STONE ENERGY CORPORATION LAFAYETTE, La., Aug. 5, 2015 /PRNewswire/ -- Stone Energy Corporation (NYSE: SGY) today announced financial and operational results for the second quarter of 2015. Some of the highlights include:
-- Production volumes exceeded the upper end of second quarter 2015
guidance.
-- Cardona #6 well was drilled and completed under budget and is expected
to come on line by the end of the third quarter.
-- Recognized an upward working interest adjustment to a number of wells in
the Mary field in Appalachia.
-- Quarter-end cash position of $142 million and an undrawn $500 million
bank facility.
Chairman, President and Chief Executive Officer David Welch stated, "Despite a difficult macro environment, we showed solid production from our base properties and maintained a good liquidity position at quarter-end. We expect to have volumes from our Cardona #6 well on by the fourth quarter of 2015 and production from Amethyst by the first quarter of 2016. For the next several quarters, we have narrowed most of our capital expenditure activity to our deep water development program, followed by our high potential Lamprey exploration project, targeted for early in 2016. We are focused on our liquidity and are aggressively taking steps to reduce costs and capital expenditures."
Financial Results
Stone Energy had a second quarter 2015 adjusted net loss of $9.4 million, or $0.17 per share, before pre-tax non-cash impairment charges of $224.3 million ($143.5 million net of taxes). The impairment charge was primarily due to lower oil, NGL and natural gas prices used in calculating the full cost ceiling and an impairment due to an unsuccessful exploration venture in Canada. After impairment charges, the reported net loss was $152.9 million, or $2.77 per share, on oil and gas revenue of $149.5 million, compared to net income of $4.4 million, or $0.08 per share, on oil and gas revenue of $205.0 million in the second quarter of 2014.
Discretionary cash flow totaled $84.9 million during the second quarter of 2015, as compared to $117.5 million during the second quarter of 2014. Please see "Non-GAAP Financial Measures" and the accompanying financial statements for reconciliations of discretionary cash flow, a non-GAAP financial measure, to net cash flow provided by operating activities and adjusted net loss, a non-GAAP financial measure, to net loss.
During the second quarter of 2015, Stone realized an increase in working interest in multiple wells at the Mary field in Appalachia, resulting from the non-election to participate by potential partners. The acquired interest percentage ranged from approximately 9% to 25% at multiple pads at varying ownership levels, and incorporates a time period ranging from one quarter to over one year, depending on the well. Production volumes recognized in the second quarter that were attributable to previous quarters totaled approximately 18 MMcfe per day (1.7 Bcfe in aggregate) and resulted in minimal impact to the financial results.
Net daily production during the second quarter of 2015 averaged 49 thousand barrels of oil equivalent (MBoe) per day (292 million cubic feet of gas equivalent (MMcfe) per day), compared with net daily production of 46 MBoe (278 MMcfe) per day in the first quarter of 2015, and net daily production of 44 MBoe (264 MMcfe) per day in the second quarter of 2014. As previously highlighted, approximately 3 MBoe or 18 MMcfe per day of production realized in the second quarter of 2015 resulted from prior period adjustments in working interest in Appalachia. Second quarter of 2015 production mix was 35% oil, 18% natural gas liquids (NGLs) and 47% natural gas, which was partially impacted by incremental gas volumes due to the working interest adjustment. Production guidance for the third quarter of 2015 is estimated at 39 - 41 MBoe per day, or 234-246 MMcfe per day.
Updated guidance for the third quarter and full year of 2015, which incorporates the adjusted Appalachian working interest position, can be found under the section titled "2015 Guidance".
Prices realized during the second quarter of 2015 averaged $72.74 per barrel of oil, $13.90 per barrel of NGLs and $2.14 per Mcf of natural gas. Average realized prices for the second quarter of 2014 were $96.15 per barrel of oil, $34.12 per barrel of NGLs and $3.77 per Mcf of natural gas. Effective hedging transactions increased the average realized price of natural gas by $0.32 per Mcf and increased the average realized price of oil by $17.19 per barrel in the second quarter of 2015. Effective hedging transactions decreased the average realized price of natural gas by $0.26 per Mcf and decreased the average realized price of oil by $4.15 per barrel in the second quarter of 2014.
Lease operating expenses during the second quarter of 2015 totaled $27.4 million ($6.20 per Boe or $1.03 per Mcfe), compared to $49.5 million ($12.34 per Boe or $2.06 per Mcfe), in the second quarter of 2014. The decrease is primarily attributable to the sale of the non-core conventional shelf assets in July of 2014 as well as recent service cost reductions and increased operational efficiencies.
