Stone Energy Corporation today announced a 12% increase in net income, which totaled of $25.6 million, or $0.95 per share, on oil and gas revenue of $128.3 million for the third quarter of 2004, compared to net income of $22.8 million, or $0.86 per share, on oil and gas revenue of $116.0 million for the third quarter of 2003. For the nine months ended September 30, 2004, net income totaled $97.2 million, or $3.62 per share, on revenue of $404.1 million compared to net income of $107.3 million, or $4.04 per share, on revenue of $390.8 million during the comparable 2003 period. All per share amounts are on a diluted basis.
As previously announced, shut-ins for Hurricane Ivan resulted in the deferral of September production volumes from the Gulf of Mexico approximating 1.7 billion cubic feet of natural gas equivalent. Certain fields in the Main Pass and Mississippi Canyon areas remain shut-in due to hurricane damage to non-operated wells and platforms, as well as downstream production facilities and pipelines owned by third parties, which has impacted Stone’s ability to restore production at these fields. Currently, Stone has eight Gulf of Mexico properties curtailed or shut-in from Hurricane Ivan representing net daily production of approximately 62 million cubic feet of natural gas equivalent (MMcfe). Stone expects production from these fields to return beginning in the first quarter of 2005. The Company is exploring ways to hasten the return of production including associated gas re-injection and pipeline rerouting.
Net daily production volumes during the third quarter of 2004 averaged approximately 229 MMcfe, or 11% less that the average daily production of 256 MMcfe produced during the third quarter of 2003. The decline in third quarter 2004 production volumes was due to the combined impact of shut-ins for rig mobilizations and Hurricane Ivan. For the fourth quarter of 2004, Stone expects net daily production to average between 180-200 MMcfe. This estimate assumes no contribution from the wells shut-in as a result of Hurricane Ivan.
Prices realized during the third quarter of 2004 averaged $41.79 per barrel (Bbl) of oil and $5.54 per thousand cubic feet (Mcf) of natural gas, which represents a 24% increase, on a Mcfe basis, over third quarter 2003 average realized prices of $29.36 per Bbl of oil and $4.93 per Mcf of natural gas. Average realized prices during the first nine months of 2004 were $37.62 per Bbl of oil and $5.63 per Mcf of natural gas compared to $30.43 per Bbl of oil and $5.57 per Mcf of natural gas realized during the first nine months of 2003. All unit pricing amounts include the cash settlement of hedging contracts.
During the third quarter of 2004, discretionary cash flow increased 7% to $88.1 million compared to $82.7 million generated during the third quarter of 2003. Net cash flow provided by operating activities, as defined by generally accepted accounting principles (GAAP), totaled $111.6 million and $98.4 million during the three months ended September 30, 2004 and 2003, respectively. For the first nine months of 2004, discretionary cash flow totaled $301.1 million compared to $301.3 million during the first nine months of 2003. Net cash flow provided by operating activities totaled $299.9 million and $311.5 million during the nine months ended September 30, 2004 and 2003, respectively. (Please see “Non-GAAP Financial Measure” below.)
Normal lease operating expenses incurred during the third quarter of 2004 totaled $19.7 million compared to $15.1 million for the comparable quarter in 2003. For the nine months ended September 30, 2004 and 2003, normal lease operating expenses were $53.5 million and $45.8 million, respectively. The increase in normal lease operating expenses during 2004 is the combined result of an increase in the number of active offshore properties, higher oil production volumes during 2004, which are more costly to produce as compared to natural gas, the extra costs associated with storm-related shut-ins and evacuations and increases in overall service costs over 2003.
Major maintenance expenses, which represent major repair and maintenance costs that vary from period to period, totaled $11.1 million during the third quarter of 2004 compared to $5.2 million in the third quarter of 2003. Third quarter 2004 major maintenance expenses consisted primarily of replacement wells at Lafitte and Vermilion Block 131, a tubing replacement at West Delta Block 98 and a pipeline repair at East Cameron Block 64. Stone expects fourth quarter 2004 major maintenance expenses to decrease approximately 25% over third quarter 2004 major maintenance expenses based upon planned operations.
Depreciation, depletion and amortization (DD&A) expense on oil and gas properties totaled $45.5 million for the third quarter of 2004, compared to $41.3 million during the third quarter of 2003. DD&A expense on oil and gas properties for the nine months ended September 30, 2004 totaled $140.9 million compared to $122.6 million during the same year-to-date period of 2003. The increase in DD&A on a unit basis during 2004 is the result of higher per unit costs of oil and gas property acquisitions and increases in per unit full-cycle cost of finding and developing proved reserves and the impact of drilling results.
