, 2015 we entered into the 2015 Secured Credit Agreement. The 2015 Secured Credit Agreement was originally comprised of a $200.0 million revolving credit facility (“Revolver”), which was reduced to $80.0 million in February 2018. The 2015 Secured Credit Agreement formerly included financial maintenance covenants, including a Leverage Ratio, Consolidated Interest Coverage Ratio, Senior Secured Leverage Ratio, and Asset Coverage Ratio, many of which were suspended beginning in September 2015.

On February 14, 2018, we executed the Fifth Amendment to the 2015 Secured Credit Agreement (the “Fifth Amendment”) which modified the credit facility to an Asset-Based Lending structure and reduced the size of the Revolver from $100.0 million to $80.0 million. The Fifth Amendment eliminated the financial maintenance covenants previously in effect and replaced them with a liquidity covenant of $30.0 million and a monthly borrowing base calculation based on eligible rental equipment and eligible domestic accounts receivable. The liquidity covenant requires the Company to maintain a minimum of $30.0 million of liquidity (defined as availability under the borrowing base and cash on hand), of which $15.0 million is restricted, resulting in a maximum availability at any one time of the lesser of (a) an amount equal to our borrowing base minus $15.0 million, or (b) $65.0 million. Our ability to borrow under the 2015 Secured Credit Agreement is determined by reference to our borrowing base. The Fifth Amendment also allows for refinancing our existing Senior Notes with either secured or unsecured debt, adds the ability for the Company to designate certain of its subsidiaries as “Designated Borrowers” and removes our availability to make certain restricted payments. The debt issuance costs incurred relating to the Fifth Amendment were $1.4 million. The remaining debt issuance costs including all amendments as of June 30, 2018 were $1.7 million which are being amortized through January 2020 on a straight line basis.

On July 12, 2018, we executed the Sixth Amendment to the 2015 Secured Credit Agreement (the “Sixth Amendment”) which permits the Company to make Restricted Payments (as defined in the 2015 Secured Credit Agreement) in the form of certain Equity Interests (as defined in the 2015 Secured Credit Agreement).

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. In addition to the liquidity covenant and borrowing base requirements, the 2015 Secured Credit Agreement contains customary affirmative and negative covenants, such as limitations on indebtedness and liens, and restrictions on entry into certain affiliate transactions and payments (including certain payments of dividends). As of June 30, 2018, we were in compliance with all covenants contained in the 2015 Secured Credit Agreement.

Our Revolver is available for general corporate purposes and to support letters of credit. Interest on Revolver loans accrues at either:


•	Base Rate plus an Applicable Rate or


•	LIBOR plus an Applicable Rate.

Revolving loans are available subject to a monthly borrowing base calculation. As of June 30, 2018 the borrowing base under the $80.0 million Revolver was $73.4 million, which was further reduced by $15.0 million of restricted liquidity and $5.9 million in supporting letters of credit outstanding, resulting in availability under the revolver of $52.5 million. There were no amounts drawn on the Revolver as of June 30, 2018.

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Note 4 - 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 Financial Accounting Standards Board (“FASB”) Accounting Standards Codification (“ASC”) Topic No. 820, Fair Value Measurement and Disclosures 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 condensed 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, 2018				December 31, 2017
Dollars in thousands	Carrying Amount		Fair Value		Carrying Amount		Fair Value
Long-term debt
6.75% Notes	$	360,000	$	264,150	$	360,000	$	296,100
7.50% Notes	225,000		183,938		225,000		206,438
Total	$	585,000	$	448,088	$	585,000	$	502,538

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, 2018.

Note 5 - 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, 2018, we had a liability for unrecognized tax benefits of $5.9 million, primarily related to foreign operations, (all of which, if recognized, would favorably impact our effective tax rate.). At December 31, 2017, we had a liability for unrecognized tax benefits of $5.4 million, all of which would favorably impact our effective tax rate upon recognition. In addition, we recognize interest and penalties that could be applied to uncertain tax positions in periodic income tax expense. As of June 30, 2018 and December 31, 2017, we had approximately $2.2 million and $2.1 million, respectively, of accrued interest and penalties related to uncertain tax positions.

Income tax expense was $1.6 million and $1.7 million for the three months ended June 30, 2018 and 2017, respectively. Despite the pre-tax loss for the second quarter of 2018, 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.

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Note 6 - 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 condensed balance sheets or statements of cash flows, although they could have a material adverse effect on our consolidated condensed statements of operations for a particular reporting period.

Note 7 - Stockholders' Equity

In February 2017, we issued 800,000 shares (on a post-split basis) of common stock, par value $0.16 ²/₃ per share, at the public offering price of $2.10 per share, and 500,000 shares of the Convertible Preferred Stock, par value $1.00 per share, with a liquidation preference of $100 per share, for total net proceeds of $72.3 million, after underwriting discount and offering expenses.

The dividends on our Convertible Preferred Stock are payable on a cumulative basis when, as and if declared by our board of directors, or an authorized committee of our board of directors, at an annual rate of 7.25 percent of the liquidation preference of $100 per share. We may pay declared dividends in cash or, subject to certain limitations, in shares of our common stock, or in any combination of cash and shares of our common stock on March 31, June 30, September 30 and December 31 of each year, commencing on June 30, 2017 and ending on, and including, March 31, 2020.

Unless converted earlier, each share of our Convertible Preferred Stock will automatically convert into between 2.7605 and 3.1746 shares (on a post-split basis) of our common stock (respectively, the “minimum conversion rate” and “maximum conversion rate”), subject to anti-dilution adjustments. The number of shares of our common stock issuable on conversion will be determined based on the volume weighted-average price, of our common stock over the 20 consecutive trading day period beginning on, and including, the 23rd scheduled trading day immediately preceding March 31, 2020. Except in limited circumstances, at any time prior to March 31, 2020, a holder may convert Convertible Preferred Stock into shares of our common stock at the minimum conversion rate of 2.7605 shares (on a post-split basis) of common stock per share of Convertible Preferred Stock, subject to anti-dilution adjustments.

On May 10, 2018, the Company declared a cash dividend of $1.8125 per share of our Convertible Preferred Stock for the period beginning on March 31, 2018 and ending on June 29, 2018, which was paid on July 2, 2018 to holders of record of the Convertible Preferred Stock as of June 15, 2018.

On July 12, 2018, the Board of Directors of the Company declared a dividend of one right (“Right”) for each outstanding share of common stock to common stockholders of record at the close of business on July 27, 2018 (the “Rights Plan”). Each Right entitles the registered holder to purchase from the Company a unit consisting of one one-thousandth of a share (a “Fractional Share”) of Series A Junior Participating Preferred Stock, par value $1.00 per share, at a purchase price of $52.50 per Fractional Share, subject to adjustment. Initially, the Rights will be attached to all outstanding shares of common stock. The Rights will be separate from the common stock and a “Distribution Date” will occur, with certain exceptions, upon the earlier of (i) ten days following a public announcement that a person or group of affiliated or associated persons (an “Acquiring Person”) has acquired, or obtained the right to acquire, beneficial ownership of 10% or more of the outstanding shares of common stock, or (ii) ten business days following the commencement of a tender offer or exchange offer that would result in a person’s becoming an Acquiring Person. The Rights are not exercisable until the Distribution Date and will expire at the close of business on July 12, 2019, unless earlier redeemed or exchanged by the Company. If the rights become exercisable, each holder other than the Acquiring Person (and certain related parties) will be entitled to acquire shares of common stock at a 50% discount or the Company may exchange each right held by such holders for two shares of common stock.

On July 27, 2018, the Company’s 1-for-15 reverse stock split of its common stock became effective. All share and per share data have been retroactively restated for all periods presented. The reverse stock split did not affect the par value of the common stock. Shareholders who otherwise would have been entitled to receive a fractional share of common stock as a result of the reverse stock split will receive cash in lieu of such fractional share. The Company’s Convertible Preferred Stock was not subject to the reverse stock split as proportionate adjustments were made to the minimum and maximum conversion rates of the Convertible Preferred Stock.

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Note 8 - Earnings (Loss) Per Share (“EPS”)

Basic earnings (loss) per share is computed by dividing net income (loss) available to common stockholders by the weighted average number of common shares outstanding during the period. The effects of dilutive securities, stock options, unvested restricted stock, convertible debt and equity are included in the diluted EPS calculation, when applicable. See Note 7 - Stockholders' Equity for details regarding the 1-for-15 reverse stock split.

The following table represents the computation of earnings per share for the three and six months ended June 30, 2018 and 2017, respectively:



	Three Months Ended June 30,						Six Months Ended June 30,
Dollars in thousands, except per share amounts	2018			2017			2018			2017
Basic EPS
Numerator
Net Income (Loss) Available to Common Stockholders	$	(23,784	)	$	(31,127	)	$	(53,486	)	$	(70,936	)
Denominator
Weighted average shares outstanding	9,292,224			9,188,888			9,271,759			8,933,945
Number of shares used for basic EPS computation	9,292,224			9,188,888			9,271,759			8,933,945
Basic earnings (loss) per common share	$	(2.56	)	$	(3.39	)	$	(5.77	)	$	(7.94	)

Diluted EPS
Numerator
Net Income (Loss) Available to Common Stockholders	$	(23,784	)	$	(31,127	)	$	(53,486	)	$	(70,936	)
Denominator
Number of shares used for basic EPS computation	9,292,224			9,188,888			9,271,759			8,933,945
Restricted stock units⁽¹⁾	—			—			—			—
Convertible preferred stock⁽²⁾	—			—			—			—
Number of shares used for diluted EPS computation	9,292,224			9,188,888			9,271,759			8,933,945
Diluted earnings (loss) per common share	$	(2.56	)	$	(3.39	)	$	(5.77	)	$	(7.94	)


(1)	For the three and six months ended June 30, 2018 and 2017, 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 periods, therefore, inclusion of such potential common shares would be anti-dilutive.


(2)	Weighted average common shares issuable upon the assumed conversion of our Convertible Preferred Stock totaling 1,587,300 shares (on a post-split basis) were excluded from the computation of diluted EPS as such shares would be anti-dilutive.

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Note 9 - Revenue from Contracts with Customers

We adopted the Accounting Standards Update (“ASU”) 2014-09, Revenue from Contracts with Customers (Topic 606) effective January 1, 2018 using the modified retrospective implementation method. Accordingly, we have applied the five-step method outlined in Topic 606 for determining when and how revenue is recognized to all contracts that were not completed as of the date of adoption. Revenues for reporting periods beginning as of January 1, 2018 are presented under Topic 606, while prior period amounts have not been adjusted and continue to be reported under the previous revenue recognition guidance. For contracts that were modified before the effective date, we have considered the modification guidance within the new standard and determined that the revenue recognized and contract balances recorded prior to adoption for such contracts were not impacted. While Topic 606 requires additional disclosure of the nature, amount, timing, and uncertainty of revenue and cash flows arising from contracts with customers, its adoption has not had a material impact on the measurement or recognition of our revenues. As part of the adoption no adjustments were needed to the consolidated balance sheets, statements of operations and statements of cash flows.

Our business is comprised of two business lines: (1) Drilling Services and (2) Rental Tools Services. See Note 10 - Reportable Segments for further details on these business lines and revenue disaggregation amounts.

