Parker Drilling 10Q 2015 Q1 Quarterly report

Parker Drilling (PKDC) 10-Q2015 Q1 Quarterly report

Content analysis

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 March 31, 2015



¨	TRANSITION REPORT PURSUANT TO SECTION 13 OR 15 (d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the transition period from to

Commission File Number 1-7573

PARKER DRILLING COMPANY

(Exact name of registrant as specified in its charter)



Delaware		73-0618660
(State or other jurisdiction of incorporation or organization)		(I.R.S. Employer Identification No.)

5 Greenway Plaza, Suite 100, Houston, Texas		77046
(Address of principal executive offices)		(Zip code)

(281) 406-2000

(Registrant’s telephone number, including area code)

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. Yes x No ¨

Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files. Yes x No ¨

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

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 May 4, 2015 there were 122,284,611 common shares outstanding.

TABLE OF CONTENTS



	Page
Part I. Financial Information
Item 1. Financial Statements	3
Consolidated Condensed Balance Sheets as at March 31, 2015 (Unaudited) and December 31, 2014	3
Consolidated Condensed Statements of Operations (Unaudited) for the Three Months Ended March 31, 2015 and 2014	4
Consolidated Condensed Statements of Comprehensive Income (Loss) (Unaudited) for the Three Months Ended March 31, 2015 and 2014	5
Consolidated Condensed Statements of Cash Flows (Unaudited) for the Three Months Ended March 31, 2015 and 2014	6
Notes to the Unaudited Consolidated Condensed Financial Statements	7
Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations	24
Item 3. Quantitative and Qualitative Disclosures about Market Risk	34
Item 4. Controls and Procedures	34

Part II. Other Information
Item 1. Legal Proceedings	35
Item 1A. Risk Factors	35
Item 2. Unregistered Sales of Equity Securities and Use of Proceeds	35
Item 3. Defaults Upon Senior Securities	35
Item 4. Mine Safety Disclosures	35
Item 5. Other Information	35
Item 6. Exhibits	36
Signatures	37

PART I. FINANCIAL INFORMATION

Item 1. Financial Statements

PARKER DRILLING COMPANY AND SUBSIDIARIES

CONSOLIDATED CONDENSED BALANCE SHEETS

(Dollars in Thousands)



	March 31, 2015			December 31, 2014
	(Unaudited)
ASSETS
Current assets:
Cash and cash equivalents	$	113,199		$	108,456
Accounts and Notes Receivable, net of allowance for bad debts of $9,289 at March 31, 2015 and $11,188 at December 31, 2014.	279,420			270,952
Rig materials and supplies	50,336			47,943
Deferred costs	6,432			5,673
Deferred income taxes	5,648			7,476
Other tax assets	9,200			10,723
Other current assets	19,018			18,556
Total current assets	483,253			469,779
Property, plant and equipment, net of accumulated depreciation of $1,223,119 at March 31, 2015 and $1,201,058 at December 31, 2014.	885,233			895,940
Debt issuance costs	13,434			12,526
Deferred income taxes	135,820			122,689
Other noncurrent assets	22,575			19,725
Total assets	$	1,540,315		$	1,520,659
LIABILITIES AND STOCKHOLDERS' EQUITY
Current liabilities:
Current portion of long-term debt	$	—		$	10,000
Accounts payable and accrued liabilities	193,932			154,479
Accrued income taxes	15,467			14,186
Total current liabilities	209,399			178,665
Long-term debt	585,000			605,000
Other long-term liabilities	18,559			18,665
Long-term deferred tax liability	58,312			52,115
Contingencies (Note 10)
Stockholders’ equity:
Common stock	20,342			20,325
Capital in excess of par value	668,324			666,769
Accumulated deficit	(20,943		)	(24,165		)
Accumulated other comprehensive income	(2,855		)	(498		)
Total controlling interest stockholders’ equity	664,868			662,431
Noncontrolling interest	4,177			3,783
Total equity	669,045			666,214
Total liabilities and stockholders’ equity	$	1,540,315		$	1,520,659

See accompanying notes to the unaudited consolidated condensed financial statements.

PARKER DRILLING COMPANY AND SUBSIDIARIES

CONSOLIDATED CONDENSED STATEMENTS OF OPERATIONS

(Dollars in Thousands, Except Per Share Data)

(Unaudited)



	Three Months Ended March 31,
	2015			2014
Revenues	$	204,076		$	229,225
Expenses:
Operating expenses	139,270			166,025
Depreciation and amortization	40,539			34,337
	179,809			200,362
Total operating gross margin	24,267			28,863
General and administration expense	(10,837		)	(8,964		)
Gain (loss) on disposition of assets, net	2,441			(129		)
Total operating income	15,871			19,770
Other income and (expense):
Interest expense	(11,078		)	(12,039		)
Interest income	183			32
Loss on extinguishment of debt	—			(29,673		)
Other	(1,380		)	895
Total other expense	(12,275		)	(40,785		)
Income (loss) before income taxes	3,596			(21,015		)
Income tax (benefit)	(182		)	(8,623		)
Net income (loss)	3,778			(12,392		)
Less: Net income attributable to noncontrolling interest	556			157
Net income (loss) attributable to controlling interest	$	3,222		$	(12,549	)
Basic earnings per share	$	0.03		$	(0.10	)
Diluted earnings per share	$	0.03		$	(0.10	)

Number of common shares used in computing earnings per share:
Basic	121,887,072			120,368,650
Diluted	123,708,623			120,368,650

See accompanying notes to the unaudited consolidated condensed financial statements.

PARKER DRILLING COMPANY AND SUBSIDIARIES

CONSOLIDATED CONDENSED STATEMENTS OF COMPREHENSIVE INCOME (LOSS)

(Dollars in Thousands)

(Unaudited)



	Three Months Ended March 31,
	2015			2014
Comprehensive income:
Net income (loss)	$	3,778		$	(12,392	)
Other comprehensive income (loss), net of tax:
Currency translation difference on related borrowings	(1,670		)	(804		)
Currency translation difference on foreign currency net investments	(849		)	699
Total other comprehensive income (loss), net of tax:	(2,519		)	(105		)
Comprehensive income (loss)	1,259			(12,497		)
Comprehensive (income) attributable to noncontrolling interest	(394		)	(154		)
Comprehensive income (loss) attributable to controlling interest	$	865		$	(12,651	)

See accompanying notes to the unaudited consolidated condensed financial statements.

PARKER DRILLING COMPANY AND SUBSIDIARIES

CONSOLIDATED CONDENSED STATEMENTS OF CASH FLOWS

(Dollars in Thousands)

(Unaudited)



	Three Months Ended March 31,
	2015			2014
Cash flows from operating activities:
Net income (loss)	$	3,778		$	(12,392	)
Adjustments to reconcile net income to net cash flows from operating activities:
Depreciation and amortization	40,539			34,337
Loss on extinguishment of debt	—			29,673
(Gain) loss on disposition of assets	(2,441		)	129
Deferred income tax benefit	(6,304		)	(12,292		)
Expenses not requiring cash	1,737			6,844
Change in assets and liabilities:
Accounts and notes receivable	(6,650		)	(6,226		)
Other assets	(20,087		)	(394		)
Accounts payable and accrued liabilities	54,045			(8,205		)
Accrued income taxes	2,614			150
Net cash provided by operating activities	67,231			31,624

Cash flows from investing activities:
Capital expenditures	(33,455		)	(37,445		)
Proceeds from the sale of assets	246			1,626
Proceeds from insurance settlements	2,500			—
Net cash (used in) investing activities	(30,709		)	(35,819		)

Cash flows from financing activities:
Proceeds from issuance of debt	—			400,000
Repayments of long-term debt	(30,000		)	(418,699		)
Payments of debt issuance costs	(1,359		)	(7,273		)
Payments of debt extinguishment costs	—			(25,796		)
Excess tax benefit (expense) from stock based compensation	(420		)	335
Net cash (used in) financing activities	(31,779		)	(51,433		)

Net increase (decrease) in cash and cash equivalents	4,743			(55,628		)
Cash and cash equivalents, beginning of year	108,456			148,689
Cash and cash equivalents, end of period	$	113,199		$	93,061

Supplemental cash flow information:
Interest paid	$	20,805		$	20,443
Income taxes paid	$	4,601		$	4,131

See accompanying notes to the unaudited consolidated condensed financial statements.

PARKER DRILLING COMPANY AND SUBSIDIARIES

NOTES TO THE UNAUDITED CONSOLIDATED CONDENSED FINANCIAL STATEMENTS

Note 1 - General

In the opinion of the management of Parker Drilling Company (Parker Drilling or the Company), the accompanying unaudited consolidated condensed financial statements reflect all adjustments normally recurring which we believe are necessary for a fair presentation of: (1) Parker Drilling’s financial position as of March 31, 2015 and December 31, 2014, (2) Parker Drilling’s results of operations for the three month periods ended March 31, 2015 and 2014, (3) Parker Drilling’s consolidated condensed statement of comprehensive income for the three month periods ended March 31, 2015 and 2014, and (4) Parker Drilling’s cash flows for the three month periods ended March 31, 2015 and 2014. Results for the three month period ended March 31, 2015 are not necessarily indicative of the results that will be realized for the year ending December 31, 2015. The financial statements should be read in conjunction with our Annual Report on Form 10-K for the year ended December 31, 2014.

Nature of Operations — We are an international provider of drilling services and rental tools. We have operated in over 50 countries since beginning operations in 1934, making us among the most geographically experienced drilling contractors and rental tools providers in the world. We currently have operations in 23 countries. We believe we are an industry leader in quality, health, safety and environmental practices.

