10-Q

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, DC 20549

FORM 10-Q

(Mark One)

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

For the quarterly period ended March 31, 2012

or

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

For the transition period from            to            

Commission file number 1-12074

STONE ENERGY CORPORATION

(Exact Name of Registrant as Specified in Its Charter)

Delaware	72-1235413
(State or Other Jurisdiction of Incorporation or Organization)	(I.R.S. Employer Identification No.)
625 E. Kaliste Saloom Road Lafayette, Louisiana	70508
(Address of Principal Executive Offices)	(Zip Code)

Registrant’s Telephone Number, Including Area Code: (337) 237-0410

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

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

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

Large accelerated filer	x	Accelerated filer	¨
Non-accelerated filer	¨  (Do not check if a smaller reporting company)	Smaller reporting company	¨

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

As of May 7, 2012, there were 49,472,468 shares of the registrant’s common stock, par value $.01 per share, outstanding.

TABLE OF CONTENTS

		Page
PART I – FINANCIAL INFORMATION
Item 1.	Financial Statements:
	Condensed Consolidated Balance Sheet as of March 31, 2012 and December 31, 2011	1
	Condensed Consolidated Statement of Operations for the Three Months Ended March 31, 2012 and 2011	2
	Condensed Consolidated Statement of Comprehensive Income for the Three Months Ended March 31, 2012 and 2011	3
	Condensed Consolidated Statement of Cash Flows for the Three Months Ended March 31, 2012 and 2011	4
	Notes to Condensed Consolidated Financial Statements	5
Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	20
Item 3.	Quantitative and Qualitative Disclosures About Market Risk	26
Item 4.	Controls and Procedures	26
PART II – OTHER INFORMATION
Item 1.	Legal Proceedings	27
Item 1A.	Risk Factors	27
Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds	28
Item 3.	Defaults Upon Senior Securities	Not Applicable
Item 4.	Mine Safety Disclosure	Not Applicable
Item 5.	Other Information	Not Applicable
Item 6.	Exhibits	29
	Signature	31

PART I – FINANCIAL INFORMATION

Item 1. Financial Statements

STONE ENERGY CORPORATION

CONDENSED CONSOLIDATED BALANCE SHEET

(In thousands of dollars)

	March 31, 2012			December 31, 2011
	(Unaudited)
Assets
Current assets:
Cash and cash equivalents	$	263,841		$	38,451
Accounts receivable		133,266			118,139
Fair value of hedging contracts		24,352			25,177
Current income tax receivable		23,140			19,946
Deferred taxes		30,206			26,072
Inventory		4,643			4,643
Other current assets		754			791
Total current assets		480,202			233,219
Oil and gas properties, full cost method of accounting:
Proved		6,704,772			6,648,168
Less: accumulated depreciation, depletion and amortization		(5,252,894	)		(5,174,729	)
Net proved oil and gas properties		1,451,878			1,473,439
Unevaluated		443,889			401,609
Other property and equipment, net		11,444			11,172
Fair value of hedging contracts		10,937			22,543
Other assets, net		28,963			23,769
Total assets	$	2,427,313		$	2,165,751
Liabilities and Stockholders’ Equity
Current liabilities:
Accounts payable to vendors	$	86,307		$	102,946
Undistributed oil and gas proceeds		26,359			27,328
Accrued interest		10,490			14,059
Fair value of hedging contracts		27,298			11,122
Asset retirement obligations		71,256			62,676
Other current liabilities		10,740			28,370
Total current liabilities		232,450			246,501
Long-term debt		805,140			620,000
Deferred taxes		266,996			247,835
Asset retirement obligations		359,274			363,103
Fair value of hedging contracts		8,025			815
Other long-term liabilities		20,523			19,668
Total liabilities		1,692,408			1,497,922
Commitments and contingencies
Stockholders’ equity:
Common stock, $.01 par value; authorized 100,000,000 shares; issued 48,308,879 and 48,076,860 shares, respectively		483			481
Treasury stock (16,582 shares, at cost)		(860	)		(860	)
Additional paid-in capital		1,376,730			1,338,565
Accumulated deficit		(641,251	)		(692,225	)
Accumulated other comprehensive income (loss)		(197	)		21,868
Total stockholders’ equity		734,905			667,829
Total liabilities and stockholders’ equity	$	2,427,313		$	2,165,751

The accompanying notes are an integral part of this statement.

1

STONE ENERGY CORPORATION

CONDENSED CONSOLIDATED STATEMENT OF OPERATIONS

(In thousands, except per share amounts)

(Unaudited)

	Three Months Ended March 31,
	2012			2011
Operating revenue:
Oil production	$	201,758		$	151,995
Gas production		28,857			41,160
Natural gas liquids production		13,452			5,999
Other operational income		890			885
Total operating revenue		244,957			200,039
Operating expenses:
Lease operating expenses		44,480			38,287
Transportation, processing and gathering expenses		3,657			1,820
Other operational expenses		42			662
Production taxes		3,378			2,535
Depreciation, depletion and amortization		84,575			67,669
Accretion expense		8,266			7,717
Salaries, general and administrative expenses		13,705			11,733
Incentive compensation expense		1,442			2,684
Derivative expense, net		485			2,180
Total operating expenses		160,030			135,287
Income from operations		84,927			64,752
Other (income) expenses:
Interest expense		5,731			3,111
Interest income		(31	)		(94	)
Other income		(420	)		(564	)
Other expense		—			124
Total other expenses		5,280			2,577
Net income before income taxes		79,647			62,175
Provision for income taxes:
Current		1,234			—
Deferred		27,439			22,383
Total income taxes		28,673			22,383
Net income	$	50,974		$	39,792
Basic earnings per share	$	1.03		$	0.81
Diluted earnings per share	$	1.03		$	0.81
Average shares outstanding		48,254			47,898
Average shares outstanding assuming dilution		48,299			47,939

The accompanying notes are an integral part of this statement.

2

STONE ENERGY CORPORATION

CONDENSED CONSOLIDATED STATEMENT OF COMPREHENSIVE INCOME

(In thousands)

(Unaudited)

	Three Months Ended March 31,
	2012			2011
Net income	$	50,974		$	39,792
Other comprehensive loss, net of tax effect:
Adjustment for fair value accounting of derivatives		(22,065	)		(32,474	)
Comprehensive income	$	28,909		$	7,318

The accompanying notes are an integral part of this statement.

3

STONE ENERGY CORPORATION

CONDENSED CONSOLIDATED STATEMENT OF CASH FLOWS

(In thousands of dollars)

(Unaudited)

	Three Months Ended March 31,
	2012			2011
Cash flows from operating activities:
Net income	$	50,974		$	39,792
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, depletion and amortization		84,575			67,669
Accretion expense		8,266			7,717
Deferred income tax provision		27,439			22,383
Settlement of asset retirement obligations		(2,980	)		(19,034	)
Non-cash stock compensation expense		1,750			1,680
Excess tax benefits		(847	)		(649	)
Non-cash derivative expense		1,342			1,804
Other non-cash expense (income)		1,173			(104	)
Change in current income taxes		(2,647	)		(3,681	)
Increase in accounts receivable		(21,708	)		(21,555	)
Decrease in other current assets		35			25
Decrease in inventory		—			365
Increase (decrease) in accounts payable		(6,015	)		2,690
Decrease in other current liabilities		(22,168	)		(10,059	)
Other		146			272
Net cash provided by operating activities		119,335			89,315
Cash flows from investing activities:
Investment in oil and gas properties		(106,469	)		(156,535	)
Proceeds from sale of oil and gas properties		—			7,692
Sale of fixed assets		134			—
Investment in fixed and other assets		(909	)		(262	)
Net cash used in investing activities		(107,244	)		(149,105	)
Cash flows from financing activities:
Proceeds from bank borrowings		25,000			—
Repayments of bank borrowings		(70,000	)		—
Proceeds from issuance of senior convertible notes		300,000			—
Financing costs of senior convertible notes		(8,855	)		—
Proceeds from Sold Warrants		40,170			—
Payments for Purchased Call Options		(70,830	)		—
Deferred financing costs		—			(66	)
Excess tax benefits		847			649
Net payments for share based compensation		(3,033	)		(1,843	)
Net cash provided by (used in) financing activities		213,299			(1,260	)
Net change in cash and cash equivalents		225,390			(61,050	)
Cash and cash equivalents, beginning of period		38,451			106,956
Cash and cash equivalents, end of period	$	263,841		$	45,906

The accompanying notes are an integral part of this statement.

4

STONE ENERGY CORPORATION

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

Note 1 – Interim Financial Statements

The condensed consolidated financial statements of Stone Energy Corporation (“Stone”) and its subsidiaries as of March 31, 2012 and for the three-month periods ended March 31, 2012 and 2011 are unaudited and reflect all adjustments (consisting only of normal recurring adjustments), which are, in the opinion of management, necessary for a fair presentation of the financial position and operating results for the interim periods. The condensed consolidated balance sheet at December 31, 2011 has been derived from the audited financial statements at that date. The condensed consolidated financial statements should be read in conjunction with the consolidated financial statements and notes thereto, together with management’s discussion and analysis of financial condition and results of operations, contained in our Annual Report on Form 10-K for the year ended December 31, 2011. The results of operations for the three-month period ended March 31, 2012 are not necessarily indicative of future financial results. Certain prior period amounts have been reclassified to conform to current period presentation.

Note 2 – Earnings Per Share

The following table sets forth the calculation of basic and diluted weighted average shares outstanding and earnings per share for the indicated periods.

	Three Months Ended March 31,
	2012			2011
	(in thousands, except per share data)
Income (numerator):
Basic:
Net income	$	50,974		$	39,792
Net income attributable to participating securities		(1,217	)		(874	)
Net income attributable to common stock – basic	$	49,757		$	38,918
Diluted:
Net income	$	50,974		$	39,792
Net income attributable to participating securities		(1,216	)		(873	)
Net income attributable to common stock – diluted	$	49,758		$	38,919
Weighted average shares (denominator):
Weighted average shares – basic		48,254			47,898
Diluted effect of stock options		45			41
Weighted average shares – diluted		48,299			47,939
Basic income per common share	$	1.03		$	0.81
Diluted income per common share	$	1.03		$	0.81

Stock options that were considered antidilutive because the exercise price of the option exceeded the average price of our common stock for the applicable period totaled approximately 372,000 and 398,000 shares for the three months ended March 31, 2012 and 2011, respectively. During the three months ended March 31, 2012 and 2011, respectively, approximately 232,000 and 180,000 shares of common stock were issued upon the vesting of restricted stock by employees and nonemployee directors.

Because it is management’s stated intention to redeem the principal amount of our 2017 Convertible Notes (see Note 4 – Long-Term Debt) in cash, we have used the treasury method for determining potential dilution in the diluted earnings per share computation. Since the average price of our common stock was less than the effective conversion price for such notes during the reporting period, the convertible notes were not dilutive for such period. Additionally, since the average price of our common stock was less than the strike price of the Sold Warrants for the reporting period, such warrants were also not dilutive for such period.

5

Note 3 – Derivative Instruments and Hedging Activities

Our hedging strategy is designed to protect our near and intermediate term cash flow from future declines in oil and natural gas prices. This protection is essential to capital budget planning, which is sensitive to expenditures that must be committed to in advance such as rig contracts and the purchase of tubular goods. We enter into hedging transactions to secure a commodity price for a portion of future production that is acceptable at the time of the transaction. These hedges are designated as cash flow hedges upon entering into the contract. We do not enter into hedging transactions for trading purposes. We have no fair value hedges.

The nature of a derivative instrument must be evaluated to determine if it qualifies for hedge accounting treatment. If the instrument qualifies for hedge accounting treatment, it is recorded as either an asset or liability measured at fair value and subsequent changes in the derivative’s fair value are recognized in equity through other comprehensive income (loss), net of related taxes, to the extent the hedge is considered effective. Additionally, monthly settlements of effective hedges are reflected in revenue from oil and gas production and cash flows from operations. Instruments not qualifying for hedge accounting are recorded in the balance sheet at fair value and changes in fair value are recognized in earnings through derivative expense (income). Typically, a small portion of our derivative contracts are determined to be ineffective. This is because oil and natural gas price changes in the markets in which we sell our products are not 100% correlative to changes in the underlying price basis indicative in the derivative contracts. Monthly settlements of ineffective hedges are recognized in earnings through derivative expense (income) and cash flows from operations.

We have entered into fixed-price swaps with various counterparties for a portion of our expected 2012, 2013 and 2014 oil and natural gas production from the Gulf Coast Basin. Some of our fixed-price oil swap settlements are based on an average of the New York Mercantile Exchange (“NYMEX”) closing price for West Texas Intermediate (“WTI”) during the entire calendar month and some are based on the average of the Intercontinental Exchange (“ICE”) closing price for Brent crude oil during the entire calendar month. Our fixed-price gas swap settlements are based on the NYMEX price for the last day of a respective month. Swaps typically provide for monthly payments by us if prices rise above the swap price or to us if prices fall below the swap price. Our fixed-price swap contracts for 2012, 2013 and 2014 are with The Toronto-Dominion Bank, Barclays Bank PLC, BNP Paribas, the Bank of Nova Scotia, Bank of America and Natixis.

All of our derivative instruments at March 31, 2012 and December 31, 2011 were designated as effective cash flow hedges; however, during the three-month periods ended March 31, 2012 and 2011, certain of our derivative contracts were determined to be partially ineffective. The following tables disclose the location and fair value amounts of derivative instruments reported in our balance sheet at March 31, 2012 and December 31, 2011.

Fair Value of Derivative Instruments at March 31, 2012
(in millions)
	Asset Derivatives			Liability Derivatives
Description	Balance Sheet Location	Fair Value		Balance Sheet Location	Fair Value
Commodity contracts	Current assets: Fair value of hedging contracts	$	24.4	Current liabilities: Fair value of hedging contracts	($	27.3	)
	Long-term assets: Fair value of hedging contracts		10.9	Long-term liabilities: Fair value of hedging contracts		(8.0	)
		$	35.3		($	35.3	)

Fair Value of Derivative Instruments at December 31, 2011
(in millions)
	Asset Derivatives			Liability Derivatives
Description	Balance Sheet Location	Fair Value		Balance Sheet Location	Fair Value
Commodity contracts	Current assets: Fair value of hedging contracts	$	25.2	Current liabilities: Fair value of hedging contracts	($	11.1	)
	Long-term assets: Fair value of hedging contracts		22.5	Long-term liabilities: Fair value of hedging contracts		(0.8	)
		$	47.7		($	11.9	)

6

The following table discloses the effect of derivative instruments in the statement of operations for the three-month periods ended March 31, 2012 and 2011.

The Effect of Derivative Instruments on the Statement of Operations for the Three Months Ended March 31, 2012 and 2011
(in millions)
Derivatives in Cash Flow Hedging Relationships	Amount of Gain (Loss) Recognized in OCI on Derivatives (a)						Gain (Loss) Reclassified from Accumulated OCI into Income (Effective Portion) (b)							Gain (Loss) Recognized in Income on Derivatives (Ineffective Portion)
	2012			2011			Location	2012			2011			Location	2012			2011
Commodity contracts	($	22.1	)	($	32.5	)	Operating revenue - oil/gas production	($	1.0	)	($	3.9	)	Derivative income (expense), net	($	0.5	)	($	2.2	)
Total	($	22.1	)	($	32.5	)		($	1.0	)	($	3.9	)		($	0.5	)	($	2.2	)

(a) Net of related tax effect of ($12.4) million and ($18.3) million for the three months ended March 31, 2012 and 2011, respectively.

(b) For the three months ended March 31, 2012, effective hedging contracts decreased oil revenue by $5.8 million and increased gas revenue by $4.8 million. For the three months ended March 31, 2011, effective hedging contracts decreased oil revenue by $8.4 million and increased gas revenue by $4.5 million.

At March 31, 2012, we had an accumulated other comprehensive loss of $0.2 million, net of tax, which related to the fair value of our swap contracts that were outstanding as of March 31, 2012. We believe that approximately $2.0 million of the accumulated other comprehensive loss will be reclassified into earnings in the next twelve months.

The following table illustrates our hedging positions for calendar years 2012, 2013 and 2014 as of May 7, 2012:

	Fixed-Price Swaps NYMEX (except where noted)
	Natural Gas				Oil
	Daily Volume (MMBtus/d)		Swap Price ($)		Daily Volume (Bbls/d)			Swap Price ($)
2012		10,000		5.035		1,000			90.30
2012		10,000		5.040		1,000			90.41
2012		10,000		5.050		1,000			90.45
2012						1,000			95.50
2012						2,000			97.60
2012						1,000			98.15
2012						1,000			100.00
2012						1,000			101.55
2012						1,000			104.25
2012						1,000	†		111.02
2013		10,000		5.270		1,000			94.45
2013		10,000		5.320		1,000			94.60
2013						1,000			97.15
2013						1,000			101.53
2013						1,000			103.00
2013						1,000			103.15
2013						1,000			104.25
2013						1,000			104.47
2013						1,000			104.50
2013						1,000	†		107.30
2014						1,000			98.00
2014						1,000			98.30
2014						1,000			99.65
2014						1,000	†		103.30

† Brent oil contract

7

Note 4 – Long-Term Debt

Long-term debt consisted of the following at:

	March 31, 2012		December 31, 2011
	(in millions)
6 3/4% Senior Subordinated Notes due 2014	$	200.0	$	200.0
8 5/8% Senior Notes due 2017		375.0		375.0
1 3/4% Senior Convertible Notes due 2017		230.1		—
Bank debt		—		45.0
Total long-term debt	$	805.1	$	620.0

Bank Debt

On April 26, 2011, we entered into an amended and restated revolving credit facility with commitments totaling $700 million (subject to borrowing base limitations) through a syndicated bank group, replacing our previous facility. The credit facility matures on September 15, 2014. However, if the 6 ³/4% Senior Subordinated Notes due 2014 issued under our 2004 indenture are retired on or before April 15, 2014, the credit facility then matures on April 26, 2015. Our initial borrowing base under our bank credit facility was set at $400 million. On October 31, 2011, the bank group reaffirmed the existing borrowing base at $400 million. On February 28, 2012, we entered into an Amendment No. 1 and Consent to our credit agreement to permit the issuance of our 2017 Convertible Notes (see Senior Convertible Notes below). On March 6, 2012, we issued $300 million in aggregate principal amount of 2017 Convertible Notes in a private offering. Upon completion of the offering, our borrowing base under our bank credit facility was automatically reduced from $400 million to $310 million. On May 4, 2012, our borrowing base under our bank credit facility was redetermined to be $400 million.

On March 31, 2012, we had no outstanding borrowings under our bank credit facility and letters of credit totaling $27.1 million had been issued pursuant to the facility. As of May 7, 2012, we had no outstanding borrowings under our bank credit facility and letters of credit totaling $27.1 million had been issued pursuant to the facility, leaving $372.9 million of availability under the facility. Our bank credit facility is guaranteed by our only material subsidiary, Stone Energy Offshore, L.L.C. (“Stone Offshore”).

The borrowing base under our bank credit facility is redetermined semi-annually, in May and November, by the lenders taking into consideration the estimated value of our oil and gas properties and those of our direct and indirect material subsidiaries in accordance with the lenders’ customary practices for oil and gas loans. In addition, we and the lenders each have discretion at any time, but not more than two additional times in any calendar year, to have the borrowing base redetermined. Our bank credit facility is collateralized by substantially all of Stone’s and Stone Offshore’s assets. Stone and Stone Offshore are required to mortgage, and grant a security interest in, their oil and gas reserves representing at least 80% of the discounted present value of the future net cash flows from their oil and gas reserves reviewed in determining the borrowing base. At our option, loans under our bank credit facility will bear interest at a rate based on the adjusted Libor Rate plus an applicable margin, or a rate based on the prime rate or Federal funds rate plus an applicable margin. Our bank credit facility provides for optional and mandatory prepayments, affirmative and negative covenants, and interest coverage ratio and leverage ratio maintenance covenants. We were in compliance with all covenants as of March 31, 2012.

Senior Convertible Notes

On March 6, 2012, we issued in a private offering $300 million in aggregate principal amount of 1 ³/4% Senior Convertible Notes due 2017 (the “2017 Convertible Notes”) to qualified institutional buyers pursuant to Rule 144A under the Securities Act of 1933, as amended (the “Securities Act”). The 2017 Convertible Notes are fully and unconditionally guaranteed on a senior unsecured basis by Stone Offshore and by certain future restricted subsidiaries of Stone. The net proceeds from the sale of the 2017 Convertible Notes were approximately $291.1 million, after deducting fees and expenses. The 2017 Convertible Notes rank equally in right of payment with all of our existing and future senior unsecured indebtedness. The 2017 Convertible Notes are effectively subordinated to our secured indebtedness to the extent of the value of the related collateral. The 2017 Convertible Notes bear interest at a rate of 1.75% per year, payable on March 1 and September 1 of each year, beginning on September 1, 2012. The 2017 Convertible Notes mature on March 1, 2017, unless earlier converted or repurchased. We may not redeem the 2017 Convertible Notes at our option prior to the maturity date.

The 2017 Convertible Notes are convertible into cash, shares of our common stock or a combination of cash and shares of our common stock, at our election, based on an initial conversion rate of 23.4449 shares of our common stock per $1,000

8

principal amount of 2017 Convertible Notes, which corresponds to an initial conversion price of approximately $42.65 per share of our common stock. On March 30, 2012, our closing share price was $28.59. The conversion rate, and thus the conversion price, may be adjusted under certain circumstances as described in the indenture related to the 2017 Convertible Notes.

The 2017 Convertible Notes may be converted by the holder, in multiples of $1,000 principal amount, only under the following circumstances:

• prior to December 1, 2016, on any date during any calendar quarter beginning after June 30, 2012 (and only during such calendar quarter) if the closing sale price of our common stock was more than 130% of the then current conversion price for at least 20 trading days in the period of the 30 consecutive trading days ending on the last trading day of the previous calendar quarter;

• prior to December 1, 2016, if we distribute to all or substantially all holders of our common stock rights, options or warrants entitling them to purchase, for a period of 45 calendar days or less from the declaration date for such distribution, shares of our common stock at a price per share less than the average closing sale price of our common stock for the ten consecutive trading days immediately preceding, but excluding, the declaration date for such distribution;

• prior to December 1, 2016, if we distribute to all or substantially all holders of our common stock cash, other assets, securities or rights to purchase our securities, which distribution has a per share value exceeding 10% of the closing sale price of our common stock on the trading day immediately preceding the declaration date for such distribution, or if we engage in certain corporate transactions described in the indenture related to the 2017 Convertible Notes;

• prior to December 1, 2016, during the five consecutive business-day period following any five consecutive trading-day period in which the trading price per $1,000 principal amount of 2017 Convertible Notes for each trading day during such five trading-day period was less than 98% of the closing sale price of our common stock for each trading day during such five trading-day period multiplied by the then current conversion rate; or

• on or after December 1, 2016, and prior to the close of business on the second scheduled trading day immediately preceding the maturity date of the 2017 Convertible Notes, which is March 1, 2017, without regard to the foregoing conditions.

Upon conversion, we will be obligated to pay or deliver, as the case may be, cash, shares of our common stock or a combination of cash and shares of our common stock, at our election. If we satisfy our conversion obligation solely in cash or through payment and delivery, as the case may be, of a combination of cash and shares of our common stock, the amount of cash and shares of common stock, if any, due upon conversion will be based on a daily conversion value (as described in the indenture related to the 2017 Convertible Notes) calculated on a proportionate basis for each trading day in a 25 consecutive trading-day conversion period (as described in the indenture related to the 2017 Convertible Notes). Upon any conversion, subject to certain exceptions, holders of the 2017 Convertible Notes will not receive any cash payment representing accrued and unpaid interest. Instead, interest will be deemed to be paid by the cash, shares of our common stock or a combination of cash and shares of our common stock paid or delivered, as the case may be, upon conversion of a 2017 Convertible Note.

If we undergo a fundamental change (as defined in the indenture related to the 2017 Convertible Notes) prior to maturity, holders of the 2017 Convertible Notes will have the right, at their option, to require us to repurchase for cash some or all of their 2017 Convertible Notes at a repurchase price equal to 100% of the principal amount of the 2017 Convertible Notes being repurchased, plus accrued and unpaid interest (including additional interest, if any) to, but excluding, the fundamental change repurchase date.

If holders elect to convert the 2017 Convertible Notes in connection with certain fundamental change transactions described in the indenture, we will increase the conversion rate by a number of additional shares determined by reference to the provisions contained in the indenture based on the effective date of, and the price paid (or deemed paid) per share of our common stock in, such make-whole fundamental change. If holders of our common stock receive only cash in connection with certain make-whole fundamental changes, the price paid (or deemed paid) per share will be the cash amount paid per share. Otherwise, the price paid (or deemed paid) per share will be equal to the average of the closing sale prices of our common stock on the five trading days prior to, but excluding, the effective date of such make-whole fundamental change.

In connection with the sale of the 2017 Convertible Notes, we entered into convertible note hedge transactions with respect to our common stock (the “Purchased Call Options”) with Barclays Capital Inc., acting as agent for Barclays Bank PLC,

9

and Bank of America, N.A. (the “Dealers”). We paid an aggregate amount of approximately $70.8 million to the Dealers for the Purchased Call Options. The Purchased Call Options cover, subject to customary anti-dilution adjustments, approximately 7,033,470 shares of our common stock at a strike price that corresponds to the initial conversion price of the 2017 Convertible Notes, also subject to adjustment, and are exercisable upon conversion of the 2017 Convertible Notes.

We also entered into separate warrant transactions whereby, in reliance upon the exemption from registration provided by Section 4(2) of the Securities Act, we sold to the Dealers warrants to acquire, subject to customary anti-dilution adjustments, approximately 7,033,470 shares of our common stock (the “Sold Warrants”) at a strike price of $55.91 per share of common stock. We received aggregate proceeds of approximately $40.1 million from the sale of the Sold Warrants to the Dealers. If, upon expiration of the Sold Warrants, the price per share of our common stock, as measured under the Sold Warrants, is greater than the strike price of the Sold Warrants, we will be required to issue, without further consideration, under each Sold Warrant a number of shares of our common stock with a value equal to the amount of such difference.

