Cash Flow Up 14% to $897 Million
CALGARY, ALBERTA--(Marketwire - July 28, 2011) -
Talisman Energy Inc. (
News -
Market indicators) (NYSE:TLM) reported its operating and financial results for the second quarter of 2011. The company is reporting under International Financial Reporting Standards (IFRS) and all values in this release are in US$ unless otherwise stated.
- Cash flow(1) was $897 million for the quarter, up 14% compared to $790 million a year ago and $811 million in the first quarter.
- Net income was $698 million versus $572 million in 2010 and a net loss of $326 million in the previous quarter.
- Earnings from operations(1) were $168 million, up 14% from the same period last year and up from $157 million in the prior quarter.
- Production for the quarter averaged 420,000 boe/d, compared to 411,000 boe/d in 2010. Production from ongoing operations was up 13%, compared to 372,000 boe/d a year ago.
- Net debt(1) at June 30, 2011 was $3 billion versus $2.5 billion at March 31, 2011.
- The company closed a second transaction with Sasol, selling a 50% interest in its Cypress A Montney shale properties for C$1.05 billion, including certain future development costs.
- Talisman acquired additional acreage in the Alberta Duvernay shale play, bringing its land position to 360,000 net acres.
- The company continues to deliver strong natural gas volumes in Southeast Asia, with price realizations of $9.78/mcf.
- Talisman plans to drill a number of important exploration wells in the second half of this year.
(1) The terms "cash flow", "earnings from operations" and "net debt" are non-GAAP measures. Please see the advisories and reconciliations elsewhere in this news release.
"Talisman achieved a strong financial performance this quarter" said John A. Manzoni, President & CEO. "We continue to grow and strengthen our shale portfolio in North America, and are looking forward to results from a number of significant exploration wells in the second half of the year.
"Total volumes in the quarter were 2% above the comparable number for 2010, although down from the first quarter, largely due to annual maintenance turnarounds. Excluding volumes from assets which have been sold, underlying growth in production is 13% year over year.
"We continue to see strong growth in North American shale volumes, which averaged approximately 470 mmcfe per day in the quarter, an increase of 178% over the same period last year and up 4% over the previous quarter. Our success in the Marcellus is continuing, with production averaging over 400 mmcf per day during the quarter.
"In the liquids-rich Eagle Ford shale play, we now have six rigs running and are planning to build to 10 by year-end. In the Montney shale, we are operating 10 rigs and closed the second transaction with Sasol during the quarter, for approximately C$1 billion, including certain future development costs.
"We are continuing to build our North American shale portfolio, with a sizeable land acquisition during the quarter, in what we hope will emerge as another successful liquids-rich play. Talisman now holds approximately 360,000 net acres in the Alberta Duvernay shale play, acquired at an average cost of about $2,000 per acre. We will begin drilling into the play in the second half of the year, with two rigs.
"In Southeast Asia, volumes continue to be strong, although down from a year ago, reflecting a one-time upward adjustment in the second quarter of last year and annual maintenance turnarounds. Natural gas prices in the region averaged about $9.80 per mcf during the quarter, reflecting strong regional demand and linkage to oil prices.
"North Sea volumes were down relative to both the previous year and the prior quarter, with annual maintenance turnarounds and natural production declines. Ongoing planned turnarounds will result in slightly lower North Sea production in the third quarter, with a return to higher volumes in the fourth quarter when work is completed. Work on future development projects continues and we have seen encouraging early test results at the Grosbeak discovery in Norway.
"The Yme project in Norway took a significant step forward with offshore installation completed at the end of the quarter; however there is still a significant amount of remaining work to commission the topsides. The amount of rework which is required on the platform has turned out to be substantial, and I believe we are now close to defining the full scope. In light of what we have found we are now moving our expectation for first production to the second quarter of 2012.
"In addition, we have seen a slight delay in the final stages of commissioning the non-operated Kitan project, and our Eagle Ford ramp-up was delayed by about three months.
"This combination of factors has led us to revise our current view of production for this year, including Colombia, to between 430,000 and 440,000 boe per day. Excluding Colombia, this represents only slight absolute growth over last year, although it represents between 7 - 10% organic growth from ongoing operations in 2010. It is, nonetheless, below our minimum expectation of 5% absolute growth for the year and I am very disappointed to miss our own target for the first time since I joined the company.
"The factors which have led to this reduction are specific and identifiable, and we remain confident in the underlying quality of the portfolio. Our growth target of 5 - 10% annually in the medium term remains firmly in place.
"There are continuing signs of success in the early testing phase of our international exploration portfolio, which has been largely focused on Colombia and Papua New Guinea to date. In the second half of the year, we plan to drill significant wells in Indonesia, Peru, Poland and the Kurdistan region of northern Iraq.
"Cash flow was $897 million during the quarter, up 14% year over year, reflecting higher oil prices. Similarly, earnings from operations, which adjust for non-operational impacts, were also up 14% to $168 million.
"Net income was $698 million compared to $572 million a year earlier and a loss of $326 million in the first quarter. This reflects the impact of changing commodity prices on the mark-to-market value of held-for-trading financial instruments and changes in the non-cash value of share based payments.
"We continue to expect that our cash exploration and development capital spending will be between $4 to $4.5 billion. In addition, we have spent $510 million on land purchases in the quarter.
"I am confident in the structure of our portfolio to deliver long-term, profitable growth of 5 - 10%. The project set-backs we have experienced are localized, but nevertheless, reinforce the need to continue the improvements we have begun across our business to address project execution and delivery. We can look forward to getting these issues behind us, and to drilling a number of important exploration wells through the second half. The underlying financial performance was strong this quarter, and we will continue to focus on effectively delivering against our strategy, with our strong portfolio of assets."
Financial Results
June 30 Three Months Ended Six Months Ended
2011 2010 2011 2010
------------------------------------
------------------------------------
Cash flow ($ million) 897 790 1,708 1,595
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Cash flow per share(2) 0.88 0.78 1.67 1.57
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------------------------------------
Net income ($ million) 698 572 372 943
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Net income per share 0.68 0.56 0.36 0.93
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------------------------------------
Earnings from operations ($ million) 168 148 325 303
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Earnings from operations per share (2) 0.16 0.15 0.32 0.30
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------------------------------------
Average shares outstanding
- basic (million) 1,025 1,018 1,024 1,018
(2) The terms "cash flow per share" and "earnings from operations per share"
are non-GAAP measures. For a reconciliation of non-GAAP measures to the
corresponding GAAP measures and presentation of diluted cash flow per
share and earnings from operations per share, please see the advisories
and reconciliations elsewhere in this news release.