Our business is comprised of two business lines: (1) Drilling Services and (2) Rental Tools Services. We have completed a business review and as a result have aligned our reportable segments with our two core business lines and our current internal organizational structure. We continue to report our Rental Tools Services business as one reportable segment (Rental Tools); however, effective with the first quarter of 2015, the Company is reporting its Drilling Services business as two segments: (1) U.S. (Lower 48) Drilling and (2) International & Alaska Drilling.

In our Drilling Services business, we own and operate drilling rigs and drilling-related equipment and also perform drilling-related services, referred to as operations and maintenance (O&M) services, for customer-owned drilling rigs on a contracted basis. In addition, we provide engineering and related services during concept development, pre-FEED (Front End Engineering Design) and FEED phases of customer-owned drilling facility projects. We have extensive experience and expertise in drilling geologically difficult wells and in managing the logistical and technological challenges of operating in remote, harsh and ecologically sensitive areas. Our U.S. (Lower 48) Drilling segment includes our Gulf of Mexico (GOM) barge drilling fleet and 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 water depths of 6 to 12 feet. Our International & Alaska Drilling segment includes operations related to Parker-owned and customer-owned rigs as well as project related services. We provide O&M and other project management services, such as labor, maintenance, technical and logistics support for operators who own their own drilling rigs, but choose Parker Drilling to operate the rigs for them.

In our Rental Tools Services business, we provide premium rental equipment and services to exploration and production companies, drilling contractors and service companies on land and offshore in the United States (U.S.) and select international markets. Tools we provide include drill collars, standard and heavy-weight drill pipe, all of which are available with standard or high-torque connections, tubing, and pressure control equipment including blow-out preventers (BOPs). We also provide well construction services which include tubular running services and downhole tools and well intervention services which include whip stock, fishing products and services, as well as inspection and machine shop support.

Consolidation — The consolidated 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.

Noncontrolling Interest — We apply accounting standards related to noncontrolling interests for ownership interests in our subsidiaries held by parties other than Parker Drilling. The entities that comprise the noncontrolling interest include ITS Arabia Limited and ITS Egypt SAE. We report noncontrolling interest as equity on the consolidated balance sheets and report net income (loss) attributable to controlling interest and to noncontrolling interest separately on the consolidated statements of operations.

Reclassifications — Certain reclassifications have been made to prior period amounts to conform to the current period presentation. These reclassifications did not materially affect our consolidated financial results.

Revenue Recognition — Drilling revenues and expenses, comprised of daywork drilling contracts, call-outs against master service agreements and engineering and related project service contracts, are recognized as services are performed and collection is reasonably assured. For certain contracts, we receive payments contractually designated for the mobilization of rigs and other drilling equipment. Mobilization payments received, and direct costs incurred for the mobilization, are deferred and recognized over the primary term of the related drilling contract; however, costs incurred to relocate rigs and other drilling equipment to areas in which a contract has not been secured are expensed as incurred. Reimbursements received for out-of-pocket expenses are recorded as both revenues and direct costs. For contracts that are terminated prior to the specified term, early termination payments received by us are recognized as revenues when all contractual requirements are met. Revenues from rental activities are recognized ratably over the rental term which is generally less than six months. Our project related services contracts include engineering, consulting, and project management scopes of work and revenue is typically recognized on a time and materials basis.

Reimbursable Costs — The Company recognizes reimbursements received for out-of-pocket expenses incurred as revenues and accounts for out-of-pocket expenses as direct operating costs. Such amounts totaled $19.7 million and $16.4 million during the first quarters of 2015 and 2014, respectively. Additionally, the Company typically receives a nominal handling fee, which is recognized as earned revenues in our consolidated statement of operations.

Use of Estimates — The preparation of financial statements in accordance with accounting policies generally accepted in the United States (U.S. GAAP) requires us 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 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.

Intangible Assets – Our intangible assets are related to trade names, customer relationships, and developed technology, which are associated with a previous acquisition and are generally amortized over a weighted average period of approximately three 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.

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 major, independent, national and international oil and gas companies and integrated service providers. We generally do not require collateral on our trade receivables.

At March 31, 2015 and December 31, 2014, we had deposits in domestic banks in excess of federally insured limits of approximately $47.1 million and $59.3 million, respectively. In addition, as of March 31, 2015 and December 31, 2014, we had deposits in foreign banks, which were not insured of $66.1 million and $54.4 million, respectively.

Our customer base primarily consists of major, independent, national and international oil and gas companies and integrated service providers. We depend on a limited number of significant customers. Our largest customer, Exxon Neftegas Limited (ENL), constituted approximately 22.9% of our revenues for the three months ended March 31, 2015. Each of our segments depends on a limited number of key customers and the loss of any one or more key customers could have a material adverse effect on a segment.

Note 2 - Acquisition of ITS

On April 22, 2013 we acquired International Tubular Services Limited (ITS) and related assets (the ITS Acquisition) for an initial purchase price of $101.0 million paid at the closing of the ITS Acquisition. An additional $24.0 million was deposited into an escrow account, to be payable to the seller or to us, as the case may be, in accordance with the ITS Acquisition agreement (the Acquisition Agreement). As of March 31, 2015, $10.8 million of the cash deposited in escrow has been released to the seller and $3.2 million has been released to us. Based on the terms of the Acquisition Agreement, we estimate that the entire $10.0 million remaining in escrow will be paid to the seller (or to third parties on behalf of the seller).

Note 3 - Earnings per share (EPS)



	Three Months Ended March 31, 2015
	Income (Numerator)			Shares (Denominator)	Per-Share Amount
Basic EPS	$	3,222,000		121,887,072	$	0.03
Effect of dilutive securities:
Restricted stock units	—			1,821,551	—
Diluted EPS	$	3,222,000		123,708,623	$	0.03

	Three Months Ended March 31, 2014
	Income (Numerator)			Shares (Denominator)	Per-Share Amount
Basic EPS	$	(12,549,000	)	120,368,650	$	(0.10	)
Effect of dilutive securities:
Restricted stock units	—			—	—
Diluted EPS	$	(12,549,000	)	120,368,650	$	(0.10	)

For the three months ended March 31, 2015, weighted-average shares outstanding used in our computation of diluted EPS includes the dilutive effect of common shares potentially issuable in connection with outstanding restricted stock unit awards.

For the three months ended March 31, 2014, 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 a loss during the quarter, and therefore, inclusion of such potential common shares in the calculation would be anti-dilutive.

Note 4 - Accumulated Other Comprehensive Income

Accumulated other comprehensive income consisted of the following:



Dollars in thousands	Foreign Currency Items
December 31, 2014	$	(498	)
Current period other comprehensive income (loss)	(2,357		)
March 31, 2015	$	(2,855	)

No amounts were reclassified out of accumulated other comprehensive income for the three months ended March 31, 2015. The other comprehensive income for the current period includes an increase in the exchange rate on related borrowings primarily in Colombia.

Note 5 - Reportable Segments

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



	Three Months Ended March 31,
Dollars in thousands	2015			2014
Revenues: ⁽¹⁾
U.S. (Lower 48) Drilling	$	14,097		$	35,787
International & Alaska Drilling	113,921			112,932
Rental Tools	76,058			80,506
Total revenues	204,076			229,225
Operating gross margin: ⁽²⁾
U.S. (Lower 48) Drilling	(5,717		)	8,742
International & Alaska Drilling	17,354			6,776
Rental Tools	12,630			13,345
Total operating gross margin	24,267			28,863
General and administrative expense	(10,837		)	(8,964		)
Gain (loss) on disposition of assets, net	2,441			(129		)
Total operating income	15,871			19,770
Interest expense	(11,078		)	(12,039		)
Interest income	183			32
Loss on extinguishment of debt	—			(29,673		)
Other income (loss)	(1,380		)	895
Income (loss) from continuing operations before income taxes	$	3,596		$	(21,015	)

(1)For the three months ended March 31, 2015, our largest customer, Exxon Neftegas Limited (ENL), constituted approximately 22.9% of our total consolidated revenues and approximately 41.0% of our International & Alaska Drilling segment revenues. For the three months ended March 31, 2014, our largest customer, ENL, constituted approximately 17.1% of our total consolidated revenues and approximately 39.6% of our International & Alaska Drilling segment revenues.

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

Note 6 - Accounting for Uncertainty in Income Taxes

We apply the accounting guidance related to accounting for uncertainty in income taxes. This guidance prescribes a recognition threshold and a measurement attribute for the financial statement recognition and measurement of tax positions taken or expected to be taken in a tax return. For those benefits to be recognized, a tax position must be more likely than not to be sustained upon examination by taxing authorities. At March 31, 2015, we had a liability for unrecognized tax benefits of $8.2 million (which includes $3.6 million of benefits which would favorably impact our effective tax rate upon recognition), primarily related to foreign operations. As of March 31, 2014, we had a liability for unrecognized tax benefits of $12.4 million ($5.6 million of which, if recognized, would favorably impact our effective tax rate). In addition, we recognize interest and penalties that could be applied to uncertain tax positions in periodic income tax expense. As of March 31, 2015 and December 31, 2014, we had approximately $3.4 million and $3.3 million, respectively, of accrued interest and penalties related to uncertain tax positions. Management believes that the Company is properly reserved with respect to accounting for uncertainty in income taxes.

Note 7 - Income Tax Benefit/Expense

During the first quarter of 2015 we had an income tax benefit of $0.2 million compared to a benefit of $8.6 million for the first quarter of 2014. The current period income tax benefit is primarily a result of changes in the carrying value of certain deferred tax assets due to changes in tax law and taxing jurisdictions during the first quarter of 2015. The income tax benefit in the first quarter of 2014 was primarily due to a reduction of pre-tax earnings primarily driven by the debt extinguishment costs recorded during the first quarter of 2014.

