Helmerich & Payne, Inc. - Quarter Report: 2015 March (Form 10-Q)

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UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

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

For quarterly period ended: March 31, 2015

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

For the transition period from to

Commission File Number: 1-4221

HELMERICH & PAYNE, INC.

(Exact name of registrant as specified in its charter)

Delaware		73-0679879
(State or other jurisdiction of		(I.R.S. Employer I.D. Number)
incorporation or organization)

1437 South Boulder Avenue, Tulsa, Oklahoma, 74119

(Address of principal executive office)(Zip Code)

(918) 742-5531

(Registrant’s telephone number, including area code)

N/A

(Former name, former address and former fiscal year,

if changed since last report)

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 o

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

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

Large accelerated filer x		Accelerated filer o

Non-accelerated filer o		Smaller reporting company o
(Do not check if a smaller reporting company)

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

CLASS		OUTSTANDING AT April 30, 2015
Common Stock, $0.10 par value		107,654,499

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HELMERICH & PAYNE, INC. AND SUBSIDIARIES

TABLE OF CONTENTS

		Page No.

PART I.	FINANCIAL INFORMATION

Item 1.	Financial Statements

	Consolidated Condensed Balance Sheets as of March 31, 2015 and September 30, 2014	3

	Consolidated Condensed Statements of Income for the Three and Six Months Ended March 31, 2015 and 2014	4

	Consolidated Condensed Statements of Comprehensive Income for the Three and Six Months Ended March 31, 2015 and 2014	5

	Consolidated Condensed Statements of Cash Flows for the Six Months Ended March 31, 2015 and 2014	6

	Consolidated Condensed Statement of Shareholders’ Equity for the Six Months Ended March 31, 2015	7

	Notes to Consolidated Condensed Financial Statements	8-22

Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	23-30

Item 3.	Quantitative and Qualitative Disclosures about Market Risk	31

Item 4.	Controls and Procedures	31

PART II.	OTHER INFORMATION

Item 1.	Legal Proceedings	31

Item 1A.	Risk Factors	31-33

Item 6.	Exhibits	34

Signatures		35

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PART I. FINANCIAL INFORMATION

HELMERICH & PAYNE, INC. AND SUBSIDIARIES

CONSOLIDATED CONDENSED BALANCE SHEETS

(Unaudited)

(in thousands, except share and per share amounts)

ITEM 1. FINANCIAL STATEMENTS

				September 30,
	March 31,			2014
	2015			(as adjusted)
ASSETS
Current assets:
Cash and cash equivalents	$	719,127		$	360,909
Accounts receivable, less reserve of $4,592 at March 31, 2015 and $4,597 at September 30, 2014	623,706			705,214
Inventories	124,269			106,241
Deferred income taxes	14,649			16,519
Prepaid expenses and other	79,132			80,912
Current assets of discontinued operations	7,486			7,206
Total current assets	1,568,369			1,277,001

Investments	164,648			236,644
Property, plant and equipment, net	5,572,818			5,188,544
Other assets	38,315			18,809

Total assets	$	7,344,150		$	6,720,998

LIABILITIES AND SHAREHOLDERS’ EQUITY
Current liabilities:
Long-term debt due within one year less unamortized debt issuance costs	$	39,207		$	39,635
Accounts payable	172,373			182,031
Accrued liabilities	176,256			282,278
Current liabilities of discontinued operations	3,309			3,217
Total current liabilities	391,145			507,161

Noncurrent liabilities:
Long-term debt less unamortized discount and debt issuance costs	532,908			39,502
Deferred income taxes	1,320,364			1,215,259
Other	93,180			64,110
Noncurrent liabilities of discontinued operations	4,177			3,989
Total noncurrent liabilities	1,950,629			1,322,860

Shareholders’ equity:
Common stock, $.10 par value, 160,000,000 shares authorized, 110,846,112 shares and 110,508,605 shares issued as of March 31, 2015 and September 30, 2014, respectively and 107,654,499 shares and 108,232,284 shares outstanding as of March 31, 2015 and September 30, 2014, respectively	11,085			11,051
Preferred stock, no par value, 1,000,000 shares authorized, no shares issued	—			—
Additional paid-in capital	402,442			383,972
Retained earnings	4,729,390			4,525,797
Accumulated other comprehensive income	40,072			83,126
Treasury stock, at cost	(180,613		)	(112,969		)
Total shareholders’ equity	5,002,376			4,890,977

Total liabilities and shareholders’ equity	$	7,344,150		$	6,720,998

The accompanying notes are an integral part of these statements.

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HELMERICH & PAYNE, INC. AND SUBSIDIARIES

CONSOLIDATED CONDENSED STATEMENTS OF INCOME

(Unaudited)

(in thousands, except per share data)

	Three Months Ended						Six Months Ended
	March 31,						March 31,
	2015			2014			2015			2014
Operating revenues:
Drilling — U.S. Land	$	718,463		$	741,791		$	1,608,510		$	1,473,465
Drilling — Offshore	62,626			63,276			132,099			122,330
Drilling — International Land	98,222			85,533			191,107			180,874
Other	3,741			2,830			7,921			5,913
	883,052			893,430			1,939,637			1,782,582

Operating costs and other:
Operating costs, excluding depreciation	469,328			480,167			1,023,571			954,215
Depreciation	149,708			123,963			287,321			244,200
General and administrative	34,902			34,431			67,809			66,674
Research and development	4,857			3,625			9,015			7,882
Income from asset sales	(2,915		)	(4,098		)	(7,070		)	(9,762		)
	655,880			638,088			1,380,646			1,263,209

Operating income from continuing operations	227,172			255,342			558,991			519,373

Other income (expense):
Interest and dividend income	2,549			490			2,834			943
Interest expense	(2,471		)	(1,725		)	(3,032		)	(2,919		)
Gain from sale of investment securities	—			21,352			—			21,352
Other	55			(32		)	369			(377		)
	133			20,085			171			18,999

Income from continuing operations before income taxes	227,305			275,427			559,162			538,372
Income tax provision	77,769			100,838			206,569			190,601
Income from continuing operations	149,536			174,589			352,593			347,771

Income (loss) from discontinued operations before income taxes	(76		)	2,786			(91		)	2,786
Income tax provision	(77		)	2,805			(77		)	2,805

Income (loss) from discontinued operations	1			(19		)	(14		)	(19		)

NET INCOME	$	149,537		$	174,570		$	352,579		$	347,752

Basic earnings per common share:
Income from continuing operations	$	1.38		$	1.61		$	3.25		$	3.22
Income from discontinued operations	—			—			—			—
Net income	$	1.38		$	1.61		$	3.25		$	3.22

Diluted earnings per common share:
Income from continuing operations	$	1.37		$	1.59		$	3.23		$	3.17
Income from discontinued operations	—			—			—			—
Net income	$	1.37		$	1.59		$	3.23		$	3.17

Weighted average shares outstanding:
Basic	107,646			107,692			107,812			107,417
Diluted	108,370			109,081			108,620			108,945

Dividends declared per common share	$	0.6875		$	0.6250		$	1.3750		$	1.2500

The accompanying notes are an integral part of these statements.

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HELMERICH & PAYNE, INC. AND SUBSIDIARIES

CONSOLIDATED CONDENSED STATEMENTS OF COMPREHENSIVE INCOME

(Unaudited)

(in thousands, except per share data)

	Three Months Ended						Six Months Ended
	March 31,						March 31,
	2015			2014			2015			2014

Net income	$	149,537		$	174,570		$	352,579		$	347,752
Other comprehensive income (loss), net of income taxes:
Unrealized depreciation on securities, net of income taxes of ($0.8) million and ($27.4) million at March 31, 2015 and ($2.3) million and ($4.3) million at March 31, 2014	(1,203		)	(3,552		)	(43,447		)	(6,513		)
Reclassification of realized gains in net income, net of income taxes of ($8.5) million at March 31, 2014	—			(12,884		)	—			(12,884		)
Minimum pension liability adjustments, net of income taxes of $0.1 million and $0.2 million at March 31, 2015 and $0.1 million and $0.2 million at March 31, 2014	197			145			393			292
Other comprehensive loss	(1,006		)	(16,291		)	(43,054		)	(19,105		)
Comprehensive income	$	148,531		$	158,279		$	309,525		$	328,647

The accompanying notes are an integral part of these statements.

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HELMERICH & PAYNE, INC. AND SUBSIDIARIES

CONSOLIDATED CONDENSED STATEMENTS OF CASH FLOWS

(Unaudited)

(in thousands)

	Six Months Ended
	March 31,
	2015			2014
OPERATING ACTIVITIES:
Net income	$	352,579		$	347,752
Adjustment for loss from discontinued operations	14			19
Income from continuing operations	352,593			347,771
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation	287,321			244,200
Amortization of debt discount and debt issuance costs	187			186
Provision for bad debt	—			(194		)
Stock-based compensation	13,079			12,804
Other	32			—
Gain on sale of investment securities	—			(21,352		)
Income from asset sales	(7,070		)	(9,762		)
Deferred income tax expense	134,185			13,751
Change in assets and liabilities:
Accounts receivable	81,508			(2,494		)
Inventories	(18,028		)	(10,963		)
Prepaid expenses and other	(17,726		)	21,629
Accounts payable	1,120			(25,337		)
Accrued liabilities	(45,405		)	(19,017		)
Deferred income taxes	(30		)	(1,109		)
Other noncurrent liabilities	30,832			(10,083		)
Net cash provided by operating activities from continuing operations	812,598			540,030
Net cash used in operating activities from discontinued operations	(14		)	(19		)
Net cash provided by operating activities	812,584			540,011

INVESTING ACTIVITIES:
Capital expenditures	(763,365		)	(356,753		)
Proceeds from sale of investment securities	—			23,338
Proceeds from asset sales	15,214			13,321
Net cash used in investing activities	(748,151		)	(320,094		)

FINANCING ACTIVITIES:
Dividends paid	(149,347		)	(121,545		)
Repurchase of common stock	(59,654		)	—
Proceeds from senior notes, net of discount and debt issuance costs	492,791			—
Proceeds on short-term debt	1,002			—
Payments on short-term debt	(1,002		)	—
Net increase in bank overdraft	12,560			—
Exercise of stock options, net of tax withholding	(1,078		)	19,701
Tax withholdings related to net share settlements of restricted stock	(4,248		)	(3,049		)
Excess tax benefit from stock-based compensation	2,761			22,087
Net cash provided by (used in) financing activities	293,785			(82,806		)

Net increase in cash and cash equivalents	358,218			137,111
Cash and cash equivalents, beginning of period	360,909			447,868
Cash and cash equivalents, end of period	$	719,127		$	584,979

The accompanying notes are an integral part of these statements.