Cash flow was $897 million for the quarter, compared to $790 million a year ago as a result of higher oil prices, which more than offset increased royalties, cash taxes and realized losses on held-for-trading financial instruments.
During the second quarter, net income increased to $698 million from $572 million a year ago, also due to higher prices. Talisman recorded a first quarter loss of $326 million but saw a substantial shift in both non-cash share based payments and the mark-to-market value of held-for-trading financial instruments.
Earnings from operations were up 14% to $168 million compared to $148 million a year earlier and $157 million in the previous quarter.
The company's depreciation, depletion and amortization (DD&A) expense was $479 million in the second quarter, up 17% over last year as a result of the Auk North field start-up, Equion acquisition, higher production volumes and the change in unlifted oil volumes. Dry hole expense was $36 million and includes an unsuccessful exploration well in Papua New Guinea. Exploration expense increased by $67 million relative to 2010 as a result of seismic activities in Indonesia, Papua New Guinea, Colombia and North America.
Net debt increased from $2.5 billion to $3 billion in the second quarter, reflecting a $510 million land acquisition in North America.
Gross production
June 30 Three Months Ended Six Months Ended
2011 2010 2011 2010
------------------------------------
------------------------------------
Oil and liquids (bbls/d) 175,000 182,000 186,000 195,000
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Natural gas (mmcf/d) 1,470 1,376 1,478 1,372
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Total (boe/d) 420,000 411,000 432,000 423,000
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------------------------------------
Ongoing operations (boe/d) 420,000 372,000 432,000 381,000
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Total production this quarter increased by 2% over the comparable period for 2010, but down by 5% over the first quarter as a result of annual maintenance turnarounds in the North Sea and Southeast Asia.
Production from ongoing operations increased by 13% over the same period last year, reflecting a 47% increase in underlying North American natural gas volumes, the Equion acquisition and the Auk North field start-up in the UK.
Netbacks
June 30 Three Months Ended Six Months Ended
$/boe 2011 2010 2011 2010
------------------------------------
------------------------------------
Sales 68.47 51.48 67.08 53.18
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Royalties (13.28) (8.51) (12.34) (8.33)
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Transportation (1.35) (1.47) (1.38) (1.49)
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Operating expenses (14.36) (12.47) (13.31) (12.60)
------------------------------------
Netback 39.48 29.03 40.05 30.76
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------------------------------------
Oil & liquids netback ($/bbl) 61.97 40.82 63.39 42.55
------------------------------------
Natural gas netback ($/mcf) 3.90 3.28 3.74 3.46
------------------------------------
Netbacks in the second quarter averaged $39.48/boe, up 36% from a year ago and 3% lower than the first quarter. Talisman's realized price (before hedging) of $68.47/boe was 33% higher than 2010, due principally to higher global oil and liquids prices. WTI oil prices averaged $103/bbl, up 31 % from the same period last year. NYMEX natural gas prices averaged $4.36/mmbtu, compared to $4.07/mmbtu a year ago.
Talisman's royalty rate averaged 18% during the quarter, up 1% from the same period last year. Unit operating expenses increased by 15% over the same period last year due to more expansive turnarounds in the North Sea, well maintenance in Southeast Asia, the change in unlifted oil volumes, additional operations in Colombia and the stronger British pound.
North America
In North America, production averaged 1,016 mmcfe/d (169,000 boe/d) for the second quarter, up 7% from a year ago. Capital spending was $433 million in the second quarter, including $388 million related to shale activities.
Production from shale averaged 470 mmcfe/d (78,000 boe/d) in the second quarter, an increase of 178% over the previous year, and an increase of 4% over the previous quarter. Conventional production averaged 546 mmcfe/d (91,000 boe/d) in the second quarter.
Talisman spent $510 million on land acquisitions in Alberta during the quarter. The company's position in the Duvernay shale now totals 360,000 net acres, with an average acquisition cost of approximately $2,000 per acre. Talisman plans drilling into the play in the second half of this year with two rigs.
In the Marcellus shale, Talisman USA drilled 39 gross wells (28 net) during the quarter for a total of 65 gross wells (49 net) for the first six months of 2011. Production averaged 406 mmcf/d for the quarter, up 16% from the previous quarter and up 184% from the second quarter of 2010. Talisman now expects to be at the upper end of its annual production guidance of 350 - 400 mmcf/d as it builds out new wells and infrastructure in the eastern part of the play.
In the Farrell Creek area of the Montney shale, Talisman drilled 12 gross (six net) development wells during the quarter for a total of 20 gross wells (10 net) in the first six months of 2011. Net production averaged 22 mmcf/d for the quarter. The company currently has 10 rigs running. Overall, in the Montney play, we continue to be on track to meet our production guidance for the year.
Talisman has closed a second deal with Sasol, selling a 50% working interest in its Cypress A properties for a total consideration of C$1.05 billion, consisting of $257 million in cash and funding certain future development costs. The two companies have commenced a feasibility study on a gas-to-liquids plant in Western Canada.
In the Eagle Ford shale, Talisman USA drilled 10 gross (four net) horizontal development wells during the quarter for a total of 19 gross wells (seven net) in the first six months of 2011. Production averaged 16 mmcfe/d for the quarter. The company has six rigs operating in the area, with plans to increase this to 10 by year-end.
Earlier this year, the partners agreed to use dedicated frac crews in the Eagle Ford rather than pay significantly higher spot rates. These crews are up and running; however, the result will be fewer wells and lower production for the year than anticipated. During the quarter, the partners also reached agreement to acquire additional acreage in the Eagle Ford.
Production from Talisman's conventional properties averaged 417 mmcf/d of natural gas and 21,600 bbls/d of liquids for the second quarter.
North Sea
North Sea production averaged 105,500 boe/d, compared to 136,000 boe/d in the previous quarter and 114,960 boe/d a year ago. Production was lower due to planned annual maintenance in both the UK and Norway, and natural field declines.
Production in the UK averaged 73,200 boe/d, a 20% reduction from the previous quarter and an increase of 14% over the previous year, primarily driven by the start-up of Auk North. Against the previous quarter, production was reduced by a turnaround, completed as planned at Piper/Tweedsmuir, as well as natural declines at Tweedsmuir. Production is expected to be impacted further in the third quarter with shutdowns planned at Claymore, Tartan, Buchan and Ross/Blake.