Transportation, processing and gathering expenses during the second quarter of 2015 totaled $19.9 million ($4.51 per Boe or $0.75 per Mcfe), compared to $14.1 million ($3.52 per Boe or $0.59 per Mcfe) during the second quarter of 2014. Transportation, processing and gathering expenses recognized in the second quarter that are attributable to previous quarters totaled approximately $2 million. The annual increase is primarily attributable to higher Appalachian gas and NGL volumes.
Depreciation, depletion and amortization (DD&A) on oil and gas properties for the second quarter of 2015 totaled $76.8 million ($17.35 per Boe or $2.89 per Mcfe), compared to $91.9 million ($22.93 per Boe or $3.82 per Mcfe), in the second quarter of 2014. Included in the $224.3 million write-down of oil and gas properties in the second quarter 2015 was a $45.2 million impairment of our Canadian investment where results from a multi-year exploration initiative were not successful.
Salaries, general and administrative (SG&A) expenses for the second quarter of 2015 were $16.4 million ($3.71 per Boe or $0.62 per Mcfe), compared to $16.6 million ($4.15 per Boe or $0.69 per Mcfe), in the second quarter of 2014.
Capital expenditures for the second quarter of 2015 were approximately $91.1 million, which includes $18.8 million of plugging and abandonment expenditures, and the sale of a deep water lease block for $10.1 million. Additionally, $7.4 million of SG&A expenses and $10.8 million of interest were capitalized during the second quarter of 2015. This compared to second quarter 2014 capital expenditures of approximately $252.9 million, which includes $15.1 million of plugging and abandonment expenditures. Additionally, $8.4 million of SG&A and $11.3 million of interest were capitalized during the second quarter of 2014. The 2015 capital expenditure budget of $450 million assumes planned sales of minority working interests in certain targeted assets. Additionally, it excludes approximately $29.5 million of capital expenditures attributable to the increased working interest in Appalachia, substantially all of which was spent in 2014.
As of June 30, 2015 and August 5, 2015, we had no outstanding borrowings under our bank credit facility. Stone had letters of credit totaling $19.2 million, resulting in $480.8 million available for borrowing under our bank credit facility, based on a borrowing base of $500 million. The $500 million borrowing base was re-affirmed on May 1, 2015 and is expected to be re-determined in October of 2015. On August 5, 2015, we had cash on hand of approximately $90 million.
Operational Update
Mississippi Canyon 29 - Cardona #6 (Deep Water). The well encountered approximately 288 feet of net pay in two intervals, similar to the Cardona #5 net pay of 275 feet. The well has been successfully cased and cemented across all productive zones, the subsea tree has been installed and completion operations are substantially finalized. The well will be tied into the existing Cardona subsea infrastructure, which flows into Stone's Pompano platform. It is expected that gross production from Cardona #6 could reach approximately 5,000 Boe per day from the lower completion by late September. The upper completion is expected to have a similar production rate and will be accessed in the future by hydraulically shifting sleeves between the upper and lower completions. Stone holds a 65% working interest in the project and is the operator.
Mississippi Canyon 35 - Vernaccia (Deep Water). The Vernaccia exploration well which targets the Miocene interval is projected to spud in late August or early September 2015 and is operated by Eni. After a recent sell down of a portion of its position, Stone now has approximately 4% working interest in the drilling cost of the well and will have an approximate 22% working interest ownership thereafter. The well is estimated to take three months to drill.
Mississippi Canyon 26 - Amethyst (Deep Water). The Amethyst discovery (100% working interest) will be completed as a single well tie-back to the Stone owned and operated Pompano platform, located less than five miles from the discovery. The ENSCO 8503 drilling rig will be outfitted with mooring capabilities prior to being mobilized to finish completion operations at the well in the fourth quarter of 2015. Production is expected to begin early in the first quarter of 2016.
Mississippi Canyon 29 - Cardona #7 (Deep Water). The Cardona #7 development well is scheduled to be drilled and completed with the ENSCO 8503 in the first quarter of 2016. It is an offset well to the existing TB-9 well in Mississippi Canyon block 29 and will be the fourth well drilled in the Cardona development program. The well will be tied back to the Pompano platform in the same looped flowline as the other three Cardona wells and is expected to add gross production volumes of approximately 5,000 Boe per day. Stone holds a 65% working interest and is the operator.