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HELMERICH & PAYNE, INC. AND SUBSIDIARIES

CONSOLIDATED CONDENSED STATEMENT OF SHAREHOLDERS’ EQUITY

SIX MONTHS ENDED MARCH 31, 2015

(Unaudited)

(in thousands, except per share amounts)

										Accumulated
				Additional						Other							Total
	Common Stock			Paid-In			Retained			Comprehensive			Treasury Stock				Shareholders’
	Shares	Amount		Capital			Earnings			Income			Shares	Amount			Equity

Balance, September 30, 2014	110,509	$	11,051	$	383,972		$	4,525,797		$	83,126		2,276	$	(112,969	)	$	4,890,977
Net income							352,579										352,579
Other comprehensive loss										(43,054		)					(43,054		)
Dividends declared ($1.375 per share)							(148,986		)								(148,986		)
Exercise of stock options, net of tax withholding	123	13		2,651									47	(3,742		)	(1,078		)
Tax benefit of stock-based awards				2,761													2,761
Stock issued for vested restricted stock, net of shares withheld for employee taxes	214	21		(21		)							59	(4,248		)	(4,248		)
Repurchase of common stock													810	(59,654		)	(59,654		)
Stock-based compensation				13,079													13,079

Balance, March 31, 2015	110,846	$	11,085	$	402,442		$	4,729,390		$	40,072		3,192	$	(180,613	)	$	5,002,376

The accompanying notes are an integral part of these statements.

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HELMERICH & PAYNE, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED CONDENSED FINANCIAL STATEMENTS

(Unaudited)

1. Basis of Presentation

Unless the context otherwise requires, the use of the terms “the Company”, “we”, “us” and “our” in these Notes to Consolidated Condensed Financial Statements refers to Helmerich & Payne, Inc. and its consolidated subsidiaries.

The accompanying unaudited Consolidated Condensed Financial Statements have been prepared in accordance with accounting principles generally accepted in the United States (“GAAP”) and applicable rules and regulations of the Securities and Exchange Commission (the “Commission”) pertaining to interim financial information. Accordingly, these interim financial statements do not include all information or footnote disclosures required by GAAP for complete financial statements and, therefore, should be read in conjunction with the Consolidated Financial Statements and notes thereto in our 2014 Annual Report on Form 10-K and other current filings with the Commission. In the opinion of management all adjustments, consisting of those of a normal recurring nature, necessary to present fairly the results of the periods presented have been included. The results of operations for the interim periods presented may not necessarily be indicative of the results to be expected for the full year.

In April 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”. ASU No. 2015-03 amends the FASB Accounting Standards Codification (“ASC”) to require that debt issuance cost be presented in the balance sheet as a direct deduction from the carrying amount of the related liability. Prior to the amendment, debt issuance costs were reported in the balance sheet as an asset. The amended guidance is effective for financial statements issued for fiscal years beginning after December 15, 2015, however, we have elected to early adopt effective January 1, 2015. The election requires retrospective application and represents a change in accounting principle. The ASU provides that debt issuance costs are similar to debt discounts and in effect reduce the proceeds of borrowing, thereby increasing the effective interest rate. As a result of the adoption, the September 30, 2014 Consolidated Condensed Balance Sheet is restated as follows:

			Effect of
	Previously		Accounting
	Reported		Principle Adoption			Adjusted
	(in thousands)

Consolidated Condensed Balance Sheet
Prepaid expenses and other	$	81,277	$	(365	)	$	80,912
Total current assets	1,277,366		(365		)	1,277,001
Other assets	19,307		(498		)	18,809
Total assets	6,721,861		(863		)	6,720,998
Long-term debt due within one year less unamortized discount and debt issuance costs	40,000		(365		)	39,635
Total current liabilities	507,526		(365		)	507,161
Long-term debt less unamortized discount and debt issuance costs	40,000		(498		)	39,502
Total noncurrent liabilities	1,323,358		(498		)	1,322,860
Total liabilities and shareholders’ equity	6,721,861		(863		)	6,720,998

Amortization of debt discount and debt issuance costs has been reclassified in the accompanying Consolidated Condensed Statements of Cash Flow for the three months ended March 31, 2014 to conform to current year presentation. The amortization was previously included as a change in assets.

As more fully described in our 2014 Annual Report on Form 10-K, our contract drilling revenues are comprised of daywork drilling contracts for which the related revenues and expenses are recognized as services are performed. For contracts that are terminated by customers prior to the expirations of their fixed terms, contractual provisions customarily require early termination amounts to be paid to us. Revenues from early terminated contracts are recognized when all contractual requirements have been met. During the three and six months ended March 31, 2015, early termination revenue was approximately $71.7 million and $95.1 million, respectively. We had no early termination revenue for the three months ended March 31, 2014 and had $9.9 million for the six months ended March 31, 2014.

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Depreciation in the Consolidated Condensed Statements of Income includes abandonments of $10.2 million and $12.2 million for the three and six months ended March 31, 2015 compared to $1.8 million and $3.7 million for the three and six months ended March 31, 2014. Effective March 31, 2015, we decommissioned all 17 of our SCR powered FlexRigs including 6 idle FlexRig1 rigs and 11 idle FlexRig2 rigs.

2. Discontinued Operations

Current assets of discontinued operations consist of restricted cash to meet remaining current obligations within the country of Venezuela. Current and noncurrent liabilities consist of municipal and income taxes payable and social obligations due within the country of Venezuela. Expenses incurred for in-country obligations are reported as discontinued operations.

3. Earnings per Share

ASC 260, Earnings per Share, requires companies to treat unvested share-based payment awards that have non-forfeitable rights to dividends or dividend equivalents as a separate class of securities in calculating earnings per share. We have granted and expect to continue to grant to employees restricted stock grants that contain non-forfeitable rights to dividends. Such grants are considered participating securities under ASC 260. As such, we are required to include these grants in the calculation of our basic earnings per share and calculate basic earnings per share using the two-class method. The two-class method of computing earnings per share is an earnings allocation formula that determines earnings per share for each class of common stock and participating security according to dividends declared (or accumulated) and participation rights in undistributed earnings.

Basic earnings per share is computed utilizing the two-class method and is calculated based on the weighted-average number of common shares outstanding during the periods presented.

Diluted earnings per share is computed using the weighted-average number of common and common equivalent shares outstanding during the periods utilizing the two-class method for stock options and nonvested restricted stock.

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The following table sets forth the computation of basic and diluted earnings per share:

	Three Months Ended						Six Months Ended
	March 31,						March 31,
	2015			2014			2015			2014
	(in thousands, except per share amounts)

Numerator:
Income from continuing operations	$	149,536		$	174,589		$	352,593		$	347,771
Loss from discontinued operations	1			(19		)	(14		)	(19		)
Net income	149,537			174,570			352,579			347,752
Adjustment for basic earnings per share:
Earnings allocated to unvested shareholders	(948		)	(1,035		)	(2,212		)	(2,027		)
Numerator for basic earnings per share:
From continuing operations	148,588			173,554			350,381			345,744
From discontinued operations	1			(19		)	(14		)	(19		)
	148,589			173,535			350,367			345,725
Adjustment for diluted earnings per share:
Effect of reallocating undistributed earnings of unvested shareholders	3			8			9			17
Numerator for diluted earnings per share:
From continuing operations	148,591			173,562			350,390			345,761
From discontinued operations	1			(19		)	(14		)	(19		)
	$	148,592		$	173,543		$	350,376		$	345,742
Denominator:
Denominator for basic earnings per share — weighted-average shares	107,646			107,692			107,812			107,417
Effect of dilutive shares from stock options and restricted stock	724			1,389			808			1,528
Denominator for diluted earnings per share — adjusted weighted-average shares	108,370			109,081			108,620			108,945
Basic earnings per common share:
Income from continuing operations	$	1.38		$	1.61		$	3.25		$	3.22
Income from discontinued operations	—			—			—			—
Net income	$	1.38		$	1.61		$	3.25		$	3.22
Diluted earnings per common share:
Income from continuing operations	$	1.37		$	1.59		$	3.23		$	3.17
Income from discontinued operations	—			—			—			—
Net income	$	1.37		$	1.59		$	3.23		$	3.17

The following shares attributable to outstanding equity awards were excluded from the calculation of diluted earnings per share because their inclusion would have been anti-dilutive:

	Three Months Ended				Six Months Ended
	March 31,				March 31,
	2015		2014		2015		2014
	(in thousands, except per share amounts)

Shares excluded from calculation of diluted earnings per share	667		215		667		256
Weighted-average price per share	$	72.85	$	79.67	$	72.85	$	79.67

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4. Financial Instruments and Fair Value Measurement

The estimated fair value of our available-for-sale securities, reflected on our Consolidated Condensed Balance Sheets as Investments, is based on market quotes. The following is a summary of available-for-sale securities, which excludes assets held in a Non-qualified Supplemental Savings Plan:

			Gross		Gross		Estimated
			Unrealized		Unrealized		Fair
	Cost		Gains		Losses		Value
	(in thousands)

Equity securities March 31, 2015	$	64,462	$	86,986	$	—	$	151,448
Equity securities September 30, 2014	$	64,462	$	157,838	$	—	$	222,300

On an ongoing basis we evaluate the marketable equity securities to determine if any decline in fair value below cost is other-than-temporary. If a decline in fair value below cost is determined to be other-than-temporary, an impairment charge is recorded and a new cost basis established. We review several factors to determine whether a loss is other-than-temporary. These factors include, but are not limited to, (i) the length of time a security is in an unrealized loss position, (ii) the extent to which fair value is less than cost, (iii) the financial condition and near-term prospects of the issuer and (iv) our intent and ability to hold the security for a period of time sufficient to allow for any anticipated recovery in fair value. The cost of securities used in determining realized gains and losses is based on the average cost basis of the security sold.

During the three months ended March 31, 2014, marketable equity available-for-sale securities with a fair value at the date of sale of $23.3 million were sold. The gross realized gain on such sales of available-for-sale securities totaled $21.4 million. We had no sales of marketable equity available-for-sale securities during the six months ended March 31, 2015.

The assets held in the Non-qualified Supplemental Savings Plan are carried at fair value which totaled $13.2 million at March 31, 2015 and $14.3 million at September 30, 2014. The assets are comprised of mutual funds that are measured using Level 1 inputs.

The majority of cash equivalents are invested in highly liquid money-market mutual funds invested primarily in direct or indirect obligations of the U.S. Government. The carrying amount of cash and cash equivalents approximates fair value due to the short maturity of those investments.

Fair value is defined as the exchange price that would be received to sell an asset or paid to transfer a liability (an exit price) in the principal or most advantageous market for the asset or liability in an orderly transaction between market participants at the measurement date. We use the fair value hierarchy established in ASC 820-10 to measure fair value to prioritize the inputs:

· Level 1 — Quoted prices (unadjusted) in active markets for identical assets or liabilities that the reporting entity can access at the measurement date.

