Attached files
file | filename |
---|---|
8-K - FORM 8-K - STONE ENERGY CORP | h85439e8vk.htm |
Exhibit 99.1
STONE ENERGY CORPORATION
Announces Third Quarter 2011 Results
LAFAYETTE, LA. November 1, 2011
Stone Energy Corporation (NYSE: SGY) today announced financial and operational results for the
third quarter of 2011. Some of the highlights include:
| Net daily production for the third quarter of 2011 averaged 34.2 MBoe (205 MMcfe) per day. Volumes were impacted by greater-than-expected downtime due to Gulf of Mexico (GOM) shut-ins from Tropical Storm Lee, Appalachian shut-ins from Hurricane Irene, and unplanned third party pipeline downtime in the GOM. Average daily production for the fourth quarter of 2011 is expected to be 35-38 MBoe per day (210-230 MMcfe per day). | ||
| The Deep Gas discovery at LaPosada/La Cantera (34.5% w.i.) was tested and is expected to produce at 20-30 MMcf (gross) per day plus associated condensate and NGLs. Production is projected to commence by the second quarter of 2012. | ||
| Also in Deep Gas, drilling continues at the ultra-deep Lighthouse Bayou Prospect (25% w.i.) with a current depth of approximately 24,000 feet. Results are expected in the fourth quarter. | ||
| In the Conventional Shelf, Stone drilled two successful oil development wells, Frost Up and Buzzjet (both 100% w.i.). Frost Up is the seventh consecutive successful well at the Amberjack field, and Buzzjet is the second consecutive successful well at Ship Shoal 113 field. Both wells are currently being completed, with production expected in November. | ||
| In the Deep Water, the Pyrenees development project is progressing, with production expected for the first quarter of 2012 (30% w.i.). | ||
| In Appalachia, the third-party midstream pipeline is projected to be operational in the Mary field during the fourth quarter. Eleven wells are expected to be tied-in and on production before year end. A total of 25 horizontal wells are expected to be drilled during 2011. | ||
| A positive pricing differential for Louisiana Sweet Crude to West Texas Intermediate provided incremental margins of over $20 per barrel during the third quarter, which is expected to continue into the fourth quarter and into 2012. | ||
| A definitive agreement was executed for the divestiture of Stones non-operated working interest in the Main Pass 296/311 field for approximately $80 million. |
President and Chief Executive Officer David H. Welch stated, Our strategy is progressing in each
of our business units as we have a number of significant projects nearing completion, while others
are commencing. We are nearing the objective at our ultra-deep Lighthouse Bayou prospect.
Production from our Mary field in West Virginia is scheduled to come on line in November, which
should boost Appalachian volumes to 30-40 Mmcfe per day, including liquids. Our first deep water
discovery at Pyrenees is due to commence production for the first quarter at a rate of over 60
Mmcfe per day (gross). Production from the LaPosada/La Cantera Deep Gas discovery is expected by
the second quarter of 2012. Finally, three wells in our Deep Water portfolio are substantially
permitted and poised for drilling in 2012. Production growth in the fourth quarter and in 2012,
combined with attractive Gulf Coast oil prices and an undrawn credit facility recently reaffirmed
at a $400 million borrowing base, should provide liquidity for the drilling of these attractive
projects. Additionally, the proceeds from the pending divestiture of our non-operated working
interest at Main Pass 296/311 will be targeted for growth opportunities.
Financial Results
For the third quarter of 2011, Stone reported net income of $51.8 million, or $1.06 per share, on
oil and gas revenue of $207.7 million, compared to net income of $19.4 million, or $0.40 per share,
on oil and gas revenue of $153.2 million in the third quarter of 2010. Discretionary cash flow
totaled $161.2 million during the third quarter of 2011, as compared to $92.5 million during the
third quarter of 2010. 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 2011 averaged 34.2 thousand barrels of oil
equivalent (MBoe) per day (205 million cubic feet of gas equivalent (MMcfe) per day), compared with
net daily production of 37.8 MBoe (227 MMcfe) per day in the second quarter of 2011, and net daily
production of 33.0 MBoe (198 MMcfe) per day in the third quarter of 2010. The gas/oil split for
the third quarter of 2011 was approximately 52%/48%.
