Forest Oil Announces Record 2005 Second Quarter Results
Forest Oil Corporation (NYSE: FST) (Forest or the Company) today announced results for the second quarter and first six months of 2005. In the second quarter of 2005 compared to the second quarter of 2004, the Company had the following highlights:
– Net earnings were a record $52 million, an increase of 86%.
– Sales volumes were a record 44.8 Bcfe, an increase of 10%.
– EBITDA was a record $200 million, an increase of 37%.
– Net cash flow from operations, exclusive of working capital
items, was a record $182 million, an increase of 39%.
– Free cash flow was a record $77 million, an increase of 97%.
– Lease operating expense was $1.02 per Mcfe, a decrease of 6%.
– Net debt was $870 million, a decrease of 13%.
H. Craig Clark, President and CEO, stated: "Forest continues to execute on its free cash flow business model. The company has generated over $155 million in free cash flow this year, and we have invested only 55% of our cash flow in drilling activities to date. This model should allow us to pay for our Buffalo Wallow acquisition with free cash flow by the end of the third quarter. Our execution has resulted in year-over-year production growth of 10%, increased proved reserves and expansion of our drilling inventory, while decreasing net debt by $130 million. So far this year we have made good on our expectations to hold per unit cash costs flat, and we are seeing a decrease in our drillbit finding and development costs as we focus more capital onshore. We believe our business model is working extremely well and provides for both growth and flexibility."
SECOND QUARTER 2005 RESULTS
For the quarter ended June 30, 2005, Forest reported net earnings of $52.2 million, or $.85 per basic share. This amount compares to net earnings of $28.1 million, or $.51 per basic share, in the corresponding 2004 period. Increased earnings for the quarter ended June 30, 2005, as compared to the corresponding period of 2004 were due primarily to increased sales volumes and higher oil and gas prices offset by higher depletion expense.
For the second quarter of 2005, Forest’s sales volumes were 492 MMcfe/d, or an increase of 10% compared to the second quarter of 2004. Natural gas volumes increased 9% and liquids volumes increased 12% in the 2005 period, compared to the 2004 period. Sales volumes decreased 27 MMcfe/d in offshore Gulf of Mexico during the quarter due to service delays in hooking up new discoveries and weather. Also, unusually wet weather in Canada limited exploration and development activity in the second quarter and specifically limited pipeline activity in the Wild River area. The Company’s EBITDA increased 37% compared to the second quarter of 2004 to $199.6 million, due to the 10% increase in production and higher per unit netbacks (oil and gas sales revenue less lease operating expenses, production and property taxes, and transportation costs).
At June 30, 2005, net debt (principal amount of long-term debt less cash on hand) decreased to $870 million compared to $1 billion at June 30, 2004. The year-over-year decrease in net debt was primarily due to the internally generated free cash flow during this period. The Company exited the second quarter of 2005 with a net debt to book capitalization rate of 36% compared to 43% at June 30, 2004.
SIX MONTHS ENDED JUNE 30, 2005, RESULTS
For the six months ended June 30, 2005, Forest reported net earnings of $91.1 million, or $1.50 per basic share. This amount compares to net earnings of $47.2 million, or $.87 per basic share in the corresponding 2004 period. Increased earnings for the six months ended June 30, 2005, as compared to the corresponding period of 2004 were due primarily to increased sales volumes and higher oil and gas prices offset by higher depletion expense.
For the six months ended June 30, 2005, Forest’s sales volumes were 495 MMcfe/d or an increase of 12% compared to the corresponding period in 2004. The Company’s EBITDA increased 39% compared to the corresponding period in 2004 to $384 million, due to the 12% increase in production and higher per unit netbacks (oil and gas sales revenue less lease operating expenses, production and property taxes, and transportation costs).