Note 8 - Long-Term Debt

The following table illustrates our debt portfolio as of March 31, 2015 and December 31, 2014:



Dollars in thousands	March 31, 2015		December 31, 2014
6.75% Senior Notes, due July 2022	$	360,000	$	360,000
7.50% Senior Notes, due August 2020	225,000		225,000
Term Note, due December 2017	—		30,000
Total debt	585,000		615,000
Less current portion ⁽¹⁾	—		10,000
Total long-term debt	$	585,000	$	605,000

(1) Current portion of the Term Loan.

6.75% Senior Notes, due July 2022

On January 22, 2014, we issued $360.0 million aggregate principal amount of 6.75% Senior Notes due 2022 (6.75% Notes) pursuant to an Indenture between the Company and The Bank of New York Mellon Trust Company, N.A., as trustee. Net proceeds from the 6.75% Notes offering plus a $40.0 million Term Loan draw under the Amended and Restated Senior Secured Credit Agreement (2012 Secured Credit Agreement) and cash on hand were utilized to purchase $416.2 million aggregate principal amount of our outstanding 9.125% Senior Notes due 2018 (9.125% Notes) pursuant to a tender and consent solicitation offer commenced on January 7, 2014. See further discussion of the tender and consent solicitation offer below entitled "9.125% Senior Notes, due April 2018".

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 (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 ($6.8 million net of amortization as of March 31, 2015) are being amortized over the term of the notes using the effective interest rate method.

decreasing each year thereafter to par beginning January 15, 2020. If we experience certain changes in control, we must offer to repurchase the 6.75% Notes at 101.0 percent of the aggregate principal amount, plus accrued and unpaid interest and additional interest, if any, to the date of repurchase.

The Indenture restricts our ability and the ability of certain subsidiaries to: (i) sell assets, (ii) pay dividends or make other distributions on capital stock or redeem or repurchase capital stock or subordinated indebtedness, (iii) make investments, (iv) incur or guarantee additional indebtedness, (v) create or incur liens, (vi) enter into sale and leaseback transactions, (vii) incur dividend or other payment restrictions affecting subsidiaries, (viii) merge or consolidate with other entities, (ix) enter into transactions with affiliates, and (x) engage in certain business activities. Additionally, the Indenture contains certain restrictive covenants designating certain events as Events of Default. These covenants are subject to a number of important exceptions and qualifications.

7.50% Senior Notes, due August 2020

On July 30, 2013, we issued $225.0 million aggregate principal amount of the 7.50% Notes pursuant to an Indenture between the Company and The Bank of New York Mellon Trust Company, N.A., as trustee. Net proceeds from the 7.50% Notes offering were primarily used to repay the $125.0 million aggregate principal amount of a term loan used to initially finance the ITS Acquisition, to repay $45.0 million of Term Loan borrowings under the 2012 Secured Credit Agreement and for general corporate purposes.

The 7.50% Notes are general unsecured obligations of the Company and rank equal in right of payment with all of our existing and future senior unsecured indebtedness. The 7.50% Notes are jointly and severally guaranteed by all of our subsidiaries that guarantee indebtedness under the 2015 Secured Credit Agreement and the 6.75% Notes. Interest on the 7.50% Notes is payable on February 1 and August 1 of each year, beginning February 1, 2014. Debt issuance costs related to the 7.50% Notes of approximately $5.6 million ($4.5 million, net of amortization as of March 31, 2015) are being amortized over the term of the notes using the effective interest rate method.

At any time prior to August 1, 2016, we may redeem up to 35 percent of the aggregate principal amount of the 7.50% Notes at a redemption price of 107.50 percent of the principal amount, plus accrued and unpaid interest to the redemption date, with the net cash proceeds of certain equity offerings by us. On and after August 1, 2016, we may redeem all or a part of the 7.50% Notes upon appropriate notice, at a redemption price of 103.750 percent of the principal amount, and at redemption prices decreasing each year thereafter to par beginning August 1, 2018. 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.

9.125% Senior Notes, due April 2018

On March 22, 2010, we issued $300.0 million aggregate principal amount of the 9.125% Notes and on April 25, 2012, we issued an additional $125.0 million aggregate principal amount of 9.125% Notes.

On January 7, 2014, we commenced a tender and consent solicitation with respect to the 9.125% Notes. The tender offer price was $1,061.98, inclusive of a $30.00 consent payment for each $1,000 principal amount of 9.125% Notes, plus accrued and unpaid interest. On January 22, 2014, we paid $453.7 million for the tendered 9.125% Notes, comprised of $416.2 million of aggregate principal amount of the 9.125% Notes, $25.8 million of tender and consent premiums and $11.7 million of accrued interest. On April 1, 2014, we redeemed the remaining $8.8 million aggregate principal amount of the outstanding 9.125% Notes for a purchase price of $9.6 million, inclusive of a $0.4 million call premium and $0.4 million interest. During the year ended December 31, 2014, we recorded a loss on extinguishment of debt of approximately $30.2 million, which included the tender and consent premiums of $25.8 million, the call premium of $0.4 million and the write-off of unamortized debt issuance costs of $7.7 million, offset by the write-off of the remaining unamortized debt issuance premium of $3.8 million.

2015 Secured Credit Agreement

On January 26, 2015 we entered into the 2015 Secured Credit Agreement, which amended and restated the 2012 Secured Credit Agreement. The 2015 Secured Credit Agreement is comprised of a $200.0 million revolving credit facility (2015 Revolver) and matures on January 26, 2020. At the closing of the 2015 Secured Credit Agreement, we repaid the outstanding $30.0 million of Term Loan borrowings under the 2012 Secured Credit Agreement with a $30.0 million draw under the 2015 Revolver. We incurred debt issuance costs related to the 2015 Secured Credit Agreement of approximately $1.4 million and had approximately $0.8 million of remaining debt issuance costs for the 2012 Secured Credit agreement. The total debt issuance costs of $2.2 million ($2.2 million, net of amortization as of March 31, 2015) are being amortized over the term of the amended credit agreement on a straight line basis.

Our obligations under the 2015 Secured Credit Agreement are guaranteed by substantially all of our direct and indirect domestic subsidiaries, other than immaterial subsidiaries and subsidiaries generating revenues primarily outside the United States, each of which has executed guaranty agreements, and are secured by first priority liens on our accounts receivable, specified rigs including barge rigs in the GOM and land rigs in Alaska, and rental equipment of the Company and its subsidiary guarantors. The 2015 Secured Credit Agreement contains customary affirmative and negative covenants, such as limitations on indebtedness, liens, restrictions on entry into certain affiliate transactions and payments (including payment of dividends) and maintenance of certain ratios and coverage tests (including a minimum asset coverage ratio of 1.25:1.00 at each quarter end). We were in compliance with all such covenants as of March 31, 2015.

Our 2015 Revolver is available for general corporate purposes and to support letters of credit. Interest on 2015 Revolver loans accrues at a Base Rate plus an Applicable Rate or LIBOR plus an Applicable Rate. The Applicable Rate ranges from 2.50 percent to 3.00 percent per annum for LIBOR rate loans and from 1.50 percent to 2.00 percent per annum for base rate loans, determined by reference to the consolidated leverage ratio (as defined in the 2015 Secured Credit Agreement). Revolving loans are available subject to a quarterly Asset Coverage Ratio calculation based on the Orderly Liquidation Value of certain specified rigs including barge rigs in the GOM and land rigs in Alaska, and rental equipment of the Company and its subsidiary guarantors and a percentage of eligible domestic accounts receivable. The $30.0 million draw at the closing of the 2015 Secured Credit Agreement was repaid in full during the first quarter of 2015 with cash on-hand. Letters of credit outstanding against the 2015 Revolver as of March 31, 2015 totaled $11.8 million.

2012 Secured Credit Agreement

The 2012 Secured Credit Agreement consisted of an $80.0 million revolving credit facility (2012 Revolver) and a $50.0 million term loan (Term Loan). Our obligations under the 2012 Secured Credit Agreement were 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 had executed guaranty agreements, and were secured by first priority liens on our accounts receivable, specified barge rigs and rental equipment. The 2012 Secured Credit Agreement contained customary affirmative and negative covenants and would have matured on December 14, 2017.

2012 Revolver

Our 2012 Revolver was available for general corporate purposes and to support letters of credit. Interest on 2012 Revolver loans accrued at a Base Rate plus an Applicable Rate or LIBOR plus an Applicable Rate. Under the 2012 Secured Credit Agreement, the Applicable Rate ranged from 2.50 percent to 3.00 percent per annum for LIBOR rate loans and from 1.50 percent to 2.00 percent per annum for base rate loans, determined by reference to the consolidated leverage ratio (as defined in the 2012 Secured Credit Agreement). Revolving loans were available subject to a borrowing base calculation based on a percentage of eligible accounts receivable, certain specified barge drilling rigs and rental equipment of the Company and its subsidiary guarantors. There were no revolving loans outstanding at December 31, 2014. Letters of credit outstanding against the 2012 Revolver as of December 31, 2014 totaled $11.0 million.

Term Loan

The Term Loan originated at $50.0 million on December 14, 2012 and required quarterly principal payments of $2.5 million, which began March 31, 2013. Interest on the Term Loan accrued at a Base Rate plus 2.00 percent or LIBOR plus 3.00 percent. In July 2013, we repaid the outstanding balance of $45.0 million of the Term Loan and amended the 2012 Secured Credit Agreement to permit re-borrowing of up to $45.0 million of the Term Loan, decreasing by $2.5 million at the end of each quarter beginning September 30, 2013 and ending March 31, 2014. In January 2014 we re-borrowed $40.0 million of the Term Loan. The outstanding balance on the Term Loan at December 31, 2014 was $30.0 million. At the closing of the 2015 Secured Credit Agreement, we repaid the Term Loan with a $30.0 million draw under the 2015 Revolver.

