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Stone Energy Corporation (SGY) today announced financial and operational results for the third quarter of 2014. Some of the highlights include:

  • Accelerated production schedule at Cardona/Cardona South development project
  • Executed attractive multi-year rig contract for deep water drilling program
  • Drilled Utica well; production test in fourth quarter
  • Closed sale of non-core conventional shelf assets
  • Production results slightly above upper guidance

Chairman, President and Chief Executive Officer David Welch stated, “In the third quarter of 2014, we continued to make progress in our development efforts as well as move forward on our exploration projects.  In the Gulf of Mexico, we expect to have the deep water Cardona development project on production by December 2014, which would boost our production exit rate for the year. We are participating in the Madison deep water exploration well which is currently drilling, and will participate in the Vernaccia deep water exploration prospect which is scheduled to spud in early 2015.  In Appalachia, we have finished drilling our Utica test well and expect to flow first production within the next few weeks.  Due to efficiencies, we now expect to drill over 35 wells in our Marcellus program this year. Despite our recent shelf and onshore properties sales, we expect to see a production increase in the fourth quarter over the third quarter of 2014.  Our cash position remains strong and we are excited about our outlook for 2015 and beyond.”

Financial Results

Stone earned third quarter 2014 adjusted net income of $0.7 million, or $0.01 per share, on oil and natural gas revenues of $175.0 million, before a pre-tax non-cash charge of $47.1 million related to the impairment of oil and gas properties.  The non-cash impairment of oil and gas properties is primarily due to lower oil and gas prices, widening basis differentials and increased transportation, processing and gathering expenses in Appalachia which reduced the future net cash flows from proved reserves.  If the net capitalized costs of proved oil and gas properties exceed the estimated discounted future net cash flows from proved reserves, an impairment occurs. After the non-cash impairment charge, the reported net loss was $29.4 million for the third quarter of 2014.  Please see “Non-GAAP Financial Measures” and the accompanying financial statements for a reconciliation of adjusted net income, a non-GAAP financial measure, to net loss.

The third quarter 2014 loss is compared to net income of $4.4 million, or $0.08 per share, on oil and natural gas revenue of $205.0 million in the second quarter of 2014, and compared to net income of $36.1 million, or $0.72 per share, on oil and natural gas revenue of $255.8 million in the third quarter of 2013.  Lower realized oil and natural gas prices and lower production due to the sale of non-core properties were the primary causes of the reduced earnings in the third quarter of 2014 compared to the second quarter of 2014.

Discretionary cash flow totaled $92.2 million during the third quarter of 2014, as compared to $117.5 million during the second quarter of 2014, and as compared to $166.1 million during the third quarter of 2013. Please see “Non-GAAP Financial Measures” and the accompanying financial statements for a reconciliation of discretionary cash flow, a non-GAAP financial measure, to net cash flow provided by operating activities.

Net daily production during the third quarter of 2014 averaged 39.6 thousand barrels of oil equivalent (MBoe) per day (237 MMcfe per day), compared with net daily production of 44.1 MBoe (264 MMcfe) per day in the second quarter of 2014, and net daily production of 49.4 MBoe (296 MMcfe) per day in the third quarter of 2013.  Production volumes in the third quarter of 2014 were impacted by the sale of non-core conventional shelf and onshore properties.  Third quarter of 2014 production mix was 36% oil, 14% natural gas liquids and 50% natural gas.

On July 31, 2014, Stone completed the sale of its non-core Gulf of Mexico conventional shelf properties to Talos Energy Offshore LLC for cash consideration of approximately $178 million, after giving effect to preliminary purchase price adjustments.  Talos also assumed related future undiscounted abandonment liabilities.  Production volumes associated with these properties averaged approximately 48 million cubic feet of gas equivalent (MMcfe) per day (58% natural gas) in July 2014.