The Purchased Call Options and Sold Warrants are separate contracts entered into by Stone and each of the Dealers, are not part of the terms of the 2017 Convertible Notes and will not affect the holders’ rights under the 2017 Convertible Notes. The Purchased Call Options are expected generally to reduce the potential dilution upon conversion of the 2017 Convertible Notes in the event that the market value per share of our common stock at the time of exercise is greater than the strike price of the Purchased Call Options. The Sold Warrants could separately have a dilutive effect to the extent that the market value per share of our common stock exceeds the applicable strike price of the Sold Warrants.

The estimated liability and equity components of this offering were recorded in accordance with Accounting Standards Codification (“ASC”) 470-20. The initial carrying amount of the liability component of $229.2 million was determined by measuring the fair value of a similar liability that does not have an associated equity component. The carrying amount of the equity component of $70.8 million was determined by deducting the fair value of the liability component from the initial proceeds from the 2017 Convertible Notes. Transaction costs of approximately $8.9 were allocated to the liability and equity components in proportion to the allocation of proceeds and accounted for as debt issuance and equity issuance costs, respectively. The cost of the convertible note hedge of $70.8 million and proceeds from the warrant transaction of $40.1 million were recorded as adjustments to equity. A summary of the entries to record the proceeds from the 2017 Convertible Notes, the cost of the Purchased Call Options and the proceeds from the Sold Warrants is as follows (in millions):

Cash	$	260.5
Other assets (deferred financing costs)		6.8
Long-term debt		(229.2	)
Additional paid-in capital		(38.1	)

Note 5 – Asset Retirement Obligations

The change in our asset retirement obligations during the three months ended March 31, 2012 is set forth below:

	Three Months Ended March  31, 2012
	(in millions)
Asset retirement obligations as of the beginning of the period, including current portion	$	425.8
Liabilities settled		(3.0	)
Divestment of properties		(0.6	)
Accretion expense		8.3
Asset retirement obligations as of the end of the period, including current portion	$	430.5

10

Note 6 – Acquisitions

On December 28, 2011, we completed the acquisition of BP Exploration & Production Inc.’s (“BP”) 75% operated working interest in the five block deep water Pompano field in Mississippi Canyon, a 51% operated working interest in the adjacent Mississippi Canyon block 29, a 50% non-operated working interest in the Mica field which ties back to the Pompano platform and a 75% interest in 23 deep water exploration leases located in the vicinity of the Pompano field. The acquisition was accounted for according to the guidance provided in ASC 805, Business Combinations, which requires application of the acquisition method. This methodology requires the recordation of net assets acquired and consideration transferred at fair value (see Note 7 – Fair Value Measurements). Differences between the net fair value of assets acquired and consideration transferred are recorded as goodwill or a bargain purchase gain. The following represents the allocation of the recorded value of net assets acquired in the transaction. Consideration transferred in the transaction was $167.6 million in cash, resulting in no goodwill or bargain purchase gain.

	(in millions)
Proved oil and gas properties	$	208.7
Unevaluated oil and gas properties		17.3
Asset retirement obligations		(58.4	)
Total fair value of net assets	$	167.6

The following unaudited summary pro forma combined statement of operations data of Stone for the three month period ended March 31, 2011 has been prepared to give effect to the acquisition of the deep water assets from BP as if it had occurred on January 1, 2010. The pro forma financial information is not necessarily indicative of the results that might have occurred had the transaction taken place on January 1, 2010 and is not intended to be a projection of future results. Future results may vary significantly from the results reflected in the following pro forma financial information because of normal production declines, changes in commodity prices, future acquisitions and divestitures, future development and exploration activities, and other factors.

	Three Months Ended March 31, 2011 (unaudited)
	(in millions, except per share amounts)
Revenues	$	241.1
Income from operations		91.4
Net income		55.9
Basic earnings per share	$	1.14
Diluted earnings per share	$	1.14

Note 7 – Fair Value Measurements

U.S. Generally Accepted Accounting Principles establish a fair value hierarchy which has three levels based on the reliability of the inputs used to determine the fair value. These levels include: Level 1, defined as inputs such as unadjusted quoted prices in active markets for identical assets or liabilities; Level 2, defined as inputs other than quoted prices in active markets that are either directly or indirectly observable; and Level 3, defined as unobservable inputs for use when little or no market data exists, therefore requiring an entity to develop its own assumptions.

As of March 31, 2012 and December 31, 2011, we held certain financial assets and liabilities that are required to be measured at fair value on a recurring basis, including our commodity derivative instruments and our investments in money market funds. We utilize the services of an independent third party to assist us in valuing our derivative instruments. We used the income approach in determining the fair value of our derivative instruments utilizing a proprietary pricing model. The model accounts for our credit risk and the credit risk of our counterparties in the discount rate applied to estimated future cash inflows and outflows. Our swap contracts are included within the Level 2 fair value hierarchy. For a more detailed description of our derivative instruments, (see Note 3 – Derivative Instruments and Hedging Activities). We used the market approach in determining the fair value of our investments in money market funds, which are included within the Level 1 fair value hierarchy.

11

The following tables present our assets and liabilities that are measured at fair value on a recurring basis at March 31, 2012:

		$00,0		$00,0		$00,0		$00,0
	Fair Value Measurements at March 31, 2012
Assets	Total		Quoted Prices in Active Markets for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)
	(in millions)
Money market funds	$	5.8	$	5.8	$	—	$	—
Hedging contracts		35.3		—		35.3		—
Total	$	41.1	$	5.8	$	35.3	$	—

		$00,0			$00,0		$00,0			$00,0
	Fair Value Measurements at March 31, 2012
Liabilities	Total			Quoted Prices in Active Markets for Identical Liabilities (Level 1)		Significant Other Observable Inputs (Level 2)			Significant Unobservable Inputs (Level 3)
	(in millions)
Hedging contracts	($	35.3	)	$	—	($	35.3	)	$	—
Total	($	35.3	)	$	—	($	35.3	)	$	—

The following tables present our assets and liabilities that are measured at fair value on a recurring basis at December 31, 2011:

	Fair Value Measurements at December 31, 2011
Assets	Total		Quoted Prices in Active Markets for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)
	(in millions)
Money market funds	$	5.6	$	5.6	$	—	$	—
Hedging contracts		47.7		—		47.7		—
Total	$	53.3	$	5.6	$	47.7	$	—

	Fair Value Measurements at December 31, 2011
Liabilities	Total			Quoted Prices in Active Markets for Identical Liabilities (Level 1)		Significant Other Observable Inputs (Level 2)			Significant Unobservable Inputs (Level 3)
	(in millions)
Hedging contracts	($	11.9	)	$	—	($	11.9	)	$	—
Total	($	11.9	)	$	—	($	11.9	)	$	—

The fair value of cash and cash equivalents and our variable rate bank debt approximated book value at March 31, 2012 and December 31, 2011. As of March 31, 2012 and December 31, 2011, the fair value of our $375 million 8 ⁵/8% Senior Notes due 2017 was approximately $392.8 million and $386.3 million, respectively. As of March 31, 2012 and December 31, 2011, the fair value of our $200 million 6 ³/4% Senior Subordinated Notes due 2014 was approximately $202.5 million and $199.0 million, respectively. As of March 31, 2012, the fair value of our 2017 Convertible Notes was approximately $292.7 million, of which $231.2 million was attributable to the liability component. The fair value of our outstanding notes was determined based upon quotes obtained from brokers, which represent Level 2 inputs.

We applied fair value concepts in determining the liability component of our 2017 Convertible Notes (see Note 4 – Long-Term Debt). The significant input in this determination was a market interest rate of 7.51% which represents a market rate based on quotes obtained from brokers and represents a Level 2 input.

12

We applied fair value concepts in the recording of deep water assets acquired from BP (see Note 6 – Acquisitions). The fair value of proved and unevaluated oil and gas properties was estimated using a market approach. Significant inputs were market value comparisons for similar transactions within a one year period. These inputs were considered Level 3 inputs. Asset retirement obligations were determined in accordance with applicable accounting standards.

Note 8 – Commitments and Contingencies

We are named as a defendant in certain lawsuits and are a party to certain regulatory proceedings arising in the ordinary course of business. We do not expect these matters, individually or in the aggregate, will have a material adverse effect on our financial condition.

Franchise Tax Action. We have been served with several petitions filed by the Louisiana Department of Revenue (“LDR”) in Louisiana state court claiming additional franchise taxes due. In addition, we have received preliminary assessments from the LDR for additional franchise taxes resulting from audits of Stone and other subsidiaries. These assessments all relate to the LDR’s assertion that sales of crude oil and natural gas from properties located on the OCS, which are transported through the state of Louisiana, should be sourced to the state of Louisiana for purposes of computing the Louisiana franchise tax apportionment ratio. Total asserted claims plus estimated accrued interest amount to approximately $30.1 million. The franchise tax years 2010 and 2011 for Stone remain subject to examination, which potentially exposes us to additional estimated assessments of $3.3 million including accrued interest. We estimate the potential range of loss upon resolution of this matter to be between $0 and $34.0 million.

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Note 9 – Guarantor Financial Statements

Stone Offshore is an unconditional guarantor (the “Guarantor Subsidiary”) of our 1 ³/4% Senior Convertible Notes due 2017, our 8 ⁵/8% Senior Notes due 2017 and our 6 ³/4% Senior Subordinated Notes due 2014. Our remaining subsidiaries (the “Non-Guarantor Subsidiaries”) have not provided guarantees. The following presents unaudited condensed consolidating financial information as of March 31, 2012 and December 31, 2011 and for the three-month periods ended March 31, 2012 and 2011 on an issuer (parent company), guarantor subsidiary, non-guarantor subsidiaries, and consolidated basis. Elimination entries presented are necessary to combine the entities.

CONDENSED CONSOLIDATING BALANCE SHEET

MARCH 31, 2012

(In thousands of dollars)

	Parent			Guarantor Subsidiary			Non-Guarantor Subsidiaries			Eliminations			Consolidated
Assets
Current assets:
Cash and cash equivalents	$	222,750		$	40,955		$	136		$	—		$	263,841
Accounts receivable		37,849			113,735			1,466			(19,784	)		133,266
Fair value of hedging contracts		—			24,352			—			—			24,352
Current income tax receivable		23,140			—			—			—			23,140
Deferred taxes *		3,194			27,012			—			—			30,206
Inventory		4,360			283			—			—			4,643
Other current assets		754			—			—			—			754
Total current assets		292,047			206,337			1,602			(19,784	)		480,202
Oil and gas properties, full cost method:
Proved		672,697			6,027,024			5,051			—			6,704,772
Less: accumulated DD&A		(321,084	)		(4,929,353	)		(2,457	)		—			(5,252,894	)
Net proved oil and gas properties		351,613			1,097,671			2,594			—			1,451,878
Unevaluated		275,920			167,969			—			—			443,889
Other property and equipment, net		11,444			—			—			—			11,444
Fair value of hedging contracts		—			10,937			—			—			10,937
Other assets, net		27,494			1,469			—			—			28,963
Investment in subsidiary		777,606			(512	)		—			(777,094	)		—
Total assets	$	1,736,124		$	1,483,871		$	4,196		($	796,878	)	$	2,427,313
Liabilities and Stockholders’ Equity
Current liabilities:
Accounts payable to vendors	$	92,986		$	12,898		$	208		($	19,785	)	$	86,307
Undistributed oil and gas proceeds		24,810			1,549			—			—			26,359
Accrued interest		10,490			—			—			—			10,490
Fair value of hedging contracts		—			27,298			—			—			27,298
Asset retirement obligations		—			71,256			—			—			71,256
Other current liabilities		4,613			6,127			—			—			10,740
Total current liabilities		132,899			119,128			208			(19,785	)		232,450
Long-term debt		805,140			—			—			—			805,140
Deferred taxes *		42,131			224,865			—			—			266,996
Asset retirement obligations		7,240			347,533			4,501			—			359,274
Fair value of hedging contracts		—			8,025			—			—			8,025
Other long-term liabilities		13,809			6,714			—			—			20,523
Total liabilities		1,001,219			706,265			4,709			(19,785	)		1,692,408
Commitments and contingencies
Stockholders’ equity:
Common stock		483			—			—			—			483
Treasury stock		(860	)		—			—			—			(860	)
Additional paid-in capital		1,376,730			1,724,232			1,639			(1,725,871	)		1,376,730
Accumulated earnings (deficit)		(641,251	)		(946,429	)		(2,152	)		948,581			(641,251	)
Accumulated other comprehensive income (loss)		(197	)		(197	)		—			197			(197	)
Total stockholders’ equity		734,905			777,606			(513	)		(777,093	)		734,905
Total liabilities and stockholders’ equity	$	1,736,124		$	1,483,871		$	4,196		($	796,878	)	$	2,427,313

* Deferred income taxes have been allocated to guarantor subsidiary where related oil and gas properties reside.

14

CONDENSED CONSOLIDATING BALANCE SHEET

DECEMBER 31, 2011

(In thousands of dollars)

	Parent			Guarantor Subsidiary			Non-Guarantor Subsidiaries			Eliminations			Consolidated
Assets
Current assets:
Cash and cash equivalents	$	37,389		$	926		$	136		$	—		$	38,451
Accounts receivable		36,463			81,452			1,353			(1,129	)		118,139
Fair value of hedging contracts		—			25,177			—			—			25,177
Current income tax receivable		19,946			—			—			—			19,946
Deferred taxes *		8,269			17,803			—			—			26,072
Inventory		4,360			283			—			—			4,643
Other current assets		791			—			—			—			791
Total current assets		107,218			125,641			1,489			(1,129	)		233,219
Oil and gas properties, full cost method:
Proved		696,975			5,946,141			5,052			—			6,648,168
Less: accumulated DD&A		(309,421	)		(4,862,949	)		(2,359	)		—			(5,174,729	)
Net proved oil and gas properties		387,554			1,083,192			2,693			—			1,473,439
Unevaluated		246,269			155,340			—			—			401,609
Other property and equipment, net		11,172			—			—			—			11,172
Fair value of hedging contracts		—			22,543			—			—			22,543
Other assets, net		20,873			2,896			—			—			23,769
Investment in subsidiary		733,533			(273	)		—			(733,260	)		—
Total assets	$	1,506,619		$	1,389,339		$	4,182		($	734,389	)	$	2,165,751
Liabilities and Stockholders’ Equity
Current liabilities:
Accounts payable to vendors	$	78,170		$	25,866		$	39		($	1,129	)	$	102,946
Undistributed oil and gas proceeds		26,036			1,292			—			—			27,328
Accrued interest		14,059			—			—			—			14,059
Fair value of hedging contracts		—			11,122			—			—			11,122
Asset retirement obligations		—			62,676			—			—			62,676
Other current liabilities		22,974			5,396			—			—			28,370
Total current liabilities		141,239			106,352			39			(1,129	)		246,501
Long-term debt		620,000			—			—			—			620,000
Deferred taxes *		56,970			190,865			—			—			247,835
Asset retirement obligations		7,626			351,061			4,416			—			363,103
Fair value of hedging contracts		—			815			—			—			815
Other long-term liabilities		12,955			6,713			—			—			19,668
Total liabilities		838,790			655,806			4,455			(1,129	)		1,497,922
Commitments and contingencies
Stockholders’ equity:
Common stock		481			—			—			—			481
Treasury stock		(860	)		—			—			—			(860	)
Additional paid-in capital		1,338,565			1,724,232			1,639			(1,725,871	)		1,338,565
Accumulated earnings (deficit)		(692,225	)		(1,012,567	)		(1,912	)		1,014,479			(692,225	)
Accumulated other comprehensive income (loss)		21,868			21,868			—			(21,868	)		21,868
Total stockholders’ equity		667,829			733,533			(273	)		(733,260	)		667,829
Total liabilities and stockholders’ equity	$	1,506,619		$	1,389,339		$	4,182		($	734,389	)	$	2,165,751

* Deferred income taxes have been allocated to guarantor subsidiary where related oil and gas properties reside.

15

CONDENSED CONSOLIDATING STATEMENT OF OPERATIONS

THREE MONTHS ENDED MARCH 31, 2012

(In thousands of dollars)

	Parent			Guarantor Subsidiary			Non- Guarantor Subsidiaries			Eliminations			Consolidated
Operating revenue:
Oil production	$	6,234		$	195,524		$	—		$	—		$	201,758
Gas production		5,631			23,226			—			—			28,857
Natural gas liquids production		3,864			9,588			—			—			13,452
Other operational income		694			63			133			—			890
Total operating revenue		16,423			228,401			133			—			244,957
Operating expenses:
Lease operating expenses		4,904			39,387			189			—			44,480
Transportation, processing and gathering expenses		2,488			1,169			—			—			3,657
Other operational expenses		42			—			—			—			42
Production taxes		1,163			2,215			—			—			3,378
Depreciation, depletion, amortization		11,477			73,000			98			—			84,575
Accretion expense		148			8,032			86			—			8,266
Salaries, general and administrative		12,654			1,051			—			—			13,705
Incentive compensation expense		1,442			—			—			—			1,442
Derivative expense, net		—			485			—			—			485
Total operating expenses		34,318			125,339			373			—			160,030
Income (loss) from operations		(17,895	)		103,062			(240	)		—			84,927
Other (income) expenses:
Interest expense		5,846			(115	)		—			—			5,731
Interest income		(30	)		(1	)		—			—			(31	)
Other income		(19	)		(401	)		—			—			(420	)
(Income) loss from investment in subsidiaries		(66,137	)		239			—			65,898			—
Total other (income) expenses		(60,340	)		(278	)		—			65,898			5,280
Income (loss) before taxes		42,445			103,340			(240	)		(65,898	)		79,647
Provision (benefit) for income taxes:
Current		1,234			—			—			—			1,234
Deferred		(9,763	)		37,202			—			—			27,439
Total income taxes		(8,529	)		37,202			—			—			28,673
Net income (loss)	$	50,974		$	66,138		($	240	)	($	65,898	)	$	50,974
Comprehensive income (loss)	$	28,909		$	66,138		($	240	)	($	65,898	)	$	28,909

16

CONDENSED CONSOLIDATING STATEMENT OF OPERATIONS

THREE MONTHS ENDED MARCH 31, 2011

(In thousands of dollars)

	Parent			Guarantor Subsidiary			Non- Guarantor Subsidiaries			Eliminations			Consolidated
Operating revenue:
Oil production	$	786		$	151,209		$	—		$	—		$	151,995
Gas production		1,280			39,880			—			—			41,160
Natural gas liquids production		—			5,999			—			—			5,999
Other operational income		722			(19	)		182			—			885
Total operating revenue		2,788			197,069			182			—			200,039
Operating expenses:
Lease operating expenses		356			37,931			—			—			38,287
Transportation, processing and gathering expenses		—			1,820			—			—			1,820
Other operational expenses		—			662			—			—			662
Production taxes		147			2,388			—			—			2,535
Depreciation, depletion, amortization		5,942			61,510			217			—			67,669
Accretion expense		4			7,622			91			—			7,717
Salaries, general and administrative		11,731			2			—			—			11,733
Incentive compensation expense		2,684			—			—			—			2,684
Derivative expense, net		—			2,180			—			—			2,180
Total operating expenses		20,864			114,115			308			—			135,287
Income (loss) from operations		(18,076	)		82,954			(126	)		—			64,752
Other (income) expenses:
Interest expense		3,031			80			—			—			3,111
Interest income		(88	)		(6	)		—			—			(94	)
Other income		—			(567	)		3			—			(564	)
Other expense		123			1			—			—			124
(Income) loss from investment in subsidiary		(53,323	)		129			—			53,194			—
Total other (income) expenses		(50,257	)		(363	)		3			53,194			2,577
Income (loss) before taxes		32,181			83,317			(129	)		(53,194	)		62,175
Provision (benefit) for income taxes:
Current		—			—			—			—			—
Deferred		(7,611	)		29,994			—			—			22,383
Total income taxes		(7,611	)		29,994			—			—			22,383
Net income (loss)	$	39,792		$	53,323		($	129	)	($	53,194	)	$	39,792
Comprehensive income (loss)	$	7,318		$	53,323		($	129	)	($	53,194	)	$	7,318

17

CONDENSED CONSOLIDATING STATEMENT OF CASH FLOWS

THREE MONTHS ENDED MARCH 31, 2012

(In thousands of dollars)

	Parent			Guarantor Subsidiary			Non-Guarantor Subsidiaries			Eliminations			Consolidated
Cash flows from operating activities:
Net income (loss)	$	50,974		$	66,138		($	240	)	($	65,898	)	$	50,974
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Depreciation, depletion and amortization		11,477			73,000			98			—			84,575
Accretion expense		148			8,032			86			—			8,266
Deferred income tax provision (benefit)		(9,763	)		37,202			—			—			27,439
Settlement of asset retirement obligations		—			(2,980	)		—			—			(2,980	)
Non-cash stock compensation expense		1,750			—			—			—			1,750
Excess tax benefits		(847	)		—			—			—			(847	)
Non-cash derivative expense		—			1,342			—			—			1,342
Non-cash (income) loss from investment in subsidiaries		(65,737	)		(161	)		—			65,898			—
Other non-cash expenses		1,173			—			—			—			1,173
Change in current income taxes		(2,647	)		—			—			—			(2,647	)
Change in intercompany receivables/payables		18,655			(18,445	)		(210	)		—			—
(Increase) decrease in accounts receivable		(983	)		(20,823	)		98			—			(21,708	)
Decrease in other current assets		35			—			—			—			35
Increase (decrease) in accounts payable		(25	)		(6,157	)		167			—			(6,015	)
Increase (decrease) in other current liabilities		(23,155	)		987			—			—			(22,168	)
Other		146			—			—			—			146
Net cash provided by (used in) operating activities		(18,799	)		138,135			(1	)		—			119,335
Cash flows from investing activities:
Investment in oil and gas properties		(8,364	)		(98,106	)		1			—			(106,469	)
Sale of fixed assets		134			—			—			—			134
Investment in fixed and other assets		(909	)		—			—			—			(909	)
Net cash provided by (used in) investing activities		(9,139	)		(98,106	)		1			—			(107,244	)
Cash flows from financing activities:
Proceeds from bank borrowings		25,000			—			—			—			25,000
Repayments of bank borrowings		(70,000	)		—			—			—			(70,000	)
Proceeds from issuance of senior convertible notes		300,000			—			—			—			300,000
Financing costs of senior convertible notes		(8,855	)		—			—			—			(8,855	)
Proceeds from Sold Warrants		40,170			—			—			—			40,170
Payments for Purchased Call Options		(70,830	)		—			—			—			(70,830	)
Excess tax benefits		847			—			—			—			847
Net payments for share based compensation		(3,033	)		—			—			—			(3,033	)
Net cash provided by financing activities		213,299			—			—			—			213,299
Net change in cash and cash equivalents		185,361			40,029			—			—			225,390
Cash and cash equivalents, beginning of period		37,389			926			136			—			38,451
Cash and cash equivalents, end of period	$	222,750		$	40,955		$	136		$	—		$	263,841

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CONDENSED CONSOLIDATING STATEMENT OF CASH FLOWS

THREE MONTHS ENDED MARCH 31, 2011

(In thousands of dollars)

	Parent			Guarantor Subsidiary			Non-Guarantor Subsidiaries			Eliminations			Consolidated
Cash flows from operating activities:
Net income (loss)	$	39,792		$	53,323		($	129	)	($	53,194	)	$	39,792
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Depreciation, depletion and amortization		5,942			61,510			217			—			67,669
Accretion expense		4			7,622			91			—			7,717
Deferred income tax provision (benefit)		(7,611	)		29,994			—			—			22,383
Settlement of asset retirement obligations		—			(19,034	)		—			—			(19,034	)
Non-cash stock compensation expense		1,680			—			—			—			1,680
Excess tax benefits		(649	)		—			—			—			(649	)
Non-cash derivative expense		—			1,804			—			—			1,804
Non-cash (income) loss from investment in subsidiary		(52,756	)		(438	)		—			53,194			—
Other non-cash income		(104	)		—			—			—			(104	)
Change in current income taxes		(3,681	)		—			—			—			(3,681	)
Change in intercompany receivables/payables		44,230			(43,804	)		(426	)		—			—
(Increase) decrease in accounts receivable		6,833			(28,509	)		121			—			(21,555	)
Decrease in other current assets		25			—			—			—			25
Decrease in inventory		365			—			—			—			365
Increase in accounts payable		2,609			81			—			—			2,690
Increase (decrease) in other current liabilities		(10,929	)		870			—			—			(10,059	)
Other		272			—			—			—			272
Net cash provided by (used in) operating activities		26,022			63,419			(126	)		—			89,315
Cash flows from investing activities:
Investment in oil and gas properties		(89,444	)		(67,087	)		(4	)		—			(156,535	)
Proceeds from sale of oil and gas properties		5,575			2,117			—			—			7,692
Investment in fixed and other assets		(262	)		—			—			—			(262	)
Net cash used in investing activities		(84,131	)		(64,970	)		(4	)		—			(149,105	)
Cash flows from financing activities:
Deferred financing costs		(66	)		—			—			—			(66	)
Excess tax benefits		649			—			—			—			649
Net payments for share based compensation		(1,843	)		—			—			—			(1,843	)
Net cash used in financing activities		(1,260	)		—			—			—			(1,260	)
Net change in cash and cash equivalents		(59,369	)		(1,551	)		(130	)		—			(61,050	)
Cash and cash equivalents, beginning of period		105,115			1,659			182			—			106,956
Cash and cash equivalents, end of period	$	45,746		$	108		$	52		$	—		$	45,906

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

Forward-Looking Statements

The information in this Quarterly Report on Form 10-Q includes “forward-looking statements” within the meaning of Section 27A of the Securities Act and Section 21E of the Securities Exchange Act of 1934, as amended (the “Exchange Act”). All statements, other than statements of historical or current facts, that address activities, events, outcomes and other matters that we plan, expect, intend, assume, believe, budget, predict, forecast, project, estimate or anticipate (and other similar expressions) will, should or may occur in the future are forward-looking statements. These forward-looking statements are based on management’s current belief, based on currently available information, as to the outcome and timing of future events. When considering forward-looking statements, you should keep in mind the risk factors and other cautionary statements as described in our 2011 Annual Report on Form 10-K and in this Quarterly Report on Form 10-Q.