Note 9 - Fair Value of Financial Instruments

Certain of our assets and liabilities are required to be measured at fair value on a recurring basis. For purposes of recording fair value adjustments for certain financial and non-financial assets and liabilities, and determining fair value disclosures, we estimate fair value at a price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants in the principal market for the asset or liability.

The fair value measurement and disclosure requirements of FASB Accounting Standards Codification Topic No. 820, Fair Value Measurement and Disclosures (ASC 820) requires inputs that we categorize using a three-level hierarchy, from highest to lowest level of observable inputs, as follows:

•Level 1 — Unadjusted quoted prices for identical assets or liabilities in active markets;


•	Level 2 — Direct or indirect observable inputs, including quoted prices or other market data, for similar assets or liabilities in active markets or identical assets or liabilities in less active markets;

•Level 3 — Unobservable inputs that require significant judgment for which there is little or no market data.

When multiple input levels are required for a valuation, we categorize the entire fair value measurement according to the lowest level of input that is significant to the entire measurement even though we may also have utilized significant inputs that are more readily observable. The amounts reported in our consolidated balance sheets for cash and cash equivalents, accounts receivable, and accounts payable approximate fair value.

Fair value of our debt instruments is determined using Level 2 inputs. Fair values and related carrying values of our debt instruments were as follows for the periods indicated:



	March 31, 2015				December 31, 2014
Dollars in thousands	Carrying Amount		Fair Value		Carrying Amount		Fair Value
Long-term Debt
6.75% Notes	$	360,000	$	285,300	$	360,000	$	270,000
7.50% Notes	225,000		180,000		225,000		180,000
Total	$	585,000	$	465,300	$	585,000	$	450,000

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 three months ended March 31, 2015.

Note 10 - Commitments and Contingencies

We are a party to various lawsuits and claims arising out of the ordinary course of business. We estimate the range of our liability related to pending litigation when we believe the amount or range of loss can be estimated. We record our best estimate of a loss when the loss is considered probable. When a liability is probable and there is a range of estimated loss with no best estimate in the range, we record the minimum estimated liability related to the lawsuits or claims. As additional information becomes available, we assess the potential liability related to our pending litigation and claims and revise our estimates. Due to uncertainties related to the resolution of lawsuits and claims, the ultimate outcome may differ significantly from our estimates. In the opinion of management and based on liability accruals provided, our ultimate exposure with respect to these pending lawsuits and claims is not expected to have a material adverse effect on our consolidated financial position or cash flows, although they could have a material adverse effect on our results of operations for a particular reporting period.

Customs Agent and Foreign Corrupt Practices Act (FCPA) Settlement

On April 16, 2013, the Company and the Department of Justice (DOJ) entered into a deferred prosecution agreement (DPA), under which the DOJ will defer for three years prosecuting the Company for criminal violations of the anti-bribery provisions of the FCPA relating to the Company’s retention and use of an individual agent in Nigeria with respect to certain customs-related issues, in return for: (i) the Company’s acceptance of responsibility for, and agreement not to contest or contradict the truthfulness of, the statement of facts and allegations that have been filed in a United States District Court concurrently with the DPA; (ii) the Company’s payment of an approximately $11.76 million fine; (iii) the Company’s reaffirming its commitment to compliance with the FCPA and other applicable anti-corruption laws in connection with the Company’s operations, and continuing cooperation with domestic and foreign authorities in connection with the matters that are the subject of the DPA; (iv) the Company’s commitment

to continue to address any identified areas for improvement in the Company’s internal controls, policies and procedures relating to compliance with the FCPA and other applicable anti-corruption laws if, and to the extent, not already addressed; and (v) the Company’s agreement to report to the DOJ in writing annually during the term of the DPA regarding remediation of the matters that are the subject of the DPA, implementation of any enhanced internal controls, and any evidence of improper payments the Company may have discovered during the term of the agreement. If the Company remains in compliance with the terms of the DPA throughout its effective period, the charge against the Company will be dismissed with prejudice. The Company also settled a related civil complaint filed by the Securities and Exchange Commission (SEC) in a United States District Court.

Demand Letter and Derivative Litigation

In April 2010, we received a demand letter from a law firm representing Ernest Maresca. The letter states that Mr. Maresca is one of our stockholders and that he believes that certain of our current and former officers and directors violated their fiduciary duties related to the issues described above under “Customs Agent and Foreign Corrupt Practices Act (FCPA) Settlement.” The letter requests that our Board of Directors take action against the individuals in question. In response to this letter, the Board formed a special committee to evaluate the issues raised by the letter and determine a course of action for the Company. The special committee engaged its own counsel for the investigation and evaluated potential claims against all individuals identified in the demand letter. The special committee considered whether pursuing each of the individuals named in the demand letter was in the best interests of the Company based upon a variety of factors, including among others, whether the Company had a potential cause of action against the individual, the defenses the individual might offer to such a claim, the ability of the individual to satisfy any judgment the Company might secure as a result of a claim asserted, and other risks to the Company of pursuing the claims. After taking various factors into account, on July 29, 2013, the special committee recommended to the Board that the Company not pursue any action against the current and former officers and directors named in the demand letter, and the Board accepted such recommendation.

On March 4, 2015 the Delaware Chancery Court ruled in the Company’s favor in Fuchs Family Trust v. Parker Drilling Company, Case No. 9986-VCN. The case centered on the plaintiff’s demand to inspect records related to the Company’s 2013 resolutions of investigations by the DOJ and the SEC into certain violations of the FCPA by Company employees. The plaintiff additionally sought costs, expenses, and attorneys’ fees. The Court determined that plaintiff could not demand inspection of the company’s books and records and denied all other relief requested by the plaintiff.

Note 11 - Recent Accounting Pronouncements

On April 7, 2015, the Financial Accounting Standards Board (FASB) issued Accounting Standards Update (ASU) No. 2015-03, Interest - Imputation of Interest (Subtopic 835-30) - Simplifying the Presentation of Debt Issuance Costs, which requires debt issuance costs related to a recognized debt liability to be presented in the balance sheet as a direct deduction from the debt liability rather than as an asset. Early adoption is permitted. Upon adoption, an entity must apply the new guidance retrospectively to all prior periods presented in the financial statements. We plan to adopt the standard on a retrospective basis effective January 1, 2016 and expect that it will result in the netting of our deferred financing costs against long-term debt balances on the consolidated balance sheets for the periods presented, and related disclosure. There will be no impact to the manner in which deferred financing costs are amortized in our consolidated financial statements.

On May 28, 2014, the FASB issued ASU 2014-09, Revenue from Contracts with Customers. This ASU supersedes the revenue recognition requirements in Accounting Standards Codification 605 - Revenue Recognition and most industry-specific guidance throughout the Codification. The standard requires that an entity recognizes revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the company expects to be entitled in exchange for those goods or services and should be applied retrospectively to each prior reporting period presented or retrospectively with the cumulative effect of initially applying the ASU recognized at the date of initial application. ASU 2014-09 was initially scheduled to be effective for the first quarter of 2017, however, on April 1, 2015, the FASB proposed to defer the effective date by one year. It is expected the proposal to defer the effective date will be finalized during the second quarter of 2015. We are in the process of assessing the impact of the adoption of ASU 2014-09 on our financial position, results of operations and cash flows. We have not yet selected a transition method nor have we determined the effect of the standard on our ongoing financial reporting.

In July 2013, the FASB issued ASU 2013-11, Income Taxes (Topic 740): Presentation of an Unrecognized Tax Benefit When a Net Operating Loss Carryforward, a Similar Tax Loss, or a Tax Credit Carryforward Exists. This ASU requires an entity to present an unrecognized tax benefit as a reduction of a deferred tax asset for a net operating loss (NOL) carryforward, or similar tax loss or tax credit carryforward, rather than as a liability when: (1) the uncertain tax position would reduce the NOL or other carryforward under the tax law of the applicable jurisdiction and (2) the entity intends to use the deferred tax asset for that purpose. This accounting guidance was effective for our first quarter in fiscal 2014 and did not have a material impact on our condensed consolidated financial statements.

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 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(a)(1) of Regulation S-X, set forth in sub-paragraph (f) of such rule. 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 March 31, 2015 and December 31, 2014 and for the three months ended March 31, 2015 and 2014, respectively. The consolidating condensed financial statements present investments in both consolidated and unconsolidated subsidiaries using the equity method of accounting.