Capital expenditures related to oil and gas properties during the third quarter of 2004 totaled $81.7 million, including $18.6 million of acquisition costs (includes promoted drilling costs), $4.0 million of capitalized salaries, general and administrative expenses and $1.7 million of capitalized interest. Year-to-date 2004 additions to oil and gas property costs of $283.8 million include $68.1 million of acquisition costs (includes promoted drilling costs), $11.9 million of capitalized salaries, general and administrative expenses and $5.0 million of capitalized interest. These investments were financed with cash flow from operating activities, working capital and bank borrowings.
OPERATIONAL UPDATE
During the third quarter of 2004 Stone evaluated 10 new wells, seven of which were productive. Through November 2, 2004, Stone has spud 48 of the 55 wells planned for 2004. The Gulf Coast Basin onshore and offshore shelf including Deep Shelf tests comprise approximately 85% of 2004 capital expenditures budget and 27 exploratory and 13 development wells. Deep water operations for 2004 include two exploratory wells representing approximately 6% of our 2004 capital budget. The remainder of capital expenditures is in the Rocky Mountains consisting of 13 wells, or approximately 9% of 2004 capital budget. The following is an update of certain ongoing or recently completed operations:
Gulf of Mexico – Shelf
Main Pass Block 288. The final well planned from the “A” platform this year, the No. A-7 STK1 Well, was drilled to a total measured depth (MD) of 10,366 feet to test theSam Adams Prospect and encountered 50 net feet of oil pay. Although not at its expected full flowing potential, the well flowed at an initial test rate of 400 barrels of oil and 340 Mcf of natural gas prior to being shut-in in preparation for Hurricane Ivan. In addition, Stone recompleted the No. A-21 STK Well into the Upper M, but was unable to get a test rate prior to the Hurricane Ivan evacuation. Stone has a 100% working interest (WI) and 83.3% net revenue interest (NRI) in these wells.
Both wells were shut in for Hurricane Ivan in mid-September along with the remainder of the wells on the “A” platforms on Main Pass Blocks 288 and 287. Extensive damage occurred to a large gas pipeline leaving the Main Pass 289 “B” platform, through which production flows. Stone has completed most of the Main Pass Block 288 “A” platform upgrades to handle increased productive capacity from the existing wells, but has placed construction of a new gas pipeline from the platform on hold pending repairs to the Main Pass Block 289 “B” platform and the damaged gas pipeline.
Viosca Knoll Block 773. Stone has begun a four-well drilling program on Viosca Knoll Block 773 from an open water location to test multiple fault blocks for possible pay accumulations and the extent of those accumulations. The No. 1 Well to test theClevelandProspect was drilled to a total depth of 5,567 feet MD and logged oil pay in four sands. A second well in the program is currently drilling to a total depth of 9,224 feet (MD). Viosca Knoll Blocks 772, 773 and 774 were acquired by Stone during the 2004 OCS Lease Sale 190. Stone has a 100% working interest in these wells which are located southwest of and contiguous to Stone’s Main Pass Block 288 Field.
Viosca Knoll Block 817. Stone has entered into an agreement with the owner of Viosca Knoll Blocks 817 and 861 to utilize an existing platform as a host structure from which to drill at least two wells and earn an interest in these blocks. The first well, the No. A-1 STK, to test theAntelope Prospect is currently drilling at 10,376 feet MD (7,614 feet TVD) and has logged 68 feet MD (37 feet of true vertical thickness (TVT)) of pay in the F4 sand with no water level. The F4 sand is the main field pay having produced more than 90 Bcf of gas in a separate fault block. The well is planned to 15,351 feet MD (12,145 feet TVD) to test deep, amplitude supported upper Miocene objectives. Viosca Knoll Blocks 817 and 861 are southwest of Main Pass Block 288 and contiguous to Viosca Knoll 773. Stone has a 100% WI in these earning wells.
East Cameron Block 265. The No. 5 Well on East Cameron Block 265 drilled from an open water location to a total depth of 4,500 feet MD in August 2004 and found 26 feet TVT of gas pay in four sands. This well established the western limits of the nine reservoirs in the No. 4 discovery well of theDonut Prospect. The decision was made to plug and abandon the No. 5 Well and use the No. 4 Well as the surface location for development of theDonutProspect. Design and construction of a six-slot tripod structure has begun and installation of the structure is expected in the first quarter of 2005. Stone has a 50% WI and 40.7% NRI in these wells.