Our drilling and rental tools services provided under each contract is a single performance obligation satisfied over time and comprised of a series of distinct time increments, or service periods. Total revenue is determined for each individual contract by estimating both fixed and variable consideration expected to be earned over the contract term. Fixed consideration generally relates to activities that are not distinct within the context of our contracts and is recognized on a straight-line basis over the contract term. Variable consideration generally relates to distinct service periods during the contract term and are recognized in the period when the services are performed. Our contract terms generally range from 2 to 60 months.

The amount estimated for variable consideration may be constrained (reduced) and is only recognized as revenue to the extent that it is probable that a significant reversal of previously recognized revenue will not occur during the contract term. When determining if variable consideration should be constrained, management considers whether there are factors outside the Company’s control that could result in a significant reversal of revenue as well as the likelihood and magnitude of a potential reversal of revenue. These estimates are re-assessed each reporting period as required. Accounts receivable are recognized when the right to consideration becomes unconditional based upon contractual billing schedules. Payment terms on invoiced amounts are typically 30 days.

Drilling Services Business

Dayrate Revenues - Our drilling services contracts generally provide for payment on a dayrate basis, with higher rates for periods when the drilling unit is operating and lower rates or zero rates for periods when drilling operations are interrupted or restricted. The dayrate invoices billed to the customer are typically determined based on the varying rates applicable to the specific activities performed on an hourly basis.

Such dayrate consideration is allocated to the distinct hourly increment to which it relates within the contract term, and therefore, recognized in line with the contractual rate billed for the services provided for any given hour.

Mobilization Revenues - We may receive fees (on either a fixed lump-sum or variable dayrate basis) for the mobilization of our rigs.

These activities are not considered to be distinct within the context of the contract and therefore, the associated revenues are allocated to the overall performance obligation and recognized ratably over the initial term of the related drilling contract. We record a contract liability for mobilization fees received, which is amortized ratably to revenue as services are rendered over the initial term of the related drilling contract. The amortized amount is adjusted accordingly if the term of the initial contract is extended.

Capital Modification Revenues - We may, from time to time, receive fees from our customers for capital improvements to our rigs to meet contractual requirements (on either a fixed lump-sum or variable dayrate basis).

Such revenues are allocated to the overall performance obligation and recognized ratably over the initial term of the related drilling contract as these activities are not considered to be distinct within the context of our contracts. We record a contract liability for such fees and recognize them ratably as revenue over the initial term of the related drilling contract.

Demobilization Revenues - We may receive fees (on either a fixed lump-sum or variable dayrate basis) for the demobilization of our rigs.

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Due to the inherent uncertainty regarding the realization, we have elected to not recognize demobilization revenues till the uncertainty is resolved. Therefore, demobilization revenues are recognized once the related performance obligations have been completed.

Reimbursable revenues - We generally receive reimbursements from our customers for the purchase of supplies, equipment, personnel services and other services provided at their request in accordance with a drilling contract or other agreement.

Such reimbursable revenues are variable and subject to uncertainty, as the amounts received and timing thereof is highly dependent on factors outside of our control. Accordingly, reimbursable revenues are not included in the total transaction price until the uncertainty is resolved, which typically occurs when the related costs are incurred on behalf of a customer. We are generally considered a principal in such transactions and record the associated revenues at the gross amount billed to the customer in our consolidated condensed statements of operations. Such amounts are recognized once the services have been performed. Such amounts totaled $12.8 million and $15.2 million for the three months ended June 30, 2018 and 2017, respectively, and $27.0 million and $30.5 million for the six months ended June 30, 2018 and 2017, respectively.

Rental Tools Services Business

Dayrate Revenues - Our rental tools services contracts generally provide for payment on a dayrate basis depending on the rate for the tool defined in the contract.

Such dayrate consideration is allocated to the distinct hourly increment it relates to within the contract term, and therefore, recognized in line with the contractual rate billed for the services provided for any given hour.

Contract costs

The following is a description of the different costs that we may incur for our contracts:

Mobilization costs - These costs include certain direct and incremental costs incurred for mobilization of contracted rigs. These costs relate directly to a contract, enhance resources of the Company that will be used in satisfying its performance obligations in the future and are expected to be recovered. These costs are capitalized when incurred as a current or noncurrent asset (depending on the length of the initial contract term), and are amortized over the initial term of the related drilling contract.

Demobilization costs - These costs are incurred for the demobilization of rigs at contract completion and are recognized as incurred during the demobilization process.

Capital Modification costs - These costs are incurred for rig modifications or upgrades required for a contract, which are considered to be capital improvements, are capitalized as property, plant and equipment and depreciated over the estimated useful life of the improvement.

Contract balances

The following table provides information about contract assets and contract liabilities from contracts with customers:



Dollars in thousands	June 30, 2018			December 31, 2017
Contract assets - current ⁽¹⁾	$	1,675		$	973
Contract assets - noncurrent ⁽¹⁾	—			—
Total contract assets	$	1,675		$	973

Contract liabilities - current ⁽²⁾	$	(904	)	$	(641	)
Contract liabilities - noncurrent ⁽²⁾	(315		)	(380		)
Total contract liabilities	$	(1,219	)	$	(1,021	)


(1)	Contract assets - current and contract assets - noncurrent are included in other current assets and other noncurrent assets respectively, in our consolidated condensed balance sheet as of June 30, 2018 and December 31, 2017.


(2)	Contract liabilities - current and contract liabilities - noncurrent are included in accounts payable and accrued liabilities and other long-term liabilities respectively, in our consolidated condensed balance sheet as of June 30, 2018 and December 31, 2017.

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Contract assets relate to mobilization costs. During the six months ended June 30, 2018, the amount of amortization of such costs was $2.1 million and there was no impairment loss in relation to capitalized costs.

Contract liabilities relate to mobilization revenues and capital modification revenues, where, cash has been received but performance obligations have not been fulfilled. These liabilities are reduced and revenue is recognized as performance obligations are fulfilled.

Contract assets and contract liabilities are netted together at the contract level and presented on a net basis as current or noncurrent contract asset or contract liability.

Significant changes to contract assets and contract liabilities balances during the six months ended June 30, 2018 are shown below:



Dollars in thousands	Contract Assets			Contract Liabilities
Balance at December 31, 2017	$	973		$	(1,021	)
Decrease due to recognition of revenue or amortization of cost that was included in the beginning contract balance	(281		)	910
Decrease due to recognition of revenue or amortization of cost for current period	(770		)	—
Increase to deferred revenue or mobilization costs during current period	1,753			(1,108		)
Balance at June 30, 2018	$	1,675		$	(1,219	)

Transaction price allocated to the remaining performance obligations

The following table includes revenues expected to be recognized in the future related to performance obligations that are unsatisfied (or partially unsatisfied) at the end of the reporting period.



	Balance at June 30, 2018
Dollars in thousands	Remaining 2018	2019	2020	Beyond 2020	Total
Deferred revenue	$1,403	$515	$239	$581	$2,738

The revenues included above consist of mobilization and capital modification revenues for both wholly and partially unsatisfied performance obligations, which have been estimated for purposes of allocating across the entire corresponding performance obligations. The amounts are derived from the specific terms within contracts that contain such provisions, and the expected timing for recognition of such revenue is based on the estimated start date and duration of each respective contract based on information known at June 30, 2018. The actual timing of recognition of such amounts may vary due to factors outside of our control. We have applied the disclosure practical expedient in ASC 606-10-50-14A(b) and have not included estimated variable consideration related to wholly unsatisfied performance obligations or to distinct future time increments within our contracts.

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Note 10 - 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. We report our Rental Tools Services business as two reportable segments: (1) U.S. Rental Tools and (2) International Rental Tools.

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 FASB ASC Topic No. 280, Segment Reporting. 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, natural gas and geothermal 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 operations and management (“O&M”) service in which operators own their own drilling rigs but choose Parker Drilling to operate and manage the rigs for them. The nature and scope of activities involved in drilling an oil and natural 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, commissioning of customer-owned drilling rig projects, operations execution, and quality and safety management. We have extensive experience and expertise in drilling geologically challenging 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 Gulf of Mexico (“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 natural gas prices and our customers’ access to project financing. Contract terms typically consist of well-to-well or multi-well programs, most commonly ranging from 20 to 180 days.

International & Alaska Drilling

Our International & Alaska Drilling segment provides drilling services, using both Company-owned rigs and O&M contracts, and project-related services. The drilling markets in which this segment operates have one or more of the following characteristics:


•	customers 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


•	O&M contracts that generally cover periods of one year or more.

During the quarter ended June 30, 2018, we had rigs operating in Alaska, Kazakhstan, the Kurdistan Region of Iraq, Guatemala, and on Sakhalin Island, Russia. In addition, we had O&M and ongoing project-related services for customer-owned rigs in Kuwait, Canada, Indonesia, Mexico and on Sakhalin Island, Russia.

Rental Tools Services Business

In our Rental Tools Services business, we provide premium rental equipment and services to exploration & production 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, drill collars, pressure control equipment, including blowout preventers and more. We also provide well construction services,

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which include tubular running services and downhole tool rentals, well intervention services, which include whipstock, fishing and related services, and inspection and machine shop support. Rental tools are used during drilling and/or workover programs and are requested by the customer as needed, requiring us to keep a broad inventory of rental tools in stock. Rental tools are usually rented on a daily or monthly basis.

U.S. Rental Tools

Our U.S. Rental Tools segment maintains an inventory of rental tools for deepwater, drilling, completion, workover, and production applications at facilities in Louisiana, Texas, Wyoming, North Dakota and West Virginia. We also provide well construction and well intervention services. Our largest single market for rental tools is U.S. land drilling, a cyclical market driven primarily by oil and natural gas prices and our customers’ access to project financing. A portion of our U.S. rental tools business is supplying tubular goods and other equipment to offshore GOM customers.

International Rental Tools

Our International Rental Tools segment maintains an inventory of rental tools and provides well construction, well intervention, and surface and tubular services to our customers in the Middle East, Latin America, United Kingdom, Europe, and Asia-Pacific regions.

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The following table represents the results of operations by reportable segment:



	Three Months Ended June 30,						Six Months Ended June 30,
Dollars in thousands	2018			2017			2018			2017
Revenues: ⁽¹⁾
Drilling Services:
U.S. (Lower 48) Drilling	$	3,283		$	5,042		$	4,637		$	6,257
International & Alaska Drilling	53,302			60,669			109,398			123,881
Total Drilling Services	56,585			65,711			114,035			130,138
Rental Tools Services:
U.S. Rental Tools	42,083			29,704			76,831			49,936
International Rental Tools	19,935			14,192			37,412			27,804
Total Rental Tools Services	62,018			43,896			114,243			77,740
Total revenues	118,603			109,607			228,278			207,878
Operating gross margin: ⁽²⁾
Drilling Services:
U.S. (Lower 48) Drilling	(3,751		)	(4,528		)	(9,041		)	(11,761		)
International & Alaska Drilling	(3,827		)	(2,788		)	(9,157		)	(4,555		)
Total Drilling Services	(7,578		)	(7,316		)	(18,198		)	(16,316		)
Rental Tools Services:
U.S. Rental Tools	11,302			2,988			15,530			(798		)
International Rental Tools	(3,891		)	(6,688		)	(7,907		)	(13,647		)
Total Rental Tools Services	7,411			(3,700		)	7,623			(14,445		)
Total operating gross margin	(167		)	(11,016		)	(10,575		)	(30,761		)
General and administrative expense	(8,288		)	(6,503		)	(14,489		)	(13,543		)
Gain (loss) on disposition of assets, net	(478		)	(113		)	(135		)	(465		)
Total operating income (loss)	(8,933		)	(17,632		)	(25,199		)	(44,769		)
Interest expense	(11,197		)	(11,095		)	(22,437		)	(21,965		)
Interest income	30			22			53			32
Other income (loss)	(1,191		)	560			(900		)	1,090
Income (loss) before income taxes	$	(21,291	)	$	(28,145	)	$	(48,483	)	$	(65,612	)

(1)

For the six months ended June 30, 2018, our largest customer, ENL, constituted approximately 26.3 percent of our total consolidated revenues and approximately 54.9 percent of our International & Alaska Drilling segment revenues. Excluding reimbursable revenues of $22.6 million, ENL constituted approximately 18.6 percent of our total consolidated revenues and approximately 45.4 percent of our International & Alaska Drilling segment revenues.