CAPITAL ACTIVITIES
In the second quarter of 2005, Forest spent $215 million on oil and gas property acquisitions, excluding the deferred tax step-up in booked fair value of the Buffalo Wallow assets, and $105 million in exploration and development activities. Total costs incurred included a non-cash charge of $89 million relating to the deferred tax step-up in the booked fair value of the assets acquired in the Buffalo Wallow acquisition. The following table summarizes capital expenditures incurred in the second quarter of 2005 for exploration, development and acquisition activities (in millions of dollars):
United Consolidated States Canada International Total ---------- ------- ------------- ------------ Exploration(1) $ 29 4 1 34 Development 63 8 -- 71 Acquisitions 215 -- -- 215 ---------- ------- ------------- ------------ Total 307 12 1 320 Add: Step-up in booked fair value of Buffalo Wallow assets 89 -- -- 89 ---------- ------- ------------- ------------ $ 396 12 1 409 ========== ======= ============= ============ (1) Includes $5 million of land and seismic expenditures.
For the six months ended June 30, 2005, Forest spent $223 million on acquisitions, excluding the deferred tax step-up in booked fair value of the Buffalo Wallow assets, and $194 million in exploration and development activities, and received $6 million from asset dispositions. Total costs incurred included a non-cash charge of $89 million relating to the deferred tax step-up in the booked fair value of the assets acquired in the Buffalo Wallow acquisition. The following table summarizes capital expenditures incurred in the six months ended June 30, 2005, for exploration, development and acquisition activities (in millions of dollars):
United Consolidated States Canada International Total -------- ------- ------------- ------------ Exploration(1) $ 54 17 1 72 Development 100 22 -- 122 Acquisitions 216 7 -- 223 -------- ------- ------------- ------------ Total 370 46 1 417 Add: Step-up in booked fair value of Buffalo Wallow assets 89 -- -- 89 -------- ------- ------------- ------------ $ 459 46 1 506 ======== ======= ============= ============ (1) Includes $13 million of land and seismic expenditures.
CERTAIN COMPARATIVE FINANCIAL AND OPERATING DATA
The following table sets forth certain of Forest’s financial and operating data for the three and six months ended June 30, 2005 and 2004:
Three Months Six Months Ended Ended June 30, June 30, ----------------- ----------------- 2005 2004 2005 2004 -------- -------- -------- -------- Daily natural gas sales volumes (MMcf): United States 254.1 241.5 256.4 237.6 Canada 48.9 35.8 48.9 35.2 -------- -------- -------- -------- Total 303.0 277.3 305.3 272.8 Daily liquids sales volumes (MBbls): United States 28.0 25.5 28.1 25.0 Canada 3.5 2.6 3.6 2.5 -------- -------- -------- -------- Total 31.5 28.1 31.7 27.5 Equivalent daily sales volumes (MMcfe): United States 422.0 394.5 424.6 387.6 Canada 69.8 51.4 70.5 50.2 -------- -------- -------- -------- Total 491.8 445.9 495.1 437.8 Total equivalent sales volumes (Bcfe) 44.8 40.6 89.6 79.7 Oil and gas sales revenue (millions)(1) $269.4 207.9 528.2 401.7 Average gas sales price (per Mcf)(1) $5.81 5.20 5.69 5.14 Average liquids sales price (per Bbl)(1) $38.17 30.00 37.33 29.28 Costs (per $ Mcfe): Lease operating expenses 1.02 1.08 1.05 1.16 Production and property taxes .24 .17 .23 .18 Transportation costs .10 .09 .11 .09 General and administrative expense .25 .20 .24 .18 Interest expense .36 .32 .34 .33 Current income tax expense .01 -- .02 .01 Capital expenditures (millions): Exploration and development $105 92 194 141 Acquisitions(2) 304 354 312 364 -------- -------- -------- -------- Total $409 446 506 505 (1) Includes effects of hedging. (2) Includes a deferred tax gross up of approximately $89 million for the three and six month periods ended June 30, 2005, and $54 million for the same periods in 2004.
FINANCIAL AND OPERATIONAL RESULTS
For the three and six month period ended June 30, 2005, oil and gas sales volumes increased approximately 10% and 12%, respectively, compared to the corresponding periods in 2004 due primarily to acquisitions of producing properties made in April 2005 and June 2004 (net of approximately $100 million of property dispositions). Increased sales volumes, coupled with increased net price realizations for oil and natural gas, respectively, increased oil and gas revenue 30% and 31% in the three and six months ended June 30, 2005, compared to the corresponding periods in 2004.