The Stone-operated No. 6 Well on theKolache Prospect on East Cameron Block 265 was also drilled from an open water location to a total depth of 4,456 feet MD (4,000 feet TVD) in August 2004 in a fault block adjacent to theDonut Prospect and found non-commercial gas pay in seven sands. The well was plugged and abandoned. Stone has a 100% WI in theKolache project.
South Marsh Island Block 192. The No. A-2 Well, the initial test of theMagic Prospect, reached a total depth of 16,144 feet MD (13,700 feet TVD) in August 2004 and logged 124 net feet (98 feet TVT) of pay before incurring mechanical difficulties. At this time, the turnkey drilling contractor is performing certain operations on the well in preparation of turning over operations to Stone. Upon completion, Stone will have a 50% WI in this well.
South Timbalier Blocks 143 and 166. Stone has exercised its preferential right to acquire additional working interests in South Timbalier Blocks 143, 164, 165, 166 and 171 for approximately $125 million, pending the execution of an Asset Purchase Agreement. After completion of the acquisition, Stone will hold a majority working interest in the blocks. Stone estimates that the wells applicable to these working interests are currently flowing at an average net daily rate of approximately 57 MMcfe. Stone expects to close this acquisition late in the fourth quarter of 2004 and intends to finance this acquisition with available cash and borrowings under its bank credit facility.
Gulf of Mexico – Deep Water
Mississippi Canyon Blocks 24. As previously announced, Stone has begun a deep water and deep shelf exploration venture with Kerr-McGee. The first well, a test of theEssex Prospect on Mississippi Canyon Block 24 was spud on October 13, 2004, with Kerr-McGee as the operator. The well is planned to a total depth of 18,000 feet TVD. The well is a test offsetting the Pompano field development. The well is currently drilling at approximately 8,778 feet. Stone has a 35% WI in this well. Kerr-McGee is the operator of the well with a 65% WI.
Rocky Mountains
Pinedale Anticline, Wyoming. Stone’s drilling program on the Pinedale Anticline in the Greater Green River Basin continues and has yielded six successful wells in 2004. During the third quarter, two wells were drilled and evaluated, both of which are completing. Four additional wells are planned for 2004. One of the wells, the Rainbow No. 13-27, is being drilled at a location more than 500 feet structurally lower than the crest of the Anticline as the initial test of the Southeast Pinedale Federal Unit. Stone has a non-operated 25% WI and 20% NRI in the Southeast Pinedale Unit. Stone has a 50% WI and a 41% NRI in the remainder of the Pinedale wells scheduled for this year and is the operator of the drilling portion of those wells.
Howard Ranch. In the Wind River Basin of central Wyoming, the field recording phase of the 70 square mile Howard Ranch 3D seismic survey ended September 30th. Processing is underway and should be complete in late December. Interpretation will follow with plans to have locations selected and drilling commenced in the second quarter of 2005. The Antelope Mesa Federal No. 1-14 Well reached a depth of 13,600 feet in early October and completion operations are underway. Stone has a 75% WI and 60% NRI in this well.
Non-GAAP Financial Measure
In this press release, Stone refers to a non-GAAP financial measure we call “discretionary cash flow.” Management believes this measure 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 within the oil and gas exploration and production industry. Many investors use the published research of these analysts in making their investment decisions. Discretionary cash flow should not be considered an alternative to net cash provided by operating activities or net income, as defined by GAAP. See reconciliation of discretionary cash flow to cash flow provided by operating activities in the Consolidated Statement of Operations and Net Cash Flow Information.
Other Information
Stone Energy has planned a conference call for 3:00 p.m. C.S.T. Thursday, November 4, 2004 to discuss the operational and financial results for the third quarter of 2004. Anyone wishing to participate should visit our Web site atwww.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 recording will be available at 6:00 p.m. C.S.T. for approximately 48 hours after the call and accessed by dialing (800) 642-1687 (ID No. 1295640). A Web-based replay will also be available approximately 24 hours following the completion of the call on Stone Energy’s Web site atwww.StoneEnergy.com. The Web-based replay will be available for approximately one week.
Stone Energy is an independent oil and gas company headquartered in Lafayette, Louisiana, and is engaged in the acquisition and subsequent exploitation, development and operation of oil and gas properties located in the Gulf Coast Basin and Rocky Mountains. For additional information, contact James H. Prince, chief financial officer at 337-237-0410-phone, 337-237-0426-fax or via e-mail atprincejh@StoneEnergy.com.