Alaminos Canyon 943 - Lamprey (Deep Water). The Lamprey exploration well is projected to spud in the second quarter of 2016. Stone currently controls 100% working interest in the prospect and is the operator. If the initial exploration well is successful, Stone plans to immediately drill an appraisal well. The initial exploration well is estimated to take two to three months to drill.
Pompano Platform Rig Development Drilling Program. Stone expects to secure a platform rig for its Pompano (Viosca Knoll 989) drill program in the fourth quarter of 2015. The program is expected to consist of three to four development wells. The rig may also be used for workovers or to drill other potential prospects located near the facility.
Appalachian Basin (Production Update). During the second quarter of 2015, Stone averaged approximately 144 MMcfe per day (94 MMcf per day of gas and 8,300 barrels per day of liquids) from its Marcellus and Utica shale positions, which excludes the 18 MMcfe per day of prior period volumes attributable to the working interests adjustment. Stone currently has a total of 25 drilled wells where completion operations have been suspended until pricing and margin improvements can be realized. A natural decline in production is expected from Stone's Appalachian basin assets throughout the remainder of 2015 as a result of suspended drilling and completion operations, but an increase is expected in annual Appalachian production from 2014 to 2015.
Appalachian Basin (Drilling Program Update). Stone finished drilling the horizontal sections of six Marcellus shale wells in early 2015 before releasing the Marcellus shale drilling rig and has ceased all further drilling operations until receiving a fit-for-purpose, hybrid rig in late 2015 or early 2016. The new rig will be capable of drilling in both the Marcellus and Utica shale formations. Stone will be evaluating optimal development plans of the Marcellus and Utica shales in the interim.
2015 Guidance
Guidance for the third quarter and full year 2015 is shown in the table below (updated guidance numbers are italicized and bolded). The guidance for the third quarter and full year of 2015 production and expenses includes the effects of the added working interests in the Appalachian basin. The guidance is also subject to all the cautionary statements and limitations described below and under the caption "Forward Looking Statements."
Third Quarter Full Year
------------- ---------
Production - MBoe per day 39 - 41 42 - 44
(MMcfe per day) (234 - 246) (252 - 264)
Lease operating expenses (in millions) - $110 - $120
(excluding transportation/processing expenses)
Transportation, processing and gathering (in millions) $67 - $73
Salaries, General & Administrative expenses (in millions) - $59 - $63
(excluding incentive compensation)
Depreciation, Depletion & Amortization (per MBoe) - $18.00 - $19.80
(per Mcfe) $3.00 - $3.30
Corporate Tax Rate (%) - 36% - 37%
Capital Expenditure Budget (in millions) - $450
(assumes planned sales of minority
working interests in certain targeted assets)
Hedge Position
The following table illustrates our derivative positions for 2015 and 2016 as of August 5, 2015:
Fixed-Price Swaps
NYMEX
-----
Natural Gas Oil
----------- ---
Daily Swap Daily Swap
Volume Price Volume Price
(MMBtus/d) (Bbls/d)
---------- --------
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
Other Information
Stone Energy has planned a conference call for 9:00 a.m. Central time on Thursday, August 6, 2015 to discuss the operational and financial results for the second quarter of 2015. 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 loss." Management believes discretionary cash flow is a financial indicator of our company's ability to internally fund capital expenditures and service debt. Management also believes this non-GAAP financial measure of cash flow is useful information to investors because it is 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. Discretionary cash flow should not be considered an alternative to net cash provided by operating activities or net income, as defined by GAAP. Management believes adjusted net income is useful to investors because it is 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. 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 loss 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, development and production of properties in the Gulf of Mexico and Appalachian basins. 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 Six Months Ended