Oil and gas production expense increased on an absolute dollar basis but decreased on a per-unit basis in the six months ended June 30, 2005, compared to the corresponding period of 2004. The components of oil and gas production expense were as follows:
Three Months Ended June 30, Six Months Ended June 30, ---------------------------- ----------------------------- Per Per Per Per 2005 Mcfe 2004 Mcfe 2005 Mcfe 2004 Mcfe -------- ----- ------- ----- -------- ----- -------- ----- (In Thousands, except per unit amounts) Direct operating expense and overhead $38,336 .86 38,631 .95 79,147 .89 80,419 1.01 Workovers 7,447 .16 5,237 .13 14,496 .16 11,638 .15 Transport- ation costs 4,583 .10 3,728 .09 9,755 .11 7,420 .09 Production and property taxes 10,547 .24 7,095 .17 20,444 .23 14,543 .18 -------- ----- ------- ----- -------- ----- -------- ----- Total production expense $60,913 1.36 54,691 1.34 123,842 1.39 114,020 1.43 ======== ===== ======= ===== ======== ===== ======== =====
Lease operating expenses (LOE), which includes direct operating expense and overhead and workovers, increased to $45.8 million for the quarter ended June 30, 2005, or 4% from $43.9 million for the corresponding 2004. On a per-unit basis, LOE decreased 6% from $1.08 per Mcfe in the second quarter of 2004 to $1.02 per Mcfe in the second quarter of 2005. For the six month period ended June 30, 2005, LOE on a per-unit basis decreased 9% to $1.05 per Mcfe from $1.16 per Mcfe in the corresponding 2004 period. The 6% and 9% decrease in LOE on an equivalent Mcfe basis for the three and six months ended June 30, 2005, respectively, is primarily a result of cost control efforts as announced in the third quarter of 2004 which have more than offset increases in service and material costs.
Production and property taxes increased by $3.5 million, or 49% during the second quarter 2005 compared to the prior year’s second quarter. For the six month period ended June 30, 2005, production and property taxes increased by 41% compared to the prior year period. The three and six month increases were attributable to higher commodity prices. As a percentage of oil and natural gas revenue excluding hedging, production and property taxes for the three and six month periods ended June 30, 2005, were 3.5% and 3.5%, respectively, and in the comparable periods of 2004 were 3.0% and 3.2%, respectively. The increase is caused by a greater percentage of our production from onshore U.S. fields.
General and administrative expense increased 36% to $11.1 million for the quarter ended June 30, 2005, compared to $8.2 million for the corresponding period in 2004. For the six months ended June 30, 2005, general and administrative expense increased 50% to $21.8 million compared to $14.5 million for the corresponding period in 2004. The three and six month increases resulted primarily from increased headcount due to acquisition activities and a decrease in our overhead capitalization rate from 42% and 45% in 2004, respectively, to 36% and 37% in 2005, respectively. Combined capitalized and expensed overhead costs increased by 23% for the comparable quarter and by 31% in the comparable six month period.
Depreciation and depletion expense increased to $97.2 million for the quarter ended June 30, 2005, from $83.5 million for the corresponding period in 2004. On a per-unit basis, the depletion rate was $2.15 per Mcfe for the quarter ended June 30, 2005, compared to $2.04 per Mcfe in the corresponding period in 2004. For the six month period June 30, 2005, depreciation and depletion expense increased to $193.5 million from $163.1 million for the comparable period in 2004. On a per-unit basis, the depletion rate was $2.14 per Mcfe for the first six months of 2005 compared to $2.03 per Mcfe in the corresponding period in 2004. The three month and six month increases in depletion expense and in the per-unit depletion rate in 2005 compared to 2004 were due primarily to the effect of marginal properties sold in Canada in the fourth quarter of 2004. The sales price received per unit was less than that cost pool’s depletion rate, therefore, the depletion rate on the remaining reserves in Canada increased.
Other expense for the three and six months ended June 30, 2005, includes a charge of $2.2 million representing our 40% share of a valuation allowance that our equity method investee recorded in June 2005 against a portion of its deferred tax assets.
The consolidated balance sheet at June 30, 2005, includes the Buffalo Wallow acquisition. Pursuant to purchase accounting rules, Forest recorded a deferred tax liability of approximately $88.7 million and an asset for goodwill of approximately $38.1 million.