· Level 2 — Observable inputs, other than quoted prices included in Level 1, such as quoted prices for similar assets or liabilities in active markets; quoted prices for similar assets and liabilities in markets that are not active; or other inputs that are observable or can be corroborated by observable market data.

· Level 3 — Unobservable inputs that are supported by little or no market activity and that are significant to the fair value of the assets or liabilities. This includes pricing models, discounted cash flow methodologies and similar techniques that use significant unobservable inputs.

At March 31, 2015, our financial instruments utilizing Level 1 inputs include cash equivalents, equity securities with active markets, money market funds we have elected to classify as restricted assets that are included in other current assets and other assets. Also included is cash denominated in a foreign currency that we have elected to classify as restricted to be used to settle the remaining liabilities of discontinued operations. For these items, quoted current market prices are readily available.

At March 31, 2015, financial instruments utilizing level 2 inputs include a bank certificate of deposit included in other current assets.

Currently, we do not have any financial instruments utilizing Level 3 inputs.

The following table summarizes our assets measured at fair value on a recurring basis presented in our Consolidated Condensed Balance Sheet as of March 31, 2015:

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			Quoted Prices
	Total		in Active		Significant
	Measure		Markets for		Other		Significant
	at		Identical		Observable		Unobservable
	Fair		Assets		Inputs		Inputs
	Value		(Level 1)		(Level 2)		(Level 3)
	(in thousands)

Assets:
Cash and cash equivalents	$	719,127	$	719,127	$	—	$	—
Equity securities	151,448		151,448		—		—
Other current assets	36,340		36,090		250		—
Other assets	2,000		2,000		—		—
Total assets measured at fair value	$	908,915	$	908,665	$	250	$	—

The following information presents the supplemental fair value information about long-term fixed-rate debt at March 31, 2015 and September 30, 2014:

	March 31,		September 30,
	2015		2014
	(in millions)

Carrying value of long-term fixed-rate debt	$	572.1	$	79.0
Fair value of long-term fixed-rate debt	$	597.2	$	84.3

The fair value for the $80 million fixed-rate debt was estimated using discounted cash flows at rates reflecting current interest rates at similar maturities plus a credit spread which was estimated using the outstanding market information on debt instruments with a similar credit profile to us. The debt was valued using a Level 2 input.

The fair value for the $500 million fixed-rate debt was based on broker quotes at March 31, 2015. The notes are classified within Level 2 as they are not actively traded in markets.

5. Shareholders’ Equity

The Company has authorization from the Board of Directors for the repurchase of up to four million shares per calendar year. The repurchases may be made using our cash and cash equivalents or other available sources. During the six months ended March 31, 2015, we purchased 810,097 common shares at an aggregate cost of $59.7 million, which are held as treasury shares. We had no purchases of common shares in fiscal 2014.

Components of accumulated other comprehensive income (loss) were as follows:

	March 31,			September 30,
	2015			2014
	(in thousands)
Pre-tax amounts:
Unrealized appreciation on securities	$	86,986		$	157,838
Unrecognized actuarial loss	(22,787		)	(23,405		)
	$	64,199		$	134,433
After-tax amounts:
Unrealized appreciation on securities	$	53,971		$	97,418
Unrecognized actuarial loss	(13,899		)	(14,292		)
	$	40,072		$	83,126

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The following is a summary of the changes in accumulated other comprehensive income (loss), net of tax, by component for the three and six months ended March 31, 2015:

	Three Months Ended March 31, 2015
	Unrealized
	Appreciation (Depreciation) on			Defined
	Available-for-sale			Benefit
	Securities			Pension Plan			Total
	(in thousands)

Balances at January 1, 2015	$	55,174		$	(14,096	)	$	41,078
Other comprehensive loss before reclassifications	(1,203		)	—			(1,203		)
Amounts reclassified from accumulated other comprehensive income (loss)	—			197			197
Net current-period other comprehensive income (loss)	(1,203		)	197			(1,006		)
Balances at March 31, 2015	$	53,971		$	(13,899	)	$	40,072

	Six Months Ended March 31, 2015
	Unrealized
	Appreciation (Depreciation) on			Defined
	Available-for-sale			Benefit
	Securities			Pension Plan			Total
	(in thousands)

Balances at October 1, 2014	$	97,418		$	(14,292	)	$	83,126
Other comprehensive loss before reclassifications	(43,447		)	—			(43,447		)
Amounts reclassified from accumulated other comprehensive income (loss)	—			393			393
Net current-period other comprehensive income (loss)	(43,447		)	393			(43,054		)
Balances at March 31, 2015	$	53,971		$	(13,899	)	$	40,072

The following provides detail about accumulated other comprehensive income (loss) components which were reclassified to the Condensed Consolidated Statement of Income during the three and six months ended March 31, 2015:

	Amount Reclassified from Accumulated Other Comprehensive Income (Loss)
Details About Accumulated Other Comprehensive Income	Three Months Ended March 31,						Six Months Ended March 31,						Affected Line Item in the Condensed Consolidated
(Loss) Components	2015			2014			2015			2014			Statement of Income
	(in thousands)						(in thousands)

Unrealized gains on available-for-sale securities	$	—		$	(21,352	)	$	—		$	(21,352	)	Gain on sale of investment securities
	—			8,468			—			8,468			Income tax provision
	$	—		$	(12,884	)	$	—		$	(12,884	)	Net of tax

Defined Benefit Pension Items Amortization of net actuarial loss	$	309		$	229		$	618		$	458		General and administrative
	(112		)	(84		)	(225		)	(166		)	Income tax provision
	$	197		$	145		$	393		$	292		Net of tax

Total reclassifications for the period	$	197		$	(12,739	)	$	393		$	(12,592	)

6. Cash Dividends

The $0.6875 per share cash dividend declared December 2, 2014, was paid March 2, 2015. On March 4, 2015, a cash dividend of $0.6875 per share was declared for shareholders of record on May 15, 2015, payable June 1, 2015. The dividend payable is included in accounts payable in the Consolidated Condensed Balance Sheet.

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7. Stock-Based Compensation

On March 2, 2011, the 2010 Long-Term Incentive Plan (the “2010 Plan”) was approved by our stockholders. The 2010 Plan, among other things, authorizes the Human Resources Committee of the Board to grant non-qualified stock options, restricted stock awards and stock appreciation rights to selected employees and to non-employee Directors. Restricted stock may be granted for no consideration other than prior and future services. The purchase price per share for stock options may not be less than market price of the underlying stock on the date of grant. Stock options expire 10 years after the grant date. There were 419,585 non-qualified stock options and 275,250 shares of restricted stock awards granted in the six months ended March 31, 2015. Awards outstanding in the 2005 Long-Term Incentive Plan (the “2005 Plan”) and one prior equity plan remain subject to the terms and conditions of those plans.

A summary of compensation cost for stock-based payment arrangements recognized in general and administrative expense is as follows:

	Three Months Ended				Six Months Ended
	March 31,				March 31,
	2015		2014		2015		2014
	(in thousands)				(in thousands)
Compensation expense
Stock options	$	1,908	$	1,989	$	4,970	$	5,642
Restricted stock	4,189		3,805		8,109		7,162
	$	6,097	$	5,794	$	13,079	$	12,804

STOCK OPTIONS

The following summarizes the weighted-average assumptions utilized in determining the fair value of options granted during the six months ended March 31, 2015 and 2014:

	2015		2014

Risk-free interest rate	1.7	%	1.6	%
Expected stock volatility	36.9	%	52.6	%
Dividend yield	3.9	%	3.1	%
Expected term (in years)	5.5		5.5

Risk-Free Interest Rate. The risk-free interest rate is based on U.S. Treasury securities for the expected term of the option.

Expected Volatility Rate. Expected volatility is based on the daily closing price of our stock based upon historical experience over a period which approximates the expected term of the option.

Expected Dividend Yield. The expected dividend yield is based on our current dividend yield.

Expected Term. The expected term of the options granted represents the period of time that they are expected to be outstanding. We estimate the expected term of options granted based on historical experience with grants and exercises.

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A summary of stock option activity under all existing long-term incentive plans for the three and six months ended March 31, 2015 is presented in the following tables:

	Three Months Ended March 31, 2015
					Weighted-
			Weighted-		Average	Aggregate
			Average		Remaining	Intrinsic
	Shares		Exercise		Contractual Term	Value
Options	(in thousands)		Price		(in years)	(in millions)

Outstanding at January 1, 2015	2,931		$	47.96
Granted	—		—
Exercised	(20	)	51.38
Forfeited/Expired	(2	)	76.68
Outstanding at March 31, 2015	2,909		$	47.91	5.6	$	61.8
Vested and expected to vest at March 31, 2015	2,902		$	47.86	5.6	$	61.8

Exercisable at March 31, 2015	2,147		$	41.22	4.6	$	58.7

	Six Months Ended March 31, 2015
			Weighted-
			Average
	Shares		Exercise
Options	(in thousands)		Price

Outstanding at October 1, 2014	2,629		$	43.46
Granted	420		68.83
Exercised	(124	)	21.56
Forfeited/Expired	(16	)	68.59
Outstanding at March 31, 2015	2,909		$	47.91

The weighted-average fair value of options granted in the first quarter of fiscal 2015 was $16.39. No options were granted in the second quarter of fiscal 2015.

The total intrinsic value of options exercised during the three and six months ended March 31, 2015 was $0.3 million and $7.2 million, respectively.

As of March 31, 2015, the unrecognized compensation cost related to stock options was $9.2 million which is expected to be recognized over a weighted-average period of 2.8 years.

RESTRICTED STOCK

Restricted stock awards consist of our common stock and are time-vested over three to six years. We recognize compensation expense on a straight-line basis over the vesting period. The fair value of restricted stock awards under the 2010 Plan is determined based on the closing price of our shares on the grant date. As of March 31, 2015, there was $29.9 million of total unrecognized compensation cost related to unvested restricted stock awards which is expected to be recognized over a weighted-average period of 2.7 years.

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A summary of the status of our restricted stock awards as of March 31, 2015 and changes in restricted stock outstanding during the six months then ended is presented below:

	Six Months Ended
	March 31, 2015
			Weighted-
			Average
	Shares		Grant-Date
Restricted Stock Awards	(in thousands)		Fair Value

Unvested at October 1, 2014	634		$	64.03
Granted	275		68.83
Vested (1)	(214	)	54.18
Forfeited	(8	)	66.51
Unvested at March 31, 2015	687		$	66.93

(1) The number of restricted stock awards vested includes shares that we withheld on behalf of our employees to satisfy the statutory tax withholding requirements.