For the six months ended June 30, 2017, our largest customer, ENL, constituted approximately 34.0 percent of our total consolidated revenues and approximately 57.0 percent of our International & Alaska Drilling segment revenues. Excluding reimbursable revenues of $27.0 million, ENL constituted approximately 24.6 percent of our total consolidated revenues and approximately 46.7 percent of our International & Alaska Drilling segment revenues. Our second largest customer, BP, constituted 10.5 percent, of our total consolidated revenues and approximately 17.6 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.

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The following table shows the Company’s revenues by geographic region:



	Three Months Ended June 30,				Six Months Ended June 30,
Dollars in Thousands	2018		2017		2018		2017
Revenues by geographic region:
United States	$	52,655	$	45,387	$	96,651	$	77,961
Russia	28,771		36,578		60,062		71,025
EMEA & Asia	22,260		13,537		42,304		28,637
Latin America	4,104		2,753		7,617		5,620
Other CIS	3,506		5,753		7,056		12,061
Other	7,307		5,599		14,588		12,574
Total revenues	$	118,603	$	109,607	$	228,278	$	207,878

Note 11 - Recent Accounting Pronouncements

In February 2016, the FASB issued ASU No. 2016-02, Leases (Topic 842). This ASU requires (a) an entity to separate the lease components from the non-lease components in a contract where the lease component will be accounted for under ASU 2016-02 and the non-lease component will be accounted for under ASU 2014-09, (b) recognition of lease assets and lease liabilities by lessees and derecognition of the leased asset and recognition of a net investment in the lease by the lessor and (c) additional disclosure requirements for both lessees and lessors. The standard is effective for fiscal years beginning after December 15, 2018, including interim periods within those fiscal years, although early adoption is permitted. Under the updated accounting standard, we have determined that our drilling contracts contain a lease component. In January 2018, the FASB issued a Proposed Accounting Standard Update to provide targeted improvements to Update 2016-02, which (1) provides for a new transition method whereby entities may elect to adopt the Update using a prospective with cumulative catch-up approach and (2) provides lessors with a practical expedient to not separate non-lease components from the related lease components, by class of underlying asset. On March 28, 2018, the FASB held a meeting to approve certain additional amendments to Update 2016-02, including a revision to the practical expedient that would allow a lessor to account for the combined lease and non-lease components under Topic 606 when the non-lease component is the predominant element of the combined component. Depending on the criteria included in the final Update, this practical expedient may be available to us. We will adopt ASU 2016-02 on January 1, 2019. Our adoption, and the ultimate effect on our consolidated condensed financial statements, will be based on an evaluation of the contract-specific facts and circumstances, and such effect could introduce variability to the timing of our revenue recognition relative to current accounting standards. We are evaluating the requirements to determine the effect such requirements may have on our consolidated balance sheets, statements of operations, statements of cash flows and on the disclosures contained in our notes to the consolidated financial statements upon the adoption of ASU 2016-02. Depending on the results of the evaluation our ultimate conclusions may vary.

In May 2014, the FASB issued ASU 2014-09, Revenue from Contracts with Customers (Topic 606). This ASU supersedes the revenue recognition requirements in ASC 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. Effective January 1, 2018, we adopted ASU 2014-09 using the modified retrospective approach and it did not have a material impact on our consolidated balance sheets, statement of operations, and statements of cash flows. See Note 9 - Revenue from Contracts with Customers for further details.

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Note 12 - 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 Company’s 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 the exception to 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, 2018 and December 31, 2017 and for the three and six months ended June 30, 2018 and 2017, respectively. The consolidating condensed financial statements present investments in both consolidated and unconsolidated subsidiaries using the equity method of accounting.

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PARKER DRILLING COMPANY AND SUBSIDIARIES

CONSOLIDATING CONDENSED BALANCE SHEET

(Dollars in Thousands)

(Unaudited)



	June 30, 2018
	Parent			Guarantor			Non-Guarantor			Eliminations			Consolidated
ASSETS
Current assets:
Cash and cash equivalents	$	46,762		$	16,223		$	51,474		$	—		$	114,459
Accounts and notes receivable, net	—			38,845			83,828			—			122,673
Rig materials and supplies	—			(1,972		)	33,494			399			31,921
Other current assets	—			8,651			14,989			—			23,640
Total current assets	46,762			61,747			183,785			399			292,693
Property, plant and equipment, net	(19		)	422,144			179,727			217			602,069
Goodwill	—			6,708			—			—			6,708
Intangible assets, net	—			5,974			—			—			5,974
Investment in subsidiaries and intercompany advances	2,923,231			2,993,050			4,100,944			(10,017,225		)	—
Other noncurrent assets	(253,593		)	231,233			532,946			(480,811		)	29,775
Total assets	$	2,716,381		$	3,720,856		$	4,997,402		$	(10,497,420	)	$	937,219

LIABILITIES AND STOCKHOLDERS’ EQUITY
Current liabilities:
Accounts payable and accrued liabilities	$	(73,337	)	$	206,807		$	586,803		$	(617,476	)	$	102,797
Accrued income taxes	83,693			(62,838		)	(17,398		)	—			3,457
Total current liabilities	10,356			143,969			569,405			(617,476		)	106,254
Long-term debt, net	578,840			—			—			—			578,840
Other long-term liabilities	2,867			3,367			4,102			(1		)	10,335
Long-term deferred tax liability	—			—			60			—			60
Intercompany payables	1,879,491			1,471,636			2,571,268			(5,922,395		)	—
Total liabilities	2,471,554			1,618,972			3,144,835			(6,539,872		)	695,489
Total stockholders’ equity	244,827			2,101,884			1,852,567			(3,957,548		)	241,730
Total liabilities and stockholders’ equity	$	2,716,381		$	3,720,856		$	4,997,402		$	(10,497,420	)	$	937,219

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PARKER DRILLING COMPANY AND SUBSIDIARIES

CONSOLIDATING CONDENSED BALANCE SHEET

(Dollars in Thousands)

(Unaudited)



	December 31, 2017
	Parent			Guarantor			Non-Guarantor			Eliminations			Consolidated
ASSETS
Current assets:
Cash and cash equivalents	$	75,342		$	20,655		$	45,552		$	—		$	141,549
Accounts and notes receivable, net	—			32,338			90,173			—			122,511
Rig materials and supplies	—			(3,025		)	34,440			—			31,415
Other current assets	—			6,362			15,999			—			22,361
Total current assets	75,342			56,330			186,164			—			317,836
Property, plant and equipment, net	(19		)	428,556			197,234			—			625,771
Goodwill	—			6,708			—			—			6,708
Intangible assets, net	—			7,128			—			—			7,128
Investment in subsidiaries and intercompany advances	2,955,050			2,971,456			3,955,553			(9,882,059		)	—
Other noncurrent assets	(261,232		)	237,755			537,124			(480,811		)	32,836
Total assets	$	2,769,141		$	3,707,933		$	4,876,075		$	(10,362,870	)	$	990,279

LIABILITIES AND STOCKHOLDERS’ EQUITY
Current liabilities:
Accounts payable and accrued liabilities	$	(51,060	)	$	179,247		$	588,536		$	(617,477	)	$	99,246
Accrued income taxes	76,883			(56,870		)	(15,583		)	—			4,430
Total current liabilities	25,823			122,377			572,953			(617,477		)	103,676
Long-term debt, net	577,971			—			—			—			577,971
Other long-term liabilities	2,867			5,741			3,825			—			12,433
Long-term deferred tax liability	(1		)	—			79			—			78
Intercompany payables	1,865,810			1,465,744			2,430,340			(5,761,894		)	—
Total liabilities	2,472,470			1,593,862			3,007,197			(6,379,371		)	694,158
Total stockholders’ equity	296,671			2,114,071			1,868,878			(3,983,499		)	296,121
Total liabilities and stockholders’ equity	$	2,769,141		$	3,707,933		$	4,876,075		$	(10,362,870	)	$	990,279

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PARKER DRILLING COMPANY AND SUBSIDIARIES

CONSOLIDATING CONDENSED STATEMENT OF OPERATIONS

(Dollars in Thousands)

(Unaudited)



	Three months ended June 30, 2018
	Parent			Guarantor			Non-Guarantor			Eliminations			Consolidated
Revenues	$	—		$	50,996		$	82,641		$	(15,034	)	$	118,603
Operating expenses	—			26,375			80,293			(15,034		)	91,634
Depreciation and amortization	—			19,488			7,648			—			27,136
Total operating gross margin (loss)	—			5,133			(5,300		)	—			(167		)
General and administrative expense ⁽¹⁾	(156		)	(8,005		)	(127		)	—			(8,288		)
Gain (loss) on disposition of assets, net	—			(63		)	(415		)	—			(478		)
Total operating income (loss)	(156		)	(2,935		)	(5,842		)	—			(8,933		)
Other income (expense):
Interest expense	(11,913		)	(51		)	(2,100		)	2,867			(11,197		)
Interest income	139			180			2,578			(2,867		)	30
Other	—			14			(1,205		)	—			(1,191		)
Equity in net earnings of subsidiaries	(11,079		)	—			—			11,079			—
Total other income (expense)	(22,853		)	143			(727		)	11,079			(12,358		)
Income (loss) before income taxes	(23,009		)	(2,792		)	(6,569		)	11,079			(21,291		)
Income tax expense (benefit)	(132		)	277			1,441			—			1,586
Net income (loss)	(22,877		)	(3,069		)	(8,010		)	11,079			(22,877		)
Less: Convertible preferred stock dividend	907			—			—			—			907
Net income (loss) available to common stockholders	$	(23,784	)	$	(3,069	)	$	(8,010	)	$	11,079		$	(23,784	)


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

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PARKER DRILLING COMPANY AND SUBSIDIARIES

CONSOLIDATING CONDENSED STATEMENT OF OPERATIONS

(Dollars in Thousands)

(Unaudited)