HEDGING
Forest currently has hedges in place for the remainder of 2005 and 2006 covering the aggregate average daily volumes and weighted average prices shown below. The majority of the volumes hedged for 2005 and 2006 are associated with Forest’s acquisition activities.
Remainder of 2005 2006 ---------- ------- Natural gas swaps: ------------------ Contract volumes (BBtu/d) 106.7(2) 50.0(1) Weighted average price (per MMBtu) $ 5.14 6.02 Natural gas collars: -------------------- Contract volumes (BBtu/d) 46.7(1) 30.0 Weighted average ceiling price (per MMBtu) $ 7.17 11.25 Weighted average floor price (per MMBtu) $ 5.89 6.54 Oil swaps: ---------- Contract volumes (MBbls/d) 8.5(2) 4.0(1) Weighted average price (per Bbl) $ 35.42 31.58 Oil collars: ------------ Contract volumes (MBbls/d) 1.0(1) 5.5(2) Weighted average ceiling price (per Bbl) $ 47.30 65.87 Weighted average floor price (per Bbl) $ 42.00 46.73 Oil three-way collars: ---------------------- Contract volumes (MBbls/d) 1.5 -- Weighted average ceiling price (per Bbl) $ 32.00 -- Weighted average floor price (per Bbl) $ 28.00 -- Three-way weighted average floor price (per Bbl) $ 24.00 -- (1) Represents hedged volumes associated with Forest's acquisition activities. (2) 100.0 of the 106.7 BBtu/d of hedged natural gas volumes and 6.5 of the 8.5 MBbls/d of hedged oil swap volumes in 2005 are associated with Forest's acquisition activities. 1.0 of the 5.5 BBtu/d of hedged natural gas collar volumes in 2006 are associated with Forest's acquisition activities.
OPERATIONAL PROJECT UPDATE
Western Business Unit
Buffalo Wallow Acquisition, Texas Panhandle (66-100% Working Interest) — As previously announced, Forest closed this acquisition on April 1, 2005, and took over operations with a four-rig drilling program immediately following closing. During the second quarter, Forest completed 8 wells with a 100% success rate and had 5 wells completing at June 30, 2005, including activity in offset areas. Initial test rates have ranged from 1 to 4.5 MMcfe/d and have averaged 1.9 MMcfe/d. Additional fracture treatments and additional Atoka pay have contributed to the higher than anticipated test rates. Total net production has increased 45% since acquiring the properties from 20 to 29 MMcfe/d.
Delaware Basin, Winkler and Loving Counties, Texas (98-100% Working Interest) — Forest has 2 deep tests drilling and one completing in the Haley Atoka trend. Results from these wells should be known in the fourth quarter of 2005. Additional wells are planned in 2005.
SE New Mexico Exploration/Exploitation Drilling Program (6-50% Working interest) — Activity has increased in the Morrow gas trend with 12 gross wells spud year to date 2005 with an 86% success rate. Test rates have been as high as 5.5 MMcfe/d and have averaged 1.9 MMcfe/d. Five wells are currently in progress.
Central Midland Basin, Texas Exploitation Activity (25-100% Working interest) — Forest has an active exploitation program on properties acquired over the last 2 years. Most of these projects are on wells located in the Dune, Fullerton, Martin, Spraberry, and Tex-Mex Fields. Production has increased on all of these acquisition projects, most notably on the Minihan acquisition, where production has increased 40% since the beginning of 2005. Forest continues to utilize its company-owned rigs in these areas.
Gulf Coast Business Unit
Sabine Prospect, Calcasieu Parish, Louisiana (45% Working Interest) — The Kirby Jones #1 Well, the fourth exploration well, was completed at 3.8 MMcfe/d at 5,700 psi flowing tubing pressure. The four wells in this field have been initially completed at an average of 4.4 MMcfe/d. A fifth exploration well is currently drilling with 5 additional wells scheduled to be drilled in 2005 in this field and the Liberty/Dayton acreage in Southeast Texas.