Forward-looking statements appear in a number of places and include statements with respect to, among other things:

• any expected results or benefits associated with our acquisitions;

• estimates of our future oil and natural gas production, including estimates of any increases in oil and gas production;

• planned capital expenditures and the availability of capital resources to fund capital expenditures;

• our outlook on oil and gas prices;

• estimates of our oil and gas reserves;

• any estimates of future earnings growth;

• the impact of political and regulatory developments;

• our outlook on the resolution of pending litigation and government inquiry;

• estimates of the impact of new accounting pronouncements on earnings in future periods;

• our future financial condition or results of operations and our future revenues and expenses;

• our access to capital and our anticipated liquidity;

• estimates of future income taxes; and

• our business strategy and other plans and objectives for future operations.

We caution you that these forward-looking statements are subject to risks and uncertainties, many of which are beyond our control, incident to the exploration for and development, production and marketing of oil and natural gas. These risks include, among other things:

• commodity price volatility;

• domestic and worldwide economic conditions;

• the availability of capital on economic terms to fund our capital expenditures and acquisitions;

• our level of indebtedness;

• declines in the value of our oil and gas properties resulting in a decrease in our borrowing base under our credit facility and ceiling test write-downs and impairments;

• our ability to replace and sustain production;

• the impact of a financial crisis on our business operations, financial condition and ability to raise capital;

• the ability of financial counterparties to perform or fulfill their obligations under existing agreements;

• third party interruption of sales to market;

• lack of availability and cost of goods and services;

• regulatory and environmental risks associated with drilling and production activities;

• drilling and other operating risks;

• unsuccessful exploration and development drilling activities;

• hurricanes and other weather conditions;

• the adverse effects of changes in applicable tax, environmental, derivatives and other regulatory legislation, including changes affecting our offshore and Appalachian operations;

• consequences of the Deepwater Horizon oil spill and resulting stringent regulatory requirements;

• the uncertainty inherent in estimating proved oil and natural gas reserves and in projecting future rates of production and timing of development expenditures; and

• the other risks described in our Annual Report on Form 10-K and our Quarterly Reports on Form 10-Q.

Should one or more of the risks or uncertainties described above, in our Annual Report on Form 10-K for the year ended December 31, 2011, or in our Quarterly Reports on Form 10-Q occur, or should underlying assumptions prove incorrect, our actual results and plans could differ materially from those expressed in any forward-looking statements. We specifically

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disclaim all responsibility to publicly update any information contained in a forward-looking statement or any forward-looking statement in its entirety and therefore disclaim any resulting liability for potentially related damages. All forward-looking statements attributable to us are expressly qualified in their entirety by this cautionary statement.

Management’s Discussion and Analysis of Financial Condition and Results of Operations (“MD&A”) contained in this Form 10-Q should be read in conjunction with the MD&A contained in our Annual Report on Form 10-K for the year ended December 31, 2011.

Overview

We are an independent oil and gas company engaged in the acquisition, exploration, exploitation, development and operation of oil and gas properties. We have been operating in the Gulf Coast Basin since our incorporation in 1993 and have established a technical and operational expertise in this area. More recently, we have expanded our reserve base outside of the conventional shelf of the Gulf of Mexico (“GOM”) and into the more prolific reserve basins of the GOM deep water and Gulf Coast deep gas as well as onshore oil and gas shale opportunities, including the Marcellus Shale in Appalachia.

Critical Accounting Policies

Our Annual Report on Form 10-K describes the accounting policies that we believe are critical to the reporting of our financial position and operating results and that require management’s most difficult, subjective or complex judgments. Our most significant estimates are:

• remaining proved oil and gas reserves volumes and the timing of their production;

• estimated costs to develop and produce proved oil and gas reserves;

• accruals of exploration costs, development costs, operating costs and production revenue;

• timing and future costs to abandon our oil and gas properties;

• the effectiveness and estimated fair value of derivative positions;

• classification of unevaluated property costs;

• capitalized general and administrative costs and interest;

• insurance recoveries related to hurricanes and other events;

• estimates of fair value in business combinations;

• current income taxes; and

• contingencies.

This Quarterly Report on Form 10-Q should be read together with the discussion contained in our Annual Report on Form 10-K regarding these critical accounting policies.

Other Factors Affecting Our Business and Financial Results

In addition to the matters discussed above, our business, financial condition and results of operations are affected by a number of other factors. This Quarterly Report on Form 10-Q should be read in conjunction with the discussion in Part I, Item 1A, of our 2011 Annual Report on Form 10-K regarding these other risk factors and in this report under Part II, Item 1A, “Risk Factors.”

Known Trends and Uncertainties

Hurricanes – Since the majority of our production originates in the GOM, we are particularly vulnerable to the effects of hurricanes on production. Additionally, affordable insurance coverage for property damage to our facilities for hurricanes is becoming more difficult to obtain. We have narrowed our insurance coverage to selected properties, increased our deductibles and are shouldering more hurricane related risk in the environment of rising insurance rates. Significant hurricane impacts could include reductions and/or deferrals of future oil and natural gas production and revenues, increased lease operating expenses for evacuations and repairs and possible acceleration of plugging and abandonment costs.

Louisiana Franchise Taxes – We have been involved in litigation with the state of Louisiana over the proper computation of franchise taxes allocable to the state. This litigation relates to the state’s position that sales of crude oil and natural gas from properties located on the Outer Continental Shelf (“OCS”), which are transported through the state of Louisiana, should be sourced to Louisiana for purposes of computing franchise taxes. We disagree with the state’s position. However, if the state’s position were to be upheld, we could incur additional expenses for alleged underpaid franchise taxes in prior years and higher franchise tax expense in future years. See “Part II, Item 1. Legal Proceedings.”

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Liquidity and Capital Resources

At May 7, 2012, we had $372.9 million of availability under our bank credit facility and cash on hand of approximately $240 million. Our capital expenditure budget for 2012 has been set at $625 million, which excludes material acquisitions and capitalized salaries, general and administrative expenses and interest. We intend to finance our capital expenditure budget primarily with cash on hand, cash flow from operations and borrowings under our bank credit facility.

Cash Flow and Working Capital. Net cash flow provided by operating activities totaled $119.3 million during the three months ended March 31, 2012 compared to $89.3 million in the comparable period in 2011. Based on our outlook of commodity prices and our estimated production, we expect to fund our 2012 capital expenditures with cash on hand, cash flow provided by operating activities and borrowings under our bank credit facility.

Net cash flow used in investing activities totaled $107.2 million and $149.1 million during the three months ended March 31, 2012 and 2011, respectively, which primarily represents our investment in oil and natural gas properties.

Net cash flow provided by financing activities totaled $213.3 million for the three months ended March 31, 2012, which primarily represents $291.1 million of net proceeds from the issuance of our 2017 Convertible Notes and $40.1 million of proceeds from the Sold Warrants, partially offset by $70.8 million for the cost of the Purchased Call Options. Additionally, we had $25.0 million of borrowings and $70.0 million of repayments of borrowings under our bank credit facility during the three months ended March 31, 2012. Net cash flow used in financing activities totaled $1.3 million for the three months ended March 31, 2011, which primarily represents tax payments for vesting on share based compensation.

We had working capital at March 31, 2012 of $247.8 million. Included in working capital at March 31, 2012 is a portion of the proceeds received from the issuance of our 2017 Convertible Notes (see Senior Convertible Notes below).

Capital Expenditures. During the three months ended March 31, 2012, additions to oil and gas property costs of $98.9 million included $1.2 million of lease and property acquisition costs, $5.6 million of capitalized salaries, general and administrative expenses (inclusive of incentive compensation) and $8.7 million of capitalized interest. These investments were financed by cash flow from operations.

Bank Credit Facility. On April 26, 2011, we entered into an amended and restated revolving credit facility totaling $700 million through a syndicated bank group, replacing our previous $700 million facility. The credit facility matures on September 15, 2014. However, if the notes issued under our 2004 indenture are retired on or before April 15, 2014, the credit facility then matures on April 26, 2015. Our initial borrowing base under the credit facility was set at $400 million. On October 31, 2011, the bank group reaffirmed the existing borrowing base at $400 million. On February 28, 2012, we entered into an Amendment No. 1 and Consent to our credit agreement to permit the issuance of our 2017 Convertible Notes (see Senior Convertible Notes below). On March 6, 2012, we issued $300 million in aggregate principal amount of 2017 Convertible Notes in a private offering. Upon completion of the offering, our borrowing base under our bank credit facility was automatically reduced from $400 million to $310 million. On May 4, 2012, our borrowing base under our bank credit facility was redetermined to be $400 million.

On March 31, 2012, we had no outstanding borrowings under our bank credit facility and letters of credit totaling $27.1 million had been issued under the facility. As of May 7, 2012, we had no outstanding borrowings under our bank credit facility and letters of credit totaling $27.1 million had been issued under the facility, leaving $372.9 million of availability under the facility. Our bank credit facility is guaranteed by our only material subsidiary, Stone Energy Offshore, L.L.C. (“Stone Offshore”).

The borrowing base under our bank credit facility is redetermined by the lenders semi-annually, on May 1 and November 1, taking into consideration the estimated value of our oil and gas properties and those of our direct and indirect material subsidiaries in accordance with the lenders’ customary practices for oil and gas loans. In addition, we and the lenders each have discretion at any time, but not more than two additional times in any calendar year, to have the borrowing base redetermined. Our bank credit facility is collateralized by substantially all of Stone’s and Stone Offshore’s assets. Stone and Stone Offshore are required to mortgage, and grant a security interest in, their oil and gas reserves representing at least 80% of the discounted present value of the future net cash flows from their oil and gas reserves reviewed in determining the borrowing base. At our option, loans under the credit facility will bear interest at a rate based on the adjusted Libor Rate plus an applicable margin, or a rate based on the prime rate or Federal funds rate plus an applicable margin. Our bank credit facility provides for optional and mandatory prepayments, affirmative and negative covenants, and interest coverage ratio and leverage ratio maintenance covenants. We were in compliance with all covenants as of March 31, 2012.

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Senior Convertible Notes. On March 6, 2012, we issued in a private offering $300 million in aggregate principal amount of 1 ³/4% Senior Convertible Notes due 2017 (the “2017 Convertible Notes”) to qualified institutional buyers pursuant to Rule 144A under the Securities Act. The 2017 Convertible Notes are fully and unconditionally guaranteed on a senior unsecured basis by Stone Offshore and by certain future restricted subsidiaries of Stone. The net proceeds from the sale of the 2017 Convertible Notes were approximately $291.1 million, after deducting fees and expenses. The 2017 Convertible Notes bear interest at a rate of 1.75% per year, payable on March 1 and September 1 of each year, beginning on September 1, 2012. The 2017 Convertible Notes mature on March 1, 2017, unless earlier converted or repurchased. We may not redeem the 2017 Convertible Notes at our option prior to the maturity date.

The 2017 Convertible Notes are convertible into cash, shares of our common stock or a combination of cash and shares of our common stock, at our election, based on an initial conversion rate of 23.4449 shares of our common stock per $1,000 principal amount of 2017 Convertible Notes, which corresponds to an initial conversion price of approximately $42.65 per share of our common stock. On March 30, 2012, our closing share price was $28.59. The conversion rate, and thus the conversion price, may be adjusted under certain circumstances as described in the indenture related to the 2017 Convertible Notes. Upon conversion, we will be obligated to pay or deliver, as the case may be, cash, shares of our common stock or a combination of cash and shares of our common stock, at our election. Prior to December 1, 2016, the Convertible Notes will be convertible only upon the occurrence of certain events and during certain periods, and thereafter, at any time until the second scheduled trading day immediately preceding the maturity date.

In connection with the offering, we entered into convertible note hedge transactions in respect of our common stock. These convertible note hedge transactions are expected to reduce the potential dilution upon future conversion of the 2017 Convertible Notes. In addition, we entered into separate warrant transactions at a higher strike price. The warrant transactions could separately have a dilutive effect to the extent that the market value per share of our common stock exceeds the applicable strike price of the warrants.

We applied a portion of the net proceeds of $291.1 million from the sale of the 2017 Convertible Notes and the proceeds from the warrant transactions of $40.1 million to fund the cost of the convertible note hedge transactions of $70.8 million. We also used a portion of the net proceeds to repay $70 million of outstanding borrowings under our bank credit facility and expect to use the remaining net proceeds for general corporate purposes, including additional acquisitions.

Share Repurchase Program. On September 24, 2007, our Board of Directors authorized a share repurchase program for an aggregate amount of up to $100 million. The shares may be repurchased from time to time in the open market or through privately negotiated transactions. The repurchase program is subject to business and market conditions, and may be suspended or discontinued at any time. Through March 31, 2012, 300,000 shares had been repurchased under this program at a total cost of approximately $7.1 million, or an average price of $23.57 per share. No shares were repurchased during the three months ended March 31, 2012.

23

Results of Operations

The following table sets forth certain information with respect to our oil and gas operations.

	Three Months Ended March 31,
	2012		2011		Variance			% Change
Production:
Oil (MBbls)		1,862		1,616		246			15	%
Natural gas (MMcf)		9,994		9,083		911			10	%
Natural gas liquids (MBbls)		200		128		72			56	%
Oil, natural gas and NGLs (MMcfe)		22,366		19,547		2,819			14	%
Revenue data (in thousands) (a):
Oil revenue	$	201,758	$	151,995	$	49,763			33	%
Natural gas revenue		28,857		41,160		(12,303	)		(30	%)
Natural gas liquids revenue		13,452		5,999		7,453			124	%
Total oil, natural gas and NGL revenue	$	244,067	$	199,154	$	44,913			23	%
Average prices (a):
Oil (per Bbl)	$	108.36	$	94.06	$	14.30			15	%
Natural gas (per Mcf)		2.89		4.53		(1.64	)		(36	%)
Natural gas liquids (per Bbl)		67.26		46.87		20.39			44	%
Oil, natural gas and NGLs (per Mcfe)		10.91		10.19		0.72			7	%
Expenses (per Mcfe):
Lease operating expenses	$	1.99	$	1.96	$	0.03			2	%
Salaries, general and administrative expenses (b)		0.61		0.60		0.01			2	%
DD&A expense on oil and gas properties		3.75		3.40		0.35			10	%

(a) Includes the cash settlement of effective hedging contracts.

(b) Exclusive of incentive compensation expense.

During the three months ended March 31, 2012, we reported net income totaling $51.0 million, or $1.03 per share, compared to net income for the three months ended March 31, 2011 of $39.8 million, or $0.81 per share. All per share amounts are on a diluted basis.

In the first quarter of 2012, we began reporting natural gas liquid (“NGL”) volumes and revenues separate from gas volumes. Historically, we reported “wet” gas volumes, which included entrained liquids. We will now report NGLs and “dry” gas (shrunk for removal of liquids) volumes. Prior period production volumes, revenues and prices have been reclassified to conform to the current presentation.

The variance in the three-month periods’ results was due to the following components:

Production. During the three months ended March 31, 2012, total production volumes increased to 22.4 Bcfe compared to 19.5 Bcfe produced during the comparable 2011 period. Oil production during the three months ended March 31, 2012 totaled approximately 1,862,000 barrels compared to 1,616,000 barrels produced during the three months ended March 31, 2011; natural gas production totaled 10.0 Bcf during the three months ended March 31, 2012 compared to 9.1 Bcf produced during the comparable period of 2011; and NGL production during the three months ended March 31, 2012 totaled approximately 200,000 barrels compared to 128,000 barrels produced during the comparable period of 2011. The increase in NGL production resulted from our liquids rich Pompano and Appalachia gas streams coming on line. Production commenced from our deep water Pyrenees well at Garden Banks 293 during the three months ended March 31, 2012. The three months ended March 31, 2012 also includes a full quarter of production from our Pompano field.

Prices. Prices realized during the three months ended March 31, 2012 averaged $108.36 per Bbl of oil, $2.89 per Mcf of natural gas and $67.26 per Bbl of NGLs or 7% higher, on an Mcfe basis, than average realized prices of $94.06 per Bbl of oil, $4.53 per Mcf of natural gas and $46.87 per Bbl of NGLs during the comparable 2011 period. All unit pricing amounts include the cash settlement of effective hedging contracts.

We enter into various hedging contracts in order to reduce our exposure to the possibility of declining oil and gas prices. Our effective hedging transactions increased our average realized natural gas price by $0.48 per Mcf and decreased our average realized oil price by $3.13 per Bbl during the three months ended March 31, 2012. During the three months ended March 31, 2011, our effective hedging transactions increased our average realized natural gas price by $0.50 per Mcf and decreased our average realized oil price by $5.23 per Bbl.

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Revenue. Oil, natural gas and NGL revenue was $244.1 million during the three months ended March 31, 2012, compared to $199.2 million during the comparable period of 2011. The increase is attributable to a 7% increase in average realized prices and a 14% increase in production quantities on a gas equivalent basis.

Expenses. Lease operating expenses during the three months ended March 31, 2012 and 2011 totaled $44.5 million and $38.3 million, respectively. On a unit of production basis, lease operating expenses were $1.99 per Mcfe and $1.96 per Mcfe for the three months ended March 31, 2012 and 2011, respectively. The increase in lease operating expenses in the first quarter of 2012 was primarily attributable to the impact of a full quarter of expenses at our newly acquired Pompano field.

Transportation, processing and gathering expenses during the three months ended March 31, 2012 and 2011 totaled $3.7 million and $1.8 million, respectively. The increase resulted from our liquids rich Pompano and Appalachia gas streams coming on line during the three months ended March 31, 2012.

The other operational expense charge of $0.7 million for the three months ended March 31, 2011 related to the settlement of litigation associated with an expensed operation.

Depreciation, depletion and amortization (“DD&A”) on oil and gas properties for the three months ended March 31, 2012 totaled $83.8 million, or $3.75 per Mcfe, compared to $66.4 million, or $3.40 per Mcfe, during the comparable period of 2011.

Salaries, general and administrative (“SG&A”) expenses (exclusive of incentive compensation) for the three months ended March 31, 2012 were $13.7 million compared to $11.7 million for the three months ended March 31, 2011. The increase is primarily the result of increased staffing and compensation adjustments and a one time management fee of $1.0 million for transition services related to our Pompano acquisition.

For the three months ended March 31, 2012 and 2011, incentive compensation expense totaled $1.4 million and $2.7 million, respectively. These amounts relate to the accrual of estimated incentive compensation bonuses calculated based on the projected achievement of certain strategic objectives for each fiscal year.

Interest expense for the three months ended March 31, 2012 totaled $5.7 million, net of $8.7 million of capitalized interest, compared to interest expense of $3.1 million, net of $9.7 million of capitalized interest, during the comparable 2011 period. The increase in interest expense is primarily the result of interest associated with the 2017 Convertible Notes issued on March 6, 2012.

Off Balance Sheet Arrangements

None.

Recent Accounting Developments

None.

Defined Terms

Oil, condensate and NGLs are stated in barrels (“Bbls”) or thousand barrels (“MBbls”). Natural gas is stated herein in billion cubic feet (“Bcf”), million cubic feet (“MMcf”) or thousand cubic feet (“Mcf”). Oil, condensate and NGLs are converted to natural gas at a ratio of one barrel of liquids per six Mcf of gas. Bcfe, MMcfe, and Mcfe represent one billion cubic feet, one million cubic feet and one thousand cubic feet of gas equivalent, respectively. MMBtu represents one million British Thermal Units and BBtu represents one billion British Thermal Units. An active property is an oil and gas property with existing production. A primary term lease is an oil and gas property with no existing production, in which we have a specific time frame to establish production without losing the rights to explore the property. Liquidity is defined as the ability to obtain cash quickly either through the conversion of assets or incurrence of liabilities.

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Item 3. Quantitative and Qualitative Disclosures About Market Risk

Commodity Price Risk

Our major market risk exposure continues to be the pricing applicable to our oil and natural gas production. Our revenues, profitability and future rate of growth depend substantially upon the market prices of oil and natural gas, which fluctuate widely. Oil and natural gas price declines and volatility could adversely affect our revenues, cash flows and profitability. Price volatility is expected to continue. In order to manage our exposure to oil and natural gas price declines, we occasionally enter into oil and natural gas price hedging arrangements to secure a price for a portion of our expected future production.

Our hedging policy provides that not more than 50% of our estimated production quantities can be hedged without the consent of the board of directors. We believe our current hedging positions have hedged approximately 42% of our estimated 2012 production from estimated proved reserves, 38% of our estimated 2013 production from estimated proved reserves and 13% of our estimated 2014 production from estimated proved reserves. See Item 1. Financial Statements – Note 3 – Derivative Instruments and Hedging Activities for a detailed discussion of hedges in place to manage our exposure to oil and natural gas price declines.

Since the filing of our Annual Report on Form 10-K for the year ended December 31, 2011, there have been no material changes in reported market risk as it relates to commodity prices.

Interest Rate Risk

We had total debt outstanding of $805.1 million at March 31, 2012, all of which bears interest at fixed rates. The $805.1 million of fixed-rate debt is comprised of $230.1 million ($300.0 million face value) of 1 ³/4% Senior Convertible Notes due 2017, $375 million of 8 ⁵/8% Senior Notes due 2017 and $200 million of 6 ³/4% Senior Subordinated Notes due 2014. We currently have no interest rate hedge positions in place to reduce our exposure to changes in interest rates.

Item 4. Controls and Procedures

Evaluation of Disclosure Controls and Procedures

We have established disclosure controls and procedures to ensure that material information relating to Stone Energy Corporation and its consolidated subsidiaries (collectively “Stone”) is made known to the officers who certify Stone’s financial reports and the Board of Directors. Disclosure controls and procedures, as defined in the rules and regulations of the Exchange Act, means controls and other procedures of an issuer that are designed to ensure that information required to be disclosed by the issuer in the reports that it files or submits under the Act (15 U.S.C. 78a et seq.) is recorded, processed, summarized and reported, within the time periods specified in the Securities and Exchange Commission’s (the “SEC”) rules and forms. Disclosure controls and procedures include, without limitation, controls and procedures designed to ensure that information required to be disclosed by an issuer in the reports that it files or submits under the Act is accumulated and communicated to the issuer’s management, including its principal executive and principal financial officers, or persons performing similar functions, as appropriate to allow timely decisions regarding required disclosure. There are inherent limitations to the effectiveness of any system of disclosure controls and procedures, including the possibility of human error and the circumvention or overriding of controls and procedures. Accordingly, even effective disclosure controls and procedures can only provide reasonable assurance of achieving their control objectives.

Our principal executive officer and our principal financial officer, with the participation of other members of our senior management, reviewed and evaluated the effectiveness of Stone’s disclosure controls and procedures as of the end of the quarterly period ended March 31, 2012. Based on this evaluation, our principal executive officer and principal financial officer believe that as of the end of the quarterly period ended March 31, 2012:

• Stone’s disclosure controls and procedures were effective to ensure that information required to be disclosed by Stone in the reports it files or submits under the Exchange Act is recorded, processed, summarized and reported within the time periods specified in the SEC’s rules and forms; and

• Stone’s disclosure controls and procedures were effective to ensure that information required to be disclosed by Stone in the reports that it files or submits under the Exchange Act was accumulated and communicated to Stone’s management, including Stone’s principal executive officer and principal financial officer, as appropriate to allow timely decisions regarding required disclosure.

26

Changes in Internal Controls Over Financial Reporting

There has not been any change in our internal control over financial reporting that occurred during the quarter ended March 31, 2012 that has materially affected, or is reasonably likely to materially affect, our internal control over financial reporting.

PART II – OTHER INFORMATION

Item 1. Legal Proceedings

Franchise Tax Action. On December 30, 2004, Stone was served with two petitions (civil action numbers 2004-6227 and 2004-6228) filed by the Louisiana Department of Revenue (“LDR”) in the 15th Judicial District Court (Parish of Lafayette, Louisiana) claiming additional franchise taxes due. In one case, the LDR is seeking additional franchise taxes from Stone in the amount of $640,000, plus accrued interest of $352,000 (calculated through December 15, 2004), for the franchise tax year 2001. In the other case, the LDR is seeking additional franchise taxes from Stone (as successor to Basin Exploration, Inc.) in the amount of $274,000, plus accrued interest of $159,000 (calculated through December 15, 2004), for the franchise tax years 1999, 2000 and 2001. On December 29, 2005, the LDR filed another petition in the 15^th Judicial District Court claiming additional franchise taxes due for the taxable years ended December 31, 2002 and 2003 in the amount of $2.6 million plus accrued interest calculated through December 15, 2005 in the amount of $1.2 million. Also, on January 2, 2008, Stone was served with a petition (civil action number 2007-6754) claiming $1.5 million of additional franchise taxes due for the 2004 franchise tax year, plus accrued interest of $800,000 calculated through November 30, 2007. Further, on January 7, 2009, Stone was served with a petition (civil action number 2008-7193) claiming additional franchise taxes due for the taxable years ended December 31, 2005 and 2006 in the amount of $4.0 million plus accrued interest calculated through October 21, 2008 in the amount of $1.7 million. In addition, we have received proposed assessments from the LDR for additional franchise taxes in the amount of $8.7 million resulting from audits of Stone and our subsidiaries. These assessments all relate to the LDR’s assertion that sales of crude oil and natural gas from properties located on the OCS, which are transported through the State of Louisiana, should be sourced to the State of Louisiana for purposes of computing the Louisiana franchise tax apportionment ratio. The Company disagrees with these contentions and intends to vigorously defend itself against these claims. The franchise tax years 2010 and 2011 for Stone remain subject to examination.