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 and other risk factors as described in Stone’s Annual Report on Form 10-K as filed with the Securities and Exchange Commission. 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.
STONE ENERGY CORPORATION
SUMMARY STATISTICS |
|---|
(In thousands, except per share/unit amounts)
(Unaudited) |
| | | Three Months Ended
September 30,
| | Nine Months Ended
September 30,
| |
| | | 2004
| | 2003
| | 2004
| | 2003
| |
| FINANCIAL RESULTS |
| | Net income | $25,565 | | $22,767 | | $97,241 | | $107,252 | |
| | Net income per share | $0.95 | | $0.86 | | $3.62 | | $4.04 | |
| |
| PRODUCTION QUANTITIES |
| | Oil (MBbls) | 1,358 | | 1,379 | | 4,454 | | 4,186 | |
| | Gas (MMcf) | 12,919 | | 15,310 | | 42,000 | | 47,255 | |
| | Oil and gas (MMcfe) | 21,067 | | 23,584 | | 68,724 | | 72,371 | |
| |
| AVERAGE DAILY PRODUCTION |
| | Oil (MBbls) | 15 | | 15 | | 16 | | 15 | |
| | Gas (MMcf) | 140 | | 166 | | 153 | | 173 | |
| | Oil and gas (MMcfe) | 229 | | 256 | | 251 | | 265 | |
| |
| REVENUE DATA (1) |
| | Oil revenue | $56,752 | | $40,492 | | $167,548 | | $127,394 | |
| | Gas revenue | 71,554 | | 75,501 | | 236,562 | | 263,357 | |
| | Total oil and gas revenue | $128,306 | | $115,993 | | $404,110 | | $390,751 | |
| |
| AVERAGE PRICES (1) |
| | Oil (per Bbl) | $41.79 | | $29.36 | | $37.62 | | $30.43 | |
| | Gas (per Mcf) | 5.54 | | 4.93 | | 5.63 | | 5.57 | |
| | Per Mcfe | 6.09 | | 4.92 | | 5.88 | | 5.40 | |
| |
| COST DATA |
| | Normal lease operating expenses | $19,666 | | $15,121 | | $53,526 | | $45,827 | |
| | Major maintenance expenses | 11,090 | | 5,209 | | 19,980 | | 10,451 | |
| | Salaries, general and administrative expenses | 3,378 | | 3,641 | | 10,668 | | 10,578 | |
| | DD&A expense on oil and gas properties | 45,480 | | 41,316 | | 140,918 | | 122,647 | |
| |
| AVERAGE COSTS (per Mcfe) |
| | Normal lease operating expenses | $0.93 | | $0.64 | | $0.78 | | $0.63 | |
| | Major maintenance expenses | 0.53 | | 0.22 | | 0.29 | | 0.14 | |
| | Salaries, general and administrative expenses | 0.16 | | 0.15 | | 0.16 | | 0.15 | |
| | DD&A expense on oil and gas properties | 2.16 | | 1.75 | | 2.05 | | 1.69 | |
| |
| AVERAGE SHARES OUTSTANDING – Diluted | 26,918 | | 26,589 | | 26,890 | | 26,560 | |
| |
| (1) Includes the cash settlement of hedging contracts. |
STONE ENERGY CORPORATION
CONSOLIDATED STATEMENT OF OPERATIONS
AND NET CASH FLOW INFORMATION |
|---|
(In thousands)
(Unaudited) |
| | | Three Months Ended
September 30,
| | Nine Months Ended
September 30,
| |
| | | 2004
| | 2003
| | 2004
| | 2003
| |
| STATEMENT OF OPERATIONS |
| Operating revenue: |
| | Oil production | $56,752 | | $40,492 | | $167,548 | | $127,394 | |
| | Gas production | 71,554
| | 75,501
| | 236,562
| | 263,357
| |
| | Total operating revenue | 128,306
| | 115,993
| | 404,110
| | 390,751
| |
| Operating expenses: |
| | Normal lease operating expenses | 19,666 | | 15,121 | | 53,526 | | 45,827 | |
| | Major maintenance expenses | 11,090 | | 5,209 | | 19,980 | | 10,451 | |
| | Production taxes | 2,169 | | 1,410 | | 5,892 | | 4,368 | |
| | Depreciation, depletion and amortization | 46,139 | | 42,020 | | 142,943 | | 124,785 | |
| | Accretion expense | 1,463 | | 1,573 | | 4,389 | | 4,719 | |
| | Salaries, general and administrative expenses | 3,378 | | 3,641 | | 10,668 | | 10,578 | |