PARKER DRILLING COMPANY AND SUBSIDIARIES

CONSOLIDATING CONDENSED BALANCE SHEET

(Dollars in Thousands)

(Unaudited)



	March 31, 2015
	Parent			Guarantor			Non-Guarantor			Eliminations			Consolidated
ASSETS
Current assets:
Cash and cash equivalents	$	31,704		$	10,944		$	70,551		$	—		$	113,199
Accounts and notes receivable, net	(52		)	110,172			169,300			—			279,420
Rig materials and supplies	—			(3,551		)	53,887			—			50,336
Deferred costs	—			—			6,432			—			6,432
Deferred income taxes	—			3,963			1,685			—			5,648
Other tax assets	—			270			8,930			—			9,200
Other current assets	—			5,762			13,256			—			19,018
Total current assets	31,652			127,560			324,041			—			483,253
Property, plant and equipment, net	(19		)	587,126			298,126			—			885,233
Investment in subsidiaries and intercompany advances	3,126,778			2,520,407			2,691,390			(8,338,575		)	—
Other noncurrent assets	(438,614		)	524,232			268,297			(182,086		)	171,829
Total assets	$	2,719,797		$	3,759,325		$	3,581,854		$	(8,520,661	)	$	1,540,315

LIABILITIES AND STOCKHOLDERS’ EQUITY
Current liabilities:
Current portion of long-term debt	$	—		$	—		$	—		$	—		$	—
Accounts payable and accrued liabilities	67,054			119,414			326,166			(318,702		)	193,932
Accrued income taxes	(16,195		)	25,438			6,224			—			15,467
Total current liabilities	50,859			144,852			332,390			(318,702		)	209,399
Long-term debt	585,000			—			—			—			585,000
Other long-term liabilities	2,869			5,864			9,826			—			18,559
Long-term deferred tax liability	—			62,296			(3,984		)	—			58,312
Intercompany payables	1,413,346			1,375,184			1,412,566			(4,201,096		)	—
Total liabilities	2,052,074			1,588,196			1,750,798			(4,519,798		)	871,270
Total equity	667,723			2,171,129			1,831,056			(4,000,863		)	669,045
Total liabilities and stockholders’ equity	$	2,719,797		$	3,759,325		$	3,581,854		$	(8,520,661	)	$	1,540,315

PARKER DRILLING COMPANY AND SUBSIDIARIES

CONSOLIDATING CONDENSED BALANCE SHEET

(Dollars in Thousands)

(Unaudited)



	December 31, 2014
	Parent			Guarantor			Non-Guarantor			Eliminations			Consolidated
ASSETS
Current assets:
Cash and cash equivalents	$	36,728		$	13,546		$	58,182		$	—		$	108,456
Accounts and notes receivable, net	(33		)	96,100			174,885			—			270,952
Rig materials and supplies	—			(1,473		)	49,416			—			47,943
Deferred costs	—			—			5,673			—			5,673
Deferred income taxes	—			6,131			1,345			—			7,476
Other tax assets	19,885			(18,273		)	9,111			—			10,723
Other current assets	—			7,999			10,557			—			18,556
Total current assets	56,580			104,030			309,169			—			469,779
Property, plant and equipment, net	(19		)	589,055			306,904			—			895,940
Investment in subsidiaries and intercompany advances	3,060,867			2,441,527			2,464,502			(7,966,896		)	—
Other noncurrent assets	(440,918		)	490,597			272,823			(167,562		)	154,940
Total assets	$	2,676,510		$	3,625,209		$	3,353,398		$	(8,134,458	)	$	1,520,659
LIABILITIES AND STOCKHOLDERS’ EQUITY
Current liabilities:
Current portion of long-term debt	$	10,000		$	—		$	—		$	—		$	10,000
Accounts payable and accrued liabilities	77,603			71,645			309,344			(304,113		)	154,479
Accrued income taxes	(4,061		)	10,109			8,138			—			14,186
Total current liabilities	83,542			81,754			317,482			(304,113		)	178,665
Long-term debt	605,000			—			—			—			605,000
Other long-term liabilities	2,867			7,135			8,663			—			18,665
Long-term deferred tax liability	—			56,105			(3,990		)	—			52,115
Intercompany payables	1,322,172			1,311,405			1,204,768			(3,838,345		)	—
Total liabilities	2,013,581			1,456,399			1,526,923			(4,142,458		)	854,445
Total equity	662,929			2,168,810			1,826,475			(3,992,000		)	666,214
Total liabilities and stockholders’ equity	$	2,676,510		$	3,625,209		$	3,353,398		$	(8,134,458	)	$	1,520,659

PARKER DRILLING COMPANY AND SUBSIDIARIES

CONSOLIDATING CONDENSED STATEMENT OF OPERATIONS

(Dollars in Thousands)

(Unaudited)



	Three months ended March 31, 2015
	Parent			Guarantor			Non-Guarantor			Eliminations			Consolidated
Total revenues	—			$	79,395		$	150,931		$	(26,250	)	$	204,076
Operating expenses	—			44,145			121,375			(26,250		)	139,270
Depreciation and amortization	—			23,311			17,228			—			40,539
Total operating gross margin	—			11,939			12,328			—			24,267
General and administration expense ⁽¹⁾	(112		)	(10,115		)	(610		)	—			(10,837		)
Gain (loss) on disposition of assets, net	—			52			2,389			—			2,441
Total operating income (loss)	(112		)	1,876			14,107			—			15,871
Other income and (expense):
Interest expense	(11,059		)	(17		)	(328		)	326			(11,078		)
Interest income	417			3			89			(326		)	183
Other	—			10			(1,390		)	—			(1,380		)
Equity in net earnings of subsidiaries	8,988			—			—			(8,988		)	—
Total other income (expense)	(1,654		)	(4		)	(1,629		)	(8,988		)	(12,275		)
Income (benefit) before income taxes	(1,766		)	1,872			12,478			(8,988		)	3,596
Total income tax expense (benefit)	(4,988		)	(447		)	5,253			—			(182		)
Net income (loss)	3,222			2,319			7,225			(8,988		)	3,778
Less: Net income attributable to noncontrolling interest	—			—			556			—			556
Net income (loss) attributable to controlling interest	$	3,222		$	2,319		$	6,669		$	(8,988	)	$	3,222

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

PARKER DRILLING COMPANY AND SUBSIDIARIES

CONSOLIDATING CONDENSED STATEMENT OF OPERATIONS

(Dollars in Thousands)

(Unaudited)



	Three Months Ended March 31, 2014
	Parent			Guarantor			Non-Guarantor			Eliminations			Consolidated
Total revenues	$	—		$	123,431		$	149,132		$	(43,338	)	$	229,225
Operating expenses	—			76,548			132,815			(43,338		)	166,025
Depreciation and amortization	—			20,168			14,169			—			34,337
Total operating gross margin	—			26,715			2,148			—			28,863
General and administration expense ⁽¹⁾	(70		)	(8,464		)	(430		)	—			(8,964		)
Gain (loss) on disposition of assets, net	(79		)	(81		)	31			—			(129		)
Total operating income (loss)	(149		)	18,170			1,749			—			19,770
Other income and (expense):
Interest expense	(12,715		)	(50		)	(2,499		)	3,225			(12,039		)
Interest income	439			176			2,642			(3,225		)	32
Loss on extinguishment of debt	(29,673		)	—			—			—			(29,673		)
Other	—			128			767			—			895
Equity in net earnings of subsidiaries	10,489			—			—			(10,489		)	—
Total other income (expense)	(31,460		)	254			910			(10,489		)	(40,785		)
Income (loss) before income taxes	(31,609		)	18,424			2,659			(10,489		)	(21,015		)
Income tax expense (benefit)	(19,060		)	6,384			4,053			—			(8,623		)
Net income (loss)	(12,549		)	12,040			(1,394		)	(10,489		)	(12,392		)
Less: Net income attributable to noncontrolling interest	—			—			157			—			157
Net income (loss) attributable to controlling interest	$	(12,549	)	$	12,040		$	(1,551	)	$	(10,489	)	$	(12,549	)

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

PARKER DRILLING COMPANY AND SUBSIDIARIES

CONSOLIDATING CONDENSED STATEMENT OF COMPREHENSIVE INCOME (LOSS)

(Dollars in Thousands)

(Unaudited)



	Three Months Ended March 31, 2015
	Parent		Guarantor		Non-Guarantor			Eliminations			Consolidated
Comprehensive income:
Net income (loss)	$	3,222	$	2,319	$	7,225		$	(8,988	)	$	3,778
Other comprehensive income (loss), net of tax:
Currency translation difference on related borrowings	—		—		(1,670		)	—			(1,670		)
Currency translation difference on foreign currency net investments	—		—		(849		)	—			(849		)
Total other comprehensive income (loss), net of tax:	—		—		(2,519		)	—			(2,519		)
Comprehensive income (loss)	3,222		2,319		4,706			(8,988		)	1,259
Comprehensive (income) attributable to noncontrolling interest	—		—		(394		)	—			(394		)
Comprehensive income (loss) attributable to controlling interest	$	3,222	$	2,319	$	4,312		$	(8,988	)	$	865

PARKER DRILLING COMPANY AND SUBSIDIARIES

CONSOLIDATING CONDENSED STATEMENT OF COMPREHENSIVE INCOME (LOSS)

(Dollars in Thousands)

(Unaudited)



	Three Months Ended March 31, 2014
	Parent			Guarantor		Non-Guarantor			Eliminations			Consolidated
Comprehensive income:
Net income (loss)	$	(12,549	)	$	12,040	$	(1,394	)	$	(10,489	)	$	(12,392	)
Other comprehensive income (loss), net of tax:
Currency translation difference on related borrowings	—			—		(804		)	—			(804		)
Currency translation difference on foreign currency net investments	—			—		699			—			$	699
Total other comprehensive income (loss), net of tax:	—			—		(105		)	—			(105		)
Comprehensive income (loss)	(12,549		)	12,040		(1,499		)	(10,489		)	(12,497		)
Comprehensive (income) attributable to noncontrolling interest	—			—		(154		)	—			(154		)
Comprehensive income (loss) attributable to controlling interest	$	(12,549	)	$	12,040	$	(1,653	)	$	(10,489	)	$	(12,651	)

PARKER DRILLING COMPANY AND SUBSIDIARIES

CONSOLIDATED CONDENSED STATEMENTS OF CASH FLOWS

(Dollars in Thousands)

(Unaudited)