8. Debt

At March 31, 2015 and September 30, 2014, we had the following unsecured long-term debt outstanding:

							Unamortized Discount and
	Principal						Debt Issuance Costs
	March 31,			September 30,			March 31,			September 30,
	2015			2014			2015			2014
	(in thousands)

Unsecured senior notes issued July 21, 2009:
Due July 21, 2015	$	40,000		$	40,000		$	112		$	141
Due July 21, 2016	40,000			40,000			113			141

Unsecured revolving credit facility issued May 25, 2012	—			—			471			581

Unsecured senior notes issued March 19, 2015:
Due March 19, 2025	500,000			—			7,189			—
	580,000			80,000			7,885			863
Less long-term debt due within one year	(40,000		)	(40,000		)	(793		)	(365		)
Long-term debt	$	540,000		$	40,000		$	7,092		$	498

We have $80 million senior unsecured fixed-rate notes outstanding at March 31, 2015 that mature over a period from July 2015 to July 2016. Interest on the notes is paid semi-annually based on an annual rate of 6.10 percent. Annual principal repayments of $40 million are due July 2015 and July 2016. We have complied with our financial covenants which require us to maintain a funded leverage ratio of less than 55 percent and an interest coverage ratio (as defined) of not less than 2.50 to 1.00.

On March 19, 2015, we issued $500 million of 4.65 percent 10-year unsecured senior notes. The net proceeds, after discount and issuance cost, of approximately $492.8 million will be used for general corporate purposes, including capital expenditures associated with our rig construction program. Interest is payable semi-annually on March 15 and September 15 each year, commencing on September 15, 2015. The debt discount is being amortized to interest expense using the effective interest method. The debt issuance costs are amortized straight-line over the stated life of the obligation, which approximates the effective yield method.

We have a $300 million unsecured revolving credit facility that will mature May 25, 2017. The credit facility has $100 million available to use for letters of credit. The majority of borrowings under the facility would accrue interest at a spread over the London Interbank Offered Rate (LIBOR). We also pay a commitment fee based on the unused balance of the facility. Borrowing spreads as well as commitment fees are determined according to a scale based on a ratio of our total debt to total capitalization. The spread over LIBOR ranges from 1.125 percent to 1.75 percent per annum and commitment fees range from .15 percent to .35 percent per annum. Based on our debt to total capitalization on March 31, 2015, the spread over LIBOR and commitment fees would be 1.125 percent and .15 percent, respectively. Financial covenants in the facility require us to maintain a funded leverage

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ratio (as defined) of less than 50 percent and an interest coverage ratio (as defined) of not less than 3.00 to 1.00. The credit facility contains additional terms, conditions, restrictions, and covenants that we believe are usual and customary in unsecured debt arrangements for companies of similar size and credit quality. At March 31, 2015, we were in compliance with all debt covenants. As of March 31, 2015, there were no borrowings, but there were three letters of credit outstanding in the amount of $48.2 million. One of the three outstanding letters of credit is a $21 million letter that supports an overdraft facility with a bank in an international location. The short-term borrowing is in local currency with an interest rate that adjusts monthly based on local market rates. Given local currency considerations, the annual interest rates approach 30 percent. At March 31, 2015, we had $251.8 million available to borrow under our $300 million unsecured credit facility.

At March 31, 2015, we had two letters of credit outstanding, totaling $12 million that were issued to support international operations. These letters of credit were issued separately from the $300 million credit facility so they do not reduce the available borrowing capacity discussed in the previous paragraph.

We have a $9.5 million unsecured line of credit with a bank in an international location that will mature on June 12, 2015. A total of $7 million may be borrowed for working capital needs and $2.5 million is reserved for bank guaranties. The interest rate for borrowings would be at seven percent. At March 31, 2015, there were no borrowings or bank guarantees outstanding against the line.

9. Income Taxes

Our effective tax rate for the first six months of fiscal 2015 and 2014 was 36.9 percent and 35.4 percent, respectively. Our effective tax rate for the three months ended March 31, 2015 and 2014 was 34.2 percent and 36.6 percent, respectively. Effective tax rates differ from the U.S. federal statutory rate of 35.0 percent primarily due to state and foreign income taxes and the tax benefit from the Internal Revenue Code Section 199 deduction for domestic production activities. The effective tax rate for the six months ended March 31, 2015 was also impacted by a December 2014 tax law change which resulted in a reduction of the fiscal 2014 Internal Revenue Code Section 199 deduction for domestic production activities.

For the next 12 months, we cannot predict with certainty whether we will achieve ultimate resolution of any uncertain tax positions associated with our U.S. and international operations that could result in increases or decreases of our unrecognized tax benefits. However, we do not expect the increases or decreases to have a material effect on results of operations or financial position. We provided for uncertain tax positions of $7.0 million, including interest and penalties, during the six months ended March 31, 2015 related to the previous disclosure of a possible increase in the reserve for uncertain tax positions of approximately $8.4 million to $11.0 million due to international tax matters.

10. Commitments and Contingencies

In conjunction with our current drilling rig construction program, purchase commitments for equipment, parts and supplies of approximately $205.2 million are outstanding at March 31, 2015.

Other than the matters described below, the Company is a party to various pending legal actions arising in the ordinary course of its business. We maintain insurance against certain business risks subject to certain deductibles. None of these legal actions are expected to have a material adverse effect on our financial condition, cash flows or results of operations.

We are contingently liable to sureties in respect of bonds issued by the sureties in connection with certain commitments entered into by us in the normal course of business. We have agreed to indemnify the sureties for any payments made by them in respect of such bonds.

During the ordinary course of our business, contingencies arise resulting from an existing condition, situation or set of circumstances involving an uncertainty as to the realization of a possible gain contingency. We account for gain contingencies in accordance with the provisions of ASC 450, Contingencies, and, therefore, we do not record gain contingencies or recognize income until realized. The property and equipment of our Venezuelan subsidiary was seized by the Venezuelan government on June 30, 2010. Our wholly-owned subsidiaries, Helmerich & Payne International Drilling Co. and Helmerich & Payne de Venezuela, C.A., filed a lawsuit in the United States District Court for the District of Columbia on September 23, 2011 against the Bolivarian Republic of Venezuela, Petroleos de Venezuela, S.A. (“PDVSA”) and PDVSA Petroleo, S.A. (“Petroleo”). Our subsidiaries seek damages for the taking of their Venezuelan drilling business in violation of international law and for breach of contract. While there exists the possibility of realizing a recovery, we are currently unable to determine the timing or amounts we may receive, if any, or the likelihood of recovery. No gain contingencies are recognized in our Consolidated Financial Statements.

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On November 8, 2013, the United States District Court for the Eastern District of Louisiana approved the previously disclosed October 30, 2013 plea agreement between our wholly owned subsidiary, Helmerich & Payne International Drilling Co., and the United States Department of Justice, United States Attorney’s Office for the Eastern District of Louisiana (“DOJ”). The court’s approval of the plea agreement resolved the DOJ’s investigation into certain choke manifold testing irregularities that occurred in 2010 at one of Helmerich & Payne International Drilling Co.’s offshore platform rigs in the Gulf of Mexico. We have been engaged in discussions with the Inspector General’s office of the Department of Interior regarding the same events that were the subject of the DOJ’s investigation. We can provide no assurances as to the timing or eventual outcome of these discussions and are unable to determine the amount of penalty, if any, that may be assessed. However, we presently believe that the outcome of our discussions will not have a material adverse effect on the Company.

11. Segment Information

We operate principally in the contract drilling industry. Our contract drilling business includes the following reportable operating segments: U.S. Land, Offshore and International Land. The contract drilling operations consist mainly of contracting Company-owned drilling equipment primarily to large oil and gas exploration companies. To provide information about the different types of business activities in which we operate, we have included Offshore and International Land, along with our U.S. Land reportable operating segment, as separate reportable operating segments. Additionally, each reportable operating segment is a strategic business unit that is managed separately. Our primary international areas of operation include Colombia, Ecuador, Argentina, Tunisia, Bahrain, U.A.E. and other South American and Middle Eastern countries. Other includes additional non-reportable operating segments. Revenues included in Other consist primarily of rental income. Consolidated revenues and expenses reflect the elimination of all material intercompany transactions.

We evaluate segment performance based on income or loss from continuing operations (segment operating income) before income taxes which includes:

· revenues from external and internal customers

· direct operating costs

· depreciation and

· allocated general and administrative costs

but excludes corporate costs for other depreciation, income from asset sales and other corporate income and expense.

General and administrative costs are allocated to the segments based primarily on specific identification and, to the extent that such identification is not practical, on other methods which we believe to be a reasonable reflection of the utilization of services provided.

Segment operating income for all segments is a non-GAAP financial measure of our performance, as it excludes certain general and administrative expenses, corporate depreciation, income from asset sales and other corporate income and expense. We consider segment operating income to be an important supplemental measure of operating performance by presenting trends in our core businesses. We use this measure to facilitate period-to-period comparisons in operating performance of our reportable segments in the aggregate by eliminating items that affect comparability between periods. We believe that segment operating income is useful to investors because it provides a means to evaluate the operating performance of the segments on an ongoing basis using criteria that are used by our internal decision makers. Additionally, it highlights operating trends and aids analytical comparisons. However, segment operating income has limitations and should not be used as an alternative to operating income or loss, a performance measure determined in accordance with GAAP, as it excludes certain costs that may affect our operating performance in future periods.

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Summarized financial information of our reportable segments for the six months ended March 31, 2015 and 2014 is shown in the following tables:

									Segment
	External		Inter-			Total			Operating
(in thousands)	Sales		Segment			Sales			Income (Loss)
March 31, 2015
Contract Drilling:
U.S. Land	$	1,608,510	$	—		$	1,608,510		$	542,988
Offshore	132,099		—			132,099			40,553
International Land	191,107		—			191,107			18,542
	1,931,716		—			1,931,716			602,083
Other	7,921		442			8,363			(5,116		)
	1,939,637		442			1,940,079			596,967
Eliminations	—		(442		)	(442		)	—
Total	$	1,939,637	$	—		$	1,939,637		$	596,967

									Segment
	External		Inter-			Total			Operating
(in thousands)	Sales		Segment			Sales			Income (Loss)
March 31, 2014
Contract Drilling:
U.S. Land	$	1,473,465	$	—		$	1,473,465		$	496,014
Offshore	122,330		—			122,330			37,841
International Land	180,874		—			180,874			23,919
	1,776,669		—			1,776,669			557,774
Other	5,913		431			6,344			(5,249		)
	1,782,582		431			1,783,013			552,525
Eliminations	—		(431		)	(431		)	—
Total	$	1,782,582	$	—		$	1,782,582		$	552,525

Summarized financial information of our reportable segments for the three months ended March 31, 2015 and 2014 is shown in the following tables:

									Segment
	External		Inter-			Total			Operating
(in thousands)	Sales		Segment			Sales			Income (Loss)
March 31, 2015
Contract Drilling:
U.S. Land	$	718,463	$	—		$	718,463		$	224,866
Offshore	62,626		—			62,626			19,069
International Land	98,222		—			98,222			6,328
	879,311		—			879,311			250,263
Other	3,741		220			3,961			(3,217		)
	883,052		220			883,272			247,046
Eliminations	—		(220		)	(220		)	—
Total	$	883,052	$	—		$	883,052		$	247,046

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									Segment
	External		Inter-			Total			Operating
(in thousands)	Sales		Segment			Sales			Income (Loss)
March 31, 2014
Contract Drilling:
U.S. Land	$	741,791	$	—		$	741,791		$	245,062
Offshore	63,276		—			63,276			19,343
International Land	85,533		—			85,533			11,168
	890,600		—			890,600			275,573
Other	2,830		211			3,041			(2,244		)
	893,430		211			893,641			273,329
Eliminations	—		(211		)	(211		)	—
Total	$	893,430	$	—		$	893,430		$	273,329

The following table reconciles segment operating income per the table above to income from continuing operations before income taxes as reported on the Consolidated Condensed Statements of Income:

	Three Months Ended						Six Months Ended
	March 31,						March 31,
	2015			2014			2015			2014
	(in thousands)						(in thousands)

Segment operating income	$	247,046		$	273,329		$	596,967		$	552,525
Income from asset sales	2,915			4,098			7,070			9,762
Corporate general and administrative costs and corporate depreciation	(22,789		)	(22,085		)	(45,046		)	(42,914		)
Operating income	227,172			255,342			558,991			519,373

Other income (expense):
Interest and dividend income	2,549			490			2,834			943
Interest expense	(2,471		)	(1,725		)	(3,032		)	(2,919		)
Gain on sale of investment securities	—			21,352			—			21,352
Other	55			(32		)	369			(377		)
Total other income (expense)	133			20,085			171			18,999

Income from continuing operations before income taxes	$	227,305		$	275,427		$	559,162		$	538,372

The following table presents total assets by reportable segment:

			September 30,
	March 31,		2014
	2015		(as adjusted)
	(in thousands)
Total assets
U.S. Land	$	5,482,725	$	5,259,947
Offshore	117,813		137,101
International Land	713,138		589,968
Other	40,228		40,080
	6,353,904		6,027,096
Investments and corporate operations	982,760		686,696
Total assets from continued operations	7,336,664		6,713,792
Discontinued operations	7,486		7,206
	$	7,344,150	$	6,720,998

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The following table presents revenues from external customers by country based on the location of service provided:

	Three Months Ended				Six Months Ended
	March 31,				March 31,
	2015		2014		2015		2014
	(in thousands)				(in thousands)

Operating revenues
United States	$	778,637	$	800,775	$	1,734,918	$	1,589,466
Argentina	39,480		26,695		64,563		53,054
Colombia	22,903		21,064		46,354		47,794
Ecuador	6,420		16,822		21,614		34,622
Other foreign	35,612		28,074		72,188		57,646
Total	$	883,052	$	893,430	$	1,939,637	$	1,782,582

12. Pensions and Other Post-retirement Benefits

The following provides information at March 31, 2015 and 2014 related to the Company-sponsored domestic defined benefit pension plan:

Components of Net Periodic Benefit Cost

	Three Months Ended						Six Months Ended
	March 31,						March 31,
	2015			2014			2015			2014
	(in thousands)						(in thousands)

Interest cost	$	1,171		$	1,201		$	2,342		$	2,402
Expected return on plan assets	(1,743		)	(1,664		)	(3,486		)	(3,328		)
Recognized net actuarial loss	309			229			618			458
Net pension expense	$	(263	)	$	(234	)	$	(526	)	$	(468	)

Employer Contributions

We did not make any contributions to the Pension Plan during the six months ended March 31, 2015. Subsequent to March 31, 2015, we contributed $2.0 million to fund distributions. We could make contributions for the remainder of fiscal 2015 to fund distributions in lieu of liquidating assets.

13. Supplemental Cash Flow Information

Capital expenditures on the Consolidated Condensed Statements of Cash Flows do not include additions which have been incurred but not paid for as of the end of the period. The following table reconciles total capital expenditures incurred to total capital expenditures in the Consolidated Condensed Statements of Cash Flows:

	Six Months Ended
	March 31,
	2015			2014
	(in thousands)

Capital expenditures incurred	$	679,771		$	372,892
Additions incurred prior year but paid for in current period	123,548			29,264
Additions incurred but not paid for as of the end of the period	(39,954		)	(45,403		)
Capital expenditures per Consolidated Condensed Statements of Cash Flows	$	763,365		$	356,753

14. International Risk Factors

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system. We are monitoring the status of this change in Venezuela’s exchange control policy. There can be no assurance that there will not be changes in local laws, regulations and administrative requirements or the interpretation thereof which could have a material adverse effect on the profitability of our operations or on our ability to continue operations in certain areas.

15. Recently Issued Accounting Standards

In May 2014, the FASB issued ASU No. 2014-09, Revenue from Contracts with Customers, which supersedes virtually all existing revenue recognition guidance. The new standard requires an entity to recognize revenue when it transfers promised goods or services to customers in an amount that reflects the consideration the entity expects to receive in exchange for those goods or services. This update also requires additional disclosure about the nature, amount, timing and uncertainty of revenue and cash flows arising from customer contracts, including significant judgments and changes in judgments and assets recognized from costs incurred to obtain or fulfill a contract. The provisions of ASU 2014-09 are effective for interim and annual periods beginning after December 15, 2016, and we have the option of using either a full retrospective or a modified retrospective approach when adopting this new standard. We are currently evaluating the alternative transition methods and the potential effects of the adoption of this update on our financial statements.

16. Subsequent Events

Due to the continued downturn in the oil and gas industry from the decline in oil prices, our customers have reduced their drilling activity. As a result, we have received termination notices for rigs that were under contract at March 31, 2015. Given the current trend, we could have less than 150 rigs contracted and generating revenue in the U.S. Land segment by June 30, 2015 and early termination revenue could exceed $75 million during the third quarter of fiscal 2015.

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ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION

AND RESULTS OF OPERATIONS

March 31, 2015

RISK FACTORS AND FORWARD-LOOKING STATEMENTS

The following discussion should be read in conjunction with the Consolidated Condensed Financial Statements and related notes included elsewhere herein and the Consolidated Financial Statements and notes thereto included in our 2014 Annual Report on Form 10-K. Our future operating results may be affected by various trends and factors which are beyond our control. These include, among other factors, fluctuations in natural gas and crude oil prices, the loss of one or a number of our largest customers, early termination of drilling contracts and failure to realize backlog drilling revenue, forfeiture of early termination payments under fixed term contracts due to sustained unacceptable performance, unsuccessful collection of receivables, inability to procure key rig components, failure to timely deliver rigs within applicable grace periods, disruption to or cessation of the business of our limited source vendors or fabricators, currency exchange losses, expropriation of assets and other international uncertainties, loss of well control, pollution of offshore waters and reservoir damage, operational risks that are not fully insured against or covered by adequate contractual indemnities, passage of laws or regulations including those limiting hydraulic fracturing, litigation and governmental investigations, failure to comply with the terms of our plea agreement with the United States Department of Justice, failure to comply with the United States Foreign Corrupt Practices Act, foreign anti-bribery laws and other governmental laws and regulations, a sluggish global economy, changes in general economic and political conditions, adverse weather conditions including hurricanes, rapid or unexpected changes in drilling or other technologies and uncertain business conditions that affect our businesses. Accordingly, past results and trends should not be used by investors to anticipate future results or trends. Our risk factors are more fully described in our 2014 Annual Report on Form 10-K and elsewhere in this Form 10-Q.

With the exception of historical information, the matters discussed in Management’s Discussion & Analysis of Financial Condition and Results of Operations include forward-looking statements. Forward-looking statements generally can be identified by the use of forward-looking terminology such as “may”, “will”, “expect”, “intend”, “estimate”, “anticipate”, “believe”, or “continue” or the negative thereof or similar terminology. These forward-looking statements are based on various assumptions. We caution that, while we believe such assumptions to be reasonable and make them in good faith, assumptions about future events and conditions almost always vary from actual results. The differences between assumed facts and actual results can be material. We are including this cautionary statement to take advantage of the “safe harbor” provisions of the Private Securities Litigation Reform Act of 1995 for any forward-looking statements made by us or persons acting on our behalf. The factors identified in this cautionary statement are important factors (but not necessarily all important factors) that could cause actual results to differ materially from those expressed in any forward-looking statement made by us or persons acting on our behalf. Except as required by law, we undertake no duty to update or revise our forward-looking statements based on changes of internal estimates on expectations or otherwise.

RESULTS OF OPERATIONS

Three Months Ended March 31, 2015 vs. Three Months Ended March 31, 2014

We reported net income of $149.5 million ($1.37 per diluted share) from operating revenues of $883.1 million for the second quarter ended March 31, 2015, compared with net income from continuing operations of $174.6 million ($1.59 per diluted share) from operating revenues of $893.4 million for the second quarter of fiscal year 2014. Net income for the second quarter of fiscal 2015 includes approximately $1.9 million ($0.02 per diluted share) of after-tax gains from the sale of assets. Net income for the second quarter of fiscal 2014 includes approximately $12.9 million ($0.12 per diluted share) of after-tax gains from the sale of investment securities and approximately $2.7 million ($0.02 per diluted share) of after-tax gains from the sale of assets.

The following tables summarize operations by reportable operating segment for the three months ended March 31, 2015 and 2014. Operating statistics in the tables exclude the effects of offshore platform and international management contracts, and do not include reimbursements of “out-of-pocket” expenses in revenue, expense and margin per day calculations. Per day calculations for international operations also exclude gains and losses from translation of foreign currency transactions. Segment operating income is described in detail in Note 11 to the Consolidated Condensed Financial Statements.

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	Three Months Ended March 31,
	2015			2014
	(in thousands, except days and per day amounts)
U.S. LAND OPERATIONS
Revenues	$	718,463		$	741,791
Direct operating expenses	352,489			378,347
General and administrative expense	12,605			10,656
Depreciation	128,503			107,726
Segment operating income	$	224,866		$	245,062

Revenue days	20,802			24,300
Average rig revenue per day	$	30,988		$	28,037
Average rig expense per day	$	13,395		$	13,080
Average rig margin per day	$	17,593		$	14,957
Rig utilization	68		%	86		%

U.S. Land segment operating income decreased to $224.9 million for the second quarter of fiscal 2015 compared to $245.1 million in the same period of fiscal 2014. Revenues were $718.5 million and $741.8 million in the second quarter of fiscal 2015 and 2014, respectively. Included in U.S. land revenues for the three months ended March 31, 2015 and 2014 are reimbursements for “out-of-pocket” expenses of $73.9 million and $60.5 million, respectively. Also included in revenue for the three months ended March 31, 2015 is early termination revenue of $71.0 million. We had no early termination fees during the same period of fiscal 2014.