Litigation is subject to substantial uncertainties concerning the outcome of material factual and legal issues relating to the litigation. Accordingly, we cannot currently predict the manner and timing of the resolution of these matters and are unable to estimate a range of possible losses or any minimum loss from such matters.

Item 1A. Risk Factors

There have been no material changes with respect to Stone’s risk factors previously reported in Stone’s Annual Report on Form 10-K for the year ended December 31, 2011.

27

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

On September 24, 2007, our Board of Directors authorized a share repurchase program for an aggregate amount of up to $100 million. The shares may be repurchased from time to time in the open market or through privately negotiated transactions. The repurchase program is subject to business and market conditions, and may be suspended or discontinued at any time. Additionally, shares were withheld from certain employees to pay taxes associated with the employees’ vesting of restricted stock. The following table sets forth information regarding our repurchases or acquisitions of common stock during the three months ended March 31, 2012:

Period	Total Number of Shares (or Units) Purchased			Average Price Paid per Share (or Unit)		Total Number of Shares (or Units) Purchased as Part of Publicly Announced Plans or Programs		Maximum Number (or Approximate Dollar Value) of Shares (or Units) that May Yet be Purchased Under the Plans or Programs
Share Repurchase Program:
January 2012		—			—		—
February 2012		—			—		—
March 2012		—			—		—
		—			—		—	$	92,928,632
Other:
January 2012		114,982	(a)	$	26.38		—
February 2012		—			—		—
March 2012		—			—		—
		114,982		$	26.38		—		N/A
Total		114,982		$	26.38		—

(a) Amount includes shares withheld from employees upon the vesting of restricted stock in order to satisfy the required tax withholding obligations.

28

Item 6. Exhibits

1.1	Purchase Agreement, dated February 29, 2012, among Stone Energy Corporation, Stone Energy Offshore, L.L.C., Barclays Capital Inc., Merrill Lynch, Pierce, Fenner & Smith Incorporated and the other initial purchasers named in Schedule I to the Purchase Agreement (incorporated by reference to Exhibit 1.1 to the Registrant’s Current Report on Form 8-K filed March 6, 2012 (File No. 001-12074)).
3.1	Certificate of Incorporation of the Registrant, as amended (incorporated by reference to Exhibit 3.1 to the Registrant’s Registration Statement on Form S-1 (Registration No. 33-62362)).
3.2	Certificate of Amendment of the Certificate of Incorporation of Stone Energy Corporation, dated February 1, 2001 (incorporated by reference to Exhibit 4.1 to the Registrant’s Form 8-K, filed February 7, 2001).
3.3	Amended & Restated Bylaws of Stone Energy Corporation, dated May 15, 2008 (incorporated by reference to Exhibit 3.1 to the Registrant’s Current Report on Form 8-K dated May 15, 2008 (File No. 001-12074)).
4.1	Indenture between Stone Energy Corporation and JPMorgan Chase Bank, National Association, as trustee, dated December 15, 2004 (incorporated by reference to Exhibit 4.1 to the Registrant’s Current Report on Form 8-K filed on December 15, 2004.)
4.2	First Supplemental Indenture, dated August 28, 2008, to the Indenture between Stone Energy Corporation and JPMorgan Chase Bank, National Association, as trustee, dated December 15, 2004 (incorporated by reference to Exhibit 4.2 to the Registrant’s Current Report on Form 8-K filed August 29, 2008 (File No. 001-12074)).
4.3	Second Supplemental Indenture, dated January 26, 2010, among Stone Energy Corporation, Stone Energy Offshore, L.L.C., and The Bank of New York Mellon Trust Company, N.A., successor to JPMorgan Chase Bank, as trustee (incorporated by reference to Exhibit 4.1 to the Registrant’s Current Report on Form 8-K filed January 29, 2010 (File No. 001-12074)).
4.4	Indenture, dated January 26, 2010, among Stone Energy Corporation, Stone Energy Offshore, L.L.C., and The Bank of New York Mellon Trust Company, N.A., as trustee (incorporated by reference to Exhibit 4.2 to the Registrant’s Current Report on Form 8-K filed January 29, 2010 (File No. 001-12074)).
4.5	First Supplemental Indenture, dated January 26, 2010, among Stone Energy Corporation, Stone Energy Offshore, L.L.C., and The Bank of New York Mellon Trust Company, N.A., as trustee (incorporated by reference to Exhibit 4.3 to the Registrant’s Current Report on Form 8-K filed January 29, 2010 (File No. 001-12074)).
4.6	Indenture related to the 1 3/4% Senior Convertible Notes due 2017, dated as of March 6, 2012, among Stone Energy Corporation, Stone Energy Offshore, L.L.C. and The Bank of New York Mellon Trust Company, N.A., as trustee (including form of 1 3/4% Senior Convertible Senior Note due 2017) (incorporated by reference to Exhibit 4.1 to the Registrant’s Current Report on Form 8-K filed March 6, 2012 (File No. 001-12074)).
10.1	Amendment No. 1 and Consent dated as of February 28, 2012 to the Third Amended and Restated Credit Agreement (incorporated by reference to Exhibit 10.1 to the Registrant’s Current Report on Form 8-K filed on March 5, 2012 (File No. 001-12074)).
10.2	Base Bond Hedge Confirmation dated as of February 29, 2012, by and between Stone Energy Corporation and Barclays Capital Inc., acting as agent for Barclays Bank PLC (incorporated by reference to Exhibit 10.1 to the Registrant’s Current Report on Form 8-K filed March 6, 2012 (File No. 001-12074)).
10.3	Base Bond Hedge Confirmation dated as of February 29, 2012, by and between Stone Energy Corporation and Bank of America N.A. (incorporated by reference to Exhibit 10.2 to the Registrant’s Current Report on Form 8-K filed March 6, 2012 (File No. 001-12074)).
10.4	Additional Bond Hedge Confirmation dated as of March 2, 2012, by and between Stone Energy Corporation and Barclays Capital Inc., acting as agent for Barclays Bank PLC (incorporated by reference to Exhibit 10.3 to the Registrant’s Current Report on Form 8-K filed March 6, 2012 (File No. 001-12074)).
10.5	Additional Bond Hedge Confirmation dated as of March 2, 2012, by and between Stone Energy Corporation and Bank of America N.A. (incorporated by reference to Exhibit 10.4 to the Registrant’s Current Report on Form 8-K filed March 6, 2012 (File No. 001-12074)).
10.6	Base Warrant Confirmation dated as of February 29, 2012, by and between Stone Energy Corporation and Barclays Capital Inc., acting as agent for Barclays Bank PLC (incorporated by reference to Exhibit 10.5 to the Registrant’s Current Report on Form 8-K filed March 6, 2012 (File No. 001-12074)).
10.7	Base Warrant Confirmation dated as of February 29, 2012, by and between Stone Energy Corporation and Bank of America N.A. (incorporated by reference to Exhibit 10.6 to the Registrant’s Current Report on Form 8-K filed March 6, 2012 (File No. 001-12074)).

29

10.8	Additional Warrant Confirmation dated as of March 2, 2012, by and between Stone Energy Corporation and Barclays Capital Inc., acting as agent for Barclays Bank PLC (incorporated by reference to Exhibit 10.7 to the Registrant’s Current Report on Form 8-K filed March 6, 2012 (File No. 001-12074)).
10.9	Additional Warrant Confirmation dated as of March 2, 2012, by and between Stone Energy Corporation and Bank of America N.A. (incorporated by reference to Exhibit 10.8 to the Registrant’s Current Report on Form 8-K filed March 6, 2012 (File No. 001-12074)).
10.10	Amendment to Base Warrant Confirmation and Additional Warrant Confirmation dated March 5, 2012, by and between Stone Energy Corporation and Barclays Capital Inc., acting as agent for Barclays Bank PLC (incorporated by reference to Exhibit 10.9 to the Registrant’s Current Report on Form 8-K filed March 6, 2012 (File No. 001-12074)).
10.11	Amendment to Base Warrant Confirmation and Additional Warrant Confirmation dated March 5, 2012, by and between Stone Energy Corporation and Bank of America N.A. (incorporated by reference to Exhibit 10.10 to the Registrant’s Current Report on Form 8-K filed March 6, 2012 (File No. 001-12074)).
*31.1	Certification of Principal Executive Officer of Stone Energy Corporation as required by Rule 13a-14(a) of the Securities Exchange Act of 1934.
*31.2	Certification of Principal Financial Officer of Stone Energy Corporation as required by Rule 13a-14(a) of the Securities Exchange Act of 1934.
*#32.1	Certification of Chief Executive Officer and Chief Financial Officer of Stone Energy Corporation pursuant to 18 U.S.C. § 1350.
**101.INS	XBRL Instance Document
**101.SCH	XBRL Schema Document
**101.CAL	XBRL Calculation Linkbase Document
**101.DEF	XBRL Definition Linkbase Document
**101.LAB	XBRL Label Linkbase Document
**101.PRE	XBRL Presentation Linkbase Document

* Filed or furnished herewith.

** Furnished, not filed. Users of this data submitted electronically herewith are advised pursuant to Rule 406T of Regulation S-T that this interactive data file is deemed not filed or part of a registration statement or prospectus for purposes of Sections 11 or 12 of the Securities Act of 1933, is deemed not filed for purposes of Section 18 of the Securities Exchange Act of 1934, and otherwise is not subject to liability under these sections.

# Not considered to be “filed” for the purposes of Section 18 of the Securities Exchange Act of 1934 or otherwise subject to the liabilities of that section.

† Identifies management contracts and compensatory plans or arrangements.

30

SIGNATURE

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 hereunto duly authorized.

	STONE ENERGY CORPORATION
Date: May 8, 2012	By:	/s/     J. Kent Pierret
		J. Kent Pierret
		Senior Vice President,
		Chief Accounting Officer and Treasurer
		(On behalf of the Registrant and as
		Chief Accounting Officer)

31

EXHIBIT INDEX

Exhibit Number	Description
1.1	Purchase Agreement, dated February 29, 2012, among Stone Energy Corporation, Stone Energy Offshore, L.L.C., Barclays Capital Inc., Merrill Lynch, Pierce, Fenner & Smith Incorporated and the other initial purchasers named in Schedule I to the Purchase Agreement (incorporated by reference to Exhibit 1.1 to the Registrant’s Current Report on Form 8-K filed March 6, 2012 (File No. 001-12074)).
3.1	Certificate of Incorporation of the Registrant, as amended (incorporated by reference to Exhibit 3.1 to the Registrant’s Registration Statement on Form S-1 (Registration No. 33-62362)).
3.2	Certificate of Amendment of the Certificate of Incorporation of Stone Energy Corporation, dated February 1, 2001 (incorporated by reference to Exhibit 4.1 to the Registrant’s Form 8-K, filed February 7, 2001).
3.3	Amended & Restated Bylaws of Stone Energy Corporation, dated May 15, 2008 (incorporated by reference to Exhibit 3.1 to the Registrant’s Current Report on Form 8-K dated May 15, 2008 (File No. 001-12074)).
4.1	Indenture between Stone Energy Corporation and JPMorgan Chase Bank, National Association, as trustee, dated December 15, 2004 (incorporated by reference to Exhibit 4.1 to the Registrant’s Current Report on Form 8-K filed on December 15, 2004.)
4.2	First Supplemental Indenture, dated August 28, 2008, to the Indenture between Stone Energy Corporation and JPMorgan Chase Bank, National Association, as trustee, dated December 15, 2004 (incorporated by reference to Exhibit 4.2 to the Registrant’s Current Report on Form 8-K filed August 29, 2008 (File No. 001-12074)).
4.3	Second Supplemental Indenture, dated January 26, 2010, among Stone Energy Corporation, Stone Energy Offshore, L.L.C., and The Bank of New York Mellon Trust Company, N.A., successor to JPMorgan Chase Bank, as trustee (incorporated by reference to Exhibit 4.1 to the Registrant’s Current Report on Form 8-K filed January 29, 2010 (File No. 001-12074)).
4.4	Indenture, dated January 26, 2010, among Stone Energy Corporation, Stone Energy Offshore, L.L.C., and The Bank of New York Mellon Trust Company, N.A., as trustee (incorporated by reference to Exhibit 4.2 to the Registrant’s Current Report on Form 8-K filed January 29, 2010 (File No. 001-12074)).
4.5	First Supplemental Indenture, dated January 26, 2010, among Stone Energy Corporation, Stone Energy Offshore, L.L.C., and The Bank of New York Mellon Trust Company, N.A., as trustee (incorporated by reference to Exhibit 4.3 to the Registrant’s Current Report on Form 8-K filed January 29, 2010 (File No. 001-12074)).
4.6	Indenture related to the 1 3/4% Senior Convertible Notes due 2017, dated as of March 6, 2012, among Stone Energy Corporation, Stone Energy Offshore, L.L.C. and The Bank of New York Mellon Trust Company, N.A., as trustee (including form of 1 3/4% Senior Convertible Senior Note due 2017) (incorporated by reference to Exhibit 4.1 to the Registrant’s Current Report on Form 8-K filed March 6, 2012 (File No. 001-12074)).
10.1	Amendment No. 1 and Consent dated as of February 28, 2012 to the Third Amended and Restated Credit Agreement (incorporated by reference to Exhibit 10.1 to the Registrant’s Current Report on Form 8-K filed on March 5, 2012 (File No. 001-12074)).
10.2	Base Bond Hedge Confirmation dated as of February 29, 2012, by and between Stone Energy Corporation and Barclays Capital Inc., acting as agent for Barclays Bank PLC (incorporated by reference to Exhibit 10.1 to the Registrant’s Current Report on Form 8-K filed March 6, 2012 (File No. 001-12074)).
10.3	Base Bond Hedge Confirmation dated as of February 29, 2012, by and between Stone Energy Corporation and Bank of America N.A. (incorporated by reference to Exhibit 10.2 to the Registrant’s Current Report on Form 8-K filed March 6, 2012 (File No. 001-12074)).
10.4	Additional Bond Hedge Confirmation dated as of March 2, 2012, by and between Stone Energy Corporation and Barclays Capital Inc., acting as agent for Barclays Bank PLC (incorporated by reference to Exhibit 10.3 to the Registrant’s Current Report on Form 8-K filed March 6, 2012 (File No. 001-12074)).
10.5	Additional Bond Hedge Confirmation dated as of March 2, 2012, by and between Stone Energy Corporation and Bank of America N.A. (incorporated by reference to Exhibit 10.4 to the Registrant’s Current Report on Form 8-K filed March 6, 2012 (File No. 001-12074)).
10.6	Base Warrant Confirmation dated as of February 29, 2012, by and between Stone Energy Corporation and Barclays Capital Inc., acting as agent for Barclays Bank PLC (incorporated by reference to Exhibit 10.5 to the Registrant’s Current Report on Form 8-K filed March 6, 2012 (File No. 001-12074)).

32

Exhibit Number	Description
10.7	Base Warrant Confirmation dated as of February 29, 2012, by and between Stone Energy Corporation and Bank of America N.A. (incorporated by reference to Exhibit 10.6 to the Registrant’s Current Report on Form 8-K filed March 6, 2012 (File No. 001-12074)).
10.8	Additional Warrant Confirmation dated as of March 2, 2012, by and between Stone Energy Corporation and Barclays Capital Inc., acting as agent for Barclays Bank PLC (incorporated by reference to Exhibit 10.7 to the Registrant’s Current Report on Form 8-K filed March 6, 2012 (File No. 001-12074)).
10.9	Additional Warrant Confirmation dated as of March 2, 2012, by and between Stone Energy Corporation and Bank of America N.A. (incorporated by reference to Exhibit 10.8 to the Registrant’s Current Report on Form 8-K filed March 6, 2012 (File No. 001-12074)).
10.10	Amendment to Base Warrant Confirmation and Additional Warrant Confirmation dated March 5, 2012, by and between Stone Energy Corporation and Barclays Capital Inc., acting as agent for Barclays Bank PLC (incorporated by reference to Exhibit 10.9 to the Registrant’s Current Report on Form 8-K filed March 6, 2012 (File No. 001-12074)).
10.11	Amendment to Base Warrant Confirmation and Additional Warrant Confirmation dated March 5, 2012, by and between Stone Energy Corporation and Bank of America N.A. (incorporated by reference to Exhibit 10.10 to the Registrant’s Current Report on Form 8-K filed March 6, 2012 (File No. 001-12074)).
*31.1	Certification of Principal Executive Officer of Stone Energy Corporation as required by Rule 13a-14(a) of the Securities Exchange Act of 1934.
*31.2	Certification of Principal Financial Officer of Stone Energy Corporation as required by Rule 13a-14(a) of the Securities Exchange Act of 1934.
*#32.1	Certification of Chief Executive Officer and Chief Financial Officer of Stone Energy Corporation pursuant to 18 U.S.C. § 1350.
**101.INS	XBRL Instance Document
**101.SCH	XBRL Schema Document
**101.CAL	XBRL Calculation Linkbase Document
**101.DEF	XBRL Definition Linkbase Document
**101.LAB	XBRL Label Linkbase Document
**101.PRE	XBRL Presentation Linkbase Document

* Filed or furnished herewith.

** Furnished, not filed. Users of this data submitted electronically herewith are advised pursuant to Rule 406T of Regulation S-T that this interactive data file is deemed not filed or part of a registration statement or prospectus for purposes of Sections 11 or 12 of the Securities Act of 1933, is deemed not filed for purposes of Section 18 of the Securities Exchange Act of 1934, and otherwise is not subject to liability under these sections.

# Not considered to be “filed” for the purposes of Section 18 of the Securities Exchange Act of 1934 or otherwise subject to the liabilities of that section.

† Identifies management contracts and compensatory plans or arrangements.

33

EX-31.1

Exhibit 31.1

CERTIFICATION OF PRINCIPAL EXECUTIVE OFFICER

I, David H. Welch, certify that:

1. I have reviewed this Quarterly Report on Form 10-Q of Stone Energy Corporation;

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant’s other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c) Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d) Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5. The registrant’s other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

	/s/ David H. Welch
May 8, 2012	David H. Welch
	President and Chief Executive Officer

EX-31.2

Exhibit 31.2

CERTIFICATION OF PRINCIPAL FINANCIAL OFFICER

I, Kenneth H. Beer, certify that:

1. I have reviewed this Quarterly Report on Form 10-Q of Stone Energy Corporation;

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant’s other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c) Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d) Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5. The registrant’s other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

	/s/ Kenneth H. Beer
May 8, 2012	Kenneth H. Beer
	Executive Vice President and Chief Financial Officer

EX-32.1

Exhibit 32.1

CERTIFICATION OF CHIEF EXECUTIVE OFFICER AND

CHIEF FINANCIAL OFFICER

Pursuant to 18 U.S.C. § 1350 and in connection with the accompanying report on Form 10-Q of Stone Energy Corporation (the “Company”) for the quarterly period ended March 31, 2012 that is being filed concurrently with the Securities and Exchange Commission on the date hereof (the “Report”), each of the undersigned officers of the Company hereby certifies, to the best of his knowledge, that:

(i.) The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(ii.) The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

May 8, 2012

/s/ David H. Welch

David H. Welch

President and Chief Executive Officer

/s/ Kenneth H. Beer

Kenneth H. Beer

Executive Vice President and Chief Financial Officer

XML

Guarantor Financial Statements (Details 2) (USD $) In Thousands, unless otherwise specified	3 Months Ended
	Mar. 31, 2012	Mar. 31, 2011
Cash flows from operating activities:
Net income	$ 50,974	$ 39,792
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, depletion and amortization	84,575	67,669
Accretion expense	8,266	7,717
Deferred income tax provision	27,439	22,383
Settlement of asset retirement obligations	(2,980)	(19,034)
Non-cash stock compensation expense	1,750	1,680
Excess tax benefits	(847)	(649)
Non-cash derivative expense	1,342	1,804
Other non-cash expenses	1,173	(104)
Change in current income taxes	(2,647)	(3,681)
Increase in accounts receivable	(21,708)	(21,555)
Decrease in other current assets	35	25
Decrease in inventory		365
Increase (decrease) in accounts payable	(6,015)	2,690
Increase (decrease) in other current liabilities	(22,168)	(10,059)
Other	146	272
Net cash provided by operating activities	119,335	89,315
Cash flows from investing activities:
Investment in oil and gas properties	(106,469)	(156,535)
Proceeds from sale of oil and gas properties		7,692
Sale of fixed assets	134
Investment in fixed and other assets	(909)	(262)
Net cash used in investing activities	(107,244)	(149,105)
Cash flows from financing activities:
Proceeds from bank borrowings	25,000
Repayments of bank borrowings	(70,000)
Proceeds from issuance of senior convertible notes	300,000
Financing costs of senior convertible notes	(8,855)	(66)
Proceeds from Sold Warrants	40,170
Payments for Purchased Call Options	(70,830)
Excess tax benefits	847	649
Net payments for share based compensation	(3,033)	(1,843)
Net cash provided by (used in) financing activities	213,299	(1,260)
Net change in cash and cash equivalents	225,390	(61,050)
Cash and cash equivalents, beginning of period	38,451	106,956
Cash and cash equivalents, end of period	263,841	45,906
Parent [Member]
Cash flows from operating activities:
Net income	50,974	39,792
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, depletion and amortization	11,477	5,942
Accretion expense	148	4
Deferred income tax provision	(9,763)	(7,611)
Non-cash stock compensation expense	1,750	1,680
Excess tax benefits	(847)	(649)
Non-cash (income) loss from investment in subsidiary	(65,737)	(52,756)
Other non-cash expenses	1,173	(104)
Change in current income taxes	(2,647)	(3,681)
Change in intercompany receivable/payables	18,655	44,230
Increase in accounts receivable	983	6,833
Decrease in other current assets	(35)	25
Decrease in inventory		365
Increase (decrease) in accounts payable	(25)	2,609
Increase (decrease) in other current liabilities	(23,155)	(10,929)
Other	(146)	272
Net cash provided by operating activities	(18,799)	26,022
Cash flows from investing activities:
Investment in oil and gas properties	8,364	(89,444)
Proceeds from sale of oil and gas properties		5,575
Sale of fixed assets	134
Investment in fixed and other assets	909	(262)
Net cash used in investing activities	(9,139)	(84,131)
Cash flows from financing activities:
Proceeds from bank borrowings	25,000
Repayments of bank borrowings	(70,000)
Proceeds from issuance of senior convertible notes	300,000
Financing costs of senior convertible notes	(8,855)	(66)
Proceeds from Sold Warrants	40,170
Payments for Purchased Call Options	70,830
Excess tax benefits	847	649
Net payments for share based compensation	3,033	(1,843)
Net cash provided by (used in) financing activities	213,299	(1,260)
Net change in cash and cash equivalents	185,361	(59,369)
Cash and cash equivalents, beginning of period	37,389	105,115
Cash and cash equivalents, end of period	222,750	45,746
Guarantor Subsidiary [Member]
Cash flows from operating activities:
Net income	66,138	53,323
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, depletion and amortization	73,000	61,510
Accretion expense	8,032	7,622
Deferred income tax provision	37,202	29,994
Settlement of asset retirement obligations	(2,980)	(19,034)
Non-cash derivative expense	1,342	1,804
Non-cash (income) loss from investment in subsidiary		(438)
Change in intercompany receivable/payables	(18,445)	(43,804)
Increase in accounts receivable	20,823	(28,509)
Increase (decrease) in accounts payable	(6,157)	81
Increase (decrease) in other current liabilities	987	870
Net cash provided by operating activities	138,135	63,419
Cash flows from investing activities:
Investment in oil and gas properties	98,106	(67,087)
Proceeds from sale of oil and gas properties		2,117
Net cash used in investing activities	(98,106)	(64,970)
Cash flows from financing activities:
Net change in cash and cash equivalents	40,029	(1,551)
Cash and cash equivalents, beginning of period	926	1,659
Cash and cash equivalents, end of period	40,955	108
Non-Guarantor Subsidiaries [Member]
Cash flows from operating activities:
Net income	(240)	(129)
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, depletion and amortization	98	217
Accretion expense	86	91
Change in intercompany receivable/payables	(210)	(426)
Increase in accounts receivable	(98)	121
Increase (decrease) in accounts payable	167
Net cash provided by operating activities	(1)	(126)
Cash flows from investing activities:
Investment in oil and gas properties	(1)	(4)
Net cash used in investing activities	1	(4)
Cash flows from financing activities:
Net change in cash and cash equivalents		(130)
Cash and cash equivalents, beginning of period	136	182
Cash and cash equivalents, end of period	136	52
Eliminations [Member]
Cash flows from operating activities:
Net income	(65,898)	(53,194)
Adjustments to reconcile net income to net cash provided by operating activities:
Non-cash (income) loss from investment in subsidiary		$ 53,194

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Acquisitions (Details) (USD $) In Millions, except Per Share data, unless otherwise specified	3 Months Ended
	Mar. 31, 2011	Dec. 28, 2011
Allocation of the recorded value of net assets acquired in the transaction
Proved oil and gas properties		$ 208.7
Unevaluated oil and gas properties		17.3
Asset retirement obligations		(58.4)
Total fair value of net assets		167.6
Pro forma of financial information
Revenues	241.1
Income from operations	91.4
Net income	55.9
Basic earnings per share	$ 1.14
Diluted earnings per share	$ 1.14
Acquisitions and Divestitures (Textual) [Abstract]
Cash consideration transferred		$ 167.6
BP Exploration and Production Inc [Member]
Acquisitions and Divestitures (Textual) [Abstract]
Percentage of operated working capital acquired		75.00%
Adjacent Mississippi Canyon Block 29 [Member]
Acquisitions and Divestitures (Textual) [Abstract]
Percentage of operated working capital acquired		51.00%
Mica Field [Member]
Acquisitions and Divestitures (Textual) [Abstract]
Percentage of non-operated working capital acquired		50.00%
Pompano Field [Member]
Acquisitions and Divestitures (Textual) [Abstract]
Percentage of non-operated working capital acquired		75.00%