	Three Months Ended March 31, 2015
	Parent			Guarantor			Non-Guarantor			Eliminations			Consolidated
Cash flows from operating activities:
Net income (loss)	$	3,222		$	2,319		$	7,225		$	(8,988	)	$	3,778
Adjustments to reconcile net income (loss):
Depreciation and amortization	—			23,311			17,228			—			40,539
Gain on disposition of assets	—			(52		)	(2,389		)	—			(2,441		)
Deferred income tax expense	(7,932		)	3,117			(1,489		)	—			(6,304		)
Expenses not requiring cash	2,443			436			(1,142		)	—			1,737
Equity in net earnings of subsidiaries	(8,988		)	—			—			8,988			—
Change in assets and liabilities:
Accounts and notes receivable	19			(12,289		)	5,620			—			(6,650		)
Other assets	25,016			(41,216		)	(3,887		)	—			(20,087		)
Accounts payable and accrued liabilities	(10,549		)	47,058			17,536			—			54,045
Accrued income taxes	(10,727		)	13,922			(581		)	—			2,614
Net cash provided by (used in) operating activities	(7,496		)	36,606			38,121			—			67,231

Cash flows from investing activities:
Capital expenditures	—			(24,418		)	(9,037		)	—			(33,455		)
Proceeds from the sale of assets	—			50			196			—			246
Proceeds from insurance settlements	—			—			2,500			—			2,500
Net cash (used in) investing activities	—			(24,368		)	(6,341		)	—			(30,709		)

Cash flows from financing activities:
Repayments of long-term debt	(30,000		)	—			—			—			(30,000		)
Payment of debt issuance costs	(1,359		)	—			—			—			(1,359		)
Excess tax benefit from stock-based compensation	(420		)	—			—			—			(420		)
Intercompany advances, net	34,251			(14,840		)	(19,411		)	—			—
Net cash provided by (used in) financing activities	2,472			(14,840		)	(19,411		)	—			(31,779		)

Net change in cash and cash equivalents	(5,024		)	(2,602		)	12,369			—			4,743
Cash and cash equivalents at beginning of year	36,728			13,546			58,182			—			108,456
Cash and cash equivalents at end of year	$	31,704		$	10,944		$	70,551		$	—		$	113,199

PARKER DRILLING COMPANY AND SUBSIDIARIES

CONSOLIDATED CONDENSED STATEMENTS OF CASH FLOWS

(Dollars in Thousands)

(Unaudited)



	Three Months Ended March 31, 2014
	Parent			Guarantor			Non-Guarantor			Eliminations			Consolidated
Cash flows from operating activities:
Net income (loss)	$	(12,549	)	$	12,040		$	(1,394	)	$	(10,489	)	$	(12,392	)
Adjustments to reconcile net income (loss)
Depreciation and amortization	—			20,168			14,169			—			34,337
Loss on extinguishment of debt	29,673			—			—			—			29,673
Gain on disposition of assets	79			81			(31		)	—			129
Deferred income tax expense	(17,472		)	3,891			1,289			—			(12,292		)
Expenses not requiring cash	4,180			129			2,535			—			6,844
Equity in net earnings of subsidiaries	(10,489		)	—			—			10,489			—
Change in assets and liabilities:
Accounts and notes receivable	11			(18,803		)	12,566			—			(6,226		)
Other assets	12,746			(14,180		)	1,040			—			(394		)
Accounts payable and accrued liabilities	(8,476		)	(34		)	305			—			(8,205		)
Accrued income taxes	(4,420		)	7,206			(2,636		)	—			150
Net cash provided by (used in) operating activities	(6,717		)	10,498			27,843			—			31,624

Cash flows from investing activities:
Capital expenditures	—			(25,523		)	(11,922		)	—			(37,445		)
Proceeds from the sale of assets	—			472			1,154			—			1,626
Net cash (used in) investing activities	—			(25,051		)	(10,768		)	—			(35,819		)

Cash flows from financing activities:
Proceeds from debt issuance	400,000			—			—			—			400,000
Repayments of long-term debt	(418,699		)	—			—			—			(418,699		)
Payment of debt issuance costs	(7,273		)	—			—			—			(7,273		)
Payment of debt extinguishment costs	(25,796		)	—			—			—			(25,796		)
Excess tax benefit from stock-based compensation	335			—			—			—			335
Intercompany advances, net	102			22,159			(22,261		)	—			—
Net cash provided by (used in) financing activities	(51,331		)	22,159			(22,261		)	—			(51,433		)

Net change in cash and cash equivalents	(58,048		)	7,606			(5,186		)	—			(55,628		)
Cash and cash equivalents at beginning of year	88,697			8,310			51,682			—			148,689
Cash and cash equivalents at end of year	$	30,649		$	15,916		$	46,496		$	—		$	93,061

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

Management's discussion and analysis (MD&A) should be read in conjunction with Item 1. Financial Statements.

DISCLOSURE NOTE REGARDING FORWARD-LOOKING STATEMENTS

This Form 10-Q contains statements that are “forward-looking statements” within the meaning of Section 27A of the Securities Act of 1933, as amended (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, including any statements regarding:

•stability or volatility of prices and demand for oil and natural gas;

•levels of oil and natural gas exploration and production activities;

•demand for drilling and drilling-related services and demand for rental tools and related services;

•our future operating results and profitability;

•our future rig utilization, dayrates and rental tools activity;


•	entering into new, or extending existing, drilling or rental contracts and our expectations concerning when operations will commence under such contracts;

•continuation of existing contracts for drilling and rental tools services for their stated duration and rate.

•entry into new markets or potential exit from existing markets;

•growth through acquisitions of companies or assets;

•organic growth of our operations;

•construction or upgrades of rigs and expectations regarding when these rigs will commence operations;

•capital expenditures for acquisition of rental tools, rigs, construction of new rigs or major upgrades to existing rigs;

•entering into joint venture agreements;

•our future liquidity;

•the sale or potential sale of assets or references to assets held for sale;

•availability and sources of funds to refinance our debt and expectations of when debt will be reduced;

•the outcome of pending or future legal proceedings, investigations, tax assessments and other claims;

•the availability of insurance coverage for pending or future claims;

•the enforceability of contractual indemnification in relation to pending or future claims; and

•compliance with covenants under our debt agreements.

In some cases, you can identify these statements by forward-looking words such as “anticipate,” “believe,” “could,” “estimate,” “expect,” “intend,” “outlook,” “may,” “should,” “will” and “would” or similar words. Forward-looking statements are based on certain assumptions and analyses 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 that 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. The following factors, as well as any other cautionary language included in this Form 10-Q, provide examples of risks, uncertainties and events that may cause our actual results to differ materially from the expectations we describe in our forward-looking statements:


•	fluctuations in the market prices of oil and natural gas, including the inability or unwillingness of our customers to fund drilling programs in low price cycles;


•	worldwide economic and business conditions that adversely affect market conditions and/or the cost of doing business, including potential currency devaluations or collapses;

•our inability to access the credit markets and U.S. credit market volatility;

•the U.S. economy and the demand for oil and natural gas;


•	low U.S. oil and natural gas prices that could adversely affect our U.S. drilling services, barge rig and U.S. rental tools services businesses;

•worldwide demand for oil;


•	imposition of trade restrictions, including additional economic sanctions and export/re-export controls affecting our business operations in Russia;

•unanticipated operating hazards and uninsured risks;

•political instability, terrorism or war;


•	governmental regulations, including changes in accounting rules or tax laws that adversely affect the cost of doing business or our ability to remit funds to the U.S.;

•changes in the tax laws that would allow double taxation on foreign sourced income;

•the outcome of investigations into possible violations of laws;

•adverse environmental events;

•adverse weather conditions;

•global health concerns;

•changes in the concentration of customer and supplier relationships;

•ability of our customers and suppliers to obtain financing for their operations;

•unexpected cost increases for new construction and upgrade and refurbishment projects;

•delays in obtaining components for capital projects and in ongoing operational maintenance and equipment certifications;

•shortages of skilled labor;

•unanticipated cancellation of contracts by customers or operators;

•breakdown of equipment;

•other operational problems including delays in start-up or commissioning of rigs;


•	inability to obtain, or delays in obtaining, licenses and permits necessary to operate, move or transport our rigs, rig components, rental tools and related equipment;

•inability to access or restrictions on access to our rigs, field locations and other facilities;

•changes in competition;

•any failure to realize expected benefits from acquisitions;

•the effect of litigation and contingencies; and


•	other similar factors, some of which are discussed in documents referred to or incorporated by reference into this Form 10-Q and our other reports and filings with the SEC.

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 the occurrence of the events described in these risk factors and elsewhere in this Form 10-Q could have a material adverse effect on our business, results of operations, financial condition and cash flows.

Overview and Outlook

Executive Overview

Since the first quarter of 2014, we have experienced significant declines in our U.S. markets for rental tools and barge drilling services following the sharp drop in oil prices in late 2014. As a result, our rental tools U.S. tubular goods utilization index declined to 75.0 for the 2015 first quarter, from 86.3 for the 2014 first quarter; and our U.S. (Lower 48) Drilling barge rig fleet utilization declined to 21 percent for the 2015 first quarter, from 74 percent for the 2014 first quarter.

While we reported lower rig fleet utilization in our International & Alaska Drilling segment, compared with the prior year’s first quarter, we benefited from growth in our international O&M (operations and maintenance) and project services, including the addition of a two-rig extended reach drilling project and a procurement and project management services contract.

Cost reductions throughout the business tempered the impact of the reduced rental tools and drilling activity.

In January, 2015, we increased the capacity of our revolving credit facility, and extended its maturity and paid off a $30.0 million term loan with a draw on the expanded revolver. Solid cash flow from operations during the 2015 first quarter allowed us to repay the $30.0 million drawn on the Revolver and close the quarter with a strong cash position.