Excluding early termination revenue of $3,413, average rig revenue per day for the second quarter of fiscal 2015 compared to the second quarter of fiscal 2014 decreased by $462 to $2,951. The decline in oil prices continues to have a negative effect on customer spending. As a result, some operators are not renewing contracts or are terminating their contracts early. Fixed-term contracts customarily provide for termination at the election of the customer, with an early termination payment to be paid to us if a contract is terminated prior to the expiration of the fixed term (except in limited circumstances including sustained unacceptable performance by us).

Depreciation increased $20.8 million in the second quarter of fiscal 2015 compared to the second quarter of fiscal 2014. Included in depreciation are abandonments of $9.9 million and $1.5 million, respectively, for the three months ended March 31, 2015 and 2014. Included in abandonments for the three months ended March 31, 2015 is the decommissioning of all 17 of our SCR powered FlexRigs including 6 idle FlexRig1 rigs and 11 idle FlexRig2 rigs. With the continued downturn in the oil and gas industry, we believe when the demand for drilling rigs returns, our SCR powered FlexRigs will not meet the needs of our customers. Excluding abandonments, depreciation increased in the comparative periods due to the increase in available rigs as new FlexRigs were added to the segment in 2014 and 2015.

U.S. land rig utilization decreased to 68 percent for the second quarter of 2015 compared to 86 percent for the second quarter of fiscal 2014. U.S. land rig revenue days for the second quarter of fiscal 2015 were 20,802 compared with 24,300 for the same period of fiscal 2014, with an average of 231.1 and 270.0 rigs working during the second quarter of fiscal 2015 and 2014, respectively. We expect rig utilization to decrease in the third quarter of fiscal 2015 as customers continue to reduce their drilling activity and rigs are idled. Given the current trend, we could have less than 150 rigs contracted and generating revenue by June 30, 2015.

At March 31, 2015, 179 out of 332 existing rigs in the U.S. Land segment were contracted. Of the 179 contracted rigs, 145 were under fixed term contracts and 34 were working in the spot market. As of April 23, 2015, 165 rigs remain contracted in the segment excluding rigs that are in the process of stacking. Based on the early termination notices received since March 31, 2015, early termination revenue could exceed $75 million during the third fiscal quarter of 2015.

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	Three Months Ended March 31,
	2015			2014
	(in thousands, except days and per day amounts)
OFFSHORE OPERATIONS
Revenues	$	62,626		$	63,276
Direct operating expenses	39,433			38,479
General and administrative expense	954			2,528
Depreciation	3,170			2,926
Segment operating income	$	19,069		$	19,343

Revenue days	794			720
Average rig revenue per day	$	49,783		$	64,242
Average rig expense per day	$	31,112		$	36,577
Average rig margin per day	$	18,671		$	27,665
Rig utilization	98		%	89		%

Offshore revenues include reimbursements for “out-of-pocket” expenses of $5.3 million and $4.9 million for the three months ended March 31, 2015 and 2014, respectively.

Average revenue per day and average rig margin per day decreased in the first quarter of fiscal 2015 compared to the first quarter of fiscal 2014 primarily due to a contractual decrease in the dayrate for one rig.

At the end of March 31, 2015 and March 31, 2014, eight platform rigs were active.

	Three Months Ended March 31,
	2015			2014
	(in thousands, except days and per day amounts)
INTERNATIONAL LAND OPERATIONS
Revenues	$	98,222		$	85,533
Direct operating expenses	77,452			63,688
General and administrative expense	1,019			964
Depreciation	13,423			9,713
Segment operating income	$	6,328		$	11,168

Revenue days	1,842			2,032
Average rig revenue per day	$	47,063		$	37,095
Average rig expense per day	$	36,166		$	26,177
Average rig margin per day	$	10,897		$	10,918
Rig utilization	52		%	78		%

International Land segment operating income for the second quarter of fiscal 2015 was $6.3 million compared to $11.2 million in the same period of fiscal 2014. Included in International land revenues for the three months ended March 31, 2015 and 2014 are reimbursements for “out-of-pocket” expenses of $11.5 million and $10.2 million, respectively. Also included in revenue for the three months ended March 31, 2015 is early termination revenue of $0.7 million.

Rigs transferred into the segment in previous quarters that have begun operations favorably impacted revenue and average rig revenue per day during the second quarter of fiscal 2015. Average rig expense per day increased due to those same rigs incurring startup costs and idle rigs incurring fixed costs while stacked. During the current quarter, an average of 20.5 rigs worked compared to an average of 22.6 rigs in the second quarter of fiscal 2014. Four of the rigs transferred into the segment during the first quarter of fiscal 2015 had not commenced operations by the end of the second quarter of fiscal 2015 which reduced the quarterly rig utilization. All four rigs are expected to begin work by the end of the third fiscal quarter.

RESEARCH AND DEVELOPMENT

For the three months ended March 31, 2015 and 2014, we incurred $4.9 million and $3.6 million, respectively, of research and development expenses related to ongoing development of a rotary steerable system.

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OTHER

General and administrative expenses were $34.9 million in the second quarter of fiscal 2015 compared to $34.4 million in the second quarter of fiscal 2014.

Income tax expense decreased to $77.8 million in the second quarter of fiscal 2015 from $100.8 in the second quarter of fiscal 2014 and the effective tax rate decreased to 34.2 percent from 36.6 percent. We expect the effective tax rate for the remaining two quarters of fiscal 2015 to be between 34 and 35 percent.

Six Months Ended March 31, 2015 vs. Six Months Ended March 31, 2014

We reported net income of $352.6 million ($3.23 per diluted share) from operating revenues of $1.9 billion for the six months ended March 31, 2015, compared with net income from continuing operations of $347.8 million ($3.17 per diluted share) from operating revenues of $1.8 billion for the first six months of fiscal year 2014. Net income for the first six months of fiscal 2015 includes approximately $4.4 million ($0.04 per diluted share) of after-tax gains from the sale of assets. Net income for the first six months of fiscal 2014 includes approximately $12.9 million ($0.12 per diluted share) of after-tax gains from the sale of investment securities and approximately $6.4 million ($0.06 per diluted share) of after-tax gains from the sale of assets.

The following tables summarize operations by reportable operating segment for the six months ended March 31, 2015 and 2014. Operating statistics in the tables exclude the effects of offshore platform and international management contracts, and do not include reimbursements of “out-of-pocket” expenses in revenue, expense and margin per day calculations. Per day calculations for international operations also exclude gains and losses from translation of foreign currency transactions. Segment operating income is described in detail in Note 11 to the Consolidated Condensed Financial Statements.

	Six Months Ended March 31,
	2015			2014
	(in thousands, except days and per day amounts)
U.S. LAND OPERATIONS
Revenues	$	1,608,510		$	1,473,465
Direct operating expenses	793,615			745,533
General and administrative expense	24,320			20,613
Depreciation	247,587			211,305
Segment operating income	$	542,988		$	496,014

Revenue days	48,157			47,764
Average rig revenue per day	$	30,118		$	28,249
Average rig expense per day	$	13,196		$	13,009
Average rig margin per day	$	16,922		$	15,240
Rig utilization	78		%	85		%

U.S. Land segment operating income increased to $543.0 million for the first six months of fiscal 2015 compared to $496.0 million in the same period of fiscal 2014. Revenues were $1.6 billion and $1.5 billion for the first six months of fiscal 2015 and 2014, respectively. Included in U.S. land revenues for the six months ended March 31, 2015 and 2014 are reimbursements for “out-of-pocket” expenses of $158.1 million and $124.2 million, respectively. Also included in revenue for the six months ended March 31, 2015 and 2014 are early termination fees of $94.4 million and $9.9 million, respectively.

Excluding early termination revenue of $1,960, average rig revenue per day for the first six months of fiscal 2015 compared to the same period of fiscal 2014 decreased by $91 to $1,869. The decline in oil prices continues to have a negative effect on customer spending. As a result, some operators are not renewing contracts or are terminating their contracts early. Fixed-term contracts customarily provide for termination at the election of the customer, with an early termination payment to be paid to us if a contract is terminated prior to the expiration of the fixed term (except in limited circumstances including sustained unacceptable performance by us).

Depreciation increased $36.3 million in the first six months of fiscal 2015 compared to the first six months of fiscal 2014. Included in depreciation are abandonments of $11.9 million and $3.2 million, respectively, for the six months ended March 31, 2015 and 2014. Included in abandonments for the six months ended March 31, 2015 is the decommissioning of all 17 of our SCR powered FlexRigs including 6 idle FlexRig1 rigs and 11 idle FlexRig2 rigs. With the continued downturn in the oil and gas industry, we believe when the demand for drilling rigs returns, our SCR powered FlexRigs will not meet the needs of our customers. Excluding abandonments, depreciation increased in the comparative periods due to the increase in available rigs as new FlexRigs were added to the segment in 2014 and 2015.

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U.S. land rig utilization decreased to 78 percent for the first six months of fiscal 2015 compared to 85 percent for the first six months of fiscal 2014. U.S. land rig revenue days for the first six months of fiscal 2015 were 48,157 compared with 47,764 for the same period of fiscal 2014, with an average of 264.6 and 262.4 rigs working during the first six months of fiscal 2015 and 2014, respectively. We expect rig utilization to decrease in the third quarter of fiscal 2015 as customers continue to reduce their drilling activity and rigs are idled. Given the current trend, we could have less than 150 rigs contracted and generating revenue by June 30, 2015.

	Six Months Ended March 31,
	2015			2014
	(in thousands, except days and per day amounts)
OFFSHORE OPERATIONS
Revenues	$	132,099		$	122,330
Direct operating expenses	83,672			73,355
General and administrative expense	1,780			4,858
Depreciation	6,094			6,276
Segment operating income	$	40,553		$	37,841

Revenue days	1,603			1,456
Average rig revenue per day	$	52,588		$	63,263
Average rig expense per day	$	32,877		$	35,707
Average rig margin per day	$	19,711		$	27,556
Rig utilization	98		%	89		%

Offshore revenues include reimbursements for “out-of-pocket” expenses of $10.8 million and $7.7 million for the first six months ended March 31, 2015 and 2014, respectively.

Total revenue and segment operating income in our Offshore segment increased in the first six months of fiscal 2015 compared to the same period of fiscal 2014 primarily due to an increase in the number of offshore management contracts. Average revenue per day and average rig margin per day decreased in the first six months of fiscal 2015 compared to the same period of fiscal 2014 primarily due to a contractual decrease in a dayrate for one rig.

At the end of March 31, 2015 and March 31, 2014, eight platform rigs were active.