Prices realized during the third quarter of 2011 averaged $103.51 per barrel of oil and $5.17 per
Mcf of natural gas, as compared to the third quarter of 2010 average realized prices of $72.52 per
barrel and $5.48 per Mcf. Effective hedging transactions increased the average realized price of
natural gas by $0.47 per Mcf in the third quarter of 2011, compared to $0.96 per Mcf in the third
quarter of 2010. Effective hedging transactions decreased the average realized price of oil by
$2.16 per barrel in the third quarter of 2011, compared to $2.79 per barrel in the third quarter of
2010.
Lease operating expenses during the third quarter of 2011 totaled $47.8 million ($15.21 per Boe or
$2.54 per Mcfe), compared to $36.9 million ($12.15 per Boe or $2.03 per Mcfe), in the third quarter
of 2010.
Depreciation, depletion and amortization (DD&A) on oil and gas properties for the third quarter of
2011 totaled $63.8 million ($20.30 per Boe or $3.38 per Mcfe), compared to $59.0 million ($19.44
per Boe or $3.24 per Mcfe), in the third quarter of 2010.
Salaries, general and administrative (SG&A) expenses (excluding incentive compensation expense) for
the third quarter of 2011 were $7.2 million ($2.28 per Boe or $0.38 per Mcfe) which included $2.6
million in one-time positive adjustments primarily due to an insurance reimbursement, compared to
$9.8 million ($3.21 per Boe or $0.54 per Mcfe), in the third quarter of 2010.
The third quarter of 2011 current income tax benefit included $10.6 million of one-time adjustments
attributable to prior tax periods, resulting in overpayments. The effective tax rate was not
materially impacted as most of the adjustments shifted from current to deferred tax expense, and
therefore had minimal impact on net income.
Capital expenditures before acquisitions and capitalized SG&A and interest during the third quarter
of 2011 were approximately $162.2 million, which includes $19.0 million of plugging and abandonment
expenditures. Additionally, $5.0 million of SG&A expenses and $11.5 million of interest were
capitalized during the quarter.
As of September 30, 2011, we had no outstanding borrowings under our bank credit facility and
letters of credit totaling $61.1 million had been issued pursuant to the facility. In late October
2011, the bank group reaffirmed the existing borrowing base at $400 million. The borrowing base
will not be affected by the pending divestiture of Stones working interest in Main Pass 296/311.
Pending Divestiture
On October 28, 2011 Stone entered into a definitive agreement to sell its non-operated working
interest in the Main Pass 296/311 field to an unrelated third party for approximately $80 million
and the assumption by the third party of the associated abandonment obligation. The divestiture
will impact current production by approximately 900 boe per day and is expected to close during the
fourth quarter. The purchase is subject to preferential rights-to-purchase held by the operator of
the properties, and the closing of the transaction is subject to customary closing conditions and
adjustments. The sale will be accounted for as an adjustment to the full cost pool with no gain or
loss recognized.
Business Strategy and Operational Update
Our business strategy is to leverage cash flow generated from existing assets to maintain
relatively stable GOM shelf production, profitably grow gas reserves and production in
price-advantaged basins such as Appalachia and the Gulf Coast Basin, and profitably grow oil
reserves and production in material impact areas such as the deep water GOM and onshore oil.
LaPosada/La Cantera Prospect (Deep Gas). A limited flow test was completed at the
LaPosada well. The test results from a 10/64 inch restricted choke indicate the well is expected to
produce at a gross daily rate of 20-30 MMcf of gas plus approximately 20 barrels of oil and 36
barrels of natural gas liquids per MMcf of gas. Stone expects to be on production by the second
quarter of 2012 and now has an approximate 34.5% working interest in the project after the purchase
of a 1.5% working interest from a small partner. The La Cantera #2 well is planned for the second
quarter of 2012 and is expected to evaluate the unbooked northern portion of the structure
offsetting the initial well. Separately, production from the Deep Gas discovery at South Erath
(14% w.i.) is projected to come on line in November at a gross rate of 10-12 MMcfe per day.
Lighthouse Bayou Deep Prospect (Ultra Deep Gas). The Lighthouse Bayou prospect, located
in Cameron Parish, is currently at a depth of approximately 24,000 feet and is permitted to drill
up to 25,000 feet. Results are expected during the fourth quarter. Stone holds a 25% working
interest in the prospect.
Garden Banks 293 Pyrenees (Deep Water). The project is in its final stages of flow-line and
umbilical installation with production expected for the first quarter of 2012 at a gross rate of
over 60 MMcfe per day. Stone holds a 30% working interest in Pyrenees.