	Three months ended June 30, 2017
	Parent			Guarantor			Non-Guarantor			Eliminations			Consolidated
Revenues	$	—		$	41,490		$	85,028		$	(16,911	)	$	109,607
Operating expenses	—			25,327			81,225			(16,911		)	89,641
Depreciation and amortization	—			20,270			10,712			—			30,982
Total operating gross margin (loss)	—			(4,107		)	(6,909		)	—			(11,016		)
General and administrative expense ⁽¹⁾	(69		)	(6,303		)	(131		)	—			(6,503		)
Gain (loss) on disposition of assets, net	—			(26		)	(87		)	—			(113		)
Total operating income (loss)	(69		)	(10,436		)	(7,127		)	—			(17,632		)
Other income (expense):
Interest expense	(11,809		)	(41		)	(2,070		)	2,825			(11,095		)
Interest income	184			179			2,484			(2,825		)	22
Other	—			15			545			—			560
Equity in net earnings of subsidiaries	(15,823		)	—			—			15,823			—
Total other income (expense)	(27,448		)	153			959			15,823			(10,513		)
Income (loss) before income taxes	(27,517		)	(10,283		)	(6,168		)	15,823			(28,145		)
Income tax expense (benefit)	2,371			(1,585		)	957			—			1,743
Net income (loss)	(29,888		)	(8,698		)	(7,125		)	15,823			(29,888		)
Less: Convertible preferred stock dividend	1,239			—			—			—			1,239
Net income (loss) available to common stockholders	$	(31,127	)	$	(8,698	)	$	(7,125	)	$	15,823		$	(31,127	)


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

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PARKER DRILLING COMPANY AND SUBSIDIARIES

CONSOLIDATING CONDENSED STATEMENT OF OPERATIONS

(Dollars in Thousands)

(Unaudited)



	Six Months Ended June 30, 2018
	Parent			Guarantor			Non-Guarantor			Eliminations			Consolidated
Revenues	$	—		$	93,587		$	164,264		$	(29,573	)	$	228,278
Operating expenses	—			52,192			160,549			(29,573		)	183,168
Depreciation and amortization	—			39,484			16,201			—			55,685
Total operating gross margin (loss)	—			1,911			(12,486		)	—			(10,575		)
General and administrative expense ⁽¹⁾	(245		)	(13,988		)	(256		)	—			(14,489		)
Gain (loss) on disposition of assets, net	—			(53		)	(82		)	—			(135		)
Total operating income (loss)	(245		)	(12,130		)	(12,824		)	—			(25,199		)
Other income (expense):
Interest expense	(24,141		)	172			(4,156		)	5,688			(22,437		)
Interest income	321			361			5,059			(5,688		)	53
Other	—			16			(916		)	—			(900		)
Equity in net earnings of subsidiaries	(27,451		)	—			—			27,451			—
Total other income (expense)	(51,271		)	549			(13		)	27,451			(23,284		)
Income (loss) before income taxes	(51,516		)	(11,581		)	(12,837		)	27,451			(48,483		)
Income tax expense (benefit)	157			607			2,426			—			3,190
Net income (loss)	(51,673		)	(12,188		)	(15,263		)	27,451			(51,673		)
Less: Convertible preferred stock dividend	1,813			—			—			—			1,813
Net income (loss) available to common stockholders	$	(53,486	)	$	(12,188	)	$	(15,263	)	$	27,451		$	(53,486	)


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

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PARKER DRILLING COMPANY AND SUBSIDIARIES

CONSOLIDATING CONDENSED STATEMENT OF OPERATIONS

(Dollars in Thousands)

(Unaudited)



	Six Months Ended June 30, 2017
	Parent			Guarantor			Non-Guarantor			Eliminations			Consolidated
Revenues	$	—		$	69,383		$	173,265		$	(34,770	)	$	207,878
Operating expenses	—			46,277			163,948			(34,770		)	175,455
Depreciation and amortization	—			41,458			21,726			—			63,184
Total operating gross margin (loss)	—			(18,352		)	(12,409		)	—			(30,761		)
General and administrative expense ⁽¹⁾	(147		)	(13,173		)	(223		)	—			(13,543		)
Gain (loss) on disposition of assets, net	—			(242		)	(223		)	—			(465		)
Total operating income (loss)	(147		)	(31,767		)	(12,855		)	—			(44,769		)
Other income (expense):
Interest expense	(23,478		)	(85		)	(4,013		)	5,611			(21,965		)
Interest income	332			357			4,954			(5,611		)	32
Other	—			47			1,043			—			1,090
Equity in net earnings of subsidiaries	(37,602		)	—			—			37,602			—
Total other income (expense)	(60,748		)	319			1,984			37,602			(20,843		)
Income (loss) before income taxes	(60,895		)	(31,448		)	(10,871		)	37,602			(65,612		)
Income tax expense (benefit)	8,801			(7,161		)	2,445			—			4,085
Net income (loss)	(69,696		)	(24,287		)	(13,316		)	37,602			(69,697		)
Less: Convertible preferred stock dividend	1,239			—			—			—			1,239
Net income (loss) available to common stockholders	$	(70,935	)	$	(24,287	)	$	(13,316	)	$	37,602		$	(70,936	)


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

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PARKER DRILLING COMPANY AND SUBSIDIARIES

CONSOLIDATING CONDENSED STATEMENT OF COMPREHENSIVE INCOME (LOSS)

(Dollars in Thousands)

(Unaudited)



	Three months ended June 30, 2018
	Parent			Guarantor			Non-Guarantor			Eliminations		Consolidated
Comprehensive income (loss):
Net income (loss)	$	(22,877	)	$	(3,069	)	$	(8,010	)	$	11,079	$	(22,877	)
Other comprehensive income (loss), net of tax:
Currency translation difference on related borrowings	—			—			(445		)	—		(445		)
Currency translation difference on foreign currency net investments	—			—			(1,802		)	—		(1,802		)
Total other comprehensive income (loss), net of tax:	—			—			(2,247		)	—		(2,247		)
Comprehensive income (loss)	$	(22,877	)	$	(3,069	)	$	(10,257	)	$	11,079	$	(25,124	)

PARKER DRILLING COMPANY AND SUBSIDIARIES

CONSOLIDATING CONDENSED STATEMENT OF COMPREHENSIVE INCOME (LOSS)

(Dollars in Thousands)

(Unaudited)



	Three months ended June 30, 2017
	Parent			Guarantor			Non-Guarantor			Eliminations		Consolidated
Comprehensive income (loss):
Net income (loss)	$	(29,888	)	$	(8,698	)	$	(7,125	)	$	15,823	$	(29,888	)
Other comprehensive income (loss), net of tax:
Currency translation difference on related borrowings	—			—			185			—		185
Currency translation difference on foreign currency net investments	—			—			686			—		686
Total other comprehensive income (loss), net of tax:	—			—			871			—		871
Comprehensive income (loss)	$	(29,888	)	$	(8,698	)	$	(6,254	)	$	15,823	$	(29,017	)

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PARKER DRILLING COMPANY AND SUBSIDIARIES

CONSOLIDATING CONDENSED STATEMENT OF COMPREHENSIVE INCOME (LOSS)

(Dollars in Thousands)

(Unaudited)



	Six Months Ended June 30, 2018
	Parent			Guarantor			Non-Guarantor			Eliminations		Consolidated
Comprehensive income (loss):
Net income (loss)	$	(51,673	)	$	(12,188	)	$	(15,263	)	$	27,451	$	(51,673	)
Other comprehensive income (loss), net of tax:
Currency translation difference on related borrowings	—			—			(169		)	—		(169		)
Currency translation difference on foreign currency net investments	—			—			(2,378		)	—		(2,378		)
Total other comprehensive income (loss), net of tax:	—			—			(2,547		)	—		(2,547		)
Comprehensive income (loss)	$	(51,673	)	$	(12,188	)	$	(17,810	)	$	27,451	$	(54,220	)

PARKER DRILLING COMPANY AND SUBSIDIARIES

CONSOLIDATING CONDENSED STATEMENT OF COMPREHENSIVE INCOME (LOSS)

(Dollars in Thousands)

(Unaudited)



	Six Months Ended June 30, 2017
	Parent			Guarantor			Non-Guarantor			Eliminations		Consolidated
Comprehensive income (loss):
Net income (loss)	$	(69,696	)	$	(24,287	)	$	(13,316	)	$	37,602	$	(69,697	)
Other comprehensive income (loss), net of tax:
Currency translation difference on related borrowings	—			—			268			—		268
Currency translation difference on foreign currency net investments	—			—			1,449			—		1,449
Total other comprehensive income (loss), net of tax:	—			—			1,717			—		1,717
Comprehensive income (loss)	$	(69,696	)	$	(24,287	)	$	(11,599	)	$	37,602	$	(67,980	)

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PARKER DRILLING COMPANY AND SUBSIDIARIES

CONSOLIDATED CONDENSED STATEMENT OF CASH FLOWS

(Dollars in Thousands)

(Unaudited)



	Six Months Ended June 30, 2018
	Parent			Guarantor			Non-Guarantor			Eliminations			Consolidated
Cash flows from operating activities:
Net income (loss)	$	(51,673	)	$	(12,188	)	$	(15,263	)	$	27,451		$	(51,673	)
Adjustments to reconcile net income (loss):
Depreciation and amortization	—			39,484			16,201			—			55,685
(Gain) loss on disposition of assets, net	—			53			82			—			135
Deferred tax expense (benefit)	(6,782		)	6,354			(468		)	—			(896		)
Expenses not requiring cash	2,681			561			(8,472		)	9,260			4,030
Change in assets and liabilities:
Accounts and notes receivable	—			(6,507		)	6,115			—			(392		)
Other assets	32,403			(22,769		)	(136,289		)	134,767			8,112
Accounts payable and accrued liabilities	(8,596		)	25,823			148,225			(171,478		)	(6,026		)
Accrued income taxes	6,810			(5,968		)	(1,786		)	—			(944		)
Net cash provided by (used in) operating activities	(25,157		)	24,843			8,345			—			8,031

Cash flows from investing activities:
Capital expenditures	—			(29,342		)	(3,207		)	—			(32,549		)
Proceeds from the sale of assets	—			67			784			—			851
Net cash provided by (used in) investing activities	—			(29,275		)	(2,423		)	—			(31,698		)

Cash flows from financing activities:
Payments of debt issuance costs	(1,440		)	—			—			—			(1,440		)
Convertible preferred stock dividend	(1,813		)	—			—			—			(1,813		)
Shares surrendered in lieu of tax	(170		)	—			—			—			(170		)
Net cash provided by (used in) financing activities	(3,423		)	—			—			—			(3,423		)

Net increase (decrease) in cash and cash equivalents	(28,580		)	(4,432		)	5,922			—			(27,090		)
Cash and cash equivalents at beginning of period	75,342			20,655			45,552			—			141,549
Cash and cash equivalents at end of period	$	46,762		$	16,223		$	51,474		$	—		$	114,459

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PARKER DRILLING COMPANY AND SUBSIDIARIES

CONSOLIDATED CONDENSED STATEMENT OF CASH FLOWS

(Dollars in Thousands)

(Unaudited)



