TIDMAN26
Talisman Energy Inc. reported its operating and financial results for the first quarter of 2009.
-- Cash flow1 during the quarter was $1.3 billion, an increase
of 6% from a year ago. Cash flow from continuing operations1
was also $1.3 billion, up 14% from the same period a year ago.
-- Net income was $455 million, down 2% from a year earlier, because
gains on asset sales were offset by lower realized prices, higher
depletion, depreciation and amortization (DD&A) and dry hole costs.
-- Earnings from continuing operations1 were $303 million,
compared to $429 million a year ago.
-- Production averaged 450,000 boe/d, 7% above the first quarter of 2008,
despite the sale of non-core assets over the past year. Production
from continuing operations averaged 436,000 boe/d, 11% above the same
quarter last year.
-- Net debt1 at