| | Incentive compensation expense | 588 | | 577 | | 1,705 | | 1,914 | |
| | Derivative expenses | 1,069
| | 2,153
| | 3,029
| | 6,407
| |
| | Total operating expenses | 85,562
| | 71,704
| | 242,132
| | 209,049
| |
Income from operations
|
42,744 | |
44,289 | |
161,978 | |
181,702 | |
| Other (income) expenses: |
| | Interest | 4,050 | | 4,760 | | 11,987 | | 15,448 | |
| | Other income | (637 | ) | (691 | ) | (1,994 | ) | (2,058 | ) |
| | Other expenses | - | | 538 | | 2,383 | | 538 | |
| | Early extinguishment of debt | -
| | 4,661
| | -
| | 4,661
| |
| | Total other expenses | 3,413
| | 9,268
| | 12,376
| | 18,589
| |
| Income before income taxes | 39,331 | | 35,021 | | 149,602 | | 163,113 | |
| |
| Provision for income taxes: |
| | Current | - | | - | | - | | - | |
| | Deferred | 13,766
| | 12,254
| | 52,361
| | 57,086
| |
| | Total income taxes | 13,766
| | 12,254
| | 52,361
| | 57,086
| |
Income before effects of accounting changes, net of tax
| 25,565 | | 22,767 | | 97,241 | | 106,027 | |
| | Cumulative effect of accounting changes, net of tax | -
| | -
| | -
| | 1,225
| |
| Net income | $25,565
| | $22,767
| | $97,241
| | $107,252
| |
NET CASH FLOW INFORMATION
|
| Reconciliation of non-GAAP financial measure: |
| | Discretionary cash flow | $88,100 | | $82,668 | | $301,118 | | $301,293 | |
| |
| | Net working capital changes and other | 23,483 | | 15,701 | | 480 | | 10,730 | |
| | Investment in put contracts | -
| | -
| | (1,683
| ) | (516
| ) |
| | Net cash flow provided by operating activities | $111,583
| | $98,369
| | $299,915
| | $311,507
| |
| |
STONE ENERGY CORPORATION
CONSOLIDATED BALANCE SHEET
(In thousands)
(Unaudited)
|
|---|
| | September 30,
2004
| December 31,
2003
|
|---|
| Assets | | | | |
| Current assets: |
| Cash and cash equivalents | $50,871 | | $17,100 | |
| Accounts receivable | 85,317 | | 75,066 | |
| Other current assets | 11,092
| | 5,914
| |
| Total current assets | 147,280 | | 98,080 | |
| Oil and gas properties: |
| Proved, net | 1,328,507 | | 1,210,333 | |
| Unevaluated | 120,321 | | 107,600 | |
| Building and land, net | 5,408 | | 5,202 | |
| Fixed assets, net | 5,001 | | 5,269 | |
| Other assets, net | 8,900
| | 7,793
| |
| Total assets | $1,615,417
| | $1,434,277
| |
| Liabilities and Stockholders' Equity | | | | |
| Current liabilities: |
| Accounts payable to vendors | $91,119 | | $87,646 | |
| Undistributed oil and gas proceeds | 39,724 | | 30,793 | |
| Fair value of hedging contracts | 19,294 | | 7,336 | |
| Other accrued liabilities | 15,368
| | 10,779
| |
| Total current liabilities | 165,505 | | 136,554 | |
| |
| 8¼% Senior Subordinated Notes due 2011 | 200,000 | | 200,000 | |
| Bank debt | 170,000 | | 170,000 | |
| Deferred taxes | 181,650 | | 130,935 | |
| Fair value of hedging contracts | 4,627 | | 4,770 | |
| Asset retirement obligations | 82,657 | | 78,877 | |
| Other long-term liabilities | 2,557
| | 2,864
| |
| Total liabilities | 806,996
| | 724,000
| |
| Common stock | 267 | | 264 | |
| Additional paid-in capital | 463,696 | | 455,391 | |
| Retained earnings | 362,163 | | 264,935 | |
| Treasury stock | (1,462 | ) | (1,550 | ) |
| Accumulated other comprehensive loss | (16,243
| ) | (8,763
| ) |
| Total stockholders' equity | 808,421
| | 710,277
| |
| Total liabilities and stockholders' equity | $1,615,417
| | $1,434,277
| |