	Six Months Ended June 30, 2017
	Parent			Guarantor			Non-Guarantor			Eliminations			Consolidated
Cash flows from operating activities:
Net income (loss)	$	(69,696	)	$	(24,287	)	$	(13,316	)	$	37,602		$	(69,697	)
Adjustments to reconcile net income (loss)
Depreciation and amortization	—			41,458			21,726			—			63,184
(Gain) loss on disposition of assets, net	—			242			223			—			465
Deferred tax expense (benefit)	(10,359		)	8,943			482			—			(934		)
Expenses not requiring cash	3,154			120			1,674			—			4,948
Equity in net earnings of subsidiaries	37,602			—			—			(37,602		)	—
Change in assets and liabilities:
Accounts and notes receivable	—			(13,787		)	6,934			—			(6,853		)
Other assets	(50,315		)	32,013			16,580			—			(1,722		)
Accounts payable and accrued liabilities	(37,753		)	29,831			(313		)	—			(8,235		)
Accrued income taxes	71,942			(54,000		)	(16,666		)	—			1,276
Net cash provided by (used in) operating activities	(55,425		)	20,533			17,324			—			(17,568		)

Cash flows from investing activities:
Capital expenditures	—			(18,726		)	(7,833		)	—			(26,559		)
Proceeds from the sale of assets	—			25			160			—			185
Net cash provided by (used in) investing activities	—			(18,701		)	(7,673		)	—			(26,374		)

Cash flows from financing activities:
Convertible preferred stock dividend	(1,239		)	—			—			—			(1,239		)
Shares surrendered in lieu of tax	(612		)	—			—			—			(612		)
Proceeds from the issuance of common stock	25,200			—			—			—			25,200
Proceeds from the issuance of convertible preferred stock	50,000			—			—			—			50,000
Payment of equity issuance costs	(2,864		)	—			—			—			(2,864		)
Intercompany advances, net	8,946			361			(9,307		)	—			—
Net cash provided by (used in) financing activities	79,431			361			(9,307		)	—			70,485

Net increase (decrease) in cash and cash equivalents	24,006			2,193			344			—			26,543
Cash and cash equivalents at beginning of period	65,000			14,365			40,326			—			119,691
Cash and cash equivalents at end of period	$	89,006		$	16,558		$	40,670		$	—		$	146,234

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Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations

Management’s discussion and analysis should be read in conjunction with Item 1. Financial Statements of this quarterly report on Form 10-Q and with our Annual Report on Form 10-K for the year ended December 31, 2017. We use rounded numbers in the Management Discussion and Analysis section which may result in slight differences with results reported under Item 1. Financial Statements.

Executive Summary

The oil and natural gas industry is highly cyclical. Activity levels are driven by traditional energy industry activity indicators, which include current and expected commodity prices, drilling rig counts, footage drilled, well counts, and our customers’ spending levels allocated to exploratory and developmental drilling.

Historical market indicators are listed below:



	Six Months Ended June 30,
	2018		2017		% Change
Worldwide Rig Count ⁽¹⁾
U.S. (land and offshore)	1,001		816		23	%
International ⁽²⁾	969		948		2	%
Commodity Prices ⁽³⁾
Crude Oil (Brent) per bbl	$	71.2	$	52.7	35	%
Crude Oil (West Texas Intermediate) per bbl	$	65.5	$	50.0	31	%
Natural Gas (Henry Hub) per mcf	$	2.8	$	3.1	(10	)%

(1) Estimate of drilling activity measured by the average active rig count for the periods indicated - Source: Baker Hughes Rig Count.

(2) Excludes Canadian Rig Count.

(3) Average daily commodity prices for the periods indicated based on NYMEX front-month composite energy prices.

Financial Results

Our revenues for the 2018 second quarter increased 8.2 percent to $118.6 million from $109.6 million for the 2017 second quarter. Operating gross margin increased $10.8 million to a $0.2 million loss for the three months ended June 30, 2018 compared with a loss of $11.0 million for the three months ended June 30, 2017. Operating gross margin increases were primarily driven by higher U.S. Rental Tools activity.

Outlook

Based on discussion with operators in the region, we expect U.S. (Lower 48) Drilling revenues to increase in the third quarter due to improved utilization. For the International & Alaska Drilling segment, we expect revenues to continue to decline in the third quarter due to completion of work for one of our rigs in Alaska.

We expect U.S. Rental Tools revenues to increase at a slower pace compared with the second quarter, as a result of slower growth in the U.S. land rig markets, particularly in the Permian Basin, and the timing of certain projects in the deepwater Gulf. For the International Rental Tools segment, we expect revenues to be relatively flat compared with the second quarter, as gains in Latin America, Europe, and Saudi Arabia will be offset by lower sales in the United Arab Emirates.

Recent Developments

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or obtained the right to acquire, beneficial ownership of 10% or more of the outstanding shares of common stock, or (ii) ten business days following the commencement of a tender offer or exchange offer that would result in a person’s becoming an Acquiring Person. The Rights are not exercisable until the Distribution Date and will expire at the close of business on July 12, 2019, unless earlier redeemed or exchanged by the Company. If the rights become exercisable, each holder other than the Acquiring Person (and certain related parties) will be entitled to acquire shares of common stock at a 50% discount or the Company may exchange each right held by such holders for two shares of common stock.

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Results of Operations

We analyze financial results for each of our reportable segments. The reportable segments presented are consistent with our reportable segments discussed in Note 10 - Reportable Segments to our consolidated condensed financial statements. We monitor our reporting segments based on several criteria, including operating gross margin and operating gross margin excluding depreciation and amortization. Operating gross margin excluding depreciation and amortization is computed as revenues less direct operating expenses, and excludes depreciation and amortization expense, where applicable. Operating gross margin percentages are computed as operating gross margin as a percent of revenues. The operating gross margin excluding depreciation and amortization amounts and percentages should not be used as a substitute for those amounts reported under accounting policies generally accepted in the United States (“U.S. GAAP”), but should be viewed in addition to the Company’s reported results prepared in accordance with U.S. GAAP. Management believes this information provides valuable insight into the information management considers important in managing the business.

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Three months ended June 30, 2018 Compared with Three months ended June 30, 2017

Revenues increased $9.0 million, or 8.2 percent, to $118.6 million for the three months ended June 30, 2018 compared with revenues of $109.6 million for the three months ended June 30, 2017. Operating gross margin increased $10.8 million to a loss of $0.2 million for the three months ended June 30, 2018 compared with a loss of $11.0 million for the three months ended June 30, 2017.

The following table presents our operating results for the comparable periods by reportable segment:



	Three Months Ended June 30,
Dollars in Thousands	2018					2017
Revenues:
Drilling Services:
U.S. (Lower 48) Drilling	$	3,283		3	%	$	5,042		5	%
International & Alaska Drilling	53,302			45	%	60,669			55	%
Total Drilling Services	56,585			48	%	65,711			60	%
Rental Tools Services:
U.S. Rental Tools	42,083			35	%	29,704			27	%
International Rental Tools	19,935			17	%	14,192			13	%
Total Rental Tools Services	62,018			52	%	43,896			40	%
Total revenues	118,603			100	%	109,607			100	%
Operating gross margin (loss) excluding depreciation and amortization:
Drilling Services:
U.S. (Lower 48) Drilling	(1,403		)	(43	)%	(1,025		)	(20	)%
International & Alaska Drilling	5,024			9	%	9,265			15	%
Total Drilling Services	3,621			6	%	8,240			13	%
Rental Tools Services:
U.S. Rental Tools	22,757			54	%	13,731			46	%
International Rental Tools	591			3	%	(2,005		)	(14	)%
Total Rental Tools Services	23,348			38	%	11,726			27	%
Total operating gross margin (loss) excluding depreciation and amortization	26,969			23	%	19,966			18	%
Depreciation and amortization	(27,136		)			(30,982		)
Total operating gross margin (loss)	(167		)			(11,016		)
General and administrative expense	(8,288		)			(6,503		)
Gain (loss) on disposition of assets, net	(478		)			(113		)
Total operating income (loss)	$	(8,933	)			$	(17,632	)

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Operating gross margin (loss) amounts are reconciled to our most comparable U.S. GAAP measure as follows:



Dollars in Thousands	U.S. (Lower 48) Drilling			International & Alaska Drilling			U.S. Rental Tools		International Rental Tools			Total
Three months ended June 30, 2018
Operating gross margin (loss) ⁽¹⁾	$	(3,751	)	$	(3,827	)	$	11,302	$	(3,891	)	$	(167	)
Depreciation and amortization	2,348			8,851			11,455		4,482			27,136
Operating gross margin (loss) excluding depreciation and amortization	$	(1,403	)	$	5,024		$	22,757	$	591		$	26,969
Three months ended June 30, 2017
Operating gross margin (loss) ⁽¹⁾	$	(4,528	)	$	(2,788	)	$	2,988	$	(6,688	)	$	(11,016	)
Depreciation and amortization	3,503			12,053			10,743		4,683			30,982
Operating gross margin (loss) excluding depreciation and amortization	$	(1,025	)	$	9,265		$	13,731	$	(2,005	)	$	19,966


(1)	Operating gross margin (loss) is calculated as revenues less direct operating expenses, including depreciation and amortization expense.

The following table presents our average utilization rates and rigs available for service for the three months ended June 30, 2018 and 2017, respectively:



	Three Months Ended June 30,
	2018		2017
U.S. (Lower 48) Drilling
Rigs available for service ⁽¹⁾	13.0		13.0
Utilization rate of rigs available for service ⁽²⁾	14	%	19	%
International & Alaska Drilling
Eastern Hemisphere
Rigs available for service ^{(1) (3)}	10.0		13.0
Utilization rate of rigs available for service ⁽²⁾	45	%	31	%
Latin America Region
Rigs available for service ⁽¹⁾	7.0		7.0
Utilization rate of rigs available for service ⁽²⁾	14	%	14	%
Alaska
Rigs available for service ⁽¹⁾	2.0		2.0
Utilization rate of rigs available for service ⁽²⁾	50	%	100	%
Total International & Alaska Drilling
Rigs available for service ⁽¹⁾	19.0		22.0
Utilization rate of rigs available for service ⁽²⁾	34	%	32	%

(1)

The number of rigs available for service is determined by calculating the number of days each rig was in our fleet and was under contract or available for contract. For example, a rig under contract or available for contract for six months of a year is 0.5 rigs available for service for such year. Our method of computation of rigs available for service may or may not be comparable to other similarly titled measures of other companies.

(2)

Rig utilization rates are based on a weighted average basis assuming total days availability for all rigs available for service. Rigs acquired or disposed of are treated as added to or removed from the rig fleet as of the date of acquisition or disposal. Rigs that are in operation or fully or partially staffed and on a revenue-producing standby status are considered to be utilized. Rigs under contract that generate revenues during moves between locations or during mobilization or demobilization are also considered to be utilized. Our method of computation of rig utilization may or may not be comparable to other similarly titled measures of other companies.

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(3)	The eastern hemisphere rigs available for service decreased due to the sale of two Indonesia rigs in the first quarter 2018 and one Papa New Guinea rig in the fourth quarter of 2017.

Drilling Services Business

U.S. (Lower 48) Drilling

U.S. (Lower 48) Drilling segment revenues decreased $1.8 million or 34.9 percent, to $3.3 million for the second quarter of 2018 compared with revenues of $5.0 million for the second quarter of 2017. The decrease was primarily due to a decrease in utilization to 14.0 percent for the quarter ended June 30, 2018 from 19.0 percent for the quarter ended June 30, 2017.

U.S. (Lower 48) Drilling segment operating gross margin excluding depreciation and amortization decreased $0.4 million, or 36.9 percent, to a loss of $1.4 million for the second quarter of 2018 compared with a loss of $1.0 million for the second quarter of 2017. The decrease was primarily due to the decrease in revenues discussed above.