Executive Outlook

We believe overall energy market conditions will remain weak. We expect our Rental Tools Services business to continue to be impacted by the severe downturn in U.S. land and shallow water offshore drilling markets, with lower utilization and continued price pressure. However, we expect improved results from our international rental tools business in 2015, compared with 2014, due to our large presence in the Middle East and improving operating performance. Similarly, we expect our Drilling Services business will continue to be impacted by the sharp decline in U.S. drilling, due to continued low barge rig fleet utilization at current commodity prices. We expect this to be tempered by more resilient activity in our International & Alaska Drilling segment. While we have international rigs that have or are expected to come off contract in the months ahead, resulting in lower utilization, we expect steady activity from international O&M services and our drilling operations in Alaska.

In response to market conditions, we are focused on lowering our cost base, sustaining our utilization, managing our cash and liquidity, and preserving our ability to respond when conditions improve. We are prepared to make further adjustments to our business to address changing market conditions and take advantage of opportunities as they occur.

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 5 to our condensed consolidated 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 U.S. GAAP. Management believes this information is useful to our investors as it more accurately reflects the cash flow from operations generated by each segment.

Three Months Ended March 31, 2015 Compared with Three Months Ended March 31, 2014

Revenues of $204.1 million for the three months ended March 31, 2015 decreased $25.1 million, or 11.0 percent, compared with $229.2 million for the three months ended March 31, 2014. Operating gross margin decreased $4.6 million, or 15.9 percent, to $24.3 million, for the three months ended March 31, 2015 compared with $28.9 million for the three months ended March 31, 2014.

The following is an analysis of our operating results for the comparable periods by reportable segment:



	Three Months Ended March 31,
Dollars in Thousands	2015					2014
Revenues:
Drilling Services:
U.S. (Lower 48) Drilling	$	14,097		7	%	$	35,787		16	%
International & Alaska Drilling	113,921			56	%	112,932			49	%
Total Drilling Services	128,018			63	%	148,719			65	%
Rental Tools	76,058			37	%	80,506			35	%
Total revenues	204,076			100	%	229,225			100	%
Operating gross margin excluding depreciation and amortization:
Drilling Services:
U.S. (Lower 48) Drilling	115			1	%	12,792			36	%
International & Alaska Drilling	35,392			31	%	21,657			19	%
Total Drilling Services	35,507			28	%	34,449			23	%
Rental Tools	29,299			39	%	28,751			36	%
Total operating gross margin excluding depreciation and amortization	64,806			32	%	63,200			28	%
Depreciation and amortization	(40,539		)			(34,337		)
Total operating gross margin	24,267					28,863
General and administrative expense	(10,837		)			(8,964		)
Gain (loss) on disposition of assets, net	2,441					(129		)
Total operating income	$	15,871				$	19,770

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		Rental Tools		Total
Three Months Ended March 31, 2015
Operating gross margin ⁽¹⁾	$	(5,717	)	$	17,354	$	12,630	$	24,267
Depreciation and amortization	5,832			18,038		16,669		40,539
Operating gross margin excluding depreciation and amortization	$	115		$	35,392	$	29,299	$	64,806
Three Months Ended March 31, 2014
Operating gross margin ⁽¹⁾	$	8,742		$	6,776	$	13,345	$	28,863
Depreciation and amortization	4,050			14,881		15,406		34,337
Operating gross margin excluding depreciation and amortization	$	12,792		$	21,657	$	28,751	$	63,200


(1)	Operating gross margin 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 March 31, 2015 and 2014:



	March 31,
	2015		2014
U.S. (Lower 48) Drilling
Rigs available for service ⁽¹⁾	13.0		11.0
Utilization rate of rigs available for service ⁽²⁾	21	%	74	%
International & Alaska Drilling
Eastern Hemisphere
Rigs available for service ⁽¹⁾	13.0		13.0
Utilization rate of rigs available for service ⁽²⁾	82	%	77	%
Latin America Region
Rigs available for service ⁽¹⁾	9.0		9.0
Utilization rate of rigs available for service ⁽²⁾	45	%	68	%
Alaska
Rigs available for service ⁽¹⁾	2.0		2.0
Utilization rate of rigs available for service ⁽²⁾	100	%	100	%
Total International & Alaska Drilling
Rigs available for service ⁽¹⁾	24.0		24.0
Utilization rate of rigs available for service ⁽²⁾	70	%	76	%

(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.

Drilling Services Business Line

U.S. (Lower 48) Drilling

U.S. (Lower 48) Drilling segment revenues decreased $21.7 million, or 60.6%, to $14.1 million for the first quarter of 2015 compared with $35.8 million for the first quarter of 2014. The decrease in revenues was due to lower utilization and a decline in average dayrates for the barge drilling fleet resulting from substantial reductions in drilling activity by operators in the inland waters of the Gulf of Mexico (GOM) resulting from lower oil prices.

U.S. (Lower 48) Drilling segment's operating gross margin excluding depreciation and amortization decreased $12.7 million, or 99.1%, to $0.1 million for the first quarter of 2015 compared with $12.8 million for the first quarter of 2014. The decrease was primarily due to the decline in utilization and average dayrates discussed above.

International & Alaska Drilling

International & Alaska Drilling segment revenues increased $1.0 million to $113.9 million for the first quarter of 2015 compared with $112.9 million for the first quarter of 2014. The increase in segment revenues was driven by increased activity and higher reimbursable expenses for our Sakhalin Island O&M operations, the initiation of a new two-rig O&M contract in Abu Dhabi, and higher utilization in the Eastern Hemisphere region. The increase in revenues was substantially offset by the completion of an O&M project in Papua New Guinea in May 2014, reduced utilization in the Latin America region as drilling activity began to reflect the impact of low commodity prices on customer drilling plans, and a decline in project services revenues resulting from decreased activity on a low-margin vendor services project. Approximately $16.1 million and $9.3 million of O&M revenues were attributable to reimbursable costs for the three month periods ended March 31, 2015 and 2014, respectively, which increased revenues, but had minimal impact on operating margins.

International & Alaska Drilling operating gross margin excluding depreciation and amortization increased $13.7 million to $35.4 million for the first quarter of 2015 compared with $21.7 million for the first quarter of 2014. The increase in operating gross margin excluding depreciation and amortization was primarily due to the increases in our O&M activity and drilling utilization in the Eastern Hemisphere region described above, as well as overall lower operating costs in both the Latin America and Eastern Hemisphere regions. Additionally, we benefited from the start-up of a new procurement and project management services contract that carries a low cost base.

Rental Tools Services Business Line

Rental Tools segment revenues decreased $4.4 million, or 5.5%, to $76.1 million for the first quarter of 2015 compared with $80.5 million for the first quarter of 2014. The decrease was primarily due to a $4.6 million decrease in our U.S. revenues driven by a decline in utilization resulting from customer initiated cutbacks brought on by the downturn in U.S. drilling activity.

Rental Tools segment operating gross margin excluding depreciation and amortization increased $0.5 million, or 1.9%, to $29.3 million in the first quarter of 2015 compared with $28.7 million for the first quarter of 2014. The increase in operating gross margin excluding depreciation and amortization is comprised of a $4.3 million increase in margin for our international operations driven by reductions in operating costs, offset by a $3.7 million decrease for our U.S. operations primarily driven by a decline in market opportunities in U.S. land markets resulting from customer cutbacks discussed above.

Other Financial Data

General and administrative expense

General and administration expense increased $1.8 million to $10.8 million for the first quarter of 2015 compared with $9.0 million for the first quarter of 2014. The increase is primarily driven by increased expenses as we implemented the second phase of our new enterprise resource planning system in the first quarter of 2015.

Gain/loss on disposition of assets

Net gains recognized on asset dispositions were $2.4 million during the first quarter of 2015 compared with $0.1 million of net losses during the first quarter of 2014. During the 2015 first quarter we received an insurance settlement related to previously realized asset losses. Activity in both periods included the result of asset sales. We periodically sell equipment deemed to be excess, obsolete, or not currently required for operations.

Interest income and expense

Interest expense decreased $0.9 million to $11.1 million for the first quarter of 2015 compared with $12.0 million for the first quarter of 2014. This decrease was primarily related to a decrease in debt-related interest expense resulting from lower interest rates and a lower total amount of outstanding debt. Interest income during the 2015 and 2014 first quarters was nominal.

Loss on extinguishment of debt

There were no debt extinguishment costs incurred during the three months ended March 31, 2015, compared with a loss on extinguishment of debt of $29.7 million during the three months ended March 31, 2014, resulting from the January 2014 tender and consent solicitation with respect to the 9.125% Notes.

Other income and expense

We incurred $1.4 million of other expense for the first quarter of 2015 compared with $0.9 million of other income for the first quarter of 2014. Other expense for the first quarter of 2015 was primarily driven by losses related to foreign currency fluctuations. Other income for the first quarter of 2014 was primarily related to earnings from our investment in an unconsolidated subsidiary that was acquired as part of the ITS Acquisition.

Income tax expense (benefit)

LIQUIDITY AND CAPITAL RESOURCES

We periodically evaluate our liability requirements, capital needs and availability of resources in view of expansion plans, debt service requirements, and other operational cash needs. To meet our short- and long-term liquidity requirements, including payment of operating expenses and repaying debt, we rely primarily on cash from operations. When determined necessary we may seek to raise additional capital in the future. We expect that for the foreseeable future, cash on hand and cash generated from operations will be sufficient to provide us the ability to fund our operations, provide the working capital necessary to support our strategy, and fund planned capital expenditures. We also have access to cash through the 2015 Revolver, subject to our compliance with the covenants contained in the 2015 Secured Credit Agreement. We do not pay dividends to our shareholders.