	Six Months Ended March 31,
	2015			2014
	(in thousands, except days and per day amounts)
INTERNATIONAL LAND OPERATIONS
Revenues	$	191,107		$	180,874
Direct operating expenses	146,389			135,618
General and administrative expense	1,706			1,964
Depreciation	24,470			19,373
Segment operating income	$	18,542		$	23,919

Revenue days	3,922			4,188
Average rig revenue per day	$	43,310		$	37,784
Average rig expense per day	$	32,481		$	27,163
Average rig margin per day	$	10,829		$	10,621
Rig utilization	57		%	80		%

International Land segment operating income for the first six months of fiscal 2015 was $18.5 million compared to $23.9 million in the same period of fiscal 2014. Included in International land revenues for the six months ended March 31, 2015 and 2014 are reimbursements for “out-of-pocket” expenses of $21.2 million and $22.6 million, respectively. Also included in revenue for the six months ended March 31, 2015 is early termination revenue of $0.7 million.

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Rigs transferred into the segment in previous quarters that started work favorably impacted revenue and revenue per day. During the first six months of fiscal 2015, an average of 21.7 rigs worked compared to an average of 23.1 rigs in the first six months of fiscal 2014. During the first six months of fiscal 2015, five FlexRigs were transferred from the U.S. Land segment and one conventional rig was transferred to the U.S. Land segment. Four of the rigs transferred into the segment had not commenced operations by the end of the second quarter of fiscal 2015 which reduced the quarterly rig utilization. All four rigs are expected to begin work by the end of the third fiscal quarter.

RESEARCH AND DEVELOPMENT

For the six months ended March 31, 2015 and 2014, we incurred $9.0 million and $7.9 million, respectively, of research and development expenses related to ongoing development of a rotary steerable system.

OTHER

General and administrative expenses were $67.8 million in the first six months of fiscal 2015 compared to $66.7 million in the first six months of fiscal 2014.

Interest expense is expected to increase due to the issuance of $500 million unsecured senior notes in March 2015. Total interest expense for fiscal 2015 is expected to be approximately $15 million.

Income tax expense increased to $206.6 million in the first six months of fiscal 2015 from $190.6 in the first six months of fiscal 2014 and the effective tax rate increased to 36.9 percent from 35.4 percent. Effective tax rates differ from the U.S. federal statutory rate of 35.0 percent primarily due to state and foreign income taxes and the tax benefit from the Internal Revenue Code Section 199 deduction for domestic production activities. The effective tax rate for the six months ended March 31, 2015 was also impacted by a December 2014 tax law change which resulted in a reduction of the fiscal 2014 Internal Revenue Code Section 199 deduction for domestic production activities.

LIQUIDITY AND CAPITAL RESOURCES

Liquidity

Cash and cash equivalents increased to $719.1 million at March 31, 2015 from $360.9 million at September 30, 2014. The following table provides a summary of cash flows:

	Six Months Ended
	March 31,
	2015			2014
	(in thousands)

Net cash provided (used) by:
Operating activities	$	812,584		$	540,011
Investing activities	(748,151		)	(320,094		)
Financing activities	293,785			(82,806		)
Increase (decrease) in cash and cash equivalents	$	358,218		$	137,111

Operating activities

Cash flows from operating activities were approximately $812.6 million for the six months ended March 31, 2015 compared to approximately $540.0 million for the same period ended March 31, 2014. Multiple items contributed to the change, including a decrease in income taxes payable during the comparative six months primarily the result of legislation passed in December 2014 extending the 50 percent special allowance for depreciation (“bonus depreciation”) for qualified property placed in service during 2014.

Investing activities

Capital expenditures during the six months ended March 31, 2015 were $763.4 million compared to $356.8 million during the six months ended March 31, 2014 due to the execution of additional fixed-term contracts during calendar 2014 for the operation of new FlexRigs.

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Financing activities

During the second quarter of fiscal 2015, we received proceeds from senior notes net of discount and debt issuance costs of $492.8 million. Dividends paid during the first six months of fiscal 2015 were $1.3750 per share or $149.3 million compared to $1.250 per share or $121.5 million paid during the first six months of fiscal 2014. Also during fiscal 2015, we purchased 810,097 common shares at an aggregate cost of $59.7 million.

Other Liquidity

Our operating cash requirements, scheduled debt repayments, interest payments, any stock repurchases and estimated capital expenditures, including our rig construction program, for fiscal 2015 are expected to be funded through current cash and cash provided from operating activities. Given current market conditions, there can be no assurance that we will continue to generate cash flows at current levels or obtain additional financing. Our indebtedness totaled $572.1 million at March 31, 2015, of which a $40.0 million principal payment is due later in fiscal 2015. For additional information regarding debt agreements, refer to Note 8 of the Consolidated Condensed Financial Statements.

Backlog

Our contract drilling backlog, being the expected future revenue from executed contracts with original terms in excess of one year, as of March 31, 2015 and September 30, 2014 was $3.9 billion and $5.0 billion, respectively. The decrease in backlog at March 31, 2015 from September 30, 2014 is primarily due to the revenue earned since September 30, 2014 and the expiration and termination of long-term contracts. Approximately 79.5 percent of the March 31, 2015 backlog is not reasonably expected to be filled in fiscal 2015. Term contracts customarily provide for termination at the election of the customer with an “early termination payment” to be paid to us if a contract is terminated prior to the expiration of the fixed term. However, under certain limited circumstances, such as destruction of a drilling rig, bankruptcy, sustained unacceptable performance by us, or delivery of a rig beyond certain grace and/or liquidated damage periods, no early termination payment would be paid to us. In addition, a portion of the backlog represents term contracts for new rigs that will be constructed in the future. We obtain certain key rig components from a single or limited number of vendors or fabricators. Certain of these vendors or fabricators are thinly capitalized independent companies located on the Texas Gulf Coast. Therefore, disruptions in rig component deliveries may occur resulting in construction delays and possibly termination of long-term contracts. Accordingly, the actual amount of revenue earned may vary from the backlog reported. See the risk factors under “Item 1A. Risk Factors” of our 2014 Annual Report on Form 10-K filed with the Securities and Exchange Commission, regarding fixed term contract risk, operational risks, including weather, and vendors that are limited in number and thinly capitalized.

The following table sets forth the total backlog by reportable segment as of March 31, 2015 and September 30, 2014, and the percentage of the March 31, 2015 backlog not reasonably expected to be filled in fiscal 2015:

	Three Months Ended
	March 31,		September 30,		Percentage Not Reasonably
Reportable Segment	2015		2014		Expected to be Filled in Fiscal 2015
	(in billions)

U.S. Land	$	2.9	$	3.8	77.7	%
Offshore	0.1		0.1		82.1	%
International Land	0.9		1.1		84.6	%
	$	3.9	$	5.0

Capital Resources

Since September 30, 2014, we have announced that we had secured multi-year term contracts to build and operate six new FlexRigs with two customers in the U.S. During the six months ended March 31, 2015, we completed 24 new FlexRigs. Four additional new FlexRigs under fixed-term contract were completed by April 23, 2015. Like those completed and placed into service in prior fiscal periods, each of the new FlexRigs is committed to work for an exploration and production company under a fixed-term contract, performing drilling services on a daywork contract basis.

Our capital spending estimate for fiscal 2015 is expected to total approximately $1.3 billion. The monthly cadence of the new FlexRig construction program is expected to decline from four to two rigs per month beginning in June 2015 through the end of September 2015, and then decline from two to one rig per month beginning October 2015 through March 2016. However, the actual spending level may vary depending primarily on actual maintenance capital requirements and on the timing of procurement related to our ongoing newbuild efforts. All new FlexRigs scheduled for delivery during calendar 2015 and 2016 are supported with multi-year contracts. Capital expenditures were $763.4 million and $356.8 million for the first six months of fiscal 2015 and 2014, respectively.

There were no other significant changes in our financial position since September 30, 2014.

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MATERIAL COMMITMENTS

In March 2015, we issued $500 million unsecured senior notes. The debt and estimated interest increases the material commitments reported in our 2014 Annual Report on Form 10-K by approximately $732 million which has annual interest of approximately $23.2 million through March 2025.

CRITICAL ACCOUNTING POLICIES

Our accounting policies that are critical or the most important to understand our financial condition and results of operations and that require management to make the most difficult judgments are described in our 2014 Annual Report on Form 10-K. There have been no material changes in these critical accounting policies.

RECENTLY ISSUED ACCOUNTING STANDARDS

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PART I. FINANCIAL INFORMATION

March 31, 2015

ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

For a description of our market risks, see

· Note 4 to the Consolidated Condensed Financial Statements contained in Item 1 of Part I hereof with regard to equity price risk is incorporated herein by reference;

· “Item 7A. Quantitative and Qualitative Disclosures About Market Risk” in our 2014 Annual Report on Form 10-K filed with the Securities and Exchange Commission on November 26, 2014;

· Note 8 to the Consolidated Condensed Financial Statements contained in Item 1 of Part I hereof with regard to interest rate risk is incorporated herein by reference; and

· Note 14 to the Consolidated Condensed Financial Statements contained in Item 1 of Part I hereof with regard to foreign currency exchange rate risk is incorporated herein by reference.

ITEM 4. CONTROLS AND PROCEDURES

As of the end of the period covered by this report, an evaluation was performed with the participation of our management, including the Chief Executive Officer and Chief Financial Officer, of the effectiveness of the design and operation of our disclosure controls and procedures. Based on that evaluation, our management, including the Chief Executive Officer and Chief Financial Officer, concluded that our disclosure controls and procedures were effective as of March 31, 2015 at ensuring that information required to be disclosed by us in the reports we file or submit under the Securities Exchange Act of 1934 is recorded, processed, summarized and reported within the time periods specified in the SEC’s rules and forms. There have been no changes in our internal controls over financial reporting that occurred during the most recent fiscal quarter 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

Investigation by the U.S. Attorney. On November 8, 2013, the United States District Court for the Eastern District of Louisiana approved the previously disclosed October 30, 2013 plea agreement between our wholly owned subsidiary, Helmerich & Payne International Drilling Co., and the United States Department of Justice, United States Attorney’s Office for the Eastern District of Louisiana (“DOJ”). The court’s approval of the plea agreement resolved the DOJ’s investigation into certain choke manifold testing irregularities that occurred in 2010 at one of Helmerich & Payne International Drilling Co.’s offshore platform rigs in the Gulf of Mexico. We have been engaged in discussions with the Inspector General’s office of the Department of Interior regarding the same events that were the subject of the DOJ’s investigation. We can provide no assurances as to the timing or eventual outcome of these discussions and are unable to determine the amount of penalty, if any, that may be assessed. However, we presently believe that the outcome of our discussions will not have a material adverse effect on the Company.