International & Alaska Drilling

International & Alaska Drilling segment revenues decreased $7.4 million, or 12.1 percent, to $53.3 million for the second quarter of 2018 compared with $60.7 million for the second quarter of 2017.

The change in revenues was primarily due to the following:


•	a decrease of $3.6 million driven by a decline in average revenues per day primarily resulting from certain Company-owned rigs being in standby or stacked mode during 2018 compared with 2017;


•	a decrease of $2.8 million, excluding revenue from reimbursable costs (“reimbursable revenues”), resulting from decreased utilization for certain Company-owned rigs in Alaska and Russia;


•	a decrease of $2.6 million in reimbursable revenues, which decreased revenues but had a minimal impact on operating margins; and


•	an increase of $2.8 million primarily driven by O&M activities, excluding reimbursable revenues.

International & Alaska Drilling segment operating gross margin excluding depreciation and amortization decreased $4.2 million, or 45.8 percent, to $5.0 million for the second quarter of 2018 compared with $9.3 million for the second quarter of 2017. The decrease in operating gross margin excluding depreciation and amortization was primarily due to the impact of declines in average revenues per day as well as the decrease in utilization for certain Company-owned rigs in Alaska and Russia as discussed above.

Rental Tools Services Business

U.S. Rental Tools

U.S. Rental Tools segment revenues increased $12.4 million, or 41.7 percent, to $42.1 million for the second quarter of 2018 compared with $29.7 million for the second quarter of 2017. The increase was primarily attributable to an increase in well construction services.

U.S. Rental Tools segment operating gross margin excluding depreciation and amortization increased $9.0 million, or 65.7 percent, to $22.8 million for the second quarter of 2018 compared with $13.7 million for the second quarter of 2017. The improvement was primarily due to the increase in revenues discussed above and cost saving initiatives undertaken throughout 2017.

International Rental Tools

International Rental Tools segment revenues increased $5.7 million, or 40.5 percent, to $19.9 million for the second quarter of 2018 compared with $14.2 million for the second quarter of 2017. The increase was primarily attributable to an increase in well construction services.

International Rental Tools segment operating gross margin excluding depreciation and amortization increased $2.6 million, or 129.5 percent, to a gain of $0.6 million for the second quarter of 2018 compared with a loss of $2.0 million for the second quarter of 2017. The improvement was primarily due to the increase in revenues discussed above.

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Other Financial Data

General and administrative expense

General and administrative expense increased $1.8 million to $8.3 million for the second quarter of 2018 compared with $6.5 million for the second quarter of 2017, primarily due to professional fees.

Gain (loss) on disposition of assets, net

Net losses recognized on asset dispositions were $0.5 million for the second quarter of 2018 compared with a net loss of $0.1 million for the second quarter of 2017. We periodically sell equipment deemed to be excess, obsolete, or not currently required for operations.

Interest expense and income

Interest expense was $11.2 million for the second quarter of 2018 compared with $11.1 million for the second quarter of 2017. The increase was primarily due to the increase in amortization expense related to the fifth amendment to the 2015 Secured Credit Agreement executed in February 2018. Interest income was nominal during each of the 2018 and 2017 second quarters.

Other

Other income and expense was $1.2 million of expense for the second quarter of 2018 and $0.6 million of income for the second quarter of 2017. Activity in both periods primarily included the impact of foreign currency fluctuations.

Income tax expense (benefit)

During the second quarter of 2018, we had income tax expense of $1.6 million compared with income tax expense of $1.7 million during the second quarter of 2017. Despite the pre-tax loss for the second quarter of 2018, we recognized income tax expense due to the jurisdictional mix of income and loss during the period, along with our continued inability to recognize the benefits associated with certain losses as a result of valuation allowances.

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Six Months Ended June 30, 2018 Compared with Six Months Ended June 30, 2017

Revenues increased $20.4 million, or 9.8 percent, to $228.3 million for the six months ended June 30, 2018 compared with revenues of $207.9 million for the six months ended June 30, 2017. Operating gross margin increased $20.2 million to a loss of $10.6 million for the six months ended June 30, 2018 compared with a loss of $30.8 million for the six months ended June 30, 2017.

The following table presents our operating results for the comparable periods by reportable segment:



	Six Months Ended June 30,
Dollars in Thousands	2018					2017
Revenues:
Drilling Services:
U.S. (Lower 48) Drilling	$	4,637		2	%	$	6,257		3	%
International & Alaska Drilling	109,398			48	%	123,881			60	%
Total Drilling Services	114,035			50	%	130,138			63	%
Rental Tools Services:
U.S. Rental Tools	76,831			34	%	49,936			24	%
International Rental Tools	37,412			16	%	27,804			13	%
Total Rental Tools Services	114,243			50	%	77,740			37	%
Total revenues	228,278			100	%	207,878			100	%
Operating gross margin (loss) excluding depreciation and amortization:
Drilling Services:
U.S. (Lower 48) Drilling	(4,102		)	(88	)%	(4,010		)	(64	)%
International & Alaska Drilling	9,694			9	%	20,294			16	%
Total Drilling Services	5,592			5	%	16,284			13	%
Rental Tools Services:
U.S. Rental Tools	38,567			50	%	20,508			41	%
International Rental Tools	951			3	%	(4,369		)	(16	)%
Total Rental Tools Services	39,518			35	%	16,139			21	%
Total operating gross margin (loss) excluding depreciation and amortization	45,110			20	%	32,423			16	%
Depreciation and amortization	(55,685		)			(63,184		)
Total operating gross margin (loss)	(10,575		)			(30,761		)
General and administrative expense	(14,489		)			(13,543		)
Gain (loss) on disposition of assets, net	(135		)			(465		)
Total operating income (loss)	$	(25,199	)			$	(44,769	)

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Operating gross margin amounts are reconciled to our most comparable U.S. GAAP measure as follows:



Dollars in Thousands	U.S. (Lower 48) Drilling			International & Alaska Drilling			U.S. Rental Tools			International Rental Tools			Total
Six Months Ended June 30, 2018
Operating gross margin (loss) ⁽¹⁾	$	(9,041	)	$	(9,157	)	$	15,530		$	(7,907	)	$	(10,575	)
Depreciation and amortization	4,939			18,851			23,037			8,858			55,685
Operating gross margin (loss) excluding depreciation and amortization	$	(4,102	)	$	9,694		$	38,567		$	951		$	45,110
Six Months Ended June 30, 2017
Operating gross margin (loss) ⁽¹⁾	$	(11,761	)	$	(4,555	)	$	(798	)	$	(13,647	)	$	(30,761	)
Depreciation and amortization	7,751			24,849			21,306			9,278			63,184
Operating gross margin (loss) excluding depreciation and amortization	$	(4,010	)	$	20,294		$	20,508		$	(4,369	)	$	32,423


(1)	Operating gross margin (loss) is calculated as revenues less direct operating expenses, including depreciation and amortization expense.

The following table presents our average utilization rates and rigs available for service for the six months ended June 30, 2018 and 2017, respectively:



	Six Months Ended June 30,
	2018		2017
U.S. (Lower 48) Drilling
Rigs available for service ⁽¹⁾	13.0		13.0
Utilization rate of rigs available for service ⁽²⁾	9	%	12	%
International & Alaska Drilling
Eastern Hemisphere
Rigs available for service ^{(1) (3)}	12.0		13.0
Utilization rate of rigs available for service ⁽²⁾	43	%	31	%
Latin America Region
Rigs available for service ⁽¹⁾	7.0		7.0
Utilization rate of rigs available for service ⁽²⁾	14	%	14	%
Alaska
Rigs available for service ⁽¹⁾	2.0		2.0
Utilization rate of rigs available for service ⁽²⁾	50	%	100	%
Total International & Alaska Drilling
Rigs available for service ⁽¹⁾	21.0		22.0
Utilization rate of rigs available for service ⁽²⁾	33	%	32	%

(1)

The number of rigs available for service is determined by calculating the number of days each rig was in our fleet and was under contract or available for contract. For example, a rig under contract or available for contract for six months of a year is 0.5 rigs available for service during such year. Our method of computation of rigs available for service may not be comparable to other similarly titled measures of other companies.

(2)

Rig utilization rates are based on a weighted average basis assuming total days availability for all rigs available for service. Rigs acquired or disposed of are treated as added to or removed from the rig fleet as of the date of acquisition or disposal. Rigs that are in operation or fully or partially staffed and on a revenue-producing standby status are considered to be utilized. Rigs under contract that generate revenues during moves between locations or during mobilization or demobilization are also considered to be utilized. Our method of computation of rig utilization may not be comparable to other similarly titled measures of other companies.

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(3)	The eastern hemisphere rigs available for service decreased due to the sale of one Papa New Guinea rig in the fourth quarter of 2017.

Drilling Services Business

U.S. (Lower 48) Drilling

U.S. (Lower 48) Drilling segment revenues decreased $1.6 million, or 25.9 percent, to $4.6 million for the six months ended June 30, 2018 compared with revenues of $6.3 million for the six months ended June 30, 2017. The decrease was primarily due to a decrease in utilization to 9.3 percent for the six months ended June 30, 2018 from 12.0 percent for the six months ended June 30, 2017.

U.S. (Lower 48) Drilling segment operating gross margin excluding depreciation and amortization decreased $0.1 million, or 2.3 percent, to a loss of $4.1 million for the six months ended June 30, 2018 compared with a loss of $4.0 million for the six months ended June 30, 2017. The decrease was primarily due to the decrease in revenues discussed above.

International & Alaska Drilling

International & Alaska Drilling segment revenues decreased $14.5 million, or 11.7 percent, to $109.4 million for the six months ended June 30, 2018 compared with $123.9 million for the six months ended June 30, 2017.

The change in revenues was primarily due to the following:


•	a decrease of $6.5 million excluding reimbursable revenues, resulting from decreased utilization for certain Company-owned rigs in Alaska and Russia;


•	a decrease of $6.3 million driven by a decline in average revenue per day primarily resulting from certain Company owned rigs being in standby mode during 2018 compared with operating mode during 2017;


•	a decrease in reimbursable revenues of $3.7 million, which decreased revenues but had a minimal impact on operating margins; and


•	an increase of $4.2 million primarily driven by O&M activities, excluding reimbursable revenues.

International & Alaska Drilling segment operating gross margin excluding depreciation and amortization decreased $10.6 million, or 52.2 percent, to $9.7 million for the six months ended June 30, 2018 compared with $20.3 million for the six months ended June 30, 2017. The decrease in operating gross margin excluding depreciation and amortization was primarily due to the decrease in utilization for certain Company-owned rigs in Alaska and Russia, as well as, due to impact of declines in average revenues per day as discussed above.

Rental Tools Services Business

U.S. Rental Tools

U.S. Rental Tools segment revenues increased $26.9 million, or 53.9 percent, to $76.8 million for the six months ended June 30, 2018 compared with $49.9 million for the six months ended June 30, 2017. The increase was primarily driven by an increase in U.S. land rentals due to higher levels of customer activity.

U.S. Rental Tools segment operating gross margin excluding depreciation and amortization increased $18.1 million, or 88.1 percent, to $38.6 million for the six months ended June 30, 2018 compared with $20.5 million for the six months ended June 30, 2017. The increase was primarily due to the increase in revenues discussed above.