Production in Norway averaged 32,300 boe/d, a 36% decrease over the same period in 2010 and a 27% decrease from the previous quarter. Volumes decreased quarter on quarter due to completion of maintenance turnarounds at Brage and Veslefrikk, with similar impacts expected in the third quarter due to a planned turnaround at Rev. Production also continues to be impacted by natural declines at Rev.
Work on future developments continued in the quarter, with Talisman spending $307 million in the North Sea. A fourth production well in the UK Auk North field was successfully completed in early July, and development wells at Gyda and Veslefrikk were also successfully completed in Norway. A gaslift project has increased production potential from Gyda by approximately 20%. A sidetrack is planned in early 2012 at Rev to mitigate the natural decline in the field.
The Yme project took a significant step forward with offshore installation at the end of the quarter. During the quarter, Talisman completed some required rework onshore; however, there is still a significant amount of remaining work to commission the topsides. The company now expects first production from Yme will commence in the second quarter of 2012.
Southeast Asia
Production for the second quarter was 116,200 boe/d, 1% higher than the previous period and 7% lower than same period last year. During the quarter, natural gas prices averaged $9.78/mcf. The company invested $22 million in development activities.
In Malaysia, production averaged 37,500 boe/d, 4% higher than last quarter, and 10% lower than the same period last year. Liquids were higher in 2010, largely due to a one-time redetermination of the company's working interest in the South Angsi field, with an associated increase of 7,000 boe/d in that period. Gas sales averaged 119 mmcf/d, 4% higher than the previous quarter, reflecting optimization initiatives at the PM3 facilities and strong regional demand. To meet fast growing gas demand across Malaysia, Talisman is working closely with its joint venture partners to develop further initiatives at PM3 to increase gas production over the coming months.
In Indonesia, production was 74,200 boe/d, 1% higher than last quarter and 5% lower than the same period last year, reflecting increased maintenance activities and planned plant shutdowns at Corridor and Tangguh during the current period. The Jambi Merang project delivered first gas sales in April, three months ahead of schedule, and attained a daily production of 76 mmcf/d gross sales gas (19 mmcf/d net sales) by the end of second quarter. Volumes are expected to reach 120 mmcf/d gross sales gas (30 mmcf/d net sales gas) in the third quarter. The first of two planned Corridor infill wells was drilled, completed and brought on production. The Sumpal 6 well was brought on stream and is currently flowing at 35 mmcf/d gross raw gas (8 mmcf/d net sales gas) and it is expected to ramp up to 120 mmcf/d gross raw gas (28 mmcf/d net sales gas) by the end of next quarter.
At Corridor, the Letang Tengah Rawa optimization project was sanctioned during the quarter and is expected to deliver 45 mmcf/d gross sales gas (16 mmcf/d net sales gas) to the premium priced Caltex/Duri gas sales contract from the beginning of 2013.
Following maintenance turnarounds in the first half of the year, the two Tangguh production trains are now operating at close to nameplate capacity.
In Vietnam, production averaged 1,800 bbls/d. The Hai Su Trang and Hai Su Den development is progressing and is expected to be sanctioned in the fourth quarter of this year.
Production averaged 2,600 bbls/d in Australia. The company expects a slight delay in commissioning the non-operated Kitan project, which is still anticipated in the fourth quarter.
International Exploration
International exploration spending in the second quarter of $282 million was focused on exploration and appraisal wells in Papua New Guinea (PNG), Colombia and the North Sea, and active seismic programs in Southeast Asia and Latin America.
Talisman is on target to participate in seven exploration and appraisal wells in the PNG Foreland Basin in 2011. Seismic acquisition for the current program was completed at the end of June. The Stanley-2 and Stanley-4 appraisal wells and the Ubuntu-1 and Awapa-1 exploration wells have been drilled, and the Siphon-1 exploration well was spudded at the end of June. The Awapa well was dry; however, this was a commitment well which was not part of the gas aggregation strategy, and we remain confident in our objective of successfully aggregating 2-4 tcf.
In Malaysia, the Sabah 3D seismic acquisition program commenced in the second quarter, and the drilling program is expected to begin in 2012. In Vietnam, 3D seismic in Blocks 135 and 136 concluded in early July, and a 2D seismic program is on target to commence in the third quarter. A Production Sharing Contract for Blocks 135 and 136 was signed in April with PetroVietnam; Talisman is the operator and has a 40% working interest.
In Indonesia, the South Makassar seismic acquisition program was completed in the second quarter, and the company is on target to spud the Lempuk well in the third quarter. Talisman signed a farmout agreement with Total E&P in three of Talisman's blocks in South Makassar (33 - 50% equity). Total is the largest gas producer in Indonesia and brings significant deepwater experience and potential access to markets. The farmout agreement is subject to government approval.
In Colombia, Talisman completed drilling the sixth stratigraphic well in Block 6. The partners in the block are in the process of converting Block 6 to an Exploration and Production Contract and finalizing plans to fully appraise the Guairuro discovery, with a possible 3D seismic acquisition program in late 2011.
In the Niscota block, the Huron-2 appraisal well spudded on June 30, 2011 and is currently drilling. The Huron-3 appraisal well is expected to spud by mid-year 2012.
In Block 8, Talisman completed the first phase (245 kilometers) of seismic data acquisition and a two-well stratigraphic drilling program is expected to commence in the fourth quarter.
In Block 9, a six month production test of the Akacias-1 discovery commenced in late May and is currently producing approximately 1,600 bbls/d (gross) of oil. The company is looking to acquire 200 kilometers of 2D seismic data and initiate a four-well appraisal well program later this year. A re-entry and test of the Humadea discovery well and a Humadea exploration well are scheduled in the first quarter 2012.
Since the closing of the acquisition of Equion Energia (49% net Talisman), production has averaged 12,000 boe/d (net Talisman). Equion is planning to drill two development wells in the Piedemonte field in the second half of 2011. These wells are part of a full-scale expansion of the Piedemonte complex, with project sanction planned for the first half of 2012.
In Peru, Talisman is progressing towards a fourth quarter spud of the Situche Norte exploration well. This is a follow-up well to the successful Situche Central 3X exploration well which was drilled in 2010.
In Norway, the Grosbeak appraisal well on PL378 reached target depth in the second quarter and the Brent formation has been successfully tested at 4,800 boe/d (gross). Talisman is also participating in the Skalle and Peking Duck exploration wells, both of which are expected to reach target depth in the third quarter.
In Poland, seismic acquisition is complete and Talisman remains on target to spud its first two shale gas wells later this year.