South Texas, Vicksburg and Wilcox Trend (100% Working Interest) — Forest had two successful wells in the McAllen Ranch and Guerra Field in the second quarter of 2005. The two wells tested at an average of 2.1 MMcfe/d with additional activity in these fields planned in 2005.
Gulf of Mexico Deep Shelf Program (75% Working Interest) — The South Timbalier Block 72 #22 exploratory well was drilled to 17,625 feet and tested 14.2 MMcfe/d at 6,300 psi flowing tubing pressure. First sales occurred at the beginning of the third quarter.
Gulf of Mexico Shallow Shelf Program (64 – 100% Working Interest) — Three significant wells were logged in the second quarter of 2005. The Eugene Island 53 G-1 well logged 78 feet of net gas pay from 3 sands, the Brazos 491 #4 well logged 60 feet net gas pay in 12 sands and the Vermilion 102 A-3 ST well logged 48 feet net gas pay in two sands. All three wells should be tied to sales in the third quarter when offshore construction barges are available. Total net production from these wells is expected to be between 15 and 20 MMcfe/d. In addition, the recompletion program at South Timbalier 295 completed in the quarter yielded an increase in production of 8.5 MMcfe/d.
Canada Business Unit
Wild River Area, Alberta, Canada (24-89% Working Interest) — Wild River continues to be our most active area in Canada with a two-rig drilling program. Gross production has increased from 26 to 36 MMcfe/d since last quarter despite wet weather delaying drilling, completion and pipeline activity. Suspended operations resumed in early June 2005 with 5 wells currently being completed and 2 additional wells awaiting pipeline connection.
Foothills Area, Alberta, Canada (40-100% Working Interest) — Three wells were drilled and cased during the first half of 2005 but testing and completion were delayed due to wet weather. Operations are expected to commence to complete and tie these wells into sales in late third quarter 2005.
Alaska Business Unit
Onshore Cook Inlet Gas Exploration Program (30 – 100% Working Interest) — Forest recently signed a two year gas sales agreement with a local consumer to sell the gas from previously announced discoveries at West Foreland on the west side of the Cook Inlet. Gas sales of 5-15 MMcfe/d will commence late in the fourth quarter of 2005. In addition, Forest and its partners performed further testing of the Three Mile Creek #1 discovery in the second quarter of 2005. Construction of the 5 mile pipeline will allow first sales at an expected rate of 5 MMcfe/d in late third quarter 2005. Two additional offset wells are planned at Three Mile Creek in 2005. Additionally, Forest plans 3 deepenings/recompletions and 2 wildcat tests onshore by the end of 2005 depending on rig availability.
2005 GUIDANCE
There are no changes to the 2005 guidance provided in Forest’s press release dated April 4, 2005.
NON-GAAP FINANCIAL MEASURES
In addition to reporting earnings from continuing operations as defined under GAAP, Forest also presents EBITDA, which consists of net earnings from continuing operations plus interest expense, income tax expense, depreciation and depletion, unrealized (gain) loss on derivatives, impairment of oil and gas properties and accretion of asset retirement obligations. Management uses this measure to assess the Company’s ability to generate cash to fund exploration and development activities and to service debt. Management interprets trends in this measure in a similar manner as trends in cash flow and liquidity. EBITDA should not be considered as an alternative to net earnings from continuing operations as defined by GAAP. The following is a reconciliation of net earnings from continuing operations to EBITDA (in thousands):
Three Months Six Months Ended Ended June 30, June 30, ----------------- ----------------- 2005 2004 2005 2004 -------- -------- -------- -------- Earnings from continuing operations $ 52,201 28,130 91,072 47,767 Interest expense 16,061 13,084 30,560 26,031 Income tax expense 31,869 16,220 53,115 28,721 Depreciation and depletion 97,249 83,474 193,525 163,102 Unrealized (gain) loss on derivatives (4,310) (1,248) 2,270 (217) Impairment of oil and gas properties -- 1,690 2,924 1,690 Change in deferred tax valuation allowance of equity investee 2,167 -- 2,167 -- Accretion of asset retirement obligations 4,322 4,153 8,599 8,428 -------- -------- -------- -------- EBITDA $199,559 145,503 384,232 275,522 ======== ======== ======== ========