International Rental Tools

International Rental Tools segment revenues increased $9.6 million, or 34.6 percent, to $37.4 million for the six months ended June 30, 2018 compared with $27.8 million for the six months ended June 30, 2017. The increase was primarily attributable to an increase in well construction services.

International Rental Tools segment operating gross margin excluding depreciation and amortization increased $5.3 million, or 121.8 percent, to a gain of $1.0 million for the six months ended June 30, 2018 compared with a loss of $4.4 million for the six months ended June 30, 2017. The improvement was primarily due to the increase is revenues discussed above.

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Other Financial Data

General and administrative expense

General and administrative expense increased $1.0 million to $14.5 million for the six months ended June 30, 2018 compared with $13.5 million for the six months ended June 30, 2017, primarily due to professional fees.

Gain (loss) on disposition of assets, net

Net losses recognized on asset dispositions were $0.1 million and $0.5 million for the six months ended June 30, 2018 and 2017, respectively. We periodically sell equipment deemed to be excess, obsolete, or not currently required for operations.

Interest expense and income

Interest expense increased $0.4 million to $22.4 million for the six months ended June 30, 2018 compared with $22.0 million for the six months ended June 30, 2017. The increase was primarily due to the increase in amortization expense related to the fifth amendment to the 2015 Secured Credit Agreement executed in February 2018. Interest income was $0.1 million for the six months ended June 30, 2018 compared with a nominal amount for the six months ended June 30, 2017.

Other

Other income and expense was $0.9 million of expense for the six months ended June 30, 2018 and $1.1 million of income for the six months ended June 30, 2017. Activity in both periods primarily included the impact of foreign currency fluctuations.

Income tax expense (benefit)

During the six months ended June 30, 2018, we had income tax expense of $3.2 million compared with income tax expense of $4.1 million during the six months ended June 30, 2017. Despite the pre-tax loss for the six months ended June 30, 2018, we recognized income tax expense due to the jurisdictional mix of income and loss during the period, along with our continued inability to recognize the benefits associated with certain losses as a result of valuation allowances.

Backlog

Backlog is our estimate of the dollar amount of revenues we expect to realize in the future as a result of executing drilling contracts. The Company’s backlog of firm orders was approximately $215.5 million at June 30, 2018 and $289.0 million at June 30, 2017, and is primarily attributable to the International & Alaska Drilling segment of our Drilling Services business. We estimate that, as of June 30, 2018, 27.7 percent of our backlog will be recognized as revenues within the fiscal year.

The amount of actual revenues earned and the actual periods during which revenues are earned could be different from amounts disclosed in our backlog calculations due to a lack of predictability of various factors, including unscheduled repairs, maintenance requirements, weather delays, contract terminations or renegotiations, new contracts and other factors. See “Our backlog of contracted revenue may not be fully realized and may reduce significantly in the future, which may have a material adverse effect on our balance sheets, statement of operations or cash flows” in Item 1A. Risk Factors of our 2017 Form 10-K.

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Liquidity and Capital Resources

We periodically evaluate our liquidity requirements, capital needs and availability of resources in view of expansion plans, debt service requirements, and other operational cash needs. To meet our short-term liquidity requirements we primarily rely on our cash on hand and cash from operations. We also have access to cash through the revolving credit facility (“Revolver”), subject to our compliance with the covenants contained in the Second Amended and Restated Senior Secured Credit Agreement, as amended from time-to-time (the “2015 Secured Credit Agreement”). We expect that these sources of liquidity will be sufficient to provide us the ability to fund our current operations and required capital expenditures. We may need to fund expansion capital expenditures, acquisitions, debt principal payments, or pursuits of business opportunities that support our strategy, through additional borrowings or the issuance of additional common stock or other forms of equity. We do not pay dividends on our common stock.

Liquidity

On February 14, 2018, we entered into the Fifth Amendment to the 2015 Secured Credit Agreement (the “Fifth Amendment”), which modified the credit facility to an Asset-Based Lending structure and reduced the size of the Revolver from $100 million to $80 million. The Fifth Amendment eliminated the financial maintenance covenants previously in effect and replaced them with a liquidity covenant of $30 million and a monthly borrowing base calculation based on eligible rental equipment and eligible domestic accounts receivable. The Liquidity covenant requires the Company to maintain a minimum of $30 million of liquidity (defined as availability under the borrowing base and cash on hand), of which $15 million is restricted, resulting in a maximum availability at any one time of $65 million. The Fifth Amendment also allows for refinancing our existing Senior Notes with either secured or unsecured debt.

The following table provides a summary of our total liquidity:



	June 30, 2018
Dollars in thousands
Cash and cash equivalents on hand ⁽¹⁾	$	114,459
Availability under Revolver ⁽²⁾	52,547
Total liquidity	$	167,006


(1)	As of June 30, 2018, approximately $50.4 million of the $114.5 million of cash and equivalents was held by our foreign subsidiaries.


(2)	The borrowing base under the $80.0 million Revolver was $73.4 million, which was further reduced by $15.0 million of restricted liquidity and $5.9 million in supporting letters of credit outstanding, resulting in availability under the revolver of $52.5 million.

The earnings of foreign subsidiaries as of June 30, 2018 were reinvested to fund our international operations. If in the future we decide to repatriate earnings, the Company may be required to pay taxes on these amounts, which could reduce the liquidity of the Company at that time.

We do not have any unconsolidated special-purpose entities, off-balance sheet financing arrangements or guarantees of third-party financial obligations. As of June 30, 2018, we have no energy, commodity, or foreign currency derivative contracts.

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Cash Flow Activity

As of June 30, 2018, we had cash and cash equivalents of $114.5 million, a decrease of $27.1 million from cash and cash equivalents of $141.5 million at December 31, 2017. The following table provides a summary of our cash flow activity:



	Six Months Ended June 30,
Dollars in thousands	2018			2017
Operating activities	$	8,031		$	(17,568	)
Investing activities	(31,698		)	(26,374		)
Financing activities	(3,423		)	70,485
Net change in cash and cash equivalents	$	(27,090	)	$	26,543

Operating Activities

Cash flows from operating activities were a source of $8.0 million and a use of $17.6 million for the six months ended June 30, 2018 and 2017, respectively. Cash flows from operating activities in each period were largely impacted by our earnings and changes in working capital. Changes in working capital were a source of cash of $0.8 million for the six months ended June 30, 2018 compared with a use of cash of $15.5 million for the six months ended June 30, 2017. In addition to the impact of earnings and working capital changes, cash flows from operating activities in each period were impacted by various non-cash charges.

It is our long-term intention to utilize our operating cash flows to fund maintenance and growth of our rental tool assets and drilling rigs. Given the current oil and natural gas services market over the past few years, our short-term focus is to preserve liquidity by managing our costs and capital expenditures. While the overall market for oilfield services remains challenging, we are beginning to see a market recovery that is expected to continue to increase our working capital and capital spending as we pursue attractive investment opportunities.

Investing Activities

Cash flows from investing activities were a use of $31.7 million and $26.4 million for the six months ended June 30, 2018 and 2017, respectively. Our primary uses of cash during the six months ended June 30, 2018 and 2017 were $32.5 million and $26.6 million, respectively, for capital expenditures. Capital expenditures in each period were primarily for tubular and other products for our Rental Tools Services business and for rig-related maintenance.

Financing Activities

Cash flows from financing activities were a use of $3.4 million for the six months ended June 30, 2018, primarily related to dividends of $1.8 million on our Convertible Preferred Stock and to the debt issuance costs incurred relating to the Fifth Amendment to the 2015 Secured Credit Agreement in the amount of $1.4 million. For the 2017 comparable period, cash flows from financing activities were a source of $70.5 million for the six months ended June 30, 2017, primarily related to the issuances of common stock and Convertible Preferred Stock, which yielded combined proceeds of $72.3 million, net of underwriting discount and offering expenses.

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Long-Term Debt Summary

Our principal amount of long-term debt, including current portion, was $585.0 million as of June 30, 2018 which consisted of:

•$360.0 million aggregate principal amount of 6.75% Notes (defined below); and

•$225.0 million aggregate principal amount of 7.50% Notes (defined below).

6.75% Senior Notes, due July 2022

7.50% Senior Notes, due August 2020

2015 Secured Credit Agreement

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Consolidated Interest Coverage Ratio, Senior Secured Leverage Ratio, and Asset Coverage Ratio, many of which were suspended beginning in September 2015.

Our Revolver is available for general corporate purposes and to support letters of credit. Interest on Revolver loans accrues at either:


•	Base Rate plus an Applicable Rate or


•	LIBOR plus an Applicable Rate.

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FORWARD-LOOKING STATEMENTS

This Form 10-Q contains statements that are “forward-looking statements” within the meaning of Section 27A of the Securities Act of 1933, as amended (the Securities Act), and Section 21E of the Securities Exchange Act of 1934, as amended, (the Exchange Act). All statements contained in this Form 10-Q, other than statements of historical facts, are forward-looking statements for purposes of these provisions. In some cases, you can identify these statements by forward-looking words such as “anticipate,” “believe,” “could,” “estimate,” “expect,” “intend,” “outlook,” “may,” “should,” “plan,” “seek,” “forecast,” “target,” “will,” and “would” or similar words. Forward-looking statements are based on certain assumptions and analyses we make in light of our experience and perception of historical trends, current conditions, expected future developments, and other factors we believe are relevant. Although we believe our assumptions are reasonable based on information currently available, those assumptions are subject to significant risks and uncertainties, many of which are outside of our control. Each forward-looking statement speaks only as of the date of this Form 10-Q, and we undertake no obligation to publicly update or revise any forward-looking statements, whether as a result of new information, future events, or otherwise. You should be aware that certain events could have a material adverse effect on our business, results of operations, financial condition, and cash flows. For more information about such events, see “Risk Factors” described in Item 1A. of the Company’s Annual Report filed on Form 10-K, along with additional risk factors described from time to time in our SEC filings.

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Item 3. Quantitative and Qualitative Disclosures about Market Risk

There has been no material change in the market risk faced by us from that reported in our 2017 Form 10-K. For more information on market risk, see Part II, Item 7A in our 2017 Form 10-K.

Item 4. Controls and Procedures

Management’s Evaluation of Disclosure Controls and Procedures

In accordance with Rules 13a-15 and 15d-15 under the Securities Exchange Act of 1934, as amended (the Exchange Act), we carried out an evaluation, under the supervision and with the participation of management, including our Chief Executive Officer and Chief Financial Officer, of the effectiveness of our disclosure controls and procedures as of the end of the period covered by this report. Based on that evaluation, our Chief Executive Officer and Chief Financial Officer concluded that our disclosure controls and procedures were effective, as of June 30, 2018, to provide reasonable assurance that information required to be disclosed in our reports filed or submitted under the Exchange Act is (1) accumulated and communicated to our management, including our Chief Executive Officer and our Chief Financial Officer, to allow timely decisions regarding required disclosure and is (2) recorded, processed, summarized and reported within the time periods specified in the Securities and Exchange Commission’s rules and forms.