Mississippi Canyon Block 109/Ship Shoal 113 (Conventional Shelf). Frost Up, the seventh and final
well of the platform rig program at Amberjack, is currently being completed with first production
anticipated in November. Stone has a 100% working interest in the Amberjack field. The Buzzjet well
at Ship Shoal 113 was also successful, with first production expected in November.
Plug & Abandonment Program (Conventional Shelf). Stone has entered into a contract for a Montco
335 lift boat to provide P&A services during 2012. This new vessel was built specifically for P&A
operations and should provide cost-saving efficiencies on these P&A projects.
Appalachian Basin (Marcellus Shale Play). In West Virginia, the third-party Caiman
pipeline is projected to be tied in during the fourth quarter with volumes from 11 wells in the Mary
field. The late December exit rate from Appalachia is projected to be 30-40 MMcfe per day,
including liquids. Current projections now call for 25 horizontal wells to be drilled in 2011,
utilizing one horizontal rig and one top-hole rig (up from previous guidance of 21-24 wells). Up to
16 wells are expected to be fractured during 2011. Current net production from the Katie area in
northeast Pennsylvania and Heather/Buddy area in West Virginia is approximately 15 MMcf per day.
Hatch Point Field Cane Creek formation (Onshore Oil). Remedial work to dissolve drilling mud
blockage was concluded on two of the three Stone wells, with resumption of oil production expected
prior to year end. A decision on project development is expected in early 2012. Stone is the
operator and has an approximate 75% working interest in the 46,000 acre project (35,000 net).
Eagle Ford shale Moczygemba #1H (Onshore Oil). This horizontal well was recently put on pump
and is flowing approximately 400 Boe per day, after producing at an initial rate of over 800 Boe
per day. The drilling of a second well (Jarzembek #1H) began in mid-October and a third well is
expected to also be drilled before year end. Stone holds a non-operated 42.5% working interest and
approximately 1,600 net acres in this play.
2011 Guidance
Guidance for the fourth quarter and full year 2011 is shown in the table 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 |
3538 | 3537 | ||||||
(MMcfe per day) |
(210230 | ) | (210220 | ) | ||||
Lease operating expenses (in millions) |
| $ | 175 $185 | |||||
Salaries, General & Administrative expenses (in
millions)
(excluding incentive compensation) |
| $ | 42 $45 |
Fourth Quarter | Full Year | |||||||
Depreciation, Depletion & Amortization (per Mcfe) |
| $ | 3.20 $3.45 | |||||
Corporate Tax Rate (%) |
| 35% 36 | % | |||||
Capital Expenditure Budget (in millions)
(excluding acquisitions) |
| $ | 500 |
Hedge Position
The following table illustrates our derivative positions for 2011, 2012, 2013 and 2014 as of
November 1, 2011:
Fixed-Price Swaps | |||||||||||||||||
NYMEX (except where noted) | |||||||||||||||||
Natural Gas | Oil | ||||||||||||||||
Daily | Daily | ||||||||||||||||
Volume | Swap | Volume | Swap | ||||||||||||||
(MMBtus/d) | Price | (Bbls/d) | Price | ||||||||||||||
2011 |
10,000 | * | $ | 4.565 | 1,000 | $ | 70.05 | ||||||||||
2011 |
20,000 | 5.200 | 1,000 | 78.20 | |||||||||||||
2011 |
10,000 | 6.830 | 1,000 | 80.20 | |||||||||||||
2011 |
1,000 | 83.00 | |||||||||||||||
2011 |
1,000 | 83.05 | |||||||||||||||
2011 |
1,000 | ** | 85.20 | ||||||||||||||
2011 |
1,000 | 85.25 | |||||||||||||||
2011 |
1,000 | 89.00 | |||||||||||||||
2011 |
1,000 | *** | 97.75 | ||||||||||||||
2011 |
1,000 | *** | 104.30 | ||||||||||||||
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 |
1,000 | 97.60 | |||||||||||||||
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 | 97.15 | |||||||||||||
2013 |
10,000 | 5.320 | 1,000 | 101.53 | |||||||||||||
2013 |
1,000 | 103.00 | |||||||||||||||
2013 |
1,000 | 104.50 | |||||||||||||||
2013 |
1,000 | | 107.30 | ||||||||||||||
2014 |
1,000 | | 103.30 |
* | February December | |
** | January June | |
*** | July December | |
| Brent oil contract |
Other Information
Stone Energy has planned a conference call for 10:00 a.m. Central Time on Wednesday, November 2,
2011 to discuss the operational and financial results for the third quarter of 2011. 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 Energys website. The replay will be available for one month.