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Derivative Instruments and Hedging Activities (Details) (Commodity contracts [Member], USD $) In Millions, unless otherwise specified	Mar. 31, 2012	Dec. 31, 2011
Asset Derivatives
Fair Value of Derivative Instruments, Assets	$ 35.3	$ 47.7
Liability Derivatives
Fair Value of Derivative Instruments, Liabilities	(35.3)	(11.9)
Current assets [Member]
Asset Derivatives
Fair Value of Derivative Instruments, Assets	24.4	25.2
Current liabilities [Member]
Liability Derivatives
Fair Value of Derivative Instruments, Liabilities	(27.3)	(11.1)
Long-term assets [Member]
Asset Derivatives
Fair Value of Derivative Instruments, Assets	10.9	22.5
Long-term liabilities [Member]
Liability Derivatives
Fair Value of Derivative Instruments, Liabilities	$ (8.0)	$ (0.8)

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Guarantor Financial Statements (Details) (USD $) In Thousands, unless otherwise specified	Mar. 31, 2012	Dec. 31, 2011	Mar. 31, 2011	Dec. 31, 2010
Current assets:
Cash and cash equivalents	$ 263,841	$ 38,451	$ 45,906	$ 106,956
Accounts receivable	133,266	118,139
Fair value of hedging contracts	24,352	25,177
Current income tax receivable	23,140	19,946
Deferred taxes	30,206	26,072
Inventory	4,643	4,643
Other current assets	754	791
Total current assets	480,202	233,219
Oil and gas properties, full cost method
Proved	6,704,772	6,648,168
Less: accumulated depreciation, depletion and amortization	(5,252,894)	(5,174,729)
Net proved oil and gas properties	1,451,878	1,473,439
Unevaluated	443,889	401,609
Other property and equipment, net	11,444	11,172
Fair value of hedging contracts	10,937	22,543
Other assets, net	28,963	23,769
Total assets	2,427,313	2,165,751
Current liabilities:
Accounts payable to vendors	86,307	102,946
Undistributed oil and gas proceeds	26,359	27,328
Accrued interest	10,490	14,059
Fair value of hedging contracts	27,298	11,122
Asset retirement obligations	71,256	62,676
Other current liabilities	10,740	28,370
Total current liabilities	232,450	246,501
Long-term debt	805,140	620,000
Deferred taxes	266,996	247,835
Asset retirement obligations	359,274	363,103
Fair value of hedging contracts	8,025	815
Other long-term liabilities	20,523	19,668
Total liabilities	1,692,408	1,497,922		1,692,408
Commitments and contingencies
Stockholders' equity:
Common stock	483	481
Treasury stock (16,582 shares, at cost)	(860)	(860)
Additional paid-in capital	1,376,730	1,338,565
Accumulated earnings (deficit)	(641,251)	(692,225)
Accumulated other comprehensive income (loss)	(197)	21,868
Total stockholders' equity	734,905	667,829
Total liabilities and stockholders' equity	2,427,313	2,165,751
Parent [Member]
Current assets:
Cash and cash equivalents	222,750	37,389	45,746	105,115
Accounts receivable	37,849	36,463
Current income tax receivable	23,140	19,946
Deferred taxes	3,194	8,269
Inventory	4,360	4,360
Other current assets	754	791
Total current assets	292,047	107,218
Oil and gas properties, full cost method
Proved	672,697	696,975
Less: accumulated depreciation, depletion and amortization	(321,084)	(309,421)
Net proved oil and gas properties	351,613	387,554
Unevaluated	275,920	246,269
Other property and equipment, net	11,444	11,172
Other assets, net	27,494	20,873
Investment in subsidiary	777,606	733,533
Total assets	1,736,124	1,506,619
Current liabilities:
Accounts payable to vendors	92,986	78,170
Undistributed oil and gas proceeds	24,810	26,036
Accrued interest	10,490	14,059
Other current liabilities	4,613	22,974
Total current liabilities	132,899	141,239
Long-term debt	805,140	620,000
Deferred taxes	42,131	56,970
Asset retirement obligations	7,240	7,626
Other long-term liabilities	13,809	12,955
Total liabilities		838,790		1,001,219
Commitments and contingencies
Stockholders' equity:
Common stock	483	481
Treasury stock (16,582 shares, at cost)	(860)	(860)
Additional paid-in capital	1,376,730	1,338,565
Accumulated earnings (deficit)	(641,251)	(692,225)
Accumulated other comprehensive income (loss)	(197)	21,868
Total stockholders' equity	734,905	667,829
Total liabilities and stockholders' equity	1,736,124	1,506,619
Guarantor Subsidiary [Member]
Current assets:
Cash and cash equivalents	40,955	926	108	1,659
Accounts receivable	113,735	81,452
Fair value of hedging contracts	24,352	25,177
Deferred taxes	27,012	17,803
Inventory	283	283
Total current assets	206,337	125,641
Oil and gas properties, full cost method
Proved	6,027,024	5,946,141
Less: accumulated depreciation, depletion and amortization	(4,929,353)	(4,862,949)
Net proved oil and gas properties	1,097,671	1,083,192
Unevaluated	167,969	155,340
Fair value of hedging contracts	10,937	22,543
Other assets, net	1,469	2,896
Investment in subsidiary	(512)	(273)
Total assets	1,483,871	1,389,339
Current liabilities:
Accounts payable to vendors	12,898	25,866
Undistributed oil and gas proceeds	1,549	1,292
Fair value of hedging contracts	27,298	11,122
Asset retirement obligations	71,256	62,676
Other current liabilities	6,127	5,396
Total current liabilities	119,128	106,352
Deferred taxes	224,865	190,865
Asset retirement obligations	347,533	351,061
Fair value of hedging contracts	8,025	815
Other long-term liabilities	6,714	6,713
Total liabilities		655,806		706,265
Commitments and contingencies
Stockholders' equity:
Additional paid-in capital	1,724,232	1,724,232
Accumulated earnings (deficit)	(946,429)	(1,012,567)
Accumulated other comprehensive income (loss)	(197)	21,868
Total stockholders' equity	777,606	733,533
Total liabilities and stockholders' equity	1,483,871	1,389,339
Non-Guarantor Subsidiaries [Member]
Current assets:
Cash and cash equivalents	136	136	52	182
Accounts receivable	1,466	1,353
Total current assets	1,602	1,489
Oil and gas properties, full cost method
Proved	5,051	5,052
Less: accumulated depreciation, depletion and amortization	(2,457)	(2,359)
Net proved oil and gas properties	2,594	2,693
Total assets	4,196	4,182
Current liabilities:
Accounts payable to vendors	208	39
Total current liabilities	208	39
Asset retirement obligations	4,501	4,416
Total liabilities		4,455		4,709
Commitments and contingencies
Stockholders' equity:
Additional paid-in capital	1,639	1,639
Accumulated earnings (deficit)	(2,152)	(1,912)
Total stockholders' equity	(513)	(273)
Total liabilities and stockholders' equity	4,196	4,182
Eliminations [Member]
Current assets:
Accounts receivable	(19,784)	(1,129)
Total current assets	(19,784)	(1,129)
Oil and gas properties, full cost method
Investment in subsidiary	(777,094)	(733,260)
Total assets	(796,878)	(734,389)
Current liabilities:
Accounts payable to vendors	(19,785)	(1,129)
Total current liabilities	(19,785)	(1,129)
Total liabilities		(1,129)		(19,785)
Commitments and contingencies
Stockholders' equity:
Additional paid-in capital	(1,725,871)	(1,725,871)
Accumulated earnings (deficit)	948,581	1,014,479
Accumulated other comprehensive income (loss)	197	(21,868)
Total stockholders' equity	(777,093)	(733,260)
Total liabilities and stockholders' equity	$ (796,878)	$ (734,389)

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Derivative Instruments and Hedging Activities

3 Months Ended

Mar. 31, 2012

Derivative Instruments and Hedging Activities [Abstract]

Derivative Instruments and Hedging Activities

Note 3 – Derivative Instruments and Hedging Activities

Our hedging strategy is designed to protect our near and intermediate term cash flow from future declines in oil and natural gas prices. This protection is essential to capital budget planning, which is sensitive to expenditures that must be committed to in advance such as rig contracts and the purchase of tubular goods. We enter into hedging transactions to secure a commodity price for a portion of future production that is acceptable at the time of the transaction. These hedges are designated as cash flow hedges upon entering into the contract. We do not enter into hedging transactions for trading purposes. We have no fair value hedges.

The nature of a derivative instrument must be evaluated to determine if it qualifies for hedge accounting treatment. If the instrument qualifies for hedge accounting treatment, it is recorded as either an asset or liability measured at fair value and subsequent changes in the derivative’s fair value are recognized in equity through other comprehensive income (loss), net of related taxes, to the extent the hedge is considered effective. Additionally, monthly settlements of effective hedges are reflected in revenue from oil and gas production and cash flows from operations. Instruments not qualifying for hedge accounting are recorded in the balance sheet at fair value and changes in fair value are recognized in earnings through derivative expense (income). Typically, a small portion of our derivative contracts are determined to be ineffective. This is because oil and natural gas price changes in the markets in which we sell our products are not 100% correlative to changes in the underlying price basis indicative in the derivative contracts. Monthly settlements of ineffective hedges are recognized in earnings through derivative expense (income) and cash flows from operations.

We have entered into fixed-price swaps with various counterparties for a portion of our expected 2012, 2013 and 2014 oil and natural gas production from the Gulf Coast Basin. Some of our fixed-price oil swap settlements are based on an average of the New York Mercantile Exchange (“NYMEX”) closing price for West Texas Intermediate (“WTI”) during the entire calendar month and some are based on the average of the Intercontinental Exchange (“ICE”) closing price for Brent crude oil during the entire calendar month. Our fixed-price gas swap settlements are based on the NYMEX price for the last day of a respective month. Swaps typically provide for monthly payments by us if prices rise above the swap price or to us if prices fall below the swap price. Our fixed-price swap contracts for 2012, 2013 and 2014 are with The Toronto-Dominion Bank, Barclays Bank PLC, BNP Paribas, the Bank of Nova Scotia, Bank of America and Natixis.

All of our derivative instruments at March 31, 2012 and December 31, 2011 were designated as effective cash flow hedges; however, during the three-month periods ended March 31, 2012 and 2011, certain of our derivative contracts were determined to be partially ineffective. The following tables disclose the location and fair value amounts of derivative instruments reported in our balance sheet at March 31, 2012 and December 31, 2011.

Fair Value of Derivative Instruments at March 31, 2012
(in millions)
	Asset Derivatives			Liability Derivatives
Description	Balance Sheet Location	Fair Value		Balance Sheet Location	Fair Value
Commodity contracts	Current assets: Fair value of hedging contracts	$	24.4	Current liabilities: Fair value of hedging contracts	($	27.3	)
	Long-term assets: Fair value of hedging contracts		10.9	Long-term liabilities: Fair value of hedging contracts		(8.0	)
		$	35.3		($	35.3	)

Fair Value of Derivative Instruments at December 31, 2011
(in millions)
	Asset Derivatives			Liability Derivatives
Description	Balance Sheet Location	Fair Value		Balance Sheet Location	Fair Value
Commodity contracts	Current assets: Fair value of hedging contracts	$	25.2	Current liabilities: Fair value of hedging contracts	($	11.1	)
	Long-term assets: Fair value of hedging contracts		22.5	Long-term liabilities: Fair value of hedging contracts		(0.8	)
		$	47.7		($	11.9	)

The following table discloses the effect of derivative instruments in the statement of operations for the three-month periods ended March 31, 2012 and 2011.

The Effect of Derivative Instruments on the Statement of Operations for the Three Months Ended March 31, 2012 and 2011
(in millions)
Derivatives in Cash Flow Hedging Relationships	Amount of Gain (Loss) Recognized in OCI on Derivatives (a)						Gain (Loss) Reclassified from Accumulated OCI into Income (Effective Portion) (b)							Gain (Loss) Recognized in Income on Derivatives (Ineffective Portion)
	2012			2011			Location	2012			2011			Location	2012			2011
Commodity contracts	($	22.1	)	($	32.5	)	Operating revenue - oil/gas production	($	1.0	)	($	3.9	)	Derivative income (expense), net	($	0.5	)	($	2.2	)
Total	($	22.1	)	($	32.5	)		($	1.0	)	($	3.9	)		($	0.5	)	($	2.2	)

(a) Net of related tax effect of ($12.4) million and ($18.3) million for the three months ended March 31, 2012 and 2011, respectively.

(b) For the three months ended March 31, 2012, effective hedging contracts decreased oil revenue by $5.8 million and increased gas revenue by $4.8 million. For the three months ended March 31, 2011, effective hedging contracts decreased oil revenue by $8.4 million and increased gas revenue by $4.5 million.

At March 31, 2012, we had an accumulated other comprehensive loss of $0.2 million, net of tax, which related to the fair value of our swap contracts that were outstanding as of March 31, 2012. We believe that approximately $2.0 million of the accumulated other comprehensive loss will be reclassified into earnings in the next twelve months.

The following table illustrates our hedging positions for calendar years 2012, 2013 and 2014 as of May 7, 2012:

	Fixed-Price Swaps NYMEX (except where noted)
	Natural Gas				Oil
	Daily Volume (MMBtus/d)		Swap Price ($)		Daily Volume (Bbls/d)			Swap Price ($)
2012		10,000		5.035		1,000			90.30
2012		10,000		5.040		1,000			90.41
2012		10,000		5.050		1,000			90.45
2012						1,000			95.50
2012						2,000			97.60
2012						1,000			98.15
2012						1,000			100.00
2012						1,000			101.55
2012						1,000			104.25
2012						1,000	†		111.02
2013		10,000		5.270		1,000			94.45
2013		10,000		5.320		1,000			94.60
2013						1,000			97.15
2013						1,000			101.53
2013						1,000			103.00
2013						1,000			103.15
2013						1,000			104.25
2013						1,000			104.47
2013						1,000			104.50
2013						1,000	†		107.30
2014						1,000			98.00
2014						1,000			98.30
2014						1,000			99.65
2014						1,000	†		103.30

† Brent oil contract

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Long - Term Debt (Details) (USD $) In Thousands, unless otherwise specified	Mar. 31, 2012	Dec. 31, 2011
Computation of long term debt
Long-term debt	$ 805,140	$ 620,000
6.75 % Senior Subordinated Notes due 2014 [Member]
Computation of long term debt
Long-term debt	200,000	200,000
8.625 % Senior Notes due 2017 [Member]
Computation of long term debt
Long-term debt	375,000	375,000
1.75 % Senior Convertible Notes due 2017 [Member]
Computation of long term debt
Long-term debt	230,100
Bank debt [Member]
Computation of long term debt
Long-term debt		$ 45,000

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Derivative Instruments and Hedging Activities (Details Textual) (USD $)	3 Months Ended
	Mar. 31, 2012	Mar. 31, 2011	Dec. 31, 2011
Derivative Instruments and Hedging Activities (Textual) [Abstract]
Maximum correlation between price of oil & natural gas in market and underlying price basis indicative in the derivative contract	100.00%
Derivative Instruments net of related tax effect		$ (18,300,000)
Accumulated other comprehensive loss, net of tax	(197,000)		21,868,000
Accumulated other comprehensive loss, to be reclassified into earning in the next twelve months	2,000,000
Oil [Member]
Derivative Instruments, Gain (Loss) Recognized in Income, Net
Decrease/Increase in oil revenue owing to effective hedging contracts	5,800,000	8,400,000
Natural Gas [Member]
Derivative Instruments, Gain (Loss) Recognized in Income, Net
Increase in oil revenue owing to effective hedging contracts	$ 4,800,000	$ 4,500,000

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Long -Term Debt (Details 1) (USD $)	Mar. 31, 2012	Dec. 31, 2011
Entries to Record Proceeds From Convertible Notes and Sold Warrants Cost of Purchased Call Options
Long-term debt	$ 805,140,000	$ 620,000,000
Senior Convertible Notes Due 2017 [Member]
Entries to Record Proceeds From Convertible Notes and Sold Warrants Cost of Purchased Call Options
Cash	260,500,000
Other assets (deferred financing costs)	6,800,000
Long-term debt	230,100,000
Additional paid-in capital	$ (38,100,000)

XML

Long - Term Debt (Details Textual) (USD $)	3 Months Ended							3 Months Ended							3 Months Ended
	Mar. 31, 2012	Dec. 31, 2011	May 07, 2012 Bank Credit Facility [Member]	Mar. 31, 2012 8.625 % Senior Notes due 2017 [Member]	Dec. 31, 2011 8.625 % Senior Notes due 2017 [Member]	Mar. 31, 2012 6.75 % Senior Subordinated Notes due 2014 [Member]	Dec. 31, 2011 6.75 % Senior Subordinated Notes due 2014 [Member]	Mar. 31, 2012 Bank debt [Member]	May 07, 2012 Bank debt [Member]	Mar. 06, 2012 Bank debt [Member]	Dec. 31, 2011 Bank debt [Member]	Apr. 26, 2011 Bank debt [Member]	May 07, 2012 Letter of Credit [Member]	Mar. 31, 2012 Letter of Credit [Member]	Mar. 31, 2012 Senior Convertible Notes Due 2017 [Member]	Mar. 30, 2012 Senior Convertible Notes Due 2017 [Member]	Mar. 06, 2012 Senior Convertible Notes Due 2017 [Member]
Long Term Debt (Textual) [Abstract]
Credit facility initial date								Apr. 26, 2011
Redetermined base borrowing and Credit Facility			$ 400,000,000									$ 700,000,000
Credit facility maturing with Syndicated Bank Group								Sep. 15, 2014
Maturity of new credit facility if note issue under 2004 indenture are retired on or before April 15, 2014								Apr. 26, 2015							Mar. 01, 2017
Initial bank and availability under facility									372,900,000	310,000,000		400,000,000
Aggregate Principal amount of Senior Subordinated Notes																	300,000,000
Outstanding borrowing under bank credit facility								0	0				27,100,000	27,100,000
Oil and gas reserve as a proportion of discounted present value of the future net cash flow, for Mortgage								80.00%
Proceeds from issuance of senior notes	300,000,000														291,100,000
Interest rate due on convertible note due 2017																	1.75%
Initial conversion rate of convertible note 2017															Initial conversion rate of 23.4449 shares of our common stock per $1,000 principal amount of 2017 Convertible Notes
Initial conversion price of convertible note 2017															$ 42.65
Closing share price																$ 28.59
Convertible notes principal amount															1,000
Percentage of current conversion price lower than closing sale price															130.00%
Maximum trading day															20 days
Consecutive trading days ending on last trading day															30 days
Period in which distribution is made to all holders of common stock rights, option or warrants															45 days
Consecutive trading days immediately preceding, but excluding, declaration date															10 days
Percentage in which distribution has per share value exceeding closing sale price of common stock															10.00%
Percentage in which closing sale price of common stock is excess of convertible notes															98.00%
Number of consecutive business day															5 days
Number of consecutive trading day															P5D
Number consecutive trading-day conversion period															25 days
Payment for call option															70,800,000
Percentage of convertible notes principal amount															100.00%
Strike price per share															$ 55.91
Anti-dilution adjustments for purchases of call option															7,033,470
Proceeds from sale of sold warrants															40,100,000
Carrying amount of liability component															229,200,000
Carrying amount of equity component															70,800,000
Transaction costs allocated to liability and equity components															8,900,000
Accrued interest	10,490,000	14,059,000
Long-term debt	$ 805,140,000	$ 620,000,000		$ 375,000,000	$ 375,000,000	$ 200,000,000	$ 200,000,000				$ 45,000,000				$ 230,100,000

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Earnings Per Share

3 Months Ended

Mar. 31, 2012

Earnings Per Share [Abstract]

Earnings Per Share

Note 2 – Earnings Per Share

The following table sets forth the calculation of basic and diluted weighted average shares outstanding and earnings per share for the indicated periods.

	Three Months Ended March 31,
	2012			2011
	(in thousands, except per share data)
Income (numerator):
Basic:
Net income	$	50,974		$	39,792
Net income attributable to participating securities		(1,217	)		(874	)
Net income attributable to common stock – basic	$	49,757		$	38,918
Diluted:
Net income	$	50,974		$	39,792
Net income attributable to participating securities		(1,216	)		(873	)
Net income attributable to common stock – diluted	$	49,758		$	38,919
Weighted average shares (denominator):
Weighted average shares – basic		48,254			47,898
Diluted effect of stock options		45			41
Weighted average shares – diluted		48,299			47,939
Basic income per common share	$	1.03		$	0.81
Diluted income per common share	$	1.03		$	0.81

Stock options that were considered antidilutive because the exercise price of the option exceeded the average price of our common stock for the applicable period totaled approximately 372,000 and 398,000 shares for the three months ended March 31, 2012 and 2011, respectively. During the three months ended March 31, 2012 and 2011, respectively, approximately 232,000 and 180,000 shares of common stock were issued upon the vesting of restricted stock by employees and nonemployee directors.

Because it is management’s stated intention to redeem the principal amount of our 2017 Convertible Notes (see Note 4 – Long-Term Debt) in cash, we have used the treasury method for determining potential dilution in the diluted earnings per share computation. Since the average price of our common stock was less than the effective conversion price for such notes during the reporting period, the convertible notes were not dilutive for such period. Additionally, since the average price of our common stock was less than the strike price of the Sold Warrants for the reporting period, such warrants were also not dilutive for such period.

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Asset Retirement Obligations (Details) (USD $)	3 Months Ended
	Mar. 31, 2012	Mar. 31, 2011
Changes in Asset Retirement Obligations
Asset retirement obligations as of the beginning of the period, including current portion	$ 425,800,000
Liabilities settled	(3,000,000)
Divestment of Properties	(600,000)
Accretion expense	8,266,000	7,717,000
Asset retirement obligations as of the end of the year, including current portion	$ 430,500,000

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Condensed Consolidated Balance Sheet (USD $) In Thousands, unless otherwise specified	Mar. 31, 2012	Dec. 31, 2011	Mar. 31, 2011	Dec. 31, 2010
Current assets:
Cash and cash equivalents	$ 263,841	$ 38,451	$ 45,906	$ 106,956
Accounts receivable	133,266	118,139
Fair value of hedging contracts	24,352	25,177
Current income tax receivable	23,140	19,946
Deferred taxes	30,206	26,072
Inventory	4,643	4,643
Other current assets	754	791
Total current assets	480,202	233,219
Oil and gas properties, full cost method of accounting:
Proved	6,704,772	6,648,168
Less: accumulated depreciation, depletion and amortization	(5,252,894)	(5,174,729)
Net proved oil and gas properties	1,451,878	1,473,439
Unevaluated	443,889	401,609
Other property and equipment, net	11,444	11,172
Fair value of hedging contracts	10,937	22,543
Other assets, net	28,963	23,769
Total assets	2,427,313	2,165,751
Current liabilities:
Accounts payable to vendors	86,307	102,946
Undistributed oil and gas proceeds	26,359	27,328
Accrued interest	10,490	14,059
Fair value of hedging contracts	27,298	11,122
Asset retirement obligations	71,256	62,676
Other current liabilities	10,740	28,370
Total current liabilities	232,450	246,501
Long-term debt	805,140	620,000
Deferred taxes	266,996	247,835
Asset retirement obligations	359,274	363,103
Fair value of hedging contracts	8,025	815
Other long-term liabilities	20,523	19,668
Total liabilities	1,692,408	1,497,922		1,692,408
Commitments and contingencies
Stockholders' equity:
Common stock, $.01 par value; authorized 100,000,000 shares; issued 48,308,879 and 48,076,860 shares, respectively	483	481
Treasury stock (16,582 shares, at cost)	(860)	(860)
Additional paid-in capital	1,376,730	1,338,565
Accumulated deficit	(641,251)	(692,225)
Accumulated other comprehensive income (loss)	(197)	21,868
Total stockholders' equity	734,905	667,829
Total liabilities and stockholders' equity	$ 2,427,313	$ 2,165,751

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Condensed Consolidated Statement of Cash Flows (Unaudited) (USD $) In Thousands, unless otherwise specified	3 Months Ended
	Mar. 31, 2012	Mar. 31, 2011
Debt Instrument [Line Items]
Financing costs of senior convertible notes	$ (8,855)	$ (66)
Cash flows from operating activities:
Net income	50,974	39,792
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, depletion and amortization	84,575	67,669
Accretion expense	8,266	7,717
Deferred income tax provision	27,439	22,383
Settlement of asset retirement obligations	(2,980)	(19,034)
Non-cash stock compensation expense	1,750	1,680
Excess tax benefits	(847)	(649)
Non-cash derivative expense	1,342	1,804
Other non-cash expenses (income)	1,173	(104)
Change in current income taxes	(2,647)	(3,681)
Increase in accounts receivable	(21,708)	(21,555)
Decrease in other current assets	35	25
Decrease in inventory		365
Increase (decrease) in accounts payable	(6,015)	2,690
Decrease in other current liabilities	(22,168)	(10,059)
Other	146	272
Net cash provided by operating activities	119,335	89,315
Cash flows from investing activities:
Investment in oil and gas properties	(106,469)	(156,535)
Proceeds from sale of oil and gas properties		7,692
Sale of fixed assets	134
Investment in fixed and other assets	(909)	(262)
Net cash used in investing activities	(107,244)	(149,105)
Cash flows from financing activities:
Proceeds from bank borrowings	25,000
Repayments of bank borrowings	(70,000)
Proceeds from issuance of senior convertible notes	300,000
Proceeds from Sold Warrants	40,170
Payments for Purchased Call Options	(70,830)
Financing costs of senior convertible notes	(8,855)	(66)
Excess tax benefits	847	649
Net payments for share based compensation	(3,033)	(1,843)
Net cash provided by (used in) financing activities	213,299	(1,260)
Net change in cash and cash equivalents	225,390	(61,050)
Cash and cash equivalents, beginning of period	38,451	106,956
Cash and cash equivalents, end of period	263,841	45,906
Senior Convertible Notes
Debt Instrument [Line Items]
Financing costs of senior convertible notes	(8,855)
Cash flows from financing activities:
Financing costs of senior convertible notes	$ (8,855)