Changes in Internal Control Over Financial Reporting

There have been no changes in our internal control over financial reporting (as defined in Rules 13a-15(f) and 15d-15(f) under the Exchange Act) during our most recent fiscal quarter that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

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PART II. OTHER INFORMATION

Item 1. Legal Proceedings

For information regarding legal proceedings, see Note 6 - Commitments and Contingencies in Item 1 of Part I of this quarterly report on Form 10-Q, which information is incorporated into this item by reference.

Item 1A. Risk Factors

The statements in this section describe the known material risks to our business and should be considered carefully. Except as set forth below, there have been no material changes in risk factors previously disclosure in our Annual Report on Form 10-K for the fiscal year ended December 31, 2017.

We are currently out of compliance with the New York Stock Exchange’s minimum share price requirement, and are at risk of the NYSE delisting our common stock, which would have an adverse impact on the trading volume, liquidity and market price of our common stock and would result in a “fundamental change” under the terms of our outstanding Convertible Preferred Stock.

On March 14, 2018, we received a notice from the NYSE that the average closing price of our common stock over a 30 consecutive trading day period was below $1.00 per share, which is below the minimum closing price required by NYSE listing standards. To increase the average trading price of our common stock, our stockholders approved a 1-for-15 reverse stock split that became effective on July 27, 2018, resulting in a closing price of our common stock on July 27, 2018 of $4.97. Accordingly, we will regain compliance if on the last trading day of any calendar month our common stock has a closing share price of at least $1.00 and an average closing share price of at least $1.00 over the 30 trading-day period ending on the last trading day of such month. If we do not regain compliance within six months of receipt of notice from the NYSE, the NYSE will commence suspension and delisting procedures.

There can be no assurance that the reverse stock split will be sufficient to bring our common stock into compliance with the NYSE’s minimum listing standards. Furthermore, even if our common stock regains compliance with NYSE listing standards, we cannot assure you that the average closing price of our common stock over a consecutive 30 trading-day period will not fall below $1.00 per share in the future.

A delisting of our common stock from the NYSE could negatively impact us as it would likely reduce the liquidity and market price of our common stock; reduce the number of investors willing to hold or acquire our common stock; and negatively impact our ability to access equity markets and obtain financing. Moreover, a delisting of our common stock would constitute a “fundamental change” under the terms of our Convertible Preferred Stock, which might require us to reserve a significantly greater number of shares of our common stock for issuance upon conversion of the Convertible Preferred Stock and deplete the number of authorized shares of common stock available for issuance for other purposes.

We have a significant level of debt, which could have significant consequences for our business and future prospects.

As of June 30, 2018, we had $585.0 million principal amount of long-term debt, operating lease commitments, and $5.9 million of standby letters of credit. Our ability to meet our debt service obligations depends on our ability to generate positive cash flows from operations. We have in the past, and may in the future, incur negative cash flows from one or more segments of our operating activities. Our future cash flows from operating activities will be influenced by the demand for our drilling services, the utilization of our rigs, the dayrates that we receive for our rigs, demand for our rental tools, oil and natural gas prices, general economic conditions, and other factors affecting our operations, many of which are beyond our control.

If we are unable to service our debt obligations, we may have to take one or more of the following actions:


•	delay spending on capital projects, including maintenance projects and the acquisition or construction of additional rigs, rental tools, and other assets;


•	issue additional equity;


•	sell assets; or


•	restructure or refinance our debt.

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Despite our current level of indebtedness, we may still be able to incur more debt. This could further exacerbate the risks associated with our substantial indebtedness, including limiting our liquidity and our ability to pursue other business opportunities.

In addition to our currently outstanding debt, at June 30, 2018, our 2015 Secured Credit Agreement provides us with a revolver of up to $80.0 million. In addition, although the 2015 Credit Agreement and the indentures that govern our Senior Notes contain restrictions on the incurrence of additional indebtedness, these restrictions are subject to a number of qualifications and exceptions, and the additional indebtedness incurred in compliance with these restrictions could be substantial. If new debt is added to our current debt levels, the related risks that we now face could intensify. Our level of indebtedness could, for instance, prevent us from engaging in transactions that might otherwise be beneficial to us or from making desirable capital expenditures. This could put us at a competitive disadvantage relative to other less leveraged competitors that have more cash flow to devote to their operations. In addition, the incurrence of additional debt could make it more difficult to satisfy our existing financial obligations.

Increases in the level of our debt and restrictions in the covenants contained in the instruments governing our debt could have important consequences to you. For example, they could:


•	result in a reduction of our credit rating, which would make it more difficult for us to obtain additional financing on acceptable terms;


•	require us to dedicate a substantial portion of our cash flows from operating activities to the repayment of our debt and the interest associated with our debt;


•	limit our operating flexibility due to financial and other restrictive covenants, including restrictions on incurring additional debt and creating liens on our properties;


•	place us at a competitive disadvantage compared with our competitors that have relatively less debt; and


•	make us more vulnerable to downturns in our business.

Our ability to borrow under our 2015 Secured Credit Agreement is subject to borrowing base and liquidity requirements, and the 2015 Secured Credit Agreement and the indentures for our Senior Notes impose significant operating and financial restrictions, which may prevent us in the future from obtaining financing or capitalizing on business opportunities.

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 monthly borrowing base calculation. As of June 30, 2018 the borrowing base under the $80 million Revolver was $73.4 million, which was further reduced by $15.0 million of restricted liquidity and $5.9 million in supporting letters of credit, resulting in availability under the revolver of $52.5 million.

Further, the 2015 Secured Credit Agreement grants the administrative agent for the lenders under such agreement significant discretion to establish additional reserves, which may further reduce our borrowing base availability. If a reduction in our borrowing base results in the outstanding amount under the facility exceeding the borrowing base less restricted liquidity, we will be required to repay the deficiency and cash collateralize any outstanding letters of credit. These covenants may adversely affect our ability to finance our future operations and capital needs and to pursue available business opportunities.

The 2015 Secured Credit Agreement, the amendments thereto, and the indentures governing our Senior Notes also impose significant operating and financial restrictions on us. These restrictions limit our ability to:


•	make investments and other restricted payments, including dividends;


•	incur additional indebtedness;


•	create liens;


•	engage in sale leaseback transactions;


•	repurchase our common stock or Senior Notes;


•	sell our assets or consolidate or merge with or into other companies; and


•	engage in transactions with affiliates.

These limitations are subject to a number of important qualifications and exceptions.

A breach of any of the covenants in the 2015 Secured Credit Agreement or in the Senior Notes could result in a default with respect to the related indebtedness. If a default were to occur, the lenders under our 2015 Secured Credit Agreement and the holders of our Senior Notes could elect to declare the indebtedness, if any outstanding at that time, together with accrued interest, immediately due and payable. If the repayment of the indebtedness were to be accelerated after any applicable notice or grace periods, we may not have sufficient funds to repay the indebtedness.

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We may be unable to repay or refinance our debt as it becomes due, whether at maturity or as a result of acceleration.

We may not be able to repay our debt as it comes due, or to refinance our debt on a timely basis or on terms acceptable to us and within the limitations contained in the 2015 Secured Credit Agreement and the indentures governing our outstanding Senior Notes. Our 2015 Secured Credit Facility matures in January 2020, and certain of our Senior Notes mature in August 2020. Failure to repay or to timely refinance any portion of our debt could result in a default under the terms of all our debt instruments and permit the acceleration of all indebtedness outstanding.

While we intend to take appropriate mitigating actions to refinance our indebtedness prior to maturity or otherwise extend the maturity dates, and to cure any potential defaults, there is no assurance that any particular actions with respect to refinancing existing indebtedness, extending the maturity of existing indebtedness or curing potential defaults in our existing and future debt agreements will be sufficient.

Item 2. Unregistered Sales of Equity Securities and Use of Proceeds

The Company currently has no active share repurchase programs.

Item 3. Defaults Upon Senior Securities

None.

Item 4. Mine Safety Disclosures

None.

Item 5. Other Information

None.

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Item 6. Exhibits

The following exhibits are filed or furnished as a part of this report:



Exhibit Number		Description

3.1	—	Restated Certificate of Incorporation of the Company, as amended on May 16, 2007 (incorporated by reference to Exhibit 3.1 to the Company’s Quarterly Report on Form 10-Q filed on November 9, 2007).

3.2	—	By-laws of the Company, as amended and restated as of March 9, 2017 (incorporated by reference to Exhibit 3.1 to the Company’s Current Report on Form 8-K filed on March 14, 2017).

3.3	—	Certificate of Designations of 7.25% Series A Mandatory Convertible Preferred Stock of Parker Drilling Company, dated February 27, 2017 (incorporated by reference to Exhibit 3.1 to the Company’s Current Report on Form 8-K filed on February 27, 2017).

3.4	—	Certificate of Designations of Series A Junior Participating Preferred Stock of Parker Drilling Company (incorporated by reference to Exhibit 3.2 to the Company’s Current Report on Form 8-K filed on July 13, 2018).

3.5	—	Certificate of Amendment of the Restated Certificate of Incorporation of Parker Drilling Company (incorporated by reference to Exhibit 3.1 to the Company’s Current Report on Form 8-K filed on July 13, 2018).

4.1	—	Rights Agreement, dated as of July 12, 2018, between Parker Drilling Company and Equiniti Trust Company, as Rights Agent (incorporated by reference to Exhibit 4.1 to the Company’s Current Report on Form 8-K filed on July 13, 2018).

10.1	—	Sixth Amendment to the Second Amendment and Restated Credit Agreement, dated July 12, 2018, among Parker Drilling Company, as Borrower, Bank of America, N.A., as Administrative Agent and L/C Issuer, Wells Fargo Bank, National Association, as Syndication Agent, Barclays Bank PLC, as Documentation Agent, and the other lenders and L/C issuers from time to time party thereto (incorporated by reference to Exhibit 10.1 to the Company’s Current Report on Form 8-K filed on July 13, 2018).

10.2	—	Parker Drilling Company 2018 Annual Incentive Cash Compensation Plan (incorporated by reference to Exhibit 10.1 to the Company’s Current Report on Form 8-K filed on June 26, 2018).

12.1	—	Computation of Ratio of Earnings to Fixed Charges.

31.1	—	Gary G. Rich, Chairman, President and Chief Executive Officer, Rule 13a-14(a)/15d-14(a) Certification.

31.2	—	Michael W. Sumruld, Senior Vice President and Chief Financial Officer, Rule 13a-14(a)/15d-14(a) Certification.

32.1	—	Gary G. Rich, Chairman, President and Chief Executive Officer, 18 U.S.C. Section 1350 Certification.

32.2	—	Michael W. Sumruld, Senior Vice President and Chief Financial Officer, 18 U.S.C. Section 1350 Certification.

101.INS	—	XBRL Instance Document.

101.SCH	—	XBRL Taxonomy Schema Document.

101.CAL	—	XBRL Calculation Linkbase Document.

101.LAB	—	XBRL Label Linkbase Document.

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101.PRE	—	XBRL Presentation Linkbase Document.

101.DEF	—	XBRL Definition Linkbase Document.

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SIGNATURES

Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.




		PARKER DRILLING COMPANY

Date:	August 2, 2018	By:	/s/ Gary G. Rich
			Gary G. Rich Chairman, President and Chief Executive Officer

		By:	/s/ Michael W. Sumruld
			Michael W. Sumruld Senior Vice President and Chief Financial Officer