Prices realized during the third quarter of 2014 averaged $93.15 per barrel of oil, $42.45 per barrel of NGLs and $2.77 per Mcf of natural gas.  Average realized prices for the third quarter of 2013 were $103.16 per barrel of oil, $38.77 per barrel of NGLs and $3.80 per Mcf of natural gas. Effective hedging transactions did not increase or decrease the average realized price of natural gas and decreased the average realized price of oil by $1.02 per barrel in the third quarter of 2014.  Ineffective hedging on gas provided approximately $5.8 million in derivative income for the third quarter of 2014. Effective hedging transactions increased the average realized price of natural gas by $0.39 per Mcf and decreased the average realized price of oil by $4.14 per barrel in the third quarter of 2013.

Lease operating expenses during the third quarter of 2014 totaled $43.6 million ($11.97 per Boe or $2.00 per Mcfe), compared to $54.0 million ($11.88 per Boe or $1.98 per Mcfe), in the third quarter of 2013.  We expect lease operating expenses to continue to decline in the fourth quarter of 2014 to reflect the sale of non-core shelf properties in the third quarter.

Transportation, processing and gathering expenses during the third quarter of 2014 totaled $16.7 million ($4.59 per Boe or $0.77 per Mcfe) compared to $13.1 million ($2.88 per Boe or $0.48 per Mcfe) in the third quarter of 2013.  The increase is attributable to higher gas and NGL volumes in Appalachia which has a higher associated charge per unit.

Depreciation, depletion and amortization (DD&A) on oil and gas properties for the third quarter of 2014 totaled $79.2 million ($21.77 per Boe or $3.63 per Mcfe), compared to $91.9 million ($20.23 per Boe or $3.37 per Mcfe), in the third quarter of 2013.  The decrease in DD&A is attributable to increased booked reserves as a result of successful drilling efforts in Appalachia and the sale of non-core conventional shelf properties.

Salaries, general and administrative (SG&A) expenses for the third quarter of 2014 were $16.3 million ($4.48 per Boe or $0.75 per Mcfe), compared to $14.2 million ($3.12 per Boe or $0.52 per Mcfe), in the third quarter of 2013.  The increase in SG&A was attributable to increased staffing and compensation adjustments.

Capital expenditures before capitalized SG&A and interest during the third quarter of 2014 were approximately $147.1 million, which includes $22.3 million of plugging and abandonment expenditures.  Additionally, $7.9 million of SG&A and $10.8 million of interest were capitalized during the third quarter of 2014.  This is compared to capital expenditures before capitalized SG&A and interest during the third quarter of 2013 of approximately $161.6 million, which includes $23.8 million of plugging and abandonment expenditures.  Additionally, $8.5 million of SG&A and $11.9 million of interest were capitalized during the third quarter of 2013.  Based on the results of our drilling programs in 2014, additional capital requirements have been identified.  On September 29, 2014, Stone announced that its Board of Directors authorized a $70 million increase of the 2014 capital expenditure budget, from $825 million to $895 million.

As of September 30 and November 3, 2014, there were no outstanding borrowings under the bank credit facility and $19.2 million in letters of credit had been issued, leaving $480.8 million of availability.  In October 2014, our $500 million borrowing base was reaffirmed.  As of November 3, 2014, we had cash on hand of approximately $307 million inclusive of $177.6 million of restricted cash, which will become available on January 27, 2015.

Operational Update   

Deep Water Drilling Program (Gulf of Mexico). On October 6, 2014, Stone Energy entered into an agreement to contract the ENSCO 8503 dynamically positioned deep water drilling rig for Stone’s multi-year deep water drilling program in the Gulf of Mexico.  The primary contract term is for 30 months and is expected to commence during the second quarter of 2015 at a rate of approximately $350,000 per day.  The contract permits Stone to exercise options to extend the term up to an additional 12 months.  Subject to notification no later than March 31, 2015, Stone may reduce the 30 month primary term contract by up to six months.