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Fair Value Measurements (Details Textual) (USD $)	Mar. 31, 2012	Dec. 31, 2011
Debt instrument value
Long term debt, Book value	$ 805,140,000	$ 620,000,000
Convertible Notes Due 2017 [Member]
Debt instrument value
Fair value of 2017 convertible notes	292,700,000
Liability attributable to Fair value of 2017 convertible	231,200,000
8.625 % Senior Notes Due 2017 [Member]
Debt instrument value
Fair value of 2017 convertible notes		375,000,000
Long term debt, Book value	375,000,000
Long term debt, Fair Value	392,800,000	386,300,000
6.75 % Senior Notes Due 2014 [Member]
Debt instrument value
Long term debt, Book value	200,000,000	200,000,000
Long term debt, Fair Value	$ 202,500,000	$ 199,000,000

XML

Guarantor Financial Statements (Tables)

3 Months Ended

Mar. 31, 2012

Guarantor Financial Statements [Abstract]

Condensed Consolidating Balance Sheet

	Parent			Guarantor Subsidiary			Non-Guarantor Subsidiaries			Eliminations			Consolidated
Assets
Current assets:
Cash and cash equivalents	$	222,750		$	40,955		$	136		$	—		$	263,841
Accounts receivable		37,849			113,735			1,466			(19,784	)		133,266
Fair value of hedging contracts		—			24,352			—			—			24,352
Current income tax receivable		23,140			—			—			—			23,140
Deferred taxes *		3,194			27,012			—			—			30,206
Inventory		4,360			283			—			—			4,643
Other current assets		754			—			—			—			754
Total current assets		292,047			206,337			1,602			(19,784	)		480,202
Oil and gas properties, full cost method:
Proved		672,697			6,027,024			5,051			—			6,704,772
Less: accumulated DD&A		(321,084	)		(4,929,353	)		(2,457	)		—			(5,252,894	)
Net proved oil and gas properties		351,613			1,097,671			2,594			—			1,451,878
Unevaluated		275,920			167,969			—			—			443,889
Other property and equipment, net		11,444			—			—			—			11,444
Fair value of hedging contracts		—			10,937			—			—			10,937
Other assets, net		27,494			1,469			—			—			28,963
Investment in subsidiary		777,606			(512	)		—			(777,094	)		—
Total assets	$	1,736,124		$	1,483,871		$	4,196		($	796,878	)	$	2,427,313
Liabilities and Stockholders’ Equity
Current liabilities:
Accounts payable to vendors	$	92,986		$	12,898		$	208		($	19,785	)	$	86,307
Undistributed oil and gas proceeds		24,810			1,549			—			—			26,359
Accrued interest		10,490			—			—			—			10,490
Fair value of hedging contracts		—			27,298			—			—			27,298
Asset retirement obligations		—			71,256			—			—			71,256
Other current liabilities		4,613			6,127			—			—			10,740
Total current liabilities		132,899			119,128			208			(19,785	)		232,450
Long-term debt		805,140			—			—			—			805,140
Deferred taxes *		42,131			224,865			—			—			266,996
Asset retirement obligations		7,240			347,533			4,501			—			359,274
Fair value of hedging contracts		—			8,025			—			—			8,025
Other long-term liabilities		13,809			6,714			—			—			20,523
Total liabilities		1,001,219			706,265			4,709			(19,785	)		1,692,408
Commitments and contingencies
Stockholders’ equity:
Common stock		483			—			—			—			483
Treasury stock		(860	)		—			—			—			(860	)
Additional paid-in capital		1,376,730			1,724,232			1,639			(1,725,871	)		1,376,730
Accumulated earnings (deficit)		(641,251	)		(946,429	)		(2,152	)		948,581			(641,251	)
Accumulated other comprehensive income (loss)		(197	)		(197	)		—			197			(197	)
Total stockholders’ equity		734,905			777,606			(513	)		(777,093	)		734,905
Total liabilities and stockholders’ equity	$	1,736,124		$	1,483,871		$	4,196		($	796,878	)	$	2,427,313

* Deferred income taxes have been allocated to guarantor subsidiary where related oil and gas properties reside.

	Parent			Guarantor Subsidiary			Non-Guarantor Subsidiaries			Eliminations			Consolidated
Assets
Current assets:
Cash and cash equivalents	$	37,389		$	926		$	136		$	—		$	38,451
Accounts receivable		36,463			81,452			1,353			(1,129	)		118,139
Fair value of hedging contracts		—			25,177			—			—			25,177
Current income tax receivable		19,946			—			—			—			19,946
Deferred taxes *		8,269			17,803			—			—			26,072
Inventory		4,360			283			—			—			4,643
Other current assets		791			—			—			—			791
Total current assets		107,218			125,641			1,489			(1,129	)		233,219
Oil and gas properties, full cost method:
Proved		696,975			5,946,141			5,052			—			6,648,168
Less: accumulated DD&A		(309,421	)		(4,862,949	)		(2,359	)		—			(5,174,729	)
Net proved oil and gas properties		387,554			1,083,192			2,693			—			1,473,439
Unevaluated		246,269			155,340			—			—			401,609
Other property and equipment, net		11,172			—			—			—			11,172
Fair value of hedging contracts		—			22,543			—			—			22,543
Other assets, net		20,873			2,896			—			—			23,769
Investment in subsidiary		733,533			(273	)		—			(733,260	)		—
Total assets	$	1,506,619		$	1,389,339		$	4,182		($	734,389	)	$	2,165,751
Liabilities and Stockholders’ Equity
Current liabilities:
Accounts payable to vendors	$	78,170		$	25,866		$	39		($	1,129	)	$	102,946
Undistributed oil and gas proceeds		26,036			1,292			—			—			27,328
Accrued interest		14,059			—			—			—			14,059
Fair value of hedging contracts		—			11,122			—			—			11,122
Asset retirement obligations		—			62,676			—			—			62,676
Other current liabilities		22,974			5,396			—			—			28,370
Total current liabilities		141,239			106,352			39			(1,129	)		246,501
Long-term debt		620,000			—			—			—			620,000
Deferred taxes *		56,970			190,865			—			—			247,835
Asset retirement obligations		7,626			351,061			4,416			—			363,103
Fair value of hedging contracts		—			815			—			—			815
Other long-term liabilities		12,955			6,713			—			—			19,668
Total liabilities		838,790			655,806			4,455			(1,129	)		1,497,922
Commitments and contingencies
Stockholders’ equity:
Common stock		481			—			—			—			481
Treasury stock		(860	)		—			—			—			(860	)
Additional paid-in capital		1,338,565			1,724,232			1,639			(1,725,871	)		1,338,565
Accumulated earnings (deficit)		(692,225	)		(1,012,567	)		(1,912	)		1,014,479			(692,225	)
Accumulated other comprehensive income (loss)		21,868			21,868			—			(21,868	)		21,868
Total stockholders’ equity		667,829			733,533			(273	)		(733,260	)		667,829
Total liabilities and stockholders’ equity	$	1,506,619		$	1,389,339		$	4,182		($	734,389	)	$	2,165,751

* Deferred income taxes have been allocated to guarantor subsidiary where related oil and gas properties reside.

Consolidating Statement of Operations

	Parent			Guarantor Subsidiary			Non- Guarantor Subsidiaries			Eliminations			Consolidated
Operating revenue:
Oil production	$	6,234		$	195,524		$	—		$	—		$	201,758
Gas production		5,631			23,226			—			—			28,857
Natural gas liquids production		3,864			9,588			—			—			13,452
Other operational income		694			63			133			—			890
Total operating revenue		16,423			228,401			133			—			244,957
Operating expenses:
Lease operating expenses		4,904			39,387			189			—			44,480
Transportation, processing and gathering expenses		2,488			1,169			—			—			3,657
Other operational expenses		42			—			—			—			42
Production taxes		1,163			2,215			—			—			3,378
Depreciation, depletion, amortization		11,477			73,000			98			—			84,575
Accretion expense		148			8,032			86			—			8,266
Salaries, general and administrative		12,654			1,051			—			—			13,705
Incentive compensation expense		1,442			—			—			—			1,442
Derivative expense, net		—			485			—			—			485
Total operating expenses		34,318			125,339			373			—			160,030
Income (loss) from operations		(17,895	)		103,062			(240	)		—			84,927
Other (income) expenses:
Interest expense		5,846			(115	)		—			—			5,731
Interest income		(30	)		(1	)		—			—			(31	)
Other income		(19	)		(401	)		—			—			(420	)
(Income) loss from investment in subsidiaries		(66,137	)		239			—			65,898			—
Total other (income) expenses		(60,340	)		(278	)		—			65,898			5,280
Income (loss) before taxes		42,445			103,340			(240	)		(65,898	)		79,647
Provision (benefit) for income taxes:
Current		1,234			—			—			—			1,234
Deferred		(9,763	)		37,202			—			—			27,439
Total income taxes		(8,529	)		37,202			—			—			28,673
Net income (loss)	$	50,974		$	66,138		($	240	)	($	65,898	)	$	50,974
Comprehensive income (loss)	$	28,909		$	66,138		($	240	)	($	65,898	)	$	28,909

	Parent			Guarantor Subsidiary			Non- Guarantor Subsidiaries			Eliminations			Consolidated
Operating revenue:
Oil production	$	786		$	151,209		$	—		$	—		$	151,995
Gas production		1,280			39,880			—			—			41,160
Natural gas liquids production		—			5,999			—			—			5,999
Other operational income		722			(19	)		182			—			885
Total operating revenue		2,788			197,069			182			—			200,039
Operating expenses:
Lease operating expenses		356			37,931			—			—			38,287
Transportation, processing and gathering expenses		—			1,820			—			—			1,820
Other operational expenses		—			662			—			—			662
Production taxes		147			2,388			—			—			2,535
Depreciation, depletion, amortization		5,942			61,510			217			—			67,669
Accretion expense		4			7,622			91			—			7,717
Salaries, general and administrative		11,731			2			—			—			11,733
Incentive compensation expense		2,684			—			—			—			2,684
Derivative expense, net		—			2,180			—			—			2,180
Total operating expenses		20,864			114,115			308			—			135,287
Income (loss) from operations		(18,076	)		82,954			(126	)		—			64,752
Other (income) expenses:
Interest expense		3,031			80			—			—			3,111
Interest income		(88	)		(6	)		—			—			(94	)
Other income		—			(567	)		3			—			(564	)
Other expense		123			1			—			—			124
(Income) loss from investment in subsidiary		(53,323	)		129			—			53,194			—
Total other (income) expenses		(50,257	)		(363	)		3			53,194			2,577
Income (loss) before taxes		32,181			83,317			(129	)		(53,194	)		62,175
Provision (benefit) for income taxes:
Current		—			—			—			—			—
Deferred		(7,611	)		29,994			—			—			22,383
Total income taxes		(7,611	)		29,994			—			—			22,383
Net income (loss)	$	39,792		$	53,323		($	129	)	($	53,194	)	$	39,792
Comprehensive income (loss)	$	7,318		$	53,323		($	129	)	($	53,194	)	$	7,318

Consolidating Statement of Cash Flows

	Parent			Guarantor Subsidiary			Non-Guarantor Subsidiaries			Eliminations			Consolidated
Cash flows from operating activities:
Net income (loss)	$	50,974		$	66,138		($	240	)	($	65,898	)	$	50,974
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Depreciation, depletion and amortization		11,477			73,000			98			—			84,575
Accretion expense		148			8,032			86			—			8,266
Deferred income tax provision (benefit)		(9,763	)		37,202			—			—			27,439
Settlement of asset retirement obligations		—			(2,980	)		—			—			(2,980	)
Non-cash stock compensation expense		1,750			—			—			—			1,750
Excess tax benefits		(847	)		—			—			—			(847	)
Non-cash derivative expense		—			1,342			—			—			1,342
Non-cash (income) loss from investment in subsidiaries		(65,737	)		(161	)		—			65,898			—
Other non-cash expenses		1,173			—			—			—			1,173
Change in current income taxes		(2,647	)		—			—			—			(2,647	)
Change in intercompany receivables/payables		18,655			(18,445	)		(210	)		—			—
(Increase) decrease in accounts receivable		(983	)		(20,823	)		98			—			(21,708	)
Decrease in other current assets		35			—			—			—			35
Increase (decrease) in accounts payable		(25	)		(6,157	)		167			—			(6,015	)
Increase (decrease) in other current liabilities		(23,155	)		987			—			—			(22,168	)
Other		146			—			—			—			146
Net cash provided by (used in) operating activities		(18,799	)		138,135			(1	)		—			119,335
Cash flows from investing activities:
Investment in oil and gas properties		(8,364	)		(98,106	)		1			—			(106,469	)
Sale of fixed assets		134			—			—			—			134
Investment in fixed and other assets		(909	)		—			—			—			(909	)
Net cash provided by (used in) investing activities		(9,139	)		(98,106	)		1			—			(107,244	)
Cash flows from financing activities:
Proceeds from bank borrowings		25,000			—			—			—			25,000
Repayments of bank borrowings		(70,000	)		—			—			—			(70,000	)
Proceeds from issuance of senior convertible notes		300,000			—			—			—			300,000
Financing costs of senior convertible notes		(8,855	)		—			—			—			(8,855	)
Proceeds from Sold Warrants		40,170			—			—			—			40,170
Payments for Purchased Call Options		(70,830	)		—			—			—			(70,830	)
Excess tax benefits		847			—			—			—			847
Net payments for share based compensation		(3,033	)		—			—			—			(3,033	)
Net cash provided by financing activities		213,299			—			—			—			213,299
Net change in cash and cash equivalents		185,361			40,029			—			—			225,390
Cash and cash equivalents, beginning of period		37,389			926			136			—			38,451
Cash and cash equivalents, end of period	$	222,750		$	40,955		$	136		$	—		$	263,841

	Parent			Guarantor Subsidiary			Non-Guarantor Subsidiaries			Eliminations			Consolidated
Cash flows from operating activities:
Net income (loss)	$	39,792		$	53,323		($	129	)	($	53,194	)	$	39,792
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Depreciation, depletion and amortization		5,942			61,510			217			—			67,669
Accretion expense		4			7,622			91			—			7,717
Deferred income tax provision (benefit)		(7,611	)		29,994			—			—			22,383
Settlement of asset retirement obligations		—			(19,034	)		—			—			(19,034	)
Non-cash stock compensation expense		1,680			—			—			—			1,680
Excess tax benefits		(649	)		—			—			—			(649	)
Non-cash derivative expense		—			1,804			—			—			1,804
Non-cash (income) loss from investment in subsidiary		(52,756	)		(438	)		—			53,194			—
Other non-cash income		(104	)		—			—			—			(104	)
Change in current income taxes		(3,681	)		—			—			—			(3,681	)
Change in intercompany receivables/payables		44,230			(43,804	)		(426	)		—			—
(Increase) decrease in accounts receivable		6,833			(28,509	)		121			—			(21,555	)
Decrease in other current assets		25			—			—			—			25
Decrease in inventory		365			—			—			—			365
Increase in accounts payable		2,609			81			—			—			2,690
Increase (decrease) in other current liabilities		(10,929	)		870			—			—			(10,059	)
Other		272			—			—			—			272
Net cash provided by (used in) operating activities		26,022			63,419			(126	)		—			89,315
Cash flows from investing activities:
Investment in oil and gas properties		(89,444	)		(67,087	)		(4	)		—			(156,535	)
Proceeds from sale of oil and gas properties		5,575			2,117			—			—			7,692
Investment in fixed and other assets		(262	)		—			—			—			(262	)
Net cash used in investing activities		(84,131	)		(64,970	)		(4	)		—			(149,105	)
Cash flows from financing activities:
Deferred financing costs		(66	)		—			—			—			(66	)
Excess tax benefits		649			—			—			—			649
Net payments for share based compensation		(1,843	)		—			—			—			(1,843	)
Net cash used in financing activities		(1,260	)		—			—			—			(1,260	)
Net change in cash and cash equivalents		(59,369	)		(1,551	)		(130	)		—			(61,050	)
Cash and cash equivalents, beginning of period		105,115			1,659			182			—			106,956
Cash and cash equivalents, end of period	$	45,746		$	108		$	52		$	—		$	45,906

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Commitments and Contingencies (Details Textual) (USD $) In Millions, unless otherwise specified	3 Months Ended
	Mar. 31, 2012
Commitments and Contingencies (Textual)
Approximate asserted claims plus accrued interest assessed by Louisiana Department of Revenue	$ 30.1
Additional estimated assessments including interest by Louisiana Department of Revenue	3.3
Minimum potential range contingency loss	0
Maximum potential range contingency loss	$ 34.0

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Earnings Per Share (Details Textual)	3 Months Ended
	Mar. 31, 2012	Mar. 31, 2011
Earnings Per Share (Textual) [Abstract]
Outstanding Stock options antidilutive	372,000	398,000
Common Stock, shares issued	232,000	180,000

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Interim Financial Statements

3 Months Ended

Mar. 31, 2012

Interim Financial Statements [Abstract]

Interim Financial Statements

Note 1 – Interim Financial Statements

The condensed consolidated financial statements of Stone Energy Corporation (“Stone”) and its subsidiaries as of March 31, 2012 and for the three-month periods ended March 31, 2012 and 2011 are unaudited and reflect all adjustments (consisting only of normal recurring adjustments), which are, in the opinion of management, necessary for a fair presentation of the financial position and operating results for the interim periods. The condensed consolidated balance sheet at December 31, 2011 has been derived from the audited financial statements at that date. The condensed consolidated financial statements should be read in conjunction with the consolidated financial statements and notes thereto, together with management’s discussion and analysis of financial condition and results of operations, contained in our Annual Report on Form 10-K for the year ended December 31, 2011. The results of operations for the three-month period ended March 31, 2012 are not necessarily indicative of future financial results. Certain prior period amounts have been reclassified to conform to current period presentation.

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Condensed Consolidated Balance Sheet (Parenthetical) (USD $)	Mar. 31, 2012	Dec. 31, 2011
Condensed Consolidated Balance Sheet [Abstract]
Common Stock, par value	$ 0.01	$ 0.01
Common stock, shares authorized	100,000,000	100,000,000
Common stock, shares issued	48,308,879	48,076,860
Treasury stock, shares	16,582	16,582

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Derivative Instruments and Hedging Activities (Tables)

3 Months Ended

Mar. 31, 2012

Derivative Instruments and Hedging Activities [Abstract]

Location and fair value amounts of derivative instruments reported in balance sheet

Fair Value of Derivative Instruments at March 31, 2012
(in millions)
	Asset Derivatives			Liability Derivatives
Description	Balance Sheet Location	Fair Value		Balance Sheet Location	Fair Value
Commodity contracts	Current assets: Fair value of hedging contracts	$	24.4	Current liabilities: Fair value of hedging contracts	($	27.3	)
	Long-term assets: Fair value of hedging contracts		10.9	Long-term liabilities: Fair value of hedging contracts		(8.0	)
		$	35.3		($	35.3	)

Fair Value of Derivative Instruments at December 31, 2011
(in millions)
	Asset Derivatives			Liability Derivatives
Description	Balance Sheet Location	Fair Value		Balance Sheet Location	Fair Value
Commodity contracts	Current assets: Fair value of hedging contracts	$	25.2	Current liabilities: Fair value of hedging contracts	($	11.1	)
	Long-term assets: Fair value of hedging contracts		22.5	Long-term liabilities: Fair value of hedging contracts		(0.8	)
		$	47.7		($	11.9	)

Effect of Derivative Instruments in the statement of operations

The Effect of Derivative Instruments on the Statement of Operations for the Three Months Ended March 31, 2012 and 2011
(in millions)
Derivatives in Cash Flow Hedging Relationships	Amount of Gain (Loss) Recognized in OCI on Derivatives (a)						Gain (Loss) Reclassified from Accumulated OCI into Income (Effective Portion) (b)							Gain (Loss) Recognized in Income on Derivatives (Ineffective Portion)
	2012			2011			Location	2012			2011			Location	2012			2011
Commodity contracts	($	22.1	)	($	32.5	)	Operating revenue - oil/gas production	($	1.0	)	($	3.9	)	Derivative income (expense), net	($	0.5	)	($	2.2	)
Total	($	22.1	)	($	32.5	)		($	1.0	)	($	3.9	)		($	0.5	)	($	2.2	)

(a) Net of related tax effect of ($12.4) million and ($18.3) million for the three months ended March 31, 2012 and 2011, respectively.

(b) For the three months ended March 31, 2012, effective hedging contracts decreased oil revenue by $5.8 million and increased gas revenue by $4.8 million. For the three months ended March 31, 2011, effective hedging contracts decreased oil revenue by $8.4 million and increased gas revenue by $4.5 million.

Hedging Positions

	Fixed-Price Swaps NYMEX (except where noted)
	Natural Gas				Oil
	Daily Volume (MMBtus/d)		Swap Price ($)		Daily Volume (Bbls/d)			Swap Price ($)
2012		10,000		5.035		1,000			90.30
2012		10,000		5.040		1,000			90.41
2012		10,000		5.050		1,000			90.45
2012						1,000			95.50
2012						2,000			97.60
2012						1,000			98.15
2012						1,000			100.00
2012						1,000			101.55
2012						1,000			104.25
2012						1,000	†		111.02
2013		10,000		5.270		1,000			94.45
2013		10,000		5.320		1,000			94.60
2013						1,000			97.15
2013						1,000			101.53
2013						1,000			103.00
2013						1,000			103.15
2013						1,000			104.25
2013						1,000			104.47
2013						1,000			104.50
2013						1,000	†		107.30
2014						1,000			98.00
2014						1,000			98.30
2014						1,000			99.65
2014						1,000	†		103.30

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Document and Entity Information	3 Months Ended
	Mar. 31, 2012	May 07, 2012
Document and Entity Information [Abstract]
Entity Registrant Name	STONE ENERGY CORP
Entity Central Index Key	0000904080
Document Type	10-Q
Document Period End Date	Mar. 31, 2012
Amendment Flag	false
Document Fiscal Year Focus	2012
Document Fiscal Period Focus	Q1
Current Fiscal Year End Date	--12-31
Entity Filer Category	Large Accelerated Filer
Entity Common Stock, Shares Outstanding		49,472,468

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Long - Term Debt (Tables)

3 Months Ended

Mar. 31, 2012

Long-Term Debt [Abstract]

Computation of Long Term Debt

	March 31, 2012		December 31, 2011
	(in millions)
6 3/ 4% Senior Subordinated Notes due 2014	$	200.0	$	200.0
8 5/ 8% Senior Notes due 2017		375.0		375.0
1 3/ 4% Senior Convertible Notes due 2017		230.1		—
Bank debt		—		45.0
Total long-term debt	$	805.1	$	620.0

Summary of records from the proceeds of 2017 Convertible Notes

Cash	$	260.5
Other assets (deferred financing costs)		6.8
Long-term debt		(229.2	)
Additional paid-in capital		(38.1	)

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Condensed Consolidated Statement of Operations (Unaudited) (USD $) In Thousands, except Per Share data, unless otherwise specified	3 Months Ended
	Mar. 31, 2012	Mar. 31, 2011
Operating revenue:
Oil production	$ 201,758	$ 151,995
Gas production	28,857	41,160
Natural gas liquids production	13,452	5,999
Other operational income	890	885
Total operating revenue	244,957	200,039
Operating expenses:
Lease operating expenses	44,480	38,287
Transportation, processing and gathering expenses	3,657	1,820
Other operational expenses	42	662
Production taxes	3,378	2,535
Depreciation, depletion and amortization	84,575	67,669
Accretion expense	8,266	7,717
Salaries, general and administrative expenses	13,705	11,733
Incentive compensation expense	1,442	2,684
Derivative expense, net	485	2,180
Total operating expenses	160,030	135,287
Income from operations	84,927	64,752
Other (income) expenses:
Interest expense	5,731	3,111
Interest income	(31)	(94)
Other income	(420)	(564)
Other expense		124
Total other expenses	5,280	2,577
Net income before income taxes	79,647	62,175
Provision for income taxes:
Current	1,234
Deferred	27,439	22,383
Total income taxes	28,673	22,383
Net income	$ 50,974	$ 39,792
Basic earnings per share	$ 1.03	$ 0.81
Diluted earnings per share	$ 1.03	$ 0.81
Average shares outstanding	48,254	47,898
Average shares outstanding assuming dilution	48,299	47,939

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Acquisitions

3 Months Ended

Mar. 31, 2012

Acquisitions [Abstract]

Acquisitions

Note 6 – Acquisitions

On December 28, 2011, we completed the acquisition of BP Exploration & Production Inc.’s (“BP”) 75% operated working interest in the five block deep water Pompano field in Mississippi Canyon, a 51% operated working interest in the adjacent Mississippi Canyon block 29, a 50% non-operated working interest in the Mica field which ties back to the Pompano platform and a 75% interest in 23 deep water exploration leases located in the vicinity of the Pompano field. The acquisition was accounted for according to the guidance provided in ASC 805, Business Combinations, which requires application of the acquisition method. This methodology requires the recordation of net assets acquired and consideration transferred at fair value (see Note 7 – Fair Value Measurements). Differences between the net fair value of assets acquired and consideration transferred are recorded as goodwill or a bargain purchase gain. The following represents the allocation of the recorded value of net assets acquired in the transaction. Consideration transferred in the transaction was $167.6 million in cash, resulting in no goodwill or bargain purchase gain.