Non-GAAP Financial Measures
In this press release, we refer to a non-GAAP financial measure we call discretionary cash flow.
Management believes discretionary cash flow is a financial indicator of our companys 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. Please see the Reconciliation of Non-GAAP Financial Measure for a
reconciliation of discretionary cash flow to cash flow provided by operating activities.
Forward Looking Statements
Certain statements in this press release are forward-looking and are based upon Stones 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 Stones 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, Stones actual results and plans could differ materially from those expressed in
the forward-looking statements.
Estimates for Stones 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. Stones 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. Our business strategy is to leverage cash flow generated from existing
assets to maintain relatively stable GOM shelf production, profitably grow gas reserves and
production in price-advantaged basins such as Appalachia and the Gulf Coast Basin, and profitably
grow oil reserves and production in material impact areas such as the deep water GOM and onshore
oil. 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)
SUMMARY STATISTICS
(In thousands, except per share/unit amounts)
(Unaudited)
Three Months Ended | Nine Months Ended | |||||||||||||||
September 30, | September 30, | |||||||||||||||
2011 | 2010 | 2011 | 2010 | |||||||||||||
FINANCIAL RESULTS |
||||||||||||||||
Net income |
$ | 51,821 | $ | 19,382 | $ | 148,809 | $ | 72,672 | ||||||||
Net income per share |
$ | 1.06 | $ | 0.40 | $ | 3.04 | $ | 1.50 | ||||||||
PRODUCTION QUANTITIES |
||||||||||||||||
Oil (MBbls) |
1,521 | 1,347 | 4,804 | 4,199 | ||||||||||||
Gas (MMcf) |
9,713 | 10,130 | 29,907 | 31,874 | ||||||||||||
Oil and gas (MBoe) |
3,140 | 3,035 | 9,789 | 9,511 | ||||||||||||
Oil and gas (MMcfe) |
18,839 | 18,212 | 58,731 | 57,068 | ||||||||||||
AVERAGE DAILY PRODUCTION |
||||||||||||||||
Oil (MBbls) |
17 | 15 | 18 | 15 | ||||||||||||
Gas (MMcf) |
106 | 110 | 110 | 117 | ||||||||||||
Oil and gas (MBoe) |
34 | 33 | 36 | 35 | ||||||||||||
Oil and gas (MMcfe) |
205 | 198 | 215 | 209 | ||||||||||||
REVENUE DATA |
||||||||||||||||
Oil revenue |
$ | 157,436 | $ | 97,688 | $ | 484,788 | $ | 301,412 | ||||||||
Gas revenue |
50,244 | 55,522 | 152,615 | 179,571 | ||||||||||||
Total oil and gas revenue |
$ | 207,680 | $ | 153,210 | $ | 637,403 | $ | 480,983 | ||||||||
AVERAGE PRICES |
||||||||||||||||
Prior to the cash settlement of effective hedging
transactions: |
||||||||||||||||
Oil (per Bbl) |
$ | 105.67 | $ | 75.31 | $ | 106.34 | $ | 76.04 | ||||||||
Gas (per Mcf) |
4.70 | 4.52 | 4.67 | 4.82 | ||||||||||||
Oil and gas (per Boe) |
65.73 | 48.51 | 66.45 | 49.71 | ||||||||||||
Oil and gas (per Mcfe) |
10.96 | 8.08 | 11.08 | 8.29 | ||||||||||||
Including the cash settlement of effective hedging
transactions: |
||||||||||||||||
Oil (per Bbl) |
$ | 103.51 | $ | 72.52 | $ | 100.91 | $ | 71.78 | ||||||||
Gas (per Mcf) |
5.17 | 5.48 | 5.10 | 5.63 | ||||||||||||
Oil and gas (per Boe) |
66.14 | 50.48 | 65.11 | 50.57 | ||||||||||||
Oil and gas (per Mcfe) |
11.02 | 8.41 | 10.85 | 8.43 | ||||||||||||
COST DATA |
||||||||||||||||
Lease operating expenses |
$ | 47,767 | $ | 36,882 | $ | 133,307 | $ | 112,429 | ||||||||
Salaries, general and administrative expenses |