June 30, June 30,
-------- --------
2015 2014 2015 2014
---- ---- ---- ----
FINANCIAL RESULTS
Net income (loss) ($152,906) $4,444 ($480,294) $30,387
Net income (loss) per
share ($2.77) $0.08 ($8.70) $0.59
PRODUCTION QUANTITIES
Oil (MBbls) 1,534 1,481 3,156 2,899
Gas (MMcf) 12,581 12,363 23,738 25,004
Natural gas liquids
(MBbls) 794 467 1,477 977
Oil, gas and NGLs
(MBoe) 4,425 4,009 8,589 8,043
Oil, gas and NGLs
(MMcfe) 26,549 24,051 51,536 48,260
AVERAGE DAILY PRODUCTION
Oil (MBbls) 16.9 16.3 17.4 16.0
Gas (MMcf) 138.3 135.9 131.1 138.1
Natural gas liquids
(MBbls) 8.7 5.1 8.2 5.4
Oil, gas and NGLs
(MBoe) 48.6 44.1 47.5 44.4
Oil, gas and NGLs
(MMcfe) 291.7 264.3 284.7 266.6
REVENUE DATA
Oil revenue $111,585 $142,393 $219,092 $280,682
Gas revenue 26,907 46,667 55,244 103,029
Natural gas liquids
revenue 11,033 15,936 23,399 43,906
Total oil, gas and
NGLs revenue $149,525 $204,996 $297,735 $427,617
AVERAGE PRICES
Prior to the cash settlement of
effective hedging transactions:
Oil (per Bbl) $55.55 $100.30 $50.28 $99.80
Gas (per Mcf) 1.82 4.03 2.04 4.43
Natural gas liquids
(per Bbl) 13.90 34.12 15.84 44.94
Oil, gas and NGLs (per
Boe) 26.93 53.44 26.85 55.20
Oil, gas and NGLs (per
Mcfe) 4.49 8.91 4.47 9.20
Including the cash settlement of
effective hedging transactions:
Oil (per Bbl) $72.74 $96.15 $69.42 $96.82
Gas (per Mcf) 2.14 3.77 2.33 4.12
Natural gas liquids
(per Bbl) 13.90 34.12 15.84 44.94
Oil, gas and NGLs (per
Boe) 33.79 51.13 34.66 53.17
Oil, gas and NGLs (per
Mcfe) 5.63 8.52 5.78 8.86
AVERAGE COSTS
Lease operating
expenses (per Boe) $6.20 $12.34 $6.40 $11.98
Lease operating
expenses (per Mcfe) 1.03 2.06 1.07 2.00
Transp, processing and
gathering exp (per
Boe) 4.51 3.52 4.38 3.57
Transp, processing and
gathering exp (per
Mcfe) 0.75 0.59 0.73 0.60
Salaries, general and
administrative
expenses (per Boe) 3.71 4.15 3.89 4.10
Salaries, general and
administrative
expenses (per Mcfe) 0.62 0.69 0.65 0.68
DD&A expense on oil
and gas properties
(per Boe) 17.35 22.93 18.87 21.60
DD&A expense on oil
and gas properties
(per Mcfe) 2.89 3.82 3.14 3.60
AVERAGE SHARES
OUTSTANDING - Diluted 55,251 52,373 55,216 50,727
STONE ENERGY CORPORATION
CONSOLIDATED STATEMENT OF OPERATIONS
(In thousands)
(Unaudited)
Three Months Ended Six Months Ended
June 30, June 30,
-------- --------
2015 2014 2015 2014
---- ---- ---- ----
Operating revenue:
Oil production $111,585 $142,393 $219,092 $280,682
Gas production 26,907 46,667 55,244 103,029
Natural gas liquids production 11,033 15,936 23,399 43,906
Other operational income 0 2,050 1,792 3,047
Derivative income, net 0 0 2,427 0
--- --- ----- ---
Total operating revenue 149,525 207,046 301,954 430,664
------- ------- ------- -------
Operating expenses:
Lease operating expenses 27,429 49,454 55,006 96,357
Transportation, processing and
gathering 19,940 14,098 37,643 28,724
Production taxes 1,827 3,257 4,342 6,319
Depreciation, depletion and
amortization 77,951 92,835 164,373 175,481
Write-down of oil and gas
properties 224,294 715,706
Accretion expense 6,408 7,733 12,817 15,288
Salaries, general and
administrative expenses 16,418 16,637 33,425 32,966
Incentive compensation expense 1,264 3,903 2,827 7,037
Derivative expenses, net 701 2,516 0 3,115
Other operational expenses 1,454 0 1,170 212
Total operating expenses 377,686 190,433 1,027,309 365,499
------- ------- --------- -------
Income (loss) from operations (228,161) 16,613 (725,355) 65,165
-------- ------ -------- ------
Other (income) expenses:
Interest expense 10,472 9,913 20,837 18,270
Interest income (66) (193) (188) (336)
Other income (613) (722) (756) (1,429)
Other expense 0 179 179
Total other expenses 9,793 9,177 19,893 16,684
----- ----- ------ ------
Income (loss) before taxes (237,954) 7,436 (745,248) 48,481