Mississippi Canyon 29 – Cardona and Cardona South (Deep Water).  Final equipment installation operations are being completed and initial production is estimated to begin on December 1, 2014.  Both wells will flow to the Stone owned (100%) and operated Pompano platform.  The combined gross rate is expected to be approximately 12,000 barrels of oil equivalent per day, with stable production expected by early first quarter of 2015.  The Cardona and Cardona South successes extend the productive zone of the Mississippi Canyon 29 TB-9 well to the adjacent fault blocks to the north and south.  In the southern fault block Stone expects to drill two additional development wells, Cardona 6 and Cardona 7, the first two wells scheduled to be drilled with the ENSCO 8503 deep water drilling rig.  Stone holds a 65% working interest in the project and is the operator.

Mississippi Canyon 26 – Amethyst (Deep Water).  Long lead items have been ordered for a single well tie-back to the Stone owned and operated Pompano platform, located less than five miles from the discovery.  Production is expected to begin in 2016.  The Amethyst discovery (100% working interest) encountered approximately 90 feet of net hydrocarbon pay in early 2014.

Development Drill Programs – Amberjack and Pompano (Deep Water).  Stone expects to secure platform drilling rigs for its Amberjack (Mississippi Canyon 109) and Pompano (Viosca Knoll 989) drill programs in 2015 and 2016.  Each program may consist of 4 to 6 development wells.

Mississippi Canyon 479 – Madison (Deep Water).  The Madison exploration well targets the Miocene interval and spud in late October of 2014.  Stone currently controls a 40% working interest in the prospect, which is operated by Noble Energy.  The well is expected to reach target depth of 16,775 feet in early 2015.

Mississippi Canyon 34 and 35 – Vernaccia (Deep Water).  The Vernaccia exploration well targets the Miocene interval and is projected to spud in the first quarter of 2015.  Stone currently controls an approximate 32% working interest in the prospect, which is operated by Eni.  The well is estimated to take three months to drill.

Mississippi Canyon 118 – Harrier (Deep Water).  The Harrier exploration well targets the Miocene interval and is projected to spud in the first half of 2015.  Stone currently controls a 37% working interest in the prospect, which is operated by ConocoPhillips.  The well is estimated to take four months to drill.

Walker Ridge 89 – Goodfellow (Deep Water).  The Goodfellow exploration well targets the Lower Tertiary and is projected to spud in late 2015.  Stone currently holds an approximate 13% working interest in the prospect, which is operated by Eni.  The well is estimated to take five months to drill.

Utica Shale Test (Appalachian Basin).  During the second and third quarters of 2014, Stone drilled a horizontal test well through the Utica shale formation with a true vertical depth of 11,350 feet, including a horizontal lateral which extends through the Point Pleasant shale formation to a length of 3,600 feet.  Completion operations and production will commence in the fourth quarter of 2014.

Marcellus Shale Drilling Program Update (Appalachian Basin).  Stone drilled nine horizontal Marcellus shale wells and performed completion operations on 14 wells during the third quarter of 2014.  Due to increased drilling efficiencies, Stone has made an upward revision to the previously forecasted range of over 32 wells to a current forecast of over 35 wells drilled in 2014.

Marcellus Shale Production Update (Appalachian Basin).   During the third quarter of 2014, Stone averaged approximately 106 MMcfe per day (73 MMcf per day of gas and 5,500 barrels per day of liquids) from Stone’s Marcellus shale position, which includes initial production from the 10-well Howell pad in the Mary field.  In addition, Stone plans to bring online the 8-well Stone pad, and the 5-well Pribble pad (includes Utica test well) during the fourth quarter of 2014, and the 8-well ZMBG pad in January 2015.

South Erath Deep (Deep Gas).  The South Erath Deep exploration well spud in August of 2014.   Stone holds a 17% working interest in the project which is operated by Hilcorp. The well is drilling ahead at 16,250 feet and is expected to reach the target depth of 20,000 feet in December of 2014.

La Montana (Deep Gas).  A rig has been identified for the La Montana exploration well, which is expected to spud in late 2014 or the first half of 2015.   Stone holds a 45% working interest in the project and is the operator.  The well is estimated to take four months to drill.