7,151 | 9,751 | 29,494 | 30,199 | ||||||||||||
DD&A expense on oil and gas properties |
63,757 | 59,001 | 201,934 | 180,434 | ||||||||||||
AVERAGE COSTS (per Mcfe) |
||||||||||||||||
Lease operating expenses (per Boe) |
$ | 15.21 | $ | 12.15 | $ | 13.62 | $ | 11.82 | ||||||||
Lease operating expenses (per Mcfe) |
2.54 | 2.03 | 2.27 | 1.97 | ||||||||||||
Salaries, general and administrative expenses (per Boe) |
2.28 | 3.21 | 3.01 | 3.18 | ||||||||||||
Salaries, general and administrative expenses (per Mcfe) |
0.38 | 0.54 | 0.50 | 0.53 | ||||||||||||
DD&A expense on oil and gas properties (per Boe) |
20.30 | 19.44 | 20.63 | 18.97 | ||||||||||||
DD&A expense on oil and gas properties (per Mcfe) |
3.38 | 3.24 | 3.44 | 3.16 | ||||||||||||
AVERAGE SHARES OUTSTANDING Diluted |
48,071 | 47,727 | 48,006 | 47,681 |
STONE ENERGY CORPORATION
CONSOLIDATED STATEMENT OF OPERATIONS
(In thousands)
(Unaudited)
CONSOLIDATED STATEMENT OF OPERATIONS
(In thousands)
(Unaudited)
Three Months Ended | Nine Months Ended | |||||||||||||||
September 30, | September 30, | |||||||||||||||
2011 | 2010 | 2011 | 2010 | |||||||||||||
Operating revenue: |
||||||||||||||||
Oil production |
$ | 157,436 | $ | 97,688 | $ | 484,788 | $ | 301,412 | ||||||||
Gas production |
50,244 | 55,522 | 152,615 | 179,571 | ||||||||||||
Other operational income |
1,245 | 1,802 | 2,994 | 4,489 | ||||||||||||
Derivative income, net |
4,082 | 405 | 3,300 | 3,818 | ||||||||||||
Total operating revenue |
213,007 | 155,417 | 643,697 | 489,290 | ||||||||||||
Operating expenses: |
||||||||||||||||
Lease operating expenses |
47,767 | 36,882 | 133,307 | 112,429 | ||||||||||||
Other operational expense |
654 | 3,003 | 1,452 | 5,450 | ||||||||||||
Production taxes |
2,492 | 1,517 | 6,828 | 4,761 | ||||||||||||
Depreciation, depletion and amortization |
64,462 | 60,482 | 204,777 | 184,900 | ||||||||||||
Accretion expense |
7,700 | 8,460 | 23,134 | 25,384 | ||||||||||||
Salaries, general and administrative expenses |
7,151 | 9,751 | 29,494 | 30,199 | ||||||||||||
Incentive compensation expense |
2,087 | 767 | 7,104 | 2,113 | ||||||||||||
Total operating expenses |
132,313 | 120,862 | 406,096 | 365,236 | ||||||||||||
Income from operations |
80,694 | 34,555 | 237,601 | 124,054 | ||||||||||||
Other (income) expenses: |
||||||||||||||||
Interest expense |
1,379 | 2,667 | 6,470 | 9,273 | ||||||||||||
Interest income |
(23 | ) | (51 | ) | (170 | ) | (1,110 | ) | ||||||||
Other income |
(372 | ) | | (1,499 | ) | (776 | ) | |||||||||
Early debt retirement expense |
| | 607 | 1,820 | ||||||||||||
Other expense |
308 | 57 | 501 | 546 | ||||||||||||
Total other expenses |
1,292 | 2,673 | 5,909 | 9,753 | ||||||||||||
Income before taxes |
79,402 | 31,882 | 231,692 | 114,301 | ||||||||||||
Provision (benefit) for income taxes: |
||||||||||||||||
Current |
(12,681 | ) | 10,182 | (15,043 | ) | 4,918 | ||||||||||
Deferred |
40,262 | 2,318 | 97,926 | 36,711 | ||||||||||||
Total income taxes |
27,581 | 12,500 | 82,883 | 41,629 | ||||||||||||
Net income |
$ | 51,821 | $ | 19,382 | $ | 148,809 | $ | 72,672 | ||||||||
STONE ENERGY CORPORATION
RECONCILIATION OF NON-GAAP FINANCIAL MEASURE
(In thousands)
(Unaudited)
RECONCILIATION OF NON-GAAP FINANCIAL MEASURE
(In thousands)
(Unaudited)
Three Months Ended | Nine Months Ended | |||||||||||||||
September 30, | September 30, | |||||||||||||||
2011 | 2010 | 2011 | 2010 | |||||||||||||
Net income as reported |
$ | 51,821 | $ | 19,382 | $ | 148,809 | $ | 72,672 | ||||||||