Forest also presents net cash flow from operations, exclusive of working capital items, which consists of net cash provided by operating activities plus the period change in accounts receivable, other current assets, accounts payable and accrued expenses. Management uses this measure to assess the Company’s ability to generate cash to fund exploration and development activities. Management interprets trends in this measure in a similar manner as trends in cash flow and liquidity. Net cash flow from operations, exclusive of working capital items should not be considered as an alternative to net cash provided by operating activities as defined by GAAP. The following is a reconciliation of net cash provided by operating activities to net cash flow from operations, exclusive of working capital items (in thousands):
Three Months Six Months Ended Ended June 30, June 30, ----------------- ----------------- 2005 2004 2005 2004 -------- -------- -------- -------- Net cash provided by operating activities $189,340 145,418 325,423 243,195 Changes in operating assets and liabilities: Accounts receivable (26,988) 14,859 (20,745) (24,251) Other current assets (2,923) (5,943) (1,324) 5,046 Accounts payable and accrued expenses 22,197 (23,604) 45,755 22,420 -------- -------- -------- -------- Net cash flow from operations, exclusive of working capital items $181,626 130,730 349,109 246,410 ======== ======== ======== ========
In addition to total debt, Forest also presents net debt, which consists of principal amount of long-term debt less cash and cash equivalents on hand at the end of the period. Management uses this measure to assess the Company’s indebtedness, based on actual principal amounts owed and cash on hand which has not been applied to reduce the amounts of the credit facility. The following table sets forth the components of net debt as of June 30, 2005, and June 30, 2004, (in millions):
June 30, 2005 June 30, 2004 ----------------- ------------------- Principal Book(1) Principal Book(1) --------- ------- ---------- -------- Credit facilities and bank debt $ 184 184 352 352 8% Senior notes due 2008 265 271 265 274 8% Senior notes due 2011 285 299 160 166 7 3/4% Senior notes due 2014 150 164 150 165 9 1/2% Senior notes assumed - - 125 127 --------- ------- ---------- -------- Total long-term debt 884 918 1,052 1,084 Cash and cash equivalents 14 14 52 52 --------- ------- ---------- -------- Net debt $ 870 904 1,000 1,032 ========= ======= ========== ======== (1) Book amounts include the principal amount of long-term debt adjusted for unamortized gains on interest rate swaps of $28.0 million and $34.9 million at June 30, 2005, and June 30, 2004, respectively and an unamortized net premium (discount) on issuance of $6.0 million and $(2.7) million at June 30, 2005, and June 30, 2004, respectively.
Forest presents free cash flow, which consists of net cash from operations, exclusive of working capital items less exploration and development capital expenditures. Management uses this measure to assess the Company’s ability to generate cash to repay debt and fund acquisitions. Management interprets trends in this measure in a similar manner as trends in cash flow and liquidity. Free cash flow should not be considered as an alternative to net cash provided by operating activities as defined by GAAP. The following is a reconciliation of net cash provided by operating activities to free cash flow (in thousands):
Three Months Six Months Ended Ended June 30, June 30, ----------------- ----------------- 2005 2004 2005 2004 -------- -------- -------- -------- Net cash provided by operating activities $189,340 145,418 325,423 243,195 Changes in operating assets and liabilities: Accounts receivable (26,988) 14,859 (20,745) (24,251) Other current assets (2,923) (5,943) (1,324) 5,046 Accounts payable and accrued expenses 22,197 (23,604) 45,755 22,420 -------- -------- -------- -------- Net cash flow from operations, exclusive of working capital items 181,626 130,730 349,109 246,410 Exploration and development capital expenditures 104,661 91,748 193,502 141,048 -------- -------- -------- -------- Free cash flow $ 76,965 38,982 155,607 105,362 ======== ======== ======== ========
TELECONFERENCE CALL
Forest Oil Corporation management will hold a teleconference call on Tuesday, August 9, 2005, at 12:00 p.m. MT to discuss the items described in this press release. If you would like to participate please call 800-399-6298 (for U.S./Canada) and 706-634-0924 (for International) and request the Forest Oil teleconference (ID # 8227916).