Cayenne (Deep Gas).  The Cayenne exploration well, slated to use the same rig as the La Montana exploration well, is expected to spud in the second or third quarter of 2015.   Stone holds a 50% working interest in the project and is the operator. The well is estimated to take four months to drill.

2014 Guidance

Guidance for the fourth quarter and full year 2014 is shown in the table below (updated guidance numbers are italicized and bolded).  The guidance for Production and Lease operating expenses has been adjusted to account for the sale of the non-core conventional shelf properties, which closed on July 31, 2014.  Based on the results of our drilling programs throughout 2014, we have additional capital requirements, which required an increase in our capital expenditure budget for 2014.  In September 2014, the Board of Directors increased the capital expenditure budget by $70 million to $895 million, which is reflected below.  The guidance is subject to all the cautionary statements and limitations described below and under the caption “Forward Looking Statements.”

Fourth Quarter

Full Year

Production – MBoe per day

40 – 44

 42 – 43

                   (MMcfe per day)

(240 – 264)

(252 – 258)

Lease operating expenses (in millions)

(excluding transportation/processing expenses)

$175 – $185

Transportation, processing and gathering (in millions)

$62 – $68

Salaries, General & Administrative expenses (in millions)

$65 – $69

(excluding incentive compensation)

Depreciation, Depletion & Amortization (per Boe)

$21.00 – $22.50

                                                              (per Mcfe)

$3.50 – $3.75

Corporate Tax Rate (%)

36% – 38%

Capital Expenditure Budget (in millions)

           (excluding acquisitions)

$895

 

Hedge Position

The following table illustrates our derivative positions for 2014, 2015 and 2016 as of November 3, 2014:

Fixed-Price Swaps

NYMEX (except where noted)

Natural Gas

Oil

Daily

Volume

(MMBtus/d)

SwapPrice

Daily

Volume

(Bbls/d)

Swap

Price

2014

10,000

$4.000

1,000

$90.06

2014

10,000

4.040

    1,000**

90.25

2014

10,000

4.105

1,000

92.25

2014

10,000

4.190

1,000

93.55

2014

  10,000*

4.250

1,000

94.00

2014

10,000

4.250

1,000

98.00

2014

10,000

4.350

1,000

98.30

2014

      2,000***

98.85

2014

1,000

99.65

2014

  1,000†

103.30

2015

10,000

4.005

1,000

89.00

2015

10,000

4.120

1,000

90.00

2015

10,000

4.150

1,000

90.25

2015

10,000

4.165

1,000

90.40

2015

10,000

4.220

1,000

91.05

2015

10,000

4.255

1,000

93.28

2015

1,000

93.37

2015

1,000

94.85

2015

1,000

95.00

2016

10,000

4.110

1,000

90.00

2016

10,000

4.120

 

*

February – December

**

October – December

***

January – June

Brent oil contract

 

Other Information

Stone Energy has planned a conference call for 9:00 a.m. Central Time on November 4, 2014 to discuss the operational and financial results for the third quarter of 2014. Anyone wishing to participate should visit our website at www.StoneEnergy.com for a live web cast or dial 1-877-228-3598 and request the “Stone Energy Call.”  If you are unable to participate in the original conference call, a replay will be available immediately following the completion of the call on Stone Energy’s website.  The replay will be available for one month.

Non-GAAP Financial Measures

In this press release, we refer to non-GAAP financial measures we call “discretionary cash flow” and “adjusted net income.” Management believes that these non-GAAP financial measures of discretionary cash flow and adjusted net income are useful to investors because they are widely used by professional research analysts in the valuation, comparison, rating and investment recommendations of companies in the oil and gas exploration and production industry. Management believes that discretionary cash flow is a financial indicator of our company’s ability to internally fund capital expenditures and service debt.  Discretionary cash flow should not be considered an alternative to net cash provided by operating activities or net income or loss, as defined by GAAP.  Please see the “Reconciliation of Non-GAAP Financial Measures” for a reconciliation of discretionary cash flow to cash flow provided by operating activities and a reconciliation of adjusted net income to net loss.