In the Kurdistan region of northern Iraq, the Topkhana-1 exploration well in Block K39 is drilling ahead and the Kurdamir-2 well in Block K44 is expected to spud in the fourth quarter.
Talisman Energy Inc. is a global, diversified, upstream oil and gas company, headquartered in Canada. Talisman's three main operating areas are North America, the North Sea and Southeast Asia. The company also has a portfolio of international exploration opportunities. Talisman is committed to conducting business safely, in a socially and environmentally responsible manner, and is included in the Dow Jones Sustainability (North America) Index. Talisman is listed on the Toronto and New York stock exchanges under the symbol TLM. Please visit our website at
www.talisman-energy.com.
Forward-Looking Information
This news release contains information that constitutes "forward-looking information" or "forward-looking statements" (collectively "forward-looking information") within the meaning of applicable securities legislation. This forward-looking information includes, among others, statements regarding:
- expected timing of first production of the Yme field;
- management's expectation for annual production growth and organic growth;
- expected cash exploration and development spending;
- planned drilling in Talisman's conventional properties in North America, and in the UK, Norway, Indonesia, Malaysia, Papua New Guinea, Peru, Poland and the Kurdistan region of Northern Iraq;
- planned drilling program in the Alberta Duvernay;
- expected drilling, rigs and production in the Eagle Ford shale;
- expected annual production in the Marcellus and Montney shale;
- expected closing of the Eagle Ford transaction;
- planned turnarounds and expected impacts on production in the North Sea;
- planned Gyda infill drilling
- expected production in Indonesia, including production from the Sumpal 6 well and Letang Tengah Rawa optimization project;
- expected seismic program in Vietnam;
- expected sanctioning of the Hai Su Trang and Hai Su Den development;
- potential initiatives at PM3;
- expected timing of the Skalle and Peking Duck wells;
- expected commissioning of the Kitan project;
- the expected spud of the Lempuk well, the Situche Norte exploration well, the Kurdamir-2 well, the Huron-3 appraisal well, and shale gas wells in Poland;
- expected appraisal, seismic acquisition, exploration, testing, drilling, and development in Colombia;
- Equion's expected drilling and project sanctioning in the Piedemonte complex; and
- other business strategy, plans and priorities.
The forward-looking information contained herein assumes production will be between 430,000 and 440,000 boe/d in 2011, a WTI oil price of approximately US$95/bbl, a NYMEX natural gas price of approximately US$4/mmbtu and 2011 cash exploration and development capital spending of $4 to $4.5 billion. Information regarding business plans generally assumes that the extraction of crude oil, natural gas and natural gas liquids remains economic. Closing of any transactions will be subject to receipt of all necessary regulatory approvals and completion of definitive agreements.
Undue reliance should not be placed on forward-looking information. Forward-looking information is based on current expectations, estimates and projections that involve a number of risks, which could cause actual results to vary and in some instances to differ materially from those anticipated by Talisman and described in the forward-looking information contained in this news release. The material risk factors include, but are not limited to:
- the risks of the oil and gas industry, such as operational risks in exploring for, developing and producing crude oil and natural gas, market demand and unpredictable facilities outages;
- risks and uncertainties involving geology of oil and gas deposits;
- uncertainty related to securing sufficient egress and markets to meet shale gas production;
- the uncertainty of reserves and resources estimates, reserves life and underlying reservoir risk;
- the uncertainty of estimates and projections relating to production, costs and expenses;
- the impact of the economy on the ability of the counterparties to the company's commodity price derivative contracts to meet their obligations under the contracts;
- potential delays or changes in plans with respect to exploration or development projects or capital expenditures;
- fluctuations in oil and gas prices, foreign currency exchange rates and interest rates;
- the outcome and effects of any future acquisitions and dispositions;
- health, safety and environmental risks;
- uncertainties as to the availability and cost of financing and changes in capital markets;
- risks in conducting foreign operations (for example, political and fiscal instability or the possibility of civil unrest or military action);
- changes in general economic and business conditions;
- the possibility that government policies or laws may change or governmental approvals may be delayed or withheld, including with respect to share gas drilling; and
- results of the company's risk mitigation strategies, including insurance and any hedging activities.
The foregoing list of risk factors is not exhaustive. Additional information on these and other factors, which could affect the company's operations or financial results, are included in the company's most recent Annual Information Form. In addition, information is available in the company's other reports on file with Canadian securities regulatory authorities and the United States Securities and Exchange Commission (SEC). Forward-looking information is based on the estimates and opinions of the company's management at the time the information is presented. The company assumes no obligation to update forward-looking information should circumstances or management's estimates or opinions change, except as required by law.
Unless the context indicates otherwise, references in this news release to "Talisman" or the "company" include, for reporting purposes only, the direct or indirect subsidiaries of Talisman Energy Inc. and the partnership interests held by Talisman Energy Inc. and its subsidiaries. Such use of "Talisman" or the "company" to refer to these other legal entities and partnership interests does not constitute waiver by Talisman Energy Inc. or such entities or partnerships of their separate legal status, for any purpose.
The completion of any contemplated disposition or acquisition is contingent on various factors including favorable market conditions, the ability of the company to negotiate acceptable terms of sale and receipt of any required approvals for such disposition.
Oil and Gas Information
Throughout this news release, Talisman makes reference to production volumes. Unless otherwise stated, such production volumes are stated on a gross basis, which means they are stated prior to the deduction of royalties and similar payments. In the US, net production volumes are reported after the deduction of these amounts.
Barrel of oil equivalent (boe) throughout this news release is calculated at a conversion rate of six thousand cubic feet (mcf) of natural gas for one barrel of oil (bbl). This news release also includes reference to mcf equivalents (mcfes) which are calculated at a conversion rate of one barrel of oil to 6,000 cubic feet of gas. Boes and mcfes may be misleading, particularly if used in isolation. A boe conversion ratio of 6 mcf:1 bbl and an mcfe conversion ration of 1 bbl: 6 mcf are based on an energy equivalence conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead.
Talisman also discloses its company netbacks in this news release. Netbacks per boe are calculated by deducting from sales price associated royalties, operating and transportation costs.
Non-GAAP Financial Measures
Included in this news release are references to financial measures commonly used in the oil and gas industry such as cash flow, earnings from operations, net debt and capital expenditure including exploration expensed. These terms are not defined by International Financial Reporting Standards (IFRS). Consequently, these are referred to as non-GAAP measures. Talisman's reported results of cash flow, earnings from operations, net debt and capital expenditure including exploration expensed may not be comparable to similarly titled measures reported by other companies.