-------- ----- -------- ------
Provision (benefit) for income
taxes:
Current portion 0 0 0 0
Deferred portion (85,048) 2,992 (264,954) 18,094
------- ----- -------- ------
Total income taxes (85,048) 2,992 (264,954) 18,094
------- ----- -------- ------
Net income (loss) ($152,906) $4,444 ($480,294) $30,387
========= ====== ========= =======
STONE ENERGY CORPORATION
RECONCILIATION OF NON-GAAP FINANCIAL MEASURE
DISCRETIONARY CASH FLOW to NET CASH FLOW FROM OPERATING ACTIVITIES
(In thousands)
(Unaudited)
Three Months Ended Six Months Ended
June 30, June 30,
-------- --------
2015 2014 2015 2014
---- ---- ---- ----
Net income (loss) as reported ($152,906) $4,444 ($480,294) $30,387
Reconciling items:
Depreciation, depletion and
amortization 77,951 92,835 164,373 175,481
Deferred income tax provision
(benefit) (85,048) 2,992 (264,954) 18,094
Accretion expense 6,408 7,733 12,817 15,288
Stock compensation expense 3,388 3,111 6,028 5,358
Write-down of oil and gas properties 224,294 - 715,706 -
Non-cash interest expense 4,419 4,159 8,737 8,229
Other 6,420 2,249 7,931 2,697
----- ----- ----- -----
Discretionary cash flow 84,926 117,523 170,344 255,534
Changes in income taxes payable 18 (6) 7,206 (6)
Settlement of asset retirement
obligations (18,778) (15,073) (35,923) (24,915)
Other working capital changes (4,023) 39,044 4,038 26,347
Net cash provided by operating
activities $62,143 $141,488 $145,665 $256,960
======= ======== ======== ========
STONE ENERGY CORPORATION
RECONCILIATION OF NON-GAAP FINANCIAL MEASURE
ADJUSTED NET LOSS to NET LOSS
(In thousands)
(Unaudited)
Three Months Ended Six Months Ended
June 30, 2015 June 30, 2015
------------- -------------
Net loss as reported ($152,906) ($480,294)
Reconciling items:
Write-down of oil and gas properties 224,294 715,706
Tax effect (80,746) (257,654)
------- --------
Write-down of oil and gas properties, net of tax 143,548 458,052
Adjusted net loss ($9,358) ($22,242)
======= ========
Net loss per share as reported ($2.77) ($8.70)
Per share effect of one-time charges $2.60 $8.30
Net loss per share before one-time charges ($0.17) ($0.40)
STONE ENERGY CORPORATION
CONSOLIDATED BALANCE SHEET
(In thousands)
(Unaudited)
June 30, December 31,
2015 2014
---- ----
Assets
------
Current assets:
Cash and cash equivalents $141,655 $74,488
Restricted Cash 177,647
Accounts receivable 68,706 120,359
Fair value of hedging contracts 74,319 139,179
Current income tax receivable 6 7,212
Inventory 3,709 3,709
Other current assets 10,076 8,118
Total current assets 298,471 530,712
Oil and gas properties, full cost
method of accounting:
Proved 9,074,425 8,817,268
Less: accumulated depreciation,
depletion and amortization (7,846,343) (6,970,631)
---------- ----------
Net proved oil and gas properties 1,228,082 1,846,637
Unevaluated 529,589 567,365
Other property and equipment, net 30,736 32,340
Fair value of hedging contracts 8,231 14,333
Other assets, net 28,082 27,224
Total assets $2,123,191 $3,018,611
========== ==========
Liabilities and Stockholders' Equity
------------------------------------
Current liabilities:
Accounts payable to vendors $69,423 $132,629
Undistributed oil and gas proceeds 17,000 23,232
Accrued interest 9,027 9,022
Deferred Taxes 7,065 20,119
Fair value of hedging contracts - -
Asset retirement obligations 56,176 69,400
Other current liabilities 46,780 49,505
Total currentliabilities 205,471 303,907
7 1/2% Senior Notes due 2022 775,000 775,000
1 3/4% Convertible Notes due 2017 273,406 266,035
Deferred taxes 11,752 286,343
Asset retirement obligations 240,613 247,009
Other long-term liabilities 32,213 38,714
Total liabilities 1,538,455 1,917,008
--------- ---------
Common stock 553 549
Treasury stock (860) (860)
Additional paid-in capital 1,639,389 1,633,307
Accumulated deficit (1,095,002) (614,708)
Accumulated other comprehensive
income (loss) 40,656 83,315
------ ------
Total stockholders' equity 584,736 1,101,603
------- ---------
Total liabilities and stockholders'
equity $2,123,191 $3,018,611
========== ==========
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SOURCE Stone Energy Corporation