Venezuela Expropriation. Our wholly-owned subsidiaries, Helmerich & Payne International Drilling Co. and Helmerich & Payne de Venezuela, C.A. filed a lawsuit in the United States District Court for the District of Columbia on September 23, 2011 against the Bolivarian Republic of Venezuela, Petroleos de Venezuela, S.A. (“PDVSA”) and PDVSA Petroleo, S.A. (“Petroleo”). We are seeking damages for the taking of our Venezuelan drilling business in violation of international law and for breach of contract. While there exists the possibility of realizing a recovery, we are currently unable to determine the timing or amounts we may receive, if any, or the likelihood of recovery.

ITEM 1A. RISK FACTORS

Our business depends on the level of activity in the oil and natural gas industry, which is significantly impacted by the volatility of oil and natural gas prices and other factors, including the recent decline in oil prices.

Our business depends on the conditions of the land and offshore oil and natural gas industry. Demand for our services depends on oil and natural gas industry exploration and production activity and expenditure levels, which are directly affected by trends in oil and natural gas prices. Oil and natural gas prices, and market expectations regarding potential changes to these prices, significantly affect oil and natural gas industry activity.

Oil prices declined significantly during the second half of 2014 and have continued to decline in 2015. In response, many of our customers have announced significant reductions in their 2015 capital spending budgets. At March 31, 2015, 179 out of an available

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349 land rigs were working in the U.S. Land segment. After giving effect to new FlexRigs placed into service and additional rig releases since March 31, 2015, as of April 23, 2015, 165 rigs remain active in the U.S. Land segment excluding rigs that are in the process of stacking. We expect additional U.S. land rigs to become idle and spot market pricing softness to continue during the third quarter of fiscal 2015. Given current oil pricing and existing market trends, the number of our contracted rigs in the U.S. may drop below 150 during the third quarter of fiscal 2015. In addition, low oil prices are expected to negatively impact drilling rigs in international locations and could affect offshore operations. In the event oil prices remain depressed for a sustained period, or decline further, we may experience further, significant declines in both drilling activity and spot dayrate pricing which could have a material adverse effect on our business, financial condition and results of operations.

Oil and natural gas prices are impacted by many factors beyond our control, including:

· the demand for oil and natural gas;

· the cost of exploring for, developing, producing and delivering oil and natural gas;

· the worldwide economy;

· expectations about future oil and natural gas prices;

· domestic and international tax policies;

· political and military conflicts in oil producing regions or other geographical areas or acts of terrorism in the U.S. or elsewhere;

· technological advances;

· the development and exploitation of alternative fuels;

· local and international political, economic and weather conditions;

· the ability of The Organization of Petroleum Exporting Countries (“OPEC”) to set and maintain production levels and pricing;

· the level of production by OPEC and non-OPEC countries; and

· the environmental and other laws and governmental regulations regarding exploration and development of oil and natural gas reserves.

The level of land and offshore exploration, development and production activity and the price for oil and natural gas is volatile and is likely to continue to be volatile in the future. Higher oil and natural gas prices do not necessarily translate into increased activity because demand for our services is typically driven by our customer’s expectations of future commodity prices. However, a sustained decline in worldwide demand for oil and natural gas or prolonged low oil or natural gas prices would likely result in reduced exploration and development of land and offshore areas and a decline in the demand for our services, which could have a material adverse effect on our business, financial condition and results of operations.

International uncertainties and local laws could adversely affect our business.

International operations are subject to certain political, economic and other uncertainties not encountered in U.S. operations, including increased risks of terrorism, kidnapping of employees, expropriation of drilling rigs, equipment, land and other property, as well as expropriation of our customer’s property and drilling rights, taxation policies, foreign exchange restrictions, currency rate fluctuations and general hazards associated with foreign sovereignty over certain areas in which operations are conducted. In January 2015, the Venezuelan government announced plans for a new foreign currency exchange system. We are monitoring the status of this change in Venezuela’s exchange control policy. There can be no assurance that there will not be changes in local laws, regulations and administrative requirements or the interpretation thereof which could have a material adverse effect on the profitability of our operations or on our ability to continue operations in certain areas.

Because of the impact of local laws, our future operations in certain areas may be conducted through entities in which local citizens own interests and through entities (including joint ventures) in which we hold only a minority interest or pursuant to arrangements under which we conduct operations under contract to local entities. While we believe that neither operating through such entities nor pursuant to such arrangements would have a material adverse effect on our operations or revenues, there can be no assurance that we will in all cases be able to structure or restructure our operations to conform to local law (or the administration thereof) on terms acceptable to us.

Although we attempt to minimize the potential impact of such risks by operating in more than one geographical area, during the six months ended March 31, 2015, approximately 11 percent of our consolidated operating revenues were generated from international locations in our contract drilling business. During the six months ended March 31, 2015, approximately 69 percent of operating revenues from international locations were from operations in South America.

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Other risk factors.

Reference is made to the risk factors pertaining to the Company’s securities portfolio and current backlog of contract drilling revenue in Item 1A of Part 1 of the Company’s Form 10-K for the year ended September 30, 2014. In order to update these risk factors for developments that have occurred during the first six months of fiscal 2015, the risk factors are hereby amended and updated by reference to, and incorporation herein of Note 4 to the Consolidated Condensed Financial Statements contained in Item 1 of Part I hereof and Liquidity and Capital Resources — Backlog contained in Item 2 of Part I hereof.

Except as discussed above, there have been no material changes to the risk factors disclosed in Item 1A of Part 1 in our Form 10-K for the year ended September 30, 2014.

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ITEM 6. EXHIBITS

The following documents are included as exhibits to this Form 10-Q. Those exhibits below incorporated by reference herein are indicated as such by the information supplied in the parenthetical thereafter. If no parenthetical appears after an exhibit, such exhibit is filed or furnished herewith.

Exhibit
Number		Description

10.1		Purchase Agreement, dated March 12, 2015, among Helmerich & Payne International Drilling Co., Helmerich & Payne, Inc., Goldman, Sachs & Co. and Wells Fargo Securities, LLC (incorporated herein by reference to Exhibit 10.1 of the Company’s Form 8-K filed on March 13, 2015, SEC File No. 001-04221).

10.2		Base Indenture, dated March 19, 2015, by and between Helmerich & Payne International Drilling Co., Helmerich & Payne, Inc. and Wells Fargo Bank, National Association (incorporated herein by reference to Exhibit 4.1 of the Company’s Form 8-K filed on March 19, 2015, SEC File No. 001-04221).

10.3		First Supplemental Indenture, dated March 19, 2015, by and between Helmerich & Payne International Drilling Co., Helmerich & Payne, Inc. and Wells Fargo Bank, National Association (incorporated herein by reference to Exhibit 4.2 of the Company’s Form 8-K filed on March 19, 2015, SEC File No. 001-04221).

10.4		Form of Note (included in Exhibit 10.3 above).

10.5		Registration Rights Agreement, dated March 19, 2015, by and between Helmerich & Payne International Drilling Co., Helmerich & Payne, Inc., Goldman, Sachs & Co. and Wells Fargo Securities, LLC (incorporated herein by reference to Exhibit 4.4 of the Company’s Form 8-K filed on March 19, 2015, SEC File No. 001-04221).

10.6		Advisory Services Agreement effective March 4, 2015 between Helmerich & Payne, Inc. and Steven R. Mackey.

10.7		Helmerich & Payne, Inc. Annual Bonus Plan for executive officers.

31.1		Certification of Chief Executive Officer, as Adopted Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.

31.2		Certification of Chief Financial Officer, as Adopted Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.

32		Certification of Chief Executive Officer and Chief Financial Officer Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.

101		Financial statements from the quarterly report on Form 10-Q of Helmerich & Payne, Inc. for the quarter ended March 31, 2015, filed on May 1, 2015, formatted in Extensive Business Reporting Language (XBRL): (i) the Consolidated Condensed Statements of Income, (ii) the Consolidated Condensed Statements of Comprehensive Income, (iii) the Consolidated Condensed Balance Sheets, (iv) the Consolidated Condensed Statements of Stockholders’ Equity, (v) the Consolidated Condensed Statements of Cash Flows and (vi) the Notes to Consolidated Condensed Financial Statements.

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SIGNATURES

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

	HELMERICH & PAYNE, INC.
	(Registrant)


Date: May 1, 2015	By:	/S/ JOHN W. LINDSAY
		John W. Lindsay, Chief Executive Officer


Date: May 1, 2015	By:	/S/ JUAN PABLO TARDIO
		Juan Pablo Tardio, Chief Financial Officer
		(Principal Financial Officer)

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EXHIBIT INDEX

Exhibit
Number		Description

10.1		Purchase Agreement, dated March 12, 2015, among Helmerich & Payne International Drilling Co., Helmerich & Payne, Inc., Goldman, Sachs & Co. and Wells Fargo Securities, LLC (incorporated herein by reference to Exhibit 10.1 of the Company’s Form 8-K filed on March 13, 2015, SEC File No. 001-04221).

10.2		Base Indenture, dated March 19, 2015, by and between Helmerich & Payne International Drilling Co., Helmerich & Payne, Inc. and Wells Fargo Bank, National Association (incorporated herein by reference to Exhibit 4.1 of the Company’s Form 8-K filed on March 19, 2015, SEC File No. 001-04221).

10.3		First Supplemental Indenture, dated March 19, 2015, by and between Helmerich & Payne International Drilling Co., Helmerich & Payne, Inc. and Wells Fargo Bank, National Association (incorporated herein by reference to Exhibit 4.2 of the Company’s Form 8-K filed on March 19, 2015, SEC File No. 001-04221).

10.4		Form of Note (included in Exhibit 10.3 above).

10.5		Registration Rights Agreement, dated March 19, 2015, by and between Helmerich & Payne International Drilling Co., Helmerich & Payne, Inc., Goldman, Sachs & Co. and Wells Fargo Securities, LLC (incorporated herein by reference to Exhibit 4.4 of the Company’s Form 8-K filed on March 19, 2015, SEC File No. 001-04221).

10.6		Advisory Services Agreement effective March 4, 2015 between Helmerich & Payne, Inc. and Steven R. Mackey.

10.7		Helmerich & Payne, Inc. Annual Bonus Plan for executive officers.

31.1		Certification of Chief Executive Officer, as Adopted Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.

31.2		Certification of Chief Financial Officer, as Adopted Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.

32		Certification of Chief Executive Officer and Chief Financial Officer Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.

101		Financial statements from the quarterly report on Form 10-Q of Helmerich & Payne, Inc. for the quarter ended March 31, 2015, filed on May 1, 2015, formatted in Extensive Business Reporting Language (XBRL): (i) the Consolidated Condensed Statements of Income, (ii) the Consolidated Condensed Statements of Comprehensive Income, (iii) the Consolidated Condensed Balance Sheets, (iv) the Consolidated Condensed Statements of Stockholders’ Equity, (v) the Consolidated Condensed Statements of Cash Flows and (vi) the Notes to Consolidated Condensed Financial Statements.