Cash Flow
US$ million, except per share amounts
Three months ended Six months ended
------------------------------------------
June 30, June 30, June 30, June 30,
2011 2010 2011 2010
----------------------------------------------------------------------------
Cash provided by operating
activities 896 860 1,779 1,892
Changes in non-cash working capital (94) (91) (221) (363)
Add: Exploration expenditure 136 69 248 162
Less: Finance costs (cash) (41) (48) (98) (96)
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Cash flow 897 790 1,708 1,595
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Cash flow per share 0.88 0.78 1.67 1.57
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Diluted cash flow per share 0.86 0.77 1.63 1.53
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Cash flow, as commonly used in the oil and gas industry, represents net income before exploration costs, DD&A, future taxes and other non-cash expenses. Cash flow is used by the company to assess operating results between years and between peer companies using different accounting policies. Cash flow should not be considered an alternative to, or more meaningful than, cash provided by operating, investing and financing activities or net income as determined in accordance with IFRS as an indicator of the company's performance or liquidity. Cash flow per share is cash flow divided by the average number of common shares outstanding during the period. Diluted cash flow per share is cash flow divided by the diluted number of common shares outstanding during the period, as reported in the interim condensed consolidated financial statements filed on July 28, 2011. A reconciliation of cash provided by operating activities to cash flow is provided above.
Earnings from Operations
US$ million, except per share amounts
Three months ended Six months ended
------------------------------------------
June 30, June 30, June 30, June 30,
2011 2010 2011 2010
----------------------------------------------------------------------------
Net income 698 572 372 943
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Gain on disposal and income from
assets sold (tax adjusted) (89) (295) (157) (370)
Unrealized (gain) loss on financial
instruments (tax adjusted)(1) (181) (95) 82 (230)
Share-based payments(2)(tax adjusted) (179) (51) (71) (100)
Foreign exchange on debt - - 8 -
Impairment losses (tax adjusted) - 3 39 32
Deferred tax adjustments(3) (81) 14 52 28
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Earnings from operations(4) 168 148 325 303
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Earnings from operations per share(4) 0.16 0.15 0.32 0.30
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Diluted earnings from operations
per share(4) 0.16 0.14 0.31 0.29
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1. Unrealized (gain) loss on financial instruments relates to the change
in the period of the mark-to-market value of the company's outstanding
commodity derivatives that are classified as held-for-trading financial
instruments.
2. Share-based payments relate principally to the mark-to-market value of
the company's outstanding stock options and cash units at June 30. The
company uses the Black-Scholes option pricing model to estimate the
fair value of its share-based payment plans.
3. Deferred tax adjustments include deferred taxes relating to unrealized
foreign exchange gains and losses associated with the impact of
fluctuations in the Canadian dollar on foreign denominated debt,
intercompany loans and tax pool balances, as well as a remeasurement of
UK deferred tax assets and liabilities in response to a statutory rate
change.
4. This is a non-GAAP measure.
Earnings from operations are calculated by adjusting the company's net income per the financial statements, for certain items of a non-operational nature, on an after tax basis. The company uses this information to evaluate performance of core operational activities on a comparable basis between periods. Earnings from operations per share are earnings from operations divided by the average number of common shares outstanding during the period. Diluted earnings from operations per share are earnings from operations divided by the diluted number of common shares outstanding during the period, as reported in the interim condensed consolidated financial statements filed on July 28, 2011. A reconciliation of net income to earnings from operations is provided above.
Net Debt
US$ million
June 30, 2011 March 31, 2011
----------------------------------------------------------------------------
Long-term debt 3,858 3,859
Bank indebtedness 2 8
Cash and cash equivalents (860) (1,327)
----------------------------------------------------------------------------
Net debt 3,000 2,540
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Net debt is calculated by adjusting the company's long-term debt per the financial statements for bank indebtedness, cash and cash equivalents. The company uses this information to assess its true debt position and eliminate the impact of timing differences.
Capital Expenditure Including Exploration Expensed
US$ million
Three Months Ended Six Months Ended
June 30, June 30, June 30, June 30,
2011 2010 2011 2010
----------------------------------------------------------------------------
Exploration, development and other 997 863 1,907 1,497
Exploration expensed 136 69 248 162
----------------------------------------------------------------------------
Total capital expenditures 1,133 932 2,155 1,659
----------------------------------------------------------------------------
Capital expenditure including exploration expensed is calculated by
adjusting the capital expenditure per the financial statements for
exploration costs that were expensed as incurred.
Talisman Energy Inc.
Highlights
(unaudited)
Three months ended Six months ended
June 30 June 30
2011 2010 2011 2010
----------------------------------------------------------------------------
Financial
(millions of US$ unless
otherwise stated)
Cash flow (1) 897 790 1,708 1,595
Net income 698 572 372 943
Capital expenditure including 1,133 932 2,155 1,659
Exploration expensed (1)
Per common share (US$)
Cash flow (1) 0.88 0.78 1.67 1.57
Net income 0.68 0.56 0.36 0.93
----------------------------------------------------------------------------
Production
(Daily Average - Gross)
Oil and liquids (bbls/d)
North America 22,730 25,165 21,911 25,480
North Sea 96,186 99,851 109,200 113,533
Southeast Asia 32,832 43,421 32,845 41,501
Other 22,983 13,470 21,578 13,821
----------------------------------------------------------------------------
Total oil and liquids 174,731 181,907 185,534 194,335
----------------------------------------------------------------------------
Natural gas (mmcf/d)
North America 875 797 880 792
North Sea 56 91 69 100
Southeast Asia 500 488 497 480
Other 39 - 32 -
----------------------------------------------------------------------------
Total natural gas 1,470 1,376 1,478 1,372
----------------------------------------------------------------------------
Total mboe/d (2) 420 411 432 423
----------------------------------------------------------------------------
Prices
Oil and liquids (US$/bbl)
North America 79.33 60.77 74.29 63.92
North Sea 117.04 78.07 110.28 77.62
Southeast Asia 118.74 79.29 118.01 77.86
Other 112.67 75.39 113.46 75.30
----------------------------------------------------------------------------
Total oil and liquids 111.88 75.77 107.77 75.71
----------------------------------------------------------------------------
Natural gas (US$/mcf)
North America 4.22 4.62 4.14 5.10
North Sea 8.82 5.28 8.66 5.44
Southeast Asia 9.78 6.60 9.26 6.65
Other 3.04 - 4.03 -
----------------------------------------------------------------------------
Total natural gas 6.25 5.37 6.07 5.67
----------------------------------------------------------------------------
Total (US$/boe) (2) 68.47 51.48 67.08 53.18
----------------------------------------------------------------------------
(1) Cash flow, capital expenditure including exploration expensed and cash
flow per share are non-GAAP measures.