A replay will be available from Tuesday, August 9 through August 16, 2005. You may access the replay by dialing toll-free 800-642-1687 (for U.S./Canada) and 706-645-9291 (for International), conference ID # 8227916.
FORWARD-LOOKING STATEMENTS
This news release includes forward-looking statements within the meaning of Section 27A of the Securities Act of 1933 and Section 21E of the Securities Exchange Act of 1934. All statements, other than statements of historical facts, that address activities that Forest assumes, plans, expects, believes, projects, estimates or anticipates (and other similar expressions) will, should or may occur in the future are forward-looking statements. The forward-looking statements provided in this press release are based on management’s current belief, based on currently available information, as to the outcome and timing of future events. Forest cautions that its future natural gas and liquids production, revenues and expenses and other forward-looking statements are subject to all of the risks and uncertainties normally incident to the exploration for and development and production and sale of oil and gas. These risks include, but are not limited to, price volatility, inflation or lack of availability of goods and services, environmental risks, drilling and other operating risks, regulatory changes, the uncertainty inherent in estimating future oil and gas production or reserves, and other risks as described in Forest’s 2004 Annual Report on Form 10-K as filed with the Securities and Exchange Commission. Also, the financial results of Forest’s foreign operations are subject to currency exchange rate risks. Any of these factors could cause Forest’s actual results and plans to differ materially from those in the forward-looking statements.
Forest Oil Corporation is engaged in the acquisition, exploration, development, and production of natural gas and liquids in North America and selected international locations. Forest’s principal reserves and producing properties are located in the United States in the Gulf of Mexico, Texas, Louisiana, Oklahoma, Utah, Wyoming and Alaska, and in Canada. Forest’s common stock trades on the New York Stock Exchange under the symbol FST. For more information about Forest, please visit our website at www.forestoil.com.
FOREST OIL CORPORATION Condensed Consolidated Balance Sheets (Unaudited) June 30, December 31, 2005 2004 ----------- ------------ (In Thousands) ASSETS Current assets: Cash and cash equivalents $ 14,048 55,251 Accounts receivable 146,138 151,927 Current deferred tax asset 66,457 38,321 Other current assets 30,019 37,969 ----------- ------------ Total current assets 256,662 283,468 Net property and equipment 3,028,635 2,721,118 Goodwill 99,897 68,560 Other assets 43,531 49,359 ----------- ------------ $ 3,428,725 3,122,505 =========== ============ LIABILITIES AND SHAREHOLDERS' EQUITY Current liabilities: Accounts payable and accrued expenses $ 203,122 217,640 Derivative instruments 136,193 80,523 Asset retirement obligations 36,772 25,452 ----------- ------------ Total current liabilities 376,087 323,615 Long-term debt 917,958 888,819 Asset retirement obligations 180,217 184,724 Derivative instruments 41,259 20,890 Other liabilities 37,492 35,785 Deferred income taxes 317,928 196,525 ----------- ------------ Total liabilities 1,870,941 1,650,358 Shareholders' equity: Common stock 6,386 6,159 Capital surplus 1,493,753 1,444,367 Retained earnings 157,066 66,007 Accumulated other comprehensive (loss) income (48,518) 6,780 Treasury stock, at cost (50,903) (51,166) ----------- ------------ Total shareholders' equity 1,557,784 1,472,147 ----------- ------------ $ 3,428,725 3,122,505 =========== ============