Forward Looking Statements

Certain statements in this press release are forward-looking and are based upon Stone’s current belief as to the outcome and timing of future events. All statements, other than statements of historical facts, that address activities that Stone plans, expects, believes, projects, estimates or anticipates will, should or may occur in the future, including future production of oil and gas, future capital expenditures and drilling of wells and future financial or operating results are forward-looking statements.  Important factors that could cause actual results to differ materially from those in the forward-looking statements herein include the timing and extent of changes in commodity prices for oil and gas, operating risks, liquidity risks, political and regulatory developments and legislation, including developments and legislation relating to our operations in the Gulf of Mexico and Appalachia, and other risk factors and known trends and uncertainties as described in Stone’s Annual Report on Form 10-K and Quarterly Reports on Form 10-Q as filed with the SEC. Should one or more of these risks or uncertainties occur, or should underlying assumptions prove incorrect, Stone’s actual results and plans could differ materially from those expressed in the forward-looking statements.

Estimates for Stone’s future production volumes are based on assumptions of capital expenditure levels and the assumption that market demand and prices for oil and gas will continue at levels that allow for economic production of these products. The production, transportation and marketing of oil and gas are subject to disruption due to transportation and processing availability, mechanical failure, human error, hurricanes and numerous other factors.  Stone’s estimates are based on certain other assumptions, such as well performance, which may vary significantly from those assumed. Delays experienced in well permitting could affect the timing of drilling and production. Lease operating expenses, which include major maintenance costs, vary in response to changes in prices of services and materials used in the operation of our properties and the amount of maintenance activity required.  Estimates of DD&A rates can vary according to reserve additions, capital expenditures, future development costs and other factors. Therefore, we can give no assurance that our future production volumes, lease operating expenses or DD&A rates will be as estimated.

Stone Energy is an independent oil and natural gas exploration and production company headquartered in Lafayette, Louisiana with additional offices in New Orleans, Houston and Morgantown, West Virginia. Stone is engaged in the acquisition, exploration, and development of properties in the Deep Water Gulf of Mexico, Appalachia, and the onshore and offshore Gulf Coast. For additional information, contact Kenneth H. Beer, Chief Financial Officer, at 337-521-2210 phone, 337-521-9880 fax or via e-mail at CFO@StoneEnergy.com.

 

STONE ENERGY CORPORATION

SUMMARY STATISTICS

(In thousands, except per share/unit amounts)

(Unaudited)

Three Months Ended

September 30,

Nine Months Ended

September 30,

2014

2013

2014

2013

FINANCIAL RESULTS

    Net income (loss)

($29,415)

$36,102

$972

$115,882

    Net income (loss) per share

($0.54)

$0.72

$0.02

$2.32

PRODUCTION QUANTITIES

    Oil (MBbls)

1,329

1,809

4,228

5,243

    Gas (MMcf)

10,891

13,866

35,895

35,969

    Natural gas liquids (MBbls)

495

425

1,472

1,048

    Oil, gas and NGLs (MBoe)

3,639

4,545

11,683

12,286

    Oil, gas and NGLs (MMcfe)

21,835

27,270

70,095

73,715

AVERAGE DAILY PRODUCTION

    Oil (MBbls)

14.4

19.7

15.5

19.2

    Gas (MMcf)

118.4

150.7

131.5

131.8

    Natural gas liquids (MBbls)

5.4

4.6

5.4

3.8

    Oil, gas and NGLs (MBoe)

39.6

49.4

42.8

45.0

    Oil, gas and NGLs (MMcfe)

237.3

296.4

256.8

270.0

REVENUE DATA

    Oil revenue

$123,795

$186,608

$404,477

$558,031

    Gas revenue

30,154

52,728

133,183

137,382

    Natural gas liquids revenue

21,014

16,476

64,920

36,854

    Total oil, gas and NGL revenue

$174,963

$255,812

$602,580

$732,267

AVERAGE PRICES

  Prior to the cash settlement of effective hedging transactions:

  Oil (per Bbl)

$94.17

$107.30

$98.03

$105.98

  Gas (per Mcf)

2.77

3.41

3.92

3.50

  Natural gas liquids (per Bbl)

42.45

38.77

44.10

35.17

  Oil, gas and NGLs (per Boe)

48.45

56.75

53.09

58.48

  Oil, gas and NGLs (per Mcfe)

8.07

9.46

8.85

9.75

  Including the cash settlement of effective hedging transactions:

  Oil (per Bbl)

$93.15

$103.16

$95.67

$106.43

  Gas (per Mcf)

2.77

3.80

3.71

3.82

  Natural gas liquids (per Bbl)

42.45

38.77

44.10

35.17

  Oil, gas and NGLs (per Boe)

48.08

56.28

51.58

59.60

  Oil, gas and NGLs (per Mcfe)

8.01

9.38

8.60

9.93

COST DATA

  Lease operating expenses

$43,561

$53,986

$139,918

$157,547

  Salaries, general and administrative expenses

16,286

14,201

49,252

43,351

  DD&A expense on oil and gas properties

79,213

91,932

252,922

252,759

AVERAGE COSTS

  Lease operating expenses (per Boe)

$11.97

$11.88

$11.98

$12.82

  Lease operating expenses (per Mcfe)

2.00

1.98

2.00

2.14

  Salaries, general and administrative expenses (per Boe)        

4.48

3.12

4.22

3.53

 Salaries, general and administrative expenses (per Mcfe)        

0.75

0.52

0.70

0.59

  DD&A expense on oil and gas properties (per Boe)

21.77

20.23

21.65

20.57

  DD&A expense on oil and gas properties (per Mcfe)

3.63

3.37

3.61

3.43

AVERAGE SHARES OUTSTANDING – Diluted

54,866

48,776

52,139

48,720

 

STONE ENERGY CORPORATION

CONSOLIDATED STATEMENT OF OPERATIONS

(In thousands)

(Unaudited)

Three Months Ended

September 30,

Nine Months Ended

September 30,

2014

2013

2014

2013

Operating revenue:

  Oil production

$123,795

$186,608

$404,477

$558,031

  Gas production

30,154

52,728

133,183

137,382

  Natural gas liquids production

21,014

16,476

64,920

36,854

  Other operational income

2,468

873

5,515

2,659

  Derivative income, net

5,782

2,667

    Total operating revenue

183,213

256,685

610,762

734,926

Operating expenses:

  Lease operating expenses

43,561

53,986

139,918

157,547

  Transportation, processing and  gathering

16,721

13,081

45,445

27,374

  Other operational expense

298

237

510

382

  Production taxes

3,651

5,224

9,970

11,404

  Depreciation, depletion and amortization

80,291

92,853

255,772

255,497

  Write-down of Oil & Gas Properties

47,130

47,130

  Accretion expense

6,539

8,431

21,827

25,012

  Salaries, general and administrative expenses

16,286

14,201

49,252

43,351

  Incentive compensation expense

3,092

4,566

10,129

8,047

  Derivative expense, net

1,684

1,537

    Total operating expenses

217,569

194,263

579,953

530,151

Income (loss) from operations

(34,356)

62,422

30,809

204,775

Other (income) expenses:

  Interest expense

10,323

7,922

28,593

26,452

  Interest income

(169)

(1,311)

(505)

(1,543)

  Other income, net

(695)

(782)

(2,124)

(2,190)

  Other expense

95

274

    Total other expenses

9,554

5,829

26,238

22,719

Income (loss) before taxes

(43,910)

56,593

4,571

182,056

Provision (benefit) for income taxes:

  Current

(88)

(10,827)

  Deferred

(14,495)

20,579

3,599

77,001

    Total income taxes

(14,495)

20,491

3,599

66,174

Net income (loss)

($29,415)

$36,102

$972

$115,882

 

STONE ENERGY CORPORATION

RECONCILIATION OF NON-GAAP FINANCIAL MEASURE DISCRETIONARY CASH FLOW

(In thousands)