(2) Barrels of oil equivalent (boe) is calculated at a conversion rate of
six thousand cubic feet (mcf) of natural gas for one barrel of oil.
Talisman Energy Inc.
Condensed Consolidated Balance Sheets
(unaudited)
June 30, December 31, January 1,
(millions of US$) 2011 2010 2010
----------------------------------------------------------------------------
Assets
Current
Cash and cash equivalents 860 1,655 1,628
Accounts receivable 1,540 1,287 1,216
Risk management 49 119 29
Inventories 187 144 141
Prepaid expenses 33 20 8
Assets held for sale - - 22
----------------------------------------------------------------------------
2,669 3,225 3,044
----------------------------------------------------------------------------
Other assets 425 788 108
Risk management 34 25 40
Goodwill 1,252 1,164 1,183
Property, plant and equipment 14,434 13,266 13,254
Exploration and evaluation assets 4,017 3,442 2,212
Deferred tax assets 206 184 147
----------------------------------------------------------------------------
20,368 18,869 16,944
----------------------------------------------------------------------------
Total assets 23,037 22,094 19,988
----------------------------------------------------------------------------
----------------------------------------------------------------------------
Liabilities
Current
Bank indebtedness 2 2 35
Accounts payable and accrued liabilities 3,014 2,722 2,040
Risk management 155 117 266
Income and other taxes payable 785 513 341
Current portion of long-term debt 7 359 10
Liabilities associated with assets held
for sale - - 7
----------------------------------------------------------------------------
3,963 3,713 2,699
----------------------------------------------------------------------------
Deferred credits 33 46 47
Decommissioning liabilities 2,636 2,580 2,003
Other long-term obligations 234 280 269
Risk management - - 6
Long-term debt 3,851 3,845 3,601
Deferred tax liabilities 2,712 2,435 2,516
----------------------------------------------------------------------------
9,466 9,186 8,442
----------------------------------------------------------------------------
Shareholders' equity
Common shares, no par value
Authorized: unlimited
Issued and outstanding:
June 30, 2011 - 1,024,656,352
(December 31, 2010 -
1,019,290,939; January 1, 2010
- 1,014,876,564) 1,610 1,480 1,401
Contributed surplus 154 108 117
Retained earnings 7,065 6,831 6,135
Accumulated other comprehensive income 779 776 1,194
----------------------------------------------------------------------------
9,608 9,195 8,847
----------------------------------------------------------------------------
Total liabilities and shareholders' equity 23,037 22,094 19,988
----------------------------------------------------------------------------
----------------------------------------------------------------------------
Talisman Energy Inc.
Condensed Consolidated Statements of Income
(unaudited)
Three months ended Six months ended
June 30 June 30
(millions of US$) 2011 2010 2011 2010
----------------------------------------------------------------------------
Revenue
Sales 2,216 1,574 4,188 3,382
Other income 18 26 46 54
----------------------------------------------------------------------------
Total revenue and other income 2,234 1,600 4,234 3,436
----------------------------------------------------------------------------
Expenses
Operating 555 459 1,007 960
Transportation 52 55 108 114
General and administrative 108 81 206 158
Depreciation, depletion and amortization 479 408 948 889
Impairment - 4 102 93
Dry hole 36 30 140 36
Exploration 136 69 248 162
Finance costs 60 68 136 137
Share-based payments recovery (176) (61) (60) (131)
(Gain) loss on held-for-trading financial
instruments (68) (64) 251 (162)
Gain on asset disposals (122) (262) (214) (315)
Other, net 23 (6) 81 15
----------------------------------------------------------------------------
Total expenses 1,083 781 2,953 1,956
----------------------------------------------------------------------------
Income before taxes 1,151 819 1,281 1,480
----------------------------------------------------------------------------
Taxes
Current income tax 436 181 879 445
Deferred income tax 17 66 30 92
----------------------------------------------------------------------------
453 247 909 537
----------------------------------------------------------------------------
Net income 698 572 372 943
----------------------------------------------------------------------------
----------------------------------------------------------------------------
Per common share (US$):
Net income 0.68 0.56 0.36 0.93
Diluted net income 0.50 0.50 0.26 0.79
----------------------------------------------------------------------------
Weighted average number of common shares
outstanding (millions)
Basic 1,025 1,018 1,024 1,018
Diluted 1,044 1,029 1,047 1,042
----------------------------------------------------------------------------
----------------------------------------------------------------------------
Talisman Energy Inc.
Condensed Consolidated Statements of Cash Flows
(unaudited)
Three months ended Six months ended
June 30 June 30
(millions of US$) 2011 2010 2011 2010
----------------------------------------------------------------------------
Operating activities
Net income 698 572 372 943
Add: Finance costs (cash and non-cash) 60 68 136 137
Items not involving cash 44 129 1,050 449
----------------------------------------------------------------------------
802 769 1,558 1,529
Changes in non-cash working capital 94 91 221 363
----------------------------------------------------------------------------
Cash provided by operating activities 896 860 1,779 1,892
----------------------------------------------------------------------------
Investing activities
Capital expenditures
Exploration, development and other (997) (863) (1,907) (1,497)
Corporate acquisitions, net of cash
acquired 19 - (156) (183)
Property acquisitions (542) (346) (573) (372)
Proceeds of resource property dispositions 290 1,193 539 1,318
Acquisition deposit - - 18 -
Investments - - 54 -
Changes in non-cash working capital 53 (25) (87) (78)
----------------------------------------------------------------------------
Cash used in investing activities (1,177) (41) (2,112) (812)
----------------------------------------------------------------------------
Financing activities
Long-term debt repaid (2) (10) (310) (10)
Common shares issued 35 5 114 10
Common shares purchased (24) (26) (42) (26)
Finance costs (cash) (41) (48) (98) (96)
Common share dividends (138) (122) (138) (122)
Deferred credits and other (17) (4) (20) (10)
Changes in non-cash working capital - 1 (1) (1)
----------------------------------------------------------------------------
Cash used in financing activities (187) (204) (495) (255)
----------------------------------------------------------------------------
Effect of translation on foreign
currency cash and cash equivalents 7 (61) 33 (34)
----------------------------------------------------------------------------
Net increase (decrease) in cash and
cash equivalents (461) 554 (795) 791
Cash and cash equivalents net of bank
indebtedness, beginning of period 1,319 1,830 1,653 1,593
----------------------------------------------------------------------------
Cash and cash equivalents net of bank
indebtedness, end of period 858 2,384 858 2,384
----------------------------------------------------------------------------
----------------------------------------------------------------------------
Cash and cash equivalents 860 2,417 860 2,417
Bank indebtedness (2) (33) (2) (33)
----------------------------------------------------------------------------
Cash and cash equivalents net of bank
indebtedness, end of period 858 2,384 858 2,384
----------------------------------------------------------------------------
----------------------------------------------------------------------------
Talisman Energy Inc.