Cash Flows

The following table provides a summary of our cash flow activity:



	Three Months Ended March 31,
Dollars in thousands	2015			2014
Operating Activities	$	67,231		$	31,624
Investing Activities	(30,709		)	(35,819		)
Financing Activities	(31,779		)	(51,433		)
Net change in cash and cash equivalents	$	4,743		$	(55,628	)

Operating Activities

As of March 31, 2015, we had cash and cash equivalents of $113.2 million, an increase of $4.7 million from December 31, 2014. Cash flows from operating activities for the three months ended March 31, 2015 were $67.2 million, compared with $31.6 million for the 2014 comparable period. Changes in working capital were a source of cash of $29.9 million and a use of cash of $14.7 million for the three months ended March 31, 2015 and 2014, respectively. Over the past few years we have reinvested a substantial portion of our operating cash flows to enhance our fleet of drilling rigs and our rental tools equipment inventory. It is our intention to continue to utilize our operating cash flows to finance further investments into our rental tools inventories and rig purchases or upgrades, as well as other strategic investments aligned with our strategies. Operating cash flows for the three months ended March 31, 2014 were also impacted by the loss on debt extinguishment, as well as the ITS Acquisition which resulted in increased receivables, inventory, and accounts payable. Changes in cash from operating activities for both periods were also impacted by non-cash charges such as depreciation expense, deferred tax benefit, and stock compensation expense.

Investing Activities

Cash flows used in investing activities were $30.7 million for the three months ended March 31, 2015 compared with $35.8 million for the 2014 comparable period. Our primary use of cash during the three months ended March 31, 2015 and 2014 were $33.5 million and $37.4 million, respectively, for capital expenditures. Capital expenditures in each period were primarily for tubular and other products for our Rental Tools Services business and rig-related enhancements and maintenance.

Financing Activities

Cash flows used in financing activities were $31.8 million for the three months ended March 31, 2015, primarily driven by the repayment of the $30.0 million term loan in the first quarter of 2015. Cash flows used in financing activities were $51.4 million for the 2014 comparable period, primarily related to the repayment of $425.0 million of our 9.125% Notes, payment of $25.8 million of related tender and consent premiums, and payment of debt issuance costs of $7.3 million. Cash provided by financing activities for the first quarter of 2014 included proceeds of $360.0 million from issuance of our 6.75% Notes and reborrowing of a $40.0 million Term Loan under our 2012 Secured Credit Agreement.

6.75% Senior Notes, due July 2022

At any time prior to January 15, 2017, we may redeem up to 35 percent of the aggregate principal amount of the 6.75% Notes at a redemption price of 106.75 percent of the principal amount, plus accrued and unpaid interest to the redemption date, with the net cash proceeds of certain equity offerings by us. On and after January 15, 2018, we may redeem all or a part of the 6.75% Notes upon appropriate notice, at a redemption price of 103.375 percent of the principal amount, and at redemption prices decreasing each year thereafter to par beginning January 15, 2020. If we experience certain changes in control, we must offer to repurchase the 6.75% Notes at 101.0 percent of the aggregate principal amount, plus accrued and unpaid interest and additional interest, if any, to the date of repurchase.

7.50% Senior Notes, due August 2020

approximately $5.6 million ($4.5 million, net of amortization as of March 31, 2015) are being amortized over the term of the notes using the effective interest rate method.

9.125% Senior Notes, due April 2018

On March 22, 2010, we issued $300.0 million aggregate principal amount of the 9.125% Notes and on April 25, 2012, we issued an additional $125.0 million aggregate principal amount of 9.125% Notes. On January 7, 2014, we commenced a tender and consent solicitation with respect to the 9.125% Notes. The tender offer price was $1,061.98, inclusive of a $30.00 consent payment for each $1,000 principal amount of 9.125% Notes, plus accrued and unpaid interest. On January 22, 2014, we paid $453.7 million for the tendered 9.125% Notes, comprised of $416.2 million of aggregate principal amount of the 9.125% Notes, $25.8 million of tender and consent premiums and $11.7 million of accrued interest. On April 1, 2014, we redeemed the remaining $8.8 million aggregate principal amount of the outstanding 9.125% Notes for a purchase price of $9.6 million, inclusive of a $0.4 million call premium and $0.4 million interest. During the year ended December 31, 2014, we recorded a loss on extinguishment of debt of approximately $30.2 million, which included the tender and consent premiums of $25.8 million, the call premium of $0.4 million and the write-off of unamortized debt issuance costs of $7.7 million, offset by the write-off of the remaining unamortized debt issuance premium of $3.8 million.

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, and rental equipment of the Company and its subsidiary guarantors. The 2015 Secured Credit Agreement contains customary affirmative and negative covenants, such as limitations on indebtedness, liens, restrictions on entry into certain affiliate transactions and payments (including payment of dividends) and maintenance of certain ratios and coverage tests (including a minimum asset coverage ratio of 1.25:1.00 at each quarter end). We were in compliance with all such covenants as of March 31, 2015.

2012 Secured Credit Agreement

2012 Revolver

Term Loan

The Term Loan originated at $50.0 million on December 14, 2012 and required quarterly principal payments of $2.5 million, which began March 31, 2013. Interest on the Term Loan accrued at a Base Rate plus 2.00 percent or LIBOR plus 3.00 percent. In July 2013, we repaid the outstanding balance of $45 million of the Term Loan and amended the 2012 Secured Credit Agreement to permit re-borrowing of up to $45 million of the Term Loan, decreasing by $2.5 million at the end of each quarter beginning September 30, 2013 and ending March 31, 2014. In January 2014 we re-borrowed $40.0 million of the Term Loan. The outstanding balance on the Term Loan at December 31, 2014 was $30.0 million. At the closing of the 2015 Secured Credit Agreement, we repaid the Term Loan with a $30.0 million draw under the 2015 Revolver.

Long-Term Debt Summary

Our principal amount of long-term debt, including current portion, was $585.0 million as of March 31, 2015 which consisted of:

•$360.0 million aggregate principal amount of 6.75% Notes;

•$225.0 million aggregate principal amount of 7.50% Notes;

As of March 31, 2015, we had approximately $301.4 million of liquidity, which consisted of $113.2 million of cash and cash equivalents on hand and $188.2 million of availability under our 2015 Revolver. In order to access the 2015 revolver, we must be in compliance with the covenants set forth in the 2015 Secured Credit Agreement.

Off-Balance Sheet Arrangements

We do not have any unconsolidated special-purpose entities, off-balance sheet financing arrangements or guarantees of third-party financial obligations. We have no energy or commodity contracts.

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 2014 Annual Report on Form 10-K filed with the SEC on February 25, 2015. For more information on market risk, see Part II, Item 7A in our 2014 Annual Report on Form 10-K.

Item 4. Controls and Procedures

Evaluation of Disclosure Controls and Procedures

In accordance with Rules 13a-15 and 15d-15 under 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 March 31, 2015 to provide reasonable assurance that information required to be disclosed in our reports filed or submitted under the Exchange Act is recorded, processed, summarized and reported within the time periods specified in the Securities and Exchange Commission's rules and forms and accumulated and communicated to our management, including our Chief Executive Officer and our Chief Financial Officer, as appropriate, to allow timely decisions regarding required disclosure.

Changes in Internal Controls Over Financial Reporting

There have been no changes in our internal controls over financial reporting during the quarter ended March 31, 2015 that have materially affected, or are reasonably likely to materially affect, our internal controls over financial reporting.

PART II. OTHER INFORMATION

Item 1. Legal Proceedings

For information regarding legal proceedings, see Note 10, “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

There have been no material changes from the risk factors disclosed in Item 1A. Risk Factors of our Annual Report on Form 10-K for the year ended December 31, 2014.

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.

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 Parker Drilling Company, as amended and restated as of July 31, 2014 (incorporated by reference to Exhibit 3.1 to the Company's Current Report on Form 8-K filed on August 1, 2014).

10.1	—	Second Amended and Restated Credit Agreement, dated January 26, 2015, 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 10.20 to the Company's Annual Report on Form 10-K filed on February 25, 2015).

12.1	—	Computation of Ratio of Earnings to Fixed Charges.

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

31.2	—	Christopher T. Weber, Senior Vice President and Chief Financial Officer, Rule 13a-14(a)/15d-14(a) Certification.

32.1	—	Gary G. Rich, President and Chief Executive Officer, Section 1350 Certification.

32.2	—	Christopher T. Weber, Senior Vice President and Chief Financial Officer, 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.

101.PRE	—	XBRL Presentation Linkbase Document.

101.DEF	—	XBRL Definition Linkbase Document.

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:	May 6, 2015	By:	/s/ Gary G. Rich
			Gary G. Rich Chairman, President and Chief Executive Officer

		By:	/s/ Christopher T. Weber
			Christopher T. Weber Senior Vice President and Chief Financial Officer

INDEX TO EXHIBITS



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 Parker Drilling Company, as amended and restated as of July 31, 2014 (incorporated by reference to Exhibit 3.1 to the Company's Current Report on Form 8-K filed on August 1, 2014).

10.1	—	Second Amended and Restated Credit Agreement, dated January 26, 2015, 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 10.20 to the Company's Annual Report on Form 10-K filed on February 25, 2015).

12.1	—	Computation of Ratio of Earnings to Fixed Charges.

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

31.2	—	Christopher T. Weber, Senior Vice President and Chief Financial Officer, Rule 13a-14(a)/15d-14(a) Certification.

32.1	—	Gary G. Rich, President and Chief Executive Officer, Section 1350 Certification.

32.2	—	Christopher T. Weber, Senior Vice President and Chief Financial Officer, 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.

101.PRE	—	XBRL Presentation Linkbase Document.

101.DEF	—	XBRL Definition Linkbase Document.

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