(Unaudited)

Three Months Ended

September 30,

Nine Months Ended

September 30,

2014

2013

2014

2013

Net income (loss) as reported

($29,415)

$36,102

$972

$115,882

Reconciling items:

Depreciation, depletion and amortization

80,291

92,853

255,772

255,497

Write-down of Oil & Gas Properties

47,130

47,130

Deferred income tax (benefit) provision

(14,495)

20,579

3,599

77,001

Accretion expense

6,539

8,431

21,827

25,012

Stock compensation expense

3,051

2,717

8,409

7,583

Non-cash interest expense

4,164

4,203

12,393

12,384

Other

(5,083)

1,263

(2,386)

1,470

Discretionary cash flow

92,182

166,148

347,716

494,829

Changes in income taxes payable

15,695

(6)

(704)

Settlement of asset retirement obligations

(22,302)

(23,843)

(47,217)

(61,178)

Other working capital changes

5,560

5,537

31,907

6,563

Net cash provided by operating activities

$75,440

$163,537

$332,400

$439,510

 

STONE ENERGY CORPORATION

RECONCILIATION OF NON-GAAP FINANCIAL MEASURE

ADJUSTED NET INCOME TO NET LOSS

(In thousands, except per share amounts)

(Unaudited)

Three Months Ended

Nine Months Ended

September 30, 2014

September 30, 2014

Net income (loss) as reported

($29,415)

$972

Reconciling items:

  Write-down of Oil & Gas Properties

47,130

47,130

  Tax effect

16,967

16,967

Total reconciling items net of tax

30,163

30,163

Adjusted net income

$748

$31,135

Net income (loss) per share as reported

($0.54)

$0.02

Per share effect of reconciling items

$0.55

$0.58

Net income per share effect of reconciling items

$0.01

$0.60

 

STONE ENERGY CORPORATION

CONSOLIDATED BALANCE SHEET

(In thousands)

(Unaudited)

September 30,

December 31,

2014

2013

Assets

Current assets:

         Cash and cash equivalents

$180,307

$331,224

         Restricted cash

177,647

         Accounts receivable

173,775

171,971

         Fair value of derivative contracts

16,635

4,549

         Current income tax receivable

7,373

7,366

         Deferred taxes

24,036

31,710

         Inventory

3,709

3,723

         Other current assets

1,884

1,874

        Total current assets

585,366

552,417

Oil and gas properties, full cost method of accounting:

Proved

8,692,017

7,804,117

Less: accumulated depreciation, depletion and amortization

(6,568,551)

(5,908,760)

Net proved oil and gas properties

2,123,466

1,895,357

Unevaluated

570,658

724,339

Other property and equipment, net

32,118

26,178

Fair value of derivative contracts

6,481

1,378

Other assets, net

40,860

48,887

         Total assets

$3,358,949

$3,248,556

Liabilities and Stockholders’ Equity

Current liabilities:

         Accounts payable to vendors

121,485

195,677

         Undistributed oil and gas proceeds

58,503

37,029

         Accrued interest

22,240

9,022

         Fair value of derivative contracts

156

7,753

         Asset retirement obligations

73,451

67,161

         Other current liabilities

57,630

54,520

         Total current liabilities

333,465

371,162

7½% Senior Notes due 2022

775,000

775,000

1¾% Senior Convertible Notes due 2017

262,440

252,084

Deferred taxes

394,846

390,693

Asset retirement obligations

336,197

435,352

Fair value of derivative contracts

24

470

Other long-term liabilities

41,350

53,509

        Total liabilities

2,143,322

2,278,270

Common stock

549

488

Treasury stock

(860)

(860)

Additional paid-in capital

1,628,942

1,397,885

Accumulated deficit

(424,193)

(425,165)

Accumulated other comprehensive income (loss)

11,189

(2,062)

         Total stockholders’ equity

1,215,627

970,286

         Total liabilities and stockholders’ equity

$3,358,949

$3,248,556