Segmented Information
(unaudited)
North America (1)
----------------------------------------------------------------------------
Three months ended Six months ended
June 30 June 30
(millions of US$) 2011 2010 2011 2010
----------------------------------------------------------------------------
Revenue
Sales 448 442 852 919
Other income 13 22 36 45
----------------------------------------------------------------------------
Total revenue and other income 461 464 888 964
----------------------------------------------------------------------------
Segmented expenses
Operating 100 130 211 257
Transportation 14 15 30 34
DD&A 203 176 404 360
Impairment - 4 - 28
Dry hole 1 (14) 3 (13)
Exploration 12 2 39 31
Other (1) (31) 6 (33)
----------------------------------------------------------------------------
Total segmented expenses 329 282 693 664
----------------------------------------------------------------------------
Segmented income (loss) before taxes 132 182 195 300
----------------------------------------------------------------------------
Non-segmented expenses
General and administrative
Finance costs
Share-based payments recovery
Currency translation
(Gain) loss on held-for-trading
financial instruments
Gain on asset disposals
----------------------------------------------------------------------------
Total non-segmented expenses
----------------------------------------------------------------------------
Income before taxes
----------------------------------------------------------------------------
----------------------------------------------------------------------------
Capital expenditures
Exploration 55 83 138 167
Development 378 291 729 447
Midstream - 1 - -
----------------------------------------------------------------------------
Exploration and development 433 375 867 614
----------------------------------------------------------------------------
Acquisitions
Proceeds on dispositions
Other non-segmented
----------------------------------------------------------------------------
Net capital expenditures
----------------------------------------------------------------------------
Property, plant and equipment 5,661 5,351
Exploration and evaluation assets 2,331 1,886
Goodwill 140 149
Other 1,024 2,389
----------------------------------------------------------------------------
Segmented assets 9,156 9,775
Non-segmented assets
----------------------------------------------------------------------------
Total assets (5)
----------------------------------------------------------------------------
Decommissioning liabilities (5) 203 210
----------------------------------------------------------------------------
North Sea (2)
----------------------------------------------------------------------------
Three months ended Six months ended
June 30 June 30
(millions of US$) 2011 2010 2011 2010
----------------------------------------------------------------------------
Revenue
Sales 1,167 717 2,255 1,658
Other income 5 3 10 8
----------------------------------------------------------------------------
Total revenue and other income 1,172 720 2,265 1,666
----------------------------------------------------------------------------
Segmented expenses
Operating 357 259 617 567
Transportation 23 23 46 47
DD&A 181 157 367 385
Impairment - - 102 65
Dry hole 2 43 77 43
Exploration 7 8 18 23
Other 5 15 14 21
----------------------------------------------------------------------------
Total segmented expenses 575 505 1,241 1,151
----------------------------------------------------------------------------
Segmented income (loss) before taxes 597 215 1,024 515
----------------------------------------------------------------------------
Non-segmented expenses
General and administrative
Finance costs
Share-based payments recovery
Currency translation
(Gain) loss on held-for-trading
financial instruments
Gain on asset disposals
----------------------------------------------------------------------------
Total non-segmented expenses
----------------------------------------------------------------------------
Income before taxes
----------------------------------------------------------------------------
----------------------------------------------------------------------------
Capital expenditures
Exploration 54 63 105 67
Development 307 244 552 506
Midstream - - - -
----------------------------------------------------------------------------
Exploration and development 361 307 657 573
----------------------------------------------------------------------------
Acquisitions
Proceeds on dispositions
Other non-segmented
----------------------------------------------------------------------------
Net capital expenditures
----------------------------------------------------------------------------
----------------------------------------------------------------------------
Property, plant and equipment 5,462 5,368
Exploration and evaluation assets 555 540
Goodwill 866 866
Other 897 920
----------------------------------------------------------------------------
Segmented assets 7,780 7,694
Non-segmented assets
----------------------------------------------------------------------------
Total assets (5)
----------------------------------------------------------------------------
----------------------------------------------------------------------------
Decommissioning liabilities (5) 2,227 2,196
----------------------------------------------------------------------------
----------------------------------------------------------------------------
1. North America 2011 2010 2011 2010
----------------------------------------------------------------------------
Canada 300 394 590 840
US 161 70 298 124
----------------------------------------------------------------------------
Total revenue and other income 461 464 888 964
----------------------------------------------------------------------------
Canada 3,807 3,920
US 1,854 1,431
----------------------------------------------------------------------------
Property, plant and equipment (5) 5,661 5,351
----------------------------------------------------------------------------
Canada 1,117 685
US 1,214 1,201
----------------------------------------------------------------------------
Exploration and evaluation assets (5) 2,331 1,886
----------------------------------------------------------------------------
2. North Sea 2011 2010 2011 2010
----------------------------------------------------------------------------
UK 866 449 1,602 1,035
Norway 306 271 663 631
----------------------------------------------------------------------------
Total revenue and other income 1,172 720 2,265 1,666
----------------------------------------------------------------------------
UK 3,705 3,763
Norway 1,757 1,605
----------------------------------------------------------------------------
Property, plant and equipment (5) 5,462 5,368
----------------------------------------------------------------------------
UK 217 260
Norway 338 280
----------------------------------------------------------------------------
Exploration and evaluation assets (5) 555 540
----------------------------------------------------------------------------
5. Current year represents balances at June 30. Prior year represents
balances at December 31.