	(in millions)
Proved oil and gas properties	$	208.7
Unevaluated oil and gas properties		17.3
Asset retirement obligations		(58.4	)
Total fair value of net assets	$	167.6

The following unaudited summary pro forma combined statement of operations data of Stone for the three month period ended March 31, 2011 has been prepared to give effect to the acquisition of the deep water assets from BP as if it had occurred on January 1, 2010. The pro forma financial information is not necessarily indicative of the results that might have occurred had the transaction taken place on January 1, 2010 and is not intended to be a projection of future results. Future results may vary significantly from the results reflected in the following pro forma financial information because of normal production declines, changes in commodity prices, future acquisitions and divestitures, future development and exploration activities, and other factors.

	Three Months Ended March 31, 2011 (unaudited)
	(in millions, except per share amounts)
Revenues	$	241.1
Income from operations		91.4
Net income		55.9
Basic earnings per share	$	1.14
Diluted earnings per share	$	1.14

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Asset Retirement Obligations

3 Months Ended

Mar. 31, 2012

Asset Retirement Obligations [Abstract]

Asset Retirement Obligations

Note 5 – Asset Retirement Obligations

The change in our asset retirement obligations during the three months ended March 31, 2012 is set forth below:

	Three Months Ended March  31, 2012
	(in millions)
Asset retirement obligations as of the beginning of the period, including current portion	$	425.8
Liabilities settled		(3.0	)
Divestment of properties		(0.6	)
Accretion expense		8.3
Asset retirement obligations as of the end of the period, including current portion	$	430.5

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Earnings Per Share (Details) (USD $) In Thousands, except Per Share data, unless otherwise specified	3 Months Ended
	Mar. 31, 2012	Mar. 31, 2011
Basic:
Net income	$ 50,974	$ 39,792
Net income attributable to participating securities	(1,217)	(874)
Net income attributable to common stock - basic	49,757	38,918
Diluted:
Net income	50,974	39,792
Net income attributable to participating securities	(1,216)	(873)
Net income attributable to common stock - diluted	$ 49,758	$ 38,919
Weighted average shares (denominator):
Weighted average shares - basic	48,254	47,898
Diluted effect of stock options	45	41
Weighted average shares - diluted	48,299	47,939
Basic income per common share	$ 1.03	$ 0.81
Diluted income per common share	$ 1.03	$ 0.81

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Asset Retirement Obligations (Tables)

3 Months Ended

Mar. 31, 2012

Asset Retirement Obligations [Abstract]

Changes in Asset Retirement Obligations

	Three Months Ended March  31, 2012
	(in millions)
Asset retirement obligations as of the beginning of the period, including current portion	$	425.8
Liabilities settled		(3.0	)
Divestment of properties		(0.6	)
Accretion expense		8.3
Asset retirement obligations as of the end of the period, including current portion	$	430.5

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Guarantor Financial Statements

3 Months Ended

Mar. 31, 2012

Guarantor Financial Statements [Abstract]

Guarantor Financial Statements

Note 9 – Guarantor Financial Statements

Stone Offshore is an unconditional guarantor (the “Guarantor Subsidiary”) of our 1  ³/4% Senior Convertible Notes due 2017, our 8 ⁵/8% Senior Notes due 2017 and our 6 ³/4% Senior Subordinated Notes due 2014. Our remaining subsidiaries (the “Non-Guarantor Subsidiaries”) have not provided guarantees. The following presents unaudited condensed consolidating financial information as of March 31, 2012 and December 31, 2011 and for the three-month periods ended March 31, 2012 and 2011 on an issuer (parent company), guarantor subsidiary, non-guarantor subsidiaries, and consolidated basis. Elimination entries presented are necessary to combine the entities.

CONDENSED CONSOLIDATING BALANCE SHEET

MARCH 31, 2012

(In thousands of dollars)

	Parent			Guarantor Subsidiary			Non-Guarantor Subsidiaries			Eliminations			Consolidated
Assets
Current assets:
Cash and cash equivalents	$	222,750		$	40,955		$	136		$	—		$	263,841
Accounts receivable		37,849			113,735			1,466			(19,784	)		133,266
Fair value of hedging contracts		—			24,352			—			—			24,352
Current income tax receivable		23,140			—			—			—			23,140
Deferred taxes *		3,194			27,012			—			—			30,206
Inventory		4,360			283			—			—			4,643
Other current assets		754			—			—			—			754
Total current assets		292,047			206,337			1,602			(19,784	)		480,202
Oil and gas properties, full cost method:
Proved		672,697			6,027,024			5,051			—			6,704,772
Less: accumulated DD&A		(321,084	)		(4,929,353	)		(2,457	)		—			(5,252,894	)
Net proved oil and gas properties		351,613			1,097,671			2,594			—			1,451,878
Unevaluated		275,920			167,969			—			—			443,889
Other property and equipment, net		11,444			—			—			—			11,444
Fair value of hedging contracts		—			10,937			—			—			10,937
Other assets, net		27,494			1,469			—			—			28,963
Investment in subsidiary		777,606			(512	)		—			(777,094	)		—
Total assets	$	1,736,124		$	1,483,871		$	4,196		($	796,878	)	$	2,427,313
Liabilities and Stockholders’ Equity
Current liabilities:
Accounts payable to vendors	$	92,986		$	12,898		$	208		($	19,785	)	$	86,307
Undistributed oil and gas proceeds		24,810			1,549			—			—			26,359
Accrued interest		10,490			—			—			—			10,490
Fair value of hedging contracts		—			27,298			—			—			27,298
Asset retirement obligations		—			71,256			—			—			71,256
Other current liabilities		4,613			6,127			—			—			10,740
Total current liabilities		132,899			119,128			208			(19,785	)		232,450
Long-term debt		805,140			—			—			—			805,140
Deferred taxes *		42,131			224,865			—			—			266,996
Asset retirement obligations		7,240			347,533			4,501			—			359,274
Fair value of hedging contracts		—			8,025			—			—			8,025
Other long-term liabilities		13,809			6,714			—			—			20,523
Total liabilities		1,001,219			706,265			4,709			(19,785	)		1,692,408
Commitments and contingencies
Stockholders’ equity:
Common stock		483			—			—			—			483
Treasury stock		(860	)		—			—			—			(860	)
Additional paid-in capital		1,376,730			1,724,232			1,639			(1,725,871	)		1,376,730
Accumulated earnings (deficit)		(641,251	)		(946,429	)		(2,152	)		948,581			(641,251	)
Accumulated other comprehensive income (loss)		(197	)		(197	)		—			197			(197	)
Total stockholders’ equity		734,905			777,606			(513	)		(777,093	)		734,905
Total liabilities and stockholders’ equity	$	1,736,124		$	1,483,871		$	4,196		($	796,878	)	$	2,427,313

* Deferred income taxes have been allocated to guarantor subsidiary where related oil and gas properties reside.

CONDENSED CONSOLIDATING BALANCE SHEET

DECEMBER 31, 2011

(In thousands of dollars)

	Parent			Guarantor Subsidiary			Non-Guarantor Subsidiaries			Eliminations			Consolidated
Assets
Current assets:
Cash and cash equivalents	$	37,389		$	926		$	136		$	—		$	38,451
Accounts receivable		36,463			81,452			1,353			(1,129	)		118,139
Fair value of hedging contracts		—			25,177			—			—			25,177
Current income tax receivable		19,946			—			—			—			19,946
Deferred taxes *		8,269			17,803			—			—			26,072
Inventory		4,360			283			—			—			4,643
Other current assets		791			—			—			—			791
Total current assets		107,218			125,641			1,489			(1,129	)		233,219
Oil and gas properties, full cost method:
Proved		696,975			5,946,141			5,052			—			6,648,168
Less: accumulated DD&A		(309,421	)		(4,862,949	)		(2,359	)		—			(5,174,729	)
Net proved oil and gas properties		387,554			1,083,192			2,693			—			1,473,439
Unevaluated		246,269			155,340			—			—			401,609
Other property and equipment, net		11,172			—			—			—			11,172
Fair value of hedging contracts		—			22,543			—			—			22,543
Other assets, net		20,873			2,896			—			—			23,769
Investment in subsidiary		733,533			(273	)		—			(733,260	)		—
Total assets	$	1,506,619		$	1,389,339		$	4,182		($	734,389	)	$	2,165,751
Liabilities and Stockholders’ Equity
Current liabilities:
Accounts payable to vendors	$	78,170		$	25,866		$	39		($	1,129	)	$	102,946
Undistributed oil and gas proceeds		26,036			1,292			—			—			27,328
Accrued interest		14,059			—			—			—			14,059
Fair value of hedging contracts		—			11,122			—			—			11,122
Asset retirement obligations		—			62,676			—			—			62,676
Other current liabilities		22,974			5,396			—			—			28,370
Total current liabilities		141,239			106,352			39			(1,129	)		246,501
Long-term debt		620,000			—			—			—			620,000
Deferred taxes *		56,970			190,865			—			—			247,835
Asset retirement obligations		7,626			351,061			4,416			—			363,103
Fair value of hedging contracts		—			815			—			—			815
Other long-term liabilities		12,955			6,713			—			—			19,668
Total liabilities		838,790			655,806			4,455			(1,129	)		1,497,922
Commitments and contingencies
Stockholders’ equity:
Common stock		481			—			—			—			481
Treasury stock		(860	)		—			—			—			(860	)
Additional paid-in capital		1,338,565			1,724,232			1,639			(1,725,871	)		1,338,565
Accumulated earnings (deficit)		(692,225	)		(1,012,567	)		(1,912	)		1,014,479			(692,225	)
Accumulated other comprehensive income (loss)		21,868			21,868			—			(21,868	)		21,868
Total stockholders’ equity		667,829			733,533			(273	)		(733,260	)		667,829
Total liabilities and stockholders’ equity	$	1,506,619		$	1,389,339		$	4,182		($	734,389	)	$	2,165,751

* Deferred income taxes have been allocated to guarantor subsidiary where related oil and gas properties reside.

CONDENSED CONSOLIDATING STATEMENT OF OPERATIONS

THREE MONTHS ENDED MARCH 31, 2012

(In thousands of dollars)

	Parent			Guarantor Subsidiary			Non- Guarantor Subsidiaries			Eliminations			Consolidated
Operating revenue:
Oil production	$	6,234		$	195,524		$	—		$	—		$	201,758
Gas production		5,631			23,226			—			—			28,857
Natural gas liquids production		3,864			9,588			—			—			13,452
Other operational income		694			63			133			—			890
Total operating revenue		16,423			228,401			133			—			244,957
Operating expenses:
Lease operating expenses		4,904			39,387			189			—			44,480
Transportation, processing and gathering expenses		2,488			1,169			—			—			3,657
Other operational expenses		42			—			—			—			42
Production taxes		1,163			2,215			—			—			3,378
Depreciation, depletion, amortization		11,477			73,000			98			—			84,575
Accretion expense		148			8,032			86			—			8,266
Salaries, general and administrative		12,654			1,051			—			—			13,705
Incentive compensation expense		1,442			—			—			—			1,442
Derivative expense, net		—			485			—			—			485
Total operating expenses		34,318			125,339			373			—			160,030
Income (loss) from operations		(17,895	)		103,062			(240	)		—			84,927
Other (income) expenses:
Interest expense		5,846			(115	)		—			—			5,731
Interest income		(30	)		(1	)		—			—			(31	)
Other income		(19	)		(401	)		—			—			(420	)
(Income) loss from investment in subsidiaries		(66,137	)		239			—			65,898			—
Total other (income) expenses		(60,340	)		(278	)		—			65,898			5,280
Income (loss) before taxes		42,445			103,340			(240	)		(65,898	)		79,647
Provision (benefit) for income taxes:
Current		1,234			—			—			—			1,234
Deferred		(9,763	)		37,202			—			—			27,439
Total income taxes		(8,529	)		37,202			—			—			28,673
Net income (loss)	$	50,974		$	66,138		($	240	)	($	65,898	)	$	50,974
Comprehensive income (loss)	$	28,909		$	66,138		($	240	)	($	65,898	)	$	28,909

CONDENSED CONSOLIDATING STATEMENT OF OPERATIONS

THREE MONTHS ENDED MARCH 31, 2011

(In thousands of dollars)

	Parent			Guarantor Subsidiary			Non- Guarantor Subsidiaries			Eliminations			Consolidated
Operating revenue:
Oil production	$	786		$	151,209		$	—		$	—		$	151,995
Gas production		1,280			39,880			—			—			41,160
Natural gas liquids production		—			5,999			—			—			5,999
Other operational income		722			(19	)		182			—			885
Total operating revenue		2,788			197,069			182			—			200,039
Operating expenses:
Lease operating expenses		356			37,931			—			—			38,287
Transportation, processing and gathering expenses		—			1,820			—			—			1,820
Other operational expenses		—			662			—			—			662
Production taxes		147			2,388			—			—			2,535
Depreciation, depletion, amortization		5,942			61,510			217			—			67,669
Accretion expense		4			7,622			91			—			7,717
Salaries, general and administrative		11,731			2			—			—			11,733
Incentive compensation expense		2,684			—			—			—			2,684
Derivative expense, net		—			2,180			—			—			2,180
Total operating expenses		20,864			114,115			308			—			135,287
Income (loss) from operations		(18,076	)		82,954			(126	)		—			64,752
Other (income) expenses:
Interest expense		3,031			80			—			—			3,111
Interest income		(88	)		(6	)		—			—			(94	)
Other income		—			(567	)		3			—			(564	)
Other expense		123			1			—			—			124
(Income) loss from investment in subsidiary		(53,323	)		129			—			53,194			—
Total other (income) expenses		(50,257	)		(363	)		3			53,194			2,577
Income (loss) before taxes		32,181			83,317			(129	)		(53,194	)		62,175
Provision (benefit) for income taxes:
Current		—			—			—			—			—
Deferred		(7,611	)		29,994			—			—			22,383
Total income taxes		(7,611	)		29,994			—			—			22,383
Net income (loss)	$	39,792		$	53,323		($	129	)	($	53,194	)	$	39,792
Comprehensive income (loss)	$	7,318		$	53,323		($	129	)	($	53,194	)	$	7,318

CONDENSED CONSOLIDATING STATEMENT OF CASH FLOWS

THREE MONTHS ENDED MARCH 31, 2012

(In thousands of dollars)

	Parent			Guarantor Subsidiary			Non-Guarantor Subsidiaries			Eliminations			Consolidated
Cash flows from operating activities:
Net income (loss)	$	50,974		$	66,138		($	240	)	($	65,898	)	$	50,974
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Depreciation, depletion and amortization		11,477			73,000			98			—			84,575
Accretion expense		148			8,032			86			—			8,266
Deferred income tax provision (benefit)		(9,763	)		37,202			—			—			27,439
Settlement of asset retirement obligations		—			(2,980	)		—			—			(2,980	)
Non-cash stock compensation expense		1,750			—			—			—			1,750
Excess tax benefits		(847	)		—			—			—			(847	)
Non-cash derivative expense		—			1,342			—			—			1,342
Non-cash (income) loss from investment in subsidiaries		(65,737	)		(161	)		—			65,898			—
Other non-cash expenses		1,173			—			—			—			1,173
Change in current income taxes		(2,647	)		—			—			—			(2,647	)
Change in intercompany receivables/payables		18,655			(18,445	)		(210	)		—			—
(Increase) decrease in accounts receivable		(983	)		(20,823	)		98			—			(21,708	)
Decrease in other current assets		35			—			—			—			35
Increase (decrease) in accounts payable		(25	)		(6,157	)		167			—			(6,015	)
Increase (decrease) in other current liabilities		(23,155	)		987			—			—			(22,168	)
Other		146			—			—			—			146
Net cash provided by (used in) operating activities		(18,799	)		138,135			(1	)		—			119,335
Cash flows from investing activities:
Investment in oil and gas properties		(8,364	)		(98,106	)		1			—			(106,469	)
Sale of fixed assets		134			—			—			—			134
Investment in fixed and other assets		(909	)		—			—			—			(909	)
Net cash provided by (used in) investing activities		(9,139	)		(98,106	)		1			—			(107,244	)
Cash flows from financing activities:
Proceeds from bank borrowings		25,000			—			—			—			25,000
Repayments of bank borrowings		(70,000	)		—			—			—			(70,000	)
Proceeds from issuance of senior convertible notes		300,000			—			—			—			300,000
Financing costs of senior convertible notes		(8,855	)		—			—			—			(8,855	)
Proceeds from Sold Warrants		40,170			—			—			—			40,170
Payments for Purchased Call Options		(70,830	)		—			—			—			(70,830	)
Excess tax benefits		847			—			—			—			847
Net payments for share based compensation		(3,033	)		—			—			—			(3,033	)
Net cash provided by financing activities		213,299			—			—			—			213,299
Net change in cash and cash equivalents		185,361			40,029			—			—			225,390
Cash and cash equivalents, beginning of period		37,389			926			136			—			38,451
Cash and cash equivalents, end of period	$	222,750		$	40,955		$	136		$	—		$	263,841

CONDENSED CONSOLIDATING STATEMENT OF CASH FLOWS

THREE MONTHS ENDED MARCH 31, 2011

(In thousands of dollars)

	Parent			Guarantor Subsidiary			Non-Guarantor Subsidiaries			Eliminations			Consolidated
Cash flows from operating activities:
Net income (loss)	$	39,792		$	53,323		($	129	)	($	53,194	)	$	39,792
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Depreciation, depletion and amortization		5,942			61,510			217			—			67,669
Accretion expense		4			7,622			91			—			7,717
Deferred income tax provision (benefit)		(7,611	)		29,994			—			—			22,383
Settlement of asset retirement obligations		—			(19,034	)		—			—			(19,034	)
Non-cash stock compensation expense		1,680			—			—			—			1,680
Excess tax benefits		(649	)		—			—			—			(649	)
Non-cash derivative expense		—			1,804			—			—			1,804
Non-cash (income) loss from investment in subsidiary		(52,756	)		(438	)		—			53,194			—
Other non-cash income		(104	)		—			—			—			(104	)
Change in current income taxes		(3,681	)		—			—			—			(3,681	)
Change in intercompany receivables/payables		44,230			(43,804	)		(426	)		—			—
(Increase) decrease in accounts receivable		6,833			(28,509	)		121			—			(21,555	)
Decrease in other current assets		25			—			—			—			25
Decrease in inventory		365			—			—			—			365
Increase in accounts payable		2,609			81			—			—			2,690
Increase (decrease) in other current liabilities		(10,929	)		870			—			—			(10,059	)
Other		272			—			—			—			272
Net cash provided by (used in) operating activities		26,022			63,419			(126	)		—			89,315
Cash flows from investing activities:
Investment in oil and gas properties		(89,444	)		(67,087	)		(4	)		—			(156,535	)
Proceeds from sale of oil and gas properties		5,575			2,117			—			—			7,692
Investment in fixed and other assets		(262	)		—			—			—			(262	)
Net cash used in investing activities		(84,131	)		(64,970	)		(4	)		—			(149,105	)
Cash flows from financing activities:
Deferred financing costs		(66	)		—			—			—			(66	)
Excess tax benefits		649			—			—			—			649
Net payments for share based compensation		(1,843	)		—			—			—			(1,843	)
Net cash used in financing activities		(1,260	)		—			—			—			(1,260	)
Net change in cash and cash equivalents		(59,369	)		(1,551	)		(130	)		—			(61,050	)
Cash and cash equivalents, beginning of period		105,115			1,659			182			—			106,956
Cash and cash equivalents, end of period	$	45,746		$	108		$	52		$	—		$	45,906

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Fair Value Measurements

3 Months Ended

Mar. 31, 2012

Fair Value Measurements [Abstract]

Fair Value Measurements

Note 7 – Fair Value Measurements

U.S. Generally Accepted Accounting Principles establish a fair value hierarchy which has three levels based on the reliability of the inputs used to determine the fair value. These levels include: Level 1, defined as inputs such as unadjusted quoted prices in active markets for identical assets or liabilities; Level 2, defined as inputs other than quoted prices in active markets that are either directly or indirectly observable; and Level 3, defined as unobservable inputs for use when little or no market data exists, therefore requiring an entity to develop its own assumptions.

As of March 31, 2012 and December 31, 2011, we held certain financial assets and liabilities that are required to be measured at fair value on a recurring basis, including our commodity derivative instruments and our investments in money market funds. We utilize the services of an independent third party to assist us in valuing our derivative instruments. We used the income approach in determining the fair value of our derivative instruments utilizing a proprietary pricing model. The model accounts for our credit risk and the credit risk of our counterparties in the discount rate applied to estimated future cash inflows and outflows. Our swap contracts are included within the Level 2 fair value hierarchy. For a more detailed description of our derivative instruments, (see Note 3 – Derivative Instruments and Hedging Activities). We used the market approach in determining the fair value of our investments in money market funds, which are included within the Level 1 fair value hierarchy.

The following tables present our assets and liabilities that are measured at fair value on a recurring basis at March 31, 2012:

		$00,0		$00,0		$00,0		$00,0
	Fair Value Measurements at March 31, 2012
Assets	Total		Quoted Prices in Active Markets for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)
	(in millions)
Money market funds	$	5.8	$	5.8	$	—	$	—
Hedging contracts		35.3		—		35.3		—
Total	$	41.1	$	5.8	$	35.3	$	—

		$00,0			$00,0		$00,0			$00,0
	Fair Value Measurements at March 31, 2012
Liabilities	Total			Quoted Prices in Active Markets for Identical Liabilities (Level 1)		Significant Other Observable Inputs (Level 2)			Significant Unobservable Inputs (Level 3)
	(in millions)
Hedging contracts	($	35.3	)	$	—	($	35.3	)	$	—
Total	($	35.3	)	$	—	($	35.3	)	$	—

The following tables present our assets and liabilities that are measured at fair value on a recurring basis at December 31, 2011:

	Fair Value Measurements at December 31, 2011
Assets	Total		Quoted Prices in Active Markets for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)
	(in millions)
Money market funds	$	5.6	$	5.6	$	—	$	—
Hedging contracts		47.7		—		47.7		—
Total	$	53.3	$	5.6	$	47.7	$	—

	Fair Value Measurements at December 31, 2011
Liabilities	Total			Quoted Prices in Active Markets for Identical Liabilities (Level 1)		Significant Other Observable Inputs (Level 2)			Significant Unobservable Inputs (Level 3)
	(in millions)
Hedging contracts	($	11.9	)	$	—	($	11.9	)	$	—
Total	($	11.9	)	$	—	($	11.9	)	$	—

The fair value of cash and cash equivalents and our variable rate bank debt approximated book value at March 31, 2012 and December 31, 2011. As of March 31, 2012 and December 31, 2011, the fair value of our $375 million 8 ⁵ /8% Senior Notes due 2017 was approximately $392.8 million and $386.3 million, respectively. As of March 31, 2012 and December 31, 2011, the fair value of our $200 million 6 ³/4% Senior Subordinated Notes due 2014 was approximately $202.5 million and $199.0 million, respectively. As of March 31, 2012, the fair value of our 2017 Convertible Notes was approximately $292.7 million, of which $231.2 million was attributable to the liability component. The fair value of our outstanding notes was determined based upon quotes obtained from brokers, which represent Level 2 inputs.

We applied fair value concepts in determining the liability component of our 2017 Convertible Notes (see Note 4 – Long-Term Debt). The significant input in this determination was a market interest rate of 7.51% which represents a market rate based on quotes obtained from brokers and represents a Level 2 input.

We applied fair value concepts in the recording of deep water assets acquired from BP (see Note 6 – Acquisitions). The fair value of proved and unevaluated oil and gas properties was estimated using a market approach. Significant inputs were market value comparisons for similar transactions within a one year period. These inputs were considered Level 3 inputs. Asset retirement obligations were determined in accordance with applicable accounting standards.

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Commitments and Contingencies

3 Months Ended

Mar. 31, 2012

Commitments and Contingencies [Abstract]

Commitments and Contingencies

Note 8 – Commitments and Contingencies

We are named as a defendant in certain lawsuits and are a party to certain regulatory proceedings arising in the ordinary course of business. We do not expect these matters, individually or in the aggregate, will have a material adverse effect on our financial condition.

Franchise Tax Action. We have been served with several petitions filed by the Louisiana Department of Revenue (“LDR”) in Louisiana state court claiming additional franchise taxes due. In addition, we have received preliminary assessments from the LDR for additional franchise taxes resulting from audits of Stone and other subsidiaries. These assessments all relate to the LDR’s assertion that sales of crude oil and natural gas from properties located on the OCS, which are transported through the state of Louisiana, should be sourced to the state of Louisiana for purposes of computing the Louisiana franchise tax apportionment ratio. Total asserted claims plus estimated accrued interest amount to approximately $30.1 million. The franchise tax years 2010 and 2011 for Stone remain subject to examination, which potentially exposes us to additional estimated assessments of $3.3 million including accrued interest. We estimate the potential range of loss upon resolution of this matter to be between $0 and $34.0 million.