FOREST OIL CORPORATION Condensed Consolidated Statements of Operations (Unaudited) Three Months Six Months Ended Ended June 30, June 30, ----------------- ----------------- 2005 2004 2005 2004 -------- -------- -------- -------- (In Thousands Except Per Share Amounts) Revenue: Oil and gas sales: Natural gas $160,115 131,153 314,641 255,215 Oil, condensate and natural gas liquids 109,240 76,735 213,584 146,510 -------- -------- -------- -------- Total oil and gas sales 269,355 207,888 528,225 401,725 Processing and marketing income, net 1,700 590 3,121 1,006 -------- -------- -------- -------- Total revenue 271,055 208,478 531,346 402,731 Operating expenses: Lease operating expenses 45,783 43,868 93,643 92,057 Production and property taxes 10,547 7,095 20,444 14,543 Transportation costs 4,583 3,728 9,755 7,420 General and administrative 11,091 8,169 21,847 14,529 Depreciation and depletion 97,249 83,474 193,525 163,102 Accretion of asset retirement obligation 4,322 4,153 8,599 8,428 Impairment of oil and gas properties -- 1,690 2,924 1,690 -------- -------- -------- -------- Total operating expenses 173,575 152,177 350,737 301,769 -------- -------- -------- -------- Earnings from operations 97,480 56,301 180,609 100,962 -------- -------- -------- -------- Other income and expense: Interest expense 16,061 13,084 30,560 26,031 Unrealized (gain) loss on derivative instruments (4,310) (1,248) 2,270 (217) Other (income) expense, net 1,659 115 3,592 (1,340) -------- -------- -------- -------- Total other income and expense 13,410 11,951 36,422 24,474 -------- -------- -------- -------- Earnings before income taxes and discontinued operations 84,070 44,350 144,187 76,488 Income tax expense: Current 617 157 2,174 868 Deferred 31,252 16,063 50,941 27,853 -------- -------- -------- -------- Total income tax expense 31,869 16,220 53,115 28,721 -------- -------- -------- -------- Earnings from continuing operations 52,201 28,130 91,072 47,767 Loss from discontinued operations, net of tax -- -- -- (575) -------- -------- -------- -------- Net earnings $ 52,201 28,130 91,072 47,192 ======== ======== ======== ======== Weighted average number of common shares outstanding: Basic 61,419 55,437 60,817 54,560 ======== ======== ======== ======== Diluted 62,727 56,437 62,433 55,594 ======== ======== ======== ======== Basic earnings per common share: Earnings from continuing operations $ .85 .51 1.50 .88 Loss from discontinued operations, net of tax -- -- -- (.01) -------- -------- -------- -------- Net earnings per common share $ .85 .51 1.50 .87 ======== ======== ======== ======== Diluted earnings per common share: Earnings from continuing operations $ .83 .50 1.46 .86 Loss from discontinued operations, net of tax -- -- -- (.01) -------- -------- -------- -------- Net earnings per common share $ .83 .50 1.46 .85 ======== ======== ======== ========
FOREST OIL CORPORATION Condensed Consolidated Statements of Cash Flows (Unaudited) Six Months Ended June 30, --------------------- 2005 2004 ----------- --------- (In Thousands) Cash flows from operating activities: Net earnings $ 91,072 47,192 Adjustments to reconcile net earnings to net cash provided by operating activities: Depreciation and depletion 193,525 163,102 Impairment of oil and gas properties 2,924 1,690 Accretion of asset retirement obligations 8,599 8,428 Unrealized loss (gain) on derivative instruments 2,270 (217) Deferred income tax expense 50,941 28,574 Other, net (222) (2,359) Changes in operating assets and liabilities, net of effects of acquisitions: Accounts receivable 20,745 24,251 Other current assets 1,324 (5,046) Accounts payable and accrued expenses (45,755) (22,420) ----------- --------- Net cash provided by operating activities 325,423 243,195 Cash flows from investing activities: Acquisition of subsidiaries (196,631) (167,968) Capital expenditures for property and equipment: Exploration, development and other acquisition costs (201,577) (163,603) Other fixed assets (4,853) (1,229) Proceeds from sales of assets 6,437 8,510 Sale of goodwill and contract value -- 8,493 Other, net (5,047) 1,168 ----------- --------- Net cash used by investing activities (401,671) (314,629) Cash flows from financing activities: Proceeds from bank borrowings 1,157,953 493,490 Repayments of bank debt assumed in acquisitions (35,000) (30,000) Repayments of bank borrowings (1,126,000) (470,000) Proceeds of common stock offering, net of offering costs -- 117,143 Proceeds from the exercise of options and warrants 38,453 4,541 Other, net 322 (2,566) ----------- --------- Net cash provided by financing activities 35,728 112,608 Effect of exchange rate changes on cash (683) (495) ----------- --------- Net (decrease) increase in cash and cash equivalents (41,203) 40,679 Cash and cash equivalents at beginning of period 55,251 11,509 ----------- --------- Cash and cash equivalents at end of period $ 14,048 52,188 =========== =========