Southeast Asia (3) Other (4)
--------------------------------------------------------
Three months Six months Three months Six months
ended ended ended ended
June 30 June 30 June 30 June 30
(millions of US$) 2011 2010 2011 2010 2011 2010 2011 2010
----------------------------------------------------------------------------
Revenue
Sales 442 360 828 719 159 55 253 86
Other income - 1 - 1 - - - -
----------------------------------------------------------------------------
Total revenue and other
income 442 361 828 720 159 55 253 86
----------------------------------------------------------------------------
Segmented expenses
Operating 75 62 147 123 23 8 32 13
Transportation 13 15 28 29 2 2 4 4
DD&A 63 67 125 131 32 8 52 13
Impairment - - - - - - - -
Dry hole 33 1 57 (7) - - 3 13
Exploration 83 21 135 44 34 38 56 64
Other 1 9 4 18 12 (6) 12 4
----------------------------------------------------------------------------
Total segmented expenses 268 175 496 338 103 50 159 111
----------------------------------------------------------------------------
Segmented income (loss)
before taxes 174 186 332 382 56 5 94 (25)
----------------------------------------------------------------------------
Non-segmented expenses
General and administrative
Finance costs
Share-based payments recovery
Currency translation
(Gain) loss on held-for-
trading financial
instruments
Gain on asset disposals
----------------------------------------------------------------------------
Total non-segmented expenses
----------------------------------------------------------------------------
Income before taxes
----------------------------------------------------------------------------
----------------------------------------------------------------------------
Capital expenditures
Exploration 79 11 128 36 25 14 41 47
Development 22 109 93 149 45 29 73 49
Midstream - - - - - - - -
----------------------------------------------------------------------------
Exploration and
development 101 120 221 185 70 43 114 96
----------------------------------------------------------------------------
Acquisitions
Proceeds on dispositions
Other non-segmented
----------------------------------------------------------------------------
Net capital expenditures
----------------------------------------------------------------------------
Property, plant and
equipment 2,272 2,296 1,039 251
Exploration and evaluation
assets 705 627 426 389
Goodwill 149 149 97 -
Other 578 628 752 141
----------------------------------------------------------------------------
Segmented assets 3,704 3,700 2,314 781
Non-segmented assets
----------------------------------------------------------------------------
Total assets (5)
----------------------------------------------------------------------------
----------------------------------------------------------------------------
Decommissioning liabilities (5) 195 189 46 15
----------------------------------------------------------------------------
Total
------------------------------------------
Three months ended Six months ended
June 30 June 30
(millions of US$) 2011 2010 2011 2010
----------------------------------------------------------------------------
Revenue
Sales 2,216 1,574 4,188 3,382
Other income 18 26 46 54
----------------------------------------------------------------------------
Total revenue and other income 2,234 1,600 4,234 3,436
----------------------------------------------------------------------------
Segmented expenses
Operating 555 459 1,007 960
Transportation 52 55 108 114
DD&A 479 408 948 889
Impairment - 4 102 93
Dry hole 36 30 140 36
Exploration 136 69 248 162
Other 17 (13) 36 10
----------------------------------------------------------------------------
Total segmented expenses 1,275 1,012 2,589 2,264
----------------------------------------------------------------------------
Segmented income (loss) before taxes 959 588 1,645 1,172
----------------------------------------------------------------------------
Non-segmented expenses
General and administrative 108 81 206 158
Finance costs 60 68 136 137
Share-based payments recovery (176) (61) (60) (131)
Currency translation 6 7 45 5
(Gain) loss on held-for-trading financial
instruments (68) (64) 251 (162)
Gain on asset disposals (122) (262) (214) (315)
----------------------------------------------------------------------------
Total non-segmented expenses (192) (231) 364 (308)
----------------------------------------------------------------------------
Income before taxes 1,151 819 1,281 1,480
----------------------------------------------------------------------------
----------------------------------------------------------------------------
Capital expenditures
Exploration 213 171 412 317
Development 752 673 1,447 1,151
Midstream - 1 - -
----------------------------------------------------------------------------
Exploration and development 965 845 1,859 1,468
----------------------------------------------------------------------------
Acquisitions 564 350 1,357 570
Proceeds on dispositions (290) (1,193) (539) (1,352)
Other non-segmented 28 19 44 28
----------------------------------------------------------------------------
Net capital expenditures 1,267 21 2,721 714
----------------------------------------------------------------------------
Property, plant and equipment 14,434 13,266
Exploration and evaluation assets 4,017 3,442
Goodwill 1,252 1,164
Other 3,251 4,078
----------------------------------------------------------------------------
Segmented assets 22,954 21,950
Non-segmented assets 83 144
----------------------------------------------------------------------------
Total assets (5) 23,037 22,094
----------------------------------------------------------------------------
Decommissioning liabilities (5) 2,671 2,610
----------------------------------------------------------------------------
3. Southeast Asia 2011 2010 2011 2010
----------------------------------------------------------------------------
Indonesia 226 219 450 427
Malaysia 121 119 244 232
Vietnam 66 15 103 30
Australia 29 8 31 31
----------------------------------------------------------------------------
Total revenue and other income 442 361 828 720
----------------------------------------------------------------------------
Indonesia 1,011 986
Malaysia 960 1,053
Vietnam 29 19
Papua New Guinea 27 26
Australia 245 212
----------------------------------------------------------------------------
Property, plant and equipment (5) 2,272 2,296
----------------------------------------------------------------------------
Indonesia 24 27
Malaysia 32 29
Vietnam 253 253
Papua New Guinea 396 318
----------------------------------------------------------------------------
Exploration and evaluation assets (5) 705 627
----------------------------------------------------------------------------
4. Other 2011 2010 2011 2010
----------------------------------------------------------------------------
Algeria 90 55 134 86
Colombia 69 - 119 -
----------------------------------------------------------------------------
Total revenue and other income 159 55 253 86
----------------------------------------------------------------------------
Algeria 270 251
Colombia 769 -
----------------------------------------------------------------------------
Property, plant and equipment (5) 1,039 251
----------------------------------------------------------------------------
Colombia 56 49
Kurdistan 264 239
Other 106 101
----------------------------------------------------------------------------
Exploration and evaluation assets (5) 426 389
----------------------------------------------------------------------------
5. Current year represents balances at June 30. Prior year represents
balances at December 31.
Talisman Energy Inc. - Media and General Inquiries
David Mann, Vice-President,
Corporate & Investor Communications
(403) 237-1196
(403) 237-1210 (FAX)
tlm@talisman-energy.com
www.talisman-energy.com
or
Talisman Energy Inc. - Shareholder and Investor Inquiries
Christopher J. LeGallais, Vice-President,
Investor Relations
(403) 237-1957
(403) 237-1210 (FAX)
tlm@talisman-energy.com
www.talisman-energy.com 