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Earnings Per Share (Tables)

3 Months Ended

Mar. 31, 2012

Earnings Per Share [Abstract]

Earnings per share basic and diluted

	Three Months Ended March 31,
	2012			2011
	(in thousands, except per share data)
Income (numerator):
Basic:
Net income	$	50,974		$	39,792
Net income attributable to participating securities		(1,217	)		(874	)
Net income attributable to common stock – basic	$	49,757		$	38,918
Diluted:
Net income	$	50,974		$	39,792
Net income attributable to participating securities		(1,216	)		(873	)
Net income attributable to common stock – diluted	$	49,758		$	38,919
Weighted average shares (denominator):
Weighted average shares – basic		48,254			47,898
Diluted effect of stock options		45			41
Weighted average shares – diluted		48,299			47,939
Basic income per common share	$	1.03		$	0.81
Diluted income per common share	$	1.03		$	0.81

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Fair Value Measurements (Details) (Recurring [Member], USD $) In Millions, unless otherwise specified	Mar. 31, 2012	Dec. 31, 2011
Assets, Fair Value Disclosure [Abstract]
Assets, Fair Value, Total	$ 41.1	$ 53.3
Liabilities, Fair Value Disclosure [Abstract]
Liabilities, Fair Value, Total	(35.3)	(11.9)
Hedging contracts [Member]
Assets, Fair Value Disclosure [Abstract]
Derivative Assets, Fair Value	35.3	47.7
Liabilities, Fair Value Disclosure [Abstract]
Derivative Liabilities, Fair Value	(35.3)	(11.9)
Money market funds [Member]
Assets, Fair Value Disclosure [Abstract]
Cash and Cash Equivalents, Fair Value	5.8	5.6
Quoted Prices In Active Markets for Identical Assets [Member]
Assets, Fair Value Disclosure [Abstract]
Assets, Fair Value, Total	5.8	5.6
Liabilities, Fair Value Disclosure [Abstract]
Liabilities, Fair Value, Total
Quoted Prices In Active Markets for Identical Assets [Member] | Hedging contracts [Member]
Liabilities, Fair Value Disclosure [Abstract]
Derivative Liabilities, Fair Value
Quoted Prices In Active Markets for Identical Assets [Member] | Money market funds [Member]
Assets, Fair Value Disclosure [Abstract]
Cash and Cash Equivalents, Fair Value	5.8	5.6
Significant Other Observable Inputs [Member]
Assets, Fair Value Disclosure [Abstract]
Assets, Fair Value, Total	35.3	47.7
Liabilities, Fair Value Disclosure [Abstract]
Liabilities, Fair Value, Total	(35.3)	(11.9)
Significant Other Observable Inputs [Member] | Hedging contracts [Member]
Assets, Fair Value Disclosure [Abstract]
Derivative Assets, Fair Value	35.3	47.7
Liabilities, Fair Value Disclosure [Abstract]
Derivative Liabilities, Fair Value	(35.3)	(11.9)
Significant Unobservable Inputs [Member]
Assets, Fair Value Disclosure [Abstract]
Assets, Fair Value, Total
Liabilities, Fair Value Disclosure [Abstract]
Liabilities, Fair Value, Total
Significant Unobservable Inputs [Member] | Hedging contracts [Member]
Assets, Fair Value Disclosure [Abstract]
Derivative Assets, Fair Value
Liabilities, Fair Value Disclosure [Abstract]
Derivative Liabilities, Fair Value
Significant Unobservable Inputs [Member] | Money market funds [Member]
Assets, Fair Value Disclosure [Abstract]
Cash and Cash Equivalents, Fair Value

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Fair Value Measurements (Tables)

3 Months Ended

Mar. 31, 2012

Fair Value Measurements [Abstract]

Fair Value Assets and Liabilities

		$00,0		$00,0		$00,0		$00,0
	Fair Value Measurements at March 31, 2012
Assets	Total		Quoted Prices in Active Markets for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)
	(in millions)
Money market funds	$	5.8	$	5.8	$	—	$	—
Hedging contracts		35.3		—		35.3		—
Total	$	41.1	$	5.8	$	35.3	$	—

		$00,0			$00,0		$00,0			$00,0
	Fair Value Measurements at March 31, 2012
Liabilities	Total			Quoted Prices in Active Markets for Identical Liabilities (Level 1)		Significant Other Observable Inputs (Level 2)			Significant Unobservable Inputs (Level 3)
	(in millions)
Hedging contracts	($	35.3	)	$	—	($	35.3	)	$	—
Total	($	35.3	)	$	—	($	35.3	)	$	—

	Fair Value Measurements at December 31, 2011
Assets	Total		Quoted Prices in Active Markets for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)
	(in millions)
Money market funds	$	5.6	$	5.6	$	—	$	—
Hedging contracts		47.7		—		47.7		—
Total	$	53.3	$	5.6	$	47.7	$	—

	Fair Value Measurements at December 31, 2011
Liabilities	Total			Quoted Prices in Active Markets for Identical Liabilities (Level 1)		Significant Other Observable Inputs (Level 2)			Significant Unobservable Inputs (Level 3)
	(in millions)
Hedging contracts	($	11.9	)	$	—	($	11.9	)	$	—
Total	($	11.9	)	$	—	($	11.9	)	$	—

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Derivative Instruments and Hedging Activities (Details 1) (USD $) In Millions, unless otherwise specified	3 Months Ended
	Mar. 31, 2012	Mar. 31, 2011
Effect of Derivative Instruments on the Statement of Operations
Derivative Instruments, Gain (Loss) Recognized in Other Comprehensive Income (Loss), Effective Portion, Net, Total		$ (18.3)
Derivative Instruments, Gain (Loss) Reclassified from Accumulated OCI into Income, Effective Portion, Net, Total	(12.4)
Cash Flow Hedging [Member]
Effect of Derivative Instruments on the Statement of Operations
Derivative Instruments, Gain (Loss) Recognized in Other Comprehensive Income (Loss), Effective Portion, Net, Total	(22.1)	(32.5)
Derivative Instruments, Gain (Loss) Reclassified from Accumulated OCI into Income, Effective Portion, Net, Total	(1.0)	(3.9)
Derivative Instruments, Gain (Loss) Recognized in Income, Ineffective Portion and Amount Excluded from Effectiveness Testing, Net, Total	(0.5)	(2.2)
Cash Flow Hedging [Member] | Commodity contracts [Member]
Effect of Derivative Instruments on the Statement of Operations
Derivative Instruments, Gain (Loss) Recognized in Other Comprehensive Income (Loss), Effective Portion, Net, Total	(22.1)	(32.5)
Operating revenue - oil/gas production [Member] | Cash Flow Hedging [Member]
Effect of Derivative Instruments on the Statement of Operations
Derivative Instruments, Gain (Loss) Reclassified from Accumulated OCI into Income, Effective Portion, Net, Total	(1.0)	(3.9)
Derivative income, net [Member] | Cash Flow Hedging [Member]
Effect of Derivative Instruments on the Statement of Operations
Derivative Instruments, Gain (Loss) Recognized in Income, Ineffective Portion and Amount Excluded from Effectiveness Testing, Net, Total	$ (0.5)	$ (2.2)

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Condensed Consolidated Statement of Comprehensive Income (Unaudited) (USD $) In Thousands, unless otherwise specified	3 Months Ended
	Mar. 31, 2012	Mar. 31, 2011
Condensed Consolidated Statement of Comprehensive Income [Abstract]
Net income	$ 50,974	$ 39,792
Other comprehensive (loss), net of tax effect:
Adjustment for fair value accounting of derivatives	(22,065)	(32,474)
Comprehensive income	$ 28,909	$ 7,318

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Long-Term Debt

3 Months Ended

Mar. 31, 2012

Long-Term Debt [Abstract]

Long-Term Debt

Note 4 – Long-Term Debt

Long-term debt consisted of the following at:

	March 31, 2012		December 31, 2011
	(in millions)
6 3/ 4% Senior Subordinated Notes due 2014	$	200.0	$	200.0
8 5/ 8% Senior Notes due 2017		375.0		375.0
1 3/ 4% Senior Convertible Notes due 2017		230.1		—
Bank debt		—		45.0
Total long-term debt	$	805.1	$	620.0

Bank Debt

On April 26, 2011, we entered into an amended and restated revolving credit facility with commitments totaling $700 million (subject to borrowing base limitations) through a syndicated bank group, replacing our previous facility. The credit facility matures on September 15, 2014. However, if the 6 ³/4% Senior Subordinated Notes due 2014 issued under our 2004 indenture are retired on or before April 15, 2014, the credit facility then matures on April 26, 2015. Our initial borrowing base under our bank credit facility was set at $400 million. On October 31, 2011, the bank group reaffirmed the existing borrowing base at $400 million. On February 28, 2012, we entered into an Amendment No. 1 and Consent to our credit agreement to permit the issuance of our 2017 Convertible Notes (see Senior Convertible Notes below). On March 6, 2012, we issued $300 million in aggregate principal amount of 2017 Convertible Notes in a private offering. Upon completion of the offering, our borrowing base under our bank credit facility was automatically reduced from $400 million to $310 million. On May 4, 2012, our borrowing base under our bank credit facility was redetermined to be $400 million.

On March 31, 2012, we had no outstanding borrowings under our bank credit facility and letters of credit totaling $27.1 million had been issued pursuant to the facility. As of May 7, 2012, we had no outstanding borrowings under our bank credit facility and letters of credit totaling $27.1 million had been issued pursuant to the facility, leaving $372.9 million of availability under the facility. Our bank credit facility is guaranteed by our only material subsidiary, Stone Energy Offshore, L.L.C. (“Stone Offshore”).

The borrowing base under our bank credit facility is redetermined semi-annually, in May and November, by the lenders taking into consideration the estimated value of our oil and gas properties and those of our direct and indirect material subsidiaries in accordance with the lenders’ customary practices for oil and gas loans. In addition, we and the lenders each have discretion at any time, but not more than two additional times in any calendar year, to have the borrowing base redetermined. Our bank credit facility is collateralized by substantially all of Stone’s and Stone Offshore’s assets. Stone and Stone Offshore are required to mortgage, and grant a security interest in, their oil and gas reserves representing at least 80% of the discounted present value of the future net cash flows from their oil and gas reserves reviewed in determining the borrowing base. At our option, loans under our bank credit facility will bear interest at a rate based on the adjusted Libor Rate plus an applicable margin, or a rate based on the prime rate or Federal funds rate plus an applicable margin. Our bank credit facility provides for optional and mandatory prepayments, affirmative and negative covenants, and interest coverage ratio and leverage ratio maintenance covenants. We were in compliance with all covenants as of March 31, 2012.

Senior Convertible Notes

On March 6, 2012, we issued in a private offering $300 million in aggregate principal amount of 1 ³/4% Senior Convertible Notes due 2017 (the “2017 Convertible Notes”) to qualified institutional buyers pursuant to Rule 144A under the Securities Act of 1933, as amended (the “Securities Act”). The 2017 Convertible Notes are fully and unconditionally guaranteed on a senior unsecured basis by Stone Offshore and by certain future restricted subsidiaries of Stone. The net proceeds from the sale of the 2017 Convertible Notes were approximately $291.1 million, after deducting fees and expenses. The 2017 Convertible Notes rank equally in right of payment with all of our existing and future senior unsecured indebtedness. The 2017 Convertible Notes are effectively subordinated to our secured indebtedness to the extent of the value of the related collateral. The 2017 Convertible Notes bear interest at a rate of 1.75% per year, payable on March 1 and September 1 of each year, beginning on September 1, 2012. The 2017 Convertible Notes mature on March 1, 2017, unless earlier converted or repurchased. We may not redeem the 2017 Convertible Notes at our option prior to the maturity date.

The 2017 Convertible Notes are convertible into cash, shares of our common stock or a combination of cash and shares of our common stock, at our election, based on an initial conversion rate of 23.4449 shares of our common stock per $1,000 principal amount of 2017 Convertible Notes, which corresponds to an initial conversion price of approximately $42.65 per share of our common stock. On March 30, 2012, our closing share price was $28.59. The conversion rate, and thus the conversion price, may be adjusted under certain circumstances as described in the indenture related to the 2017 Convertible Notes.

The 2017 Convertible Notes may be converted by the holder, in multiples of $1,000 principal amount, only under the following circumstances:

• prior to December 1, 2016, on any date during any calendar quarter beginning after June 30, 2012 (and only during such calendar quarter) if the closing sale price of our common stock was more than 130% of the then current conversion price for at least 20 trading days in the period of the 30 consecutive trading days ending on the last trading day of the previous calendar quarter;

• prior to December 1, 2016, if we distribute to all or substantially all holders of our common stock rights, options or warrants entitling them to purchase, for a period of 45 calendar days or less from the declaration date for such distribution, shares of our common stock at a price per share less than the average closing sale price of our common stock for the ten consecutive trading days immediately preceding, but excluding, the declaration date for such distribution;

• prior to December 1, 2016, if we distribute to all or substantially all holders of our common stock cash, other assets, securities or rights to purchase our securities, which distribution has a per share value exceeding 10% of the closing sale price of our common stock on the trading day immediately preceding the declaration date for such distribution, or if we engage in certain corporate transactions described in the indenture related to the 2017 Convertible Notes;

• prior to December 1, 2016, during the five consecutive business-day period following any five consecutive trading-day period in which the trading price per $1,000 principal amount of 2017 Convertible Notes for each trading day during such five trading-day period was less than 98% of the closing sale price of our common stock for each trading day during such five trading-day period multiplied by the then current conversion rate; or

• on or after December 1, 2016, and prior to the close of business on the second scheduled trading day immediately preceding the maturity date of the 2017 Convertible Notes, which is March 1, 2017, without regard to the foregoing conditions.

Upon conversion, we will be obligated to pay or deliver, as the case may be, cash, shares of our common stock or a combination of cash and shares of our common stock, at our election. If we satisfy our conversion obligation solely in cash or through payment and delivery, as the case may be, of a combination of cash and shares of our common stock, the amount of cash and shares of common stock, if any, due upon conversion will be based on a daily conversion value (as described in the indenture related to the 2017 Convertible Notes) calculated on a proportionate basis for each trading day in a 25 consecutive trading-day conversion period (as described in the indenture related to the 2017 Convertible Notes). Upon any conversion, subject to certain exceptions, holders of the 2017 Convertible Notes will not receive any cash payment representing accrued and unpaid interest. Instead, interest will be deemed to be paid by the cash, shares of our common stock or a combination of cash and shares of our common stock paid or delivered, as the case may be, upon conversion of a 2017 Convertible Note.

If we undergo a fundamental change (as defined in the indenture related to the 2017 Convertible Notes) prior to maturity, holders of the 2017 Convertible Notes will have the right, at their option, to require us to repurchase for cash some or all of their 2017 Convertible Notes at a repurchase price equal to 100% of the principal amount of the 2017 Convertible Notes being repurchased, plus accrued and unpaid interest (including additional interest, if any) to, but excluding, the fundamental change repurchase date.

If holders elect to convert the 2017 Convertible Notes in connection with certain fundamental change transactions described in the indenture, we will increase the conversion rate by a number of additional shares determined by reference to the provisions contained in the indenture based on the effective date of, and the price paid (or deemed paid) per share of our common stock in, such make-whole fundamental change. If holders of our common stock receive only cash in connection with certain make-whole fundamental changes, the price paid (or deemed paid) per share will be the cash amount paid per share. Otherwise, the price paid (or deemed paid) per share will be equal to the average of the closing sale prices of our common stock on the five trading days prior to, but excluding, the effective date of such make-whole fundamental change.

In connection with the sale of the 2017 Convertible Notes, we entered into convertible note hedge transactions with respect to our common stock (the “Purchased Call Options”) with Barclays Capital Inc., acting as agent for Barclays Bank PLC, and Bank of America, N.A. (the “Dealers”). We paid an aggregate amount of approximately $70.8 million to the Dealers for the Purchased Call Options. The Purchased Call Options cover, subject to customary anti-dilution adjustments, approximately 7,033,470 shares of our common stock at a strike price that corresponds to the initial conversion price of the 2017 Convertible Notes, also subject to adjustment, and are exercisable upon conversion of the 2017 Convertible Notes.

We also entered into separate warrant transactions whereby, in reliance upon the exemption from registration provided by Section 4(2) of the Securities Act, we sold to the Dealers warrants to acquire, subject to customary anti-dilution adjustments, approximately 7,033,470 shares of our common stock (the “Sold Warrants”) at a strike price of $55.91 per share of common stock. We received aggregate proceeds of approximately $40.1 million from the sale of the Sold Warrants to the Dealers. If, upon expiration of the Sold Warrants, the price per share of our common stock, as measured under the Sold Warrants, is greater than the strike price of the Sold Warrants, we will be required to issue, without further consideration, under each Sold Warrant a number of shares of our common stock with a value equal to the amount of such difference.

The Purchased Call Options and Sold Warrants are separate contracts entered into by Stone and each of the Dealers, are not part of the terms of the 2017 Convertible Notes and will not affect the holders’ rights under the 2017 Convertible Notes. The Purchased Call Options are expected generally to reduce the potential dilution upon conversion of the 2017 Convertible Notes in the event that the market value per share of our common stock at the time of exercise is greater than the strike price of the Purchased Call Options. The Sold Warrants could separately have a dilutive effect to the extent that the market value per share of our common stock exceeds the applicable strike price of the Sold Warrants.

The estimated liability and equity components of this offering were recorded in accordance with Accounting Standards Codification (“ASC”) 470-20. The initial carrying amount of the liability component of $229.2 million was determined by measuring the fair value of a similar liability that does not have an associated equity component. The carrying amount of the equity component of $70.8 million was determined by deducting the fair value of the liability component from the initial proceeds from the 2017 Convertible Notes. Transaction costs of approximately $8.9 were allocated to the liability and equity components in proportion to the allocation of proceeds and accounted for as debt issuance and equity issuance costs, respectively. The cost of the convertible note hedge of $70.8 million and proceeds from the warrant transaction of $40.1 million were recorded as adjustments to equity. A summary of the entries to record the proceeds from the 2017 Convertible Notes, the cost of the Purchased Call Options and the proceeds from the Sold Warrants is as follows (in millions):

Cash	$	260.5
Other assets (deferred financing costs)		6.8
Long-term debt		(229.2	)
Additional paid-in capital		(38.1	)

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Derivative Instruments and Hedging Activities (Details 2) (USD $)	May 07, 2012 MMBtusd
2012 Hedging Position One [Member] | Natural Gas [Member]
Hedging Positions
Daily Volume	10,000
Swap Price	$ 5.035
2012 Hedging Position One [Member] | Oil [Member]
Hedging Positions
Daily Volume	1,000
Swap Price	90.30
2012 Hedging Position Two [Member] | Natural Gas [Member]
Hedging Positions
Daily Volume	10,000
Swap Price	5.040
2012 Hedging Position Two [Member] | Oil [Member]
Hedging Positions
Daily Volume	1,000
Swap Price	90.41
2012 Hedging Position Three [Member] | Natural Gas [Member]
Hedging Positions
Daily Volume	10,000
Swap Price	5.050
2012 Hedging Position Three [Member] | Oil [Member]
Hedging Positions
Daily Volume	1,000
Swap Price	90.45
2012 Hedging Position Four [Member] | Oil [Member]
Hedging Positions
Daily Volume	1,000
Swap Price	95.50
2012 Hedging Position Five [Member] | Oil [Member]
Hedging Positions
Daily Volume	2,000
Swap Price	97.60
2012 Hedging Position Six [Member] | Oil [Member]
Hedging Positions
Daily Volume	1,000
Swap Price	98.15
2012 Hedging Position Seven [Member] | Oil [Member]
Hedging Positions
Daily Volume	1,000
Swap Price	100.00
2012 Hedging Position Eight [Member] | Oil [Member]
Hedging Positions
Daily Volume	1,000
Swap Price	101.55
2012 Hedging Position Nine [Member] | Oil [Member]
Hedging Positions
Daily Volume	1,000
Swap Price	104.25
2012 Hedging Position Ten [Member] | Oil [Member]
Hedging Positions
Daily Volume	1,000
Swap Price	111.02
2013 Hedging Position One [Member] | Natural Gas [Member]
Hedging Positions
Daily Volume	10,000
Swap Price	5.270
2013 Hedging Position One [Member] | Oil [Member]
Hedging Positions
Daily Volume	1,000
Swap Price	94.45
2013 Hedging Position Two [Member] | Natural Gas [Member]
Hedging Positions
Daily Volume	10,000
Swap Price	5.320
2013 Hedging Position Two [Member] | Oil [Member]
Hedging Positions
Daily Volume	1,000
Swap Price	94.60
2013 Hedging Position Three [Member] | Oil [Member]
Hedging Positions
Daily Volume	1,000
Swap Price	97.15
2013 Hedging Position Four [Member] | Oil [Member]
Hedging Positions
Daily Volume	1,000
Swap Price	101.53
2013 Hedging Position Five [Member] | Oil [Member]
Hedging Positions
Daily Volume	1,000
Swap Price	103.00
2013 Hedging Position Six [Member] | Oil [Member]
Hedging Positions
Daily Volume	1,000
Swap Price	103.15
2013 Hedging Position Seven [Member] | Oil [Member]
Hedging Positions
Daily Volume	1,000
Swap Price	104.25
2013 Hedging Position Eight [Member] | Oil [Member]
Hedging Positions
Daily Volume	1,000
Swap Price	104.47
2013 Hedging Position Nine [Member] | Oil [Member]
Hedging Positions
Daily Volume	1,000
Swap Price	104.50
2013 Hedging Position Ten [Member] | Oil [Member]
Hedging Positions
Daily Volume	1,000
Swap Price	107.30
2014 Hedging Position One [Member] | Oil [Member]
Hedging Positions
Daily Volume	1,000
Swap Price	98.00
2014 Hedging Position Two [Member] | Oil [Member]
Hedging Positions
Daily Volume	1,000
Swap Price	98.30
2014 Hedging Position Three [Member] | Oil [Member]
Hedging Positions
Daily Volume	1,000
Swap Price	99.65
2014 Hedging Position Four [Member] | Oil [Member]
Hedging Positions
Daily Volume	1,000
Swap Price	$ 103.30

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Guarantor Financial Statements (Details 1) (USD $) In Thousands, unless otherwise specified	3 Months Ended
	Mar. 31, 2012	Mar. 31, 2011
Operating revenue:
Oil production	$ 201,758	$ 151,995
Gas production	28,857	41,160
Natural gas liquids production	13,452	5,999
Other operational income	890	885
Total operating revenue	244,957	200,039
Operating expenses:
Lease operating expenses	44,480	38,287
Transportation, processing and gathering expenses	3,657	1,820
Other operational expense	42	662
Production taxes	3,378	2,535
Depreciation, depletion and amortization	84,575	67,669
Accretion expense	8,266	7,717
Salaries, general and administrative expenses	13,705	11,733
Incentive compensation expense	1,442	2,684
Derivative expense, net	485	2,180
Total operating expenses	160,030	135,287
Income from operations	84,927	64,752
Other (income) expenses:
Interest expense	5,731	3,111
Interest income	(31)	(94)
Other income	(420)	(564)
Other expense		124
Total other expenses	5,280	2,577
Net income before income taxes	79,647	62,175
Provision for income taxes:
Current	1,234
Deferred	27,439	22,383
Total income taxes	28,673	22,383
Net income	50,974	39,792
Comprehensive income (loss)	28,909	7,318
Parent [Member]
Operating revenue:
Oil production	6,234	786
Gas production	5,631	1,280
Natural gas liquids production	3,864
Other operational income	694	722
Total operating revenue	16,423	2,788
Operating expenses:
Lease operating expenses	4,904	356
Transportation, processing and gathering expenses	2,488
Other operational expense	42
Production taxes	1,163	147
Depreciation, depletion and amortization	11,477	5,942
Accretion expense	148	4
Salaries, general and administrative expenses	12,654	11,731
Incentive compensation expense	1,442	2,684
Total operating expenses	34,318	20,864
Income from operations	(17,895)	(18,076)
Other (income) expenses:
Interest expense	5,846	3,031
Interest income	(30)	(88)
Other income	(19)
Other expense		123
(Income) loss from investment in subsidiaries	(66,137)	(53,323)
Total other expenses	(60,340)	(50,257)
Net income before income taxes	42,445	32,181
Provision for income taxes:
Current	1,234
Deferred	(9,763)	(7,611)
Total income taxes	(8,529)	(7,611)
Net income	50,974	39,792
Comprehensive income (loss)	28,909	7,318
Guarantor Subsidiary [Member]
Operating revenue:
Oil production	195,524	151,209
Gas production	23,226	39,880
Natural gas liquids production	9,588	5,999
Other operational income	63	(19)
Total operating revenue	228,401	197,069
Operating expenses:
Lease operating expenses	39,387	37,931
Transportation, processing and gathering expenses	1,169	1,820
Other operational expense		662
Production taxes	2,215	2,388
Depreciation, depletion and amortization	73,000	61,510
Accretion expense	8,032	7,622
Salaries, general and administrative expenses	1,051	2
Derivative expense, net	485
Total operating expenses	125,339	114,115
Income from operations	103,062	82,954
Other (income) expenses:
Interest expense	(115)	80
Interest income	(1)	(6)
Other income	(401)	(567)
Other expense		1
(Income) loss from investment in subsidiaries	239	129
Total other expenses	(278)	(363)
Net income before income taxes	103,340	83,317
Provision for income taxes:
Deferred	37,202	29,994
Total income taxes	37,202	29,994
Net income	66,138	53,323
Comprehensive income (loss)	66,138	53,323
Non-Guarantor Subsidiaries [Member]
Operating revenue:
Other operational income	133	182
Total operating revenue	133	182
Operating expenses:
Lease operating expenses	189
Depreciation, depletion and amortization	98	217
Accretion expense	86	91
Total operating expenses	373	308
Income from operations	(240)	(126)
Other (income) expenses:
Other income		3
Total other expenses		3
Net income before income taxes	(240)	(129)
Provision for income taxes:
Net income	(240)	(129)
Comprehensive income (loss)	(240)	(129)
Eliminations [Member]
Other (income) expenses:
(Income) loss from investment in subsidiaries	65,898	53,194
Total other expenses	65,898	53,194
Net income before income taxes	(65,898)	(53,194)
Provision for income taxes:
Net income	(65,898)	(53,194)
Comprehensive income (loss)	$ (65,898)	$ (53,194)

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Acquisitions (Tables)

3 Months Ended

Mar. 31, 2012

Acquisitions [Abstract]

Allocation of the recorded value of net assets acquired in the transaction

	(in millions)
Proved oil and gas properties	$	208.7
Unevaluated oil and gas properties		17.3
Asset retirement obligations		(58.4	)
Total fair value of net assets	$	167.6

Pro forma combined statement of operations data

	Three Months Ended March 31, 2011 (unaudited)
	(in millions, except per share amounts)
Revenues	$	241.1
Income from operations		91.4
Net income		55.9
Basic earnings per share	$	1.14
Diluted earnings per share	$	1.14