Reconciling items: |
||||||||||||||||
Depreciation, depletion and amortization |
64,462 | 60,482 | 204,777 | 184,900 | ||||||||||||
Deferred income tax provision |
40,262 | 2,318 | 97,926 | 36,711 | ||||||||||||
Accretion expense |
7,700 | 8,460 | 23,134 | 25,384 | ||||||||||||
Stock compensation expense |
1,354 | 1,282 | 4,492 | 4,023 | ||||||||||||
Early extinguishment of debt |
| | 607 | 1,820 | ||||||||||||
Other |
(4,444 | ) | 578 | (5,777 | ) | (1,015 | ) | |||||||||
Discretionary cash flow |
161,155 | 92,502 | 473,968 | 324,495 | ||||||||||||
Changes in income taxes payable |
(15,465 | ) | 2,799 | (21,710 | ) | (6,014 | ) | |||||||||
Settlement of asset retirement obligations |
(18,975 | ) | (8,854 | ) | (52,543 | ) | (28,652 | ) | ||||||||
Other working capital changes |
15,166 | 12,685 | (11,302 | ) | 19,637 | |||||||||||
Net cash provided by operating activities |
$ | 141,881 | $ | 99,132 | $ | 388,413 | $ | 309,466 | ||||||||
STONE ENERGY CORPORATION
CONSOLIDATED BALANCE SHEET
(In thousands)
(Unaudited)
CONSOLIDATED BALANCE SHEET
(In thousands)
(Unaudited)
September 30, | December 31, | |||||||
2011 | 2010 | |||||||
Assets |
||||||||
Current assets: |
||||||||
Cash and cash equivalents |
$ | 65,454 | $ | 106,956 | ||||
Restricted cash |
| 5,500 | ||||||
Accounts receivable |
113,547 | 88,529 | ||||||
Fair value of hedging contracts |
56,767 | 12,955 | ||||||
Current income tax receivable |
22,149 | | ||||||
Deferred tax asset |
4,713 | 27,274 | ||||||
Inventory |
4,802 | 6,465 | ||||||
Other current assets |
933 | 768 | ||||||
Total current assets |
268,365 | 248,447 | ||||||
Oil and gas properties, full cost method of accounting: |
||||||||
Proved |
6,101,241 | 5,789,578 | ||||||
Less: accumulated depreciation, depletion and amortization |
(5,009,076 | ) | (4,804,949 | ) | ||||
Net proved oil and gas properties |
1,092,165 | 984,629 | ||||||
Unevaluated |
511,574 | 413,180 | ||||||
Other property and equipment, net |
11,191 | 10,722 | ||||||
Fair value of hedging contracts |
50,171 | | ||||||
Other assets, net |
23,795 | 22,112 | ||||||
Total assets |
$ | 1,957,261 | $ | 1,679,090 | ||||
Liabilities and Stockholders Equity |
||||||||
Current liabilities: |
||||||||
Accounts payable to vendors |
$ | 90,659 | $ | 103,208 | ||||
Undistributed oil and gas proceeds |
16,924 | 10,037 | ||||||
Accrued interest |
9,358 | 14,062 | ||||||
Fair value of hedging contracts |
951 | 32,144 | ||||||
Asset retirement obligations |
55,068 | 42,300 | ||||||
Current income tax payable |
| 239 | ||||||
Other current liabilities |
17,496 | 16,075 | ||||||
Total current liabilities |
190,456 | 218,065 | ||||||
63/4% Senior Subordinated Notes due 2014 |
200,000 | 200,000 | ||||||
8⅝% Senior Notes due 2017 |
375,000 | 375,000 | ||||||
Deferred taxes |
219,393 | 99,227 | ||||||
Asset retirement obligations |
289,604 | 331,620 | ||||||
Fair value of hedging contracts |
| 3,606 | ||||||
Other long-term liabilities |
19,034 | 21,215 | ||||||
Total liabilities |
1,293,487 | 1,248,733 | ||||||
Common stock |
481 | 478 | ||||||
Treasury stock |
(860 | ) | (860 | ) | ||||
Additional paid-in capital |
1,336,460 | 1,331,500 | ||||||
Accumulated deficit |
(737,748 | ) | (886,557 | ) | ||||
Accumulated other comprehensive income (loss) |
65,441 | (14,204 | ) | |||||
Total stockholders equity |
663,774 | 430,357 | ||||||
Total liabilities and stockholders equity |
$ | 1,957,261 | $ | 1,679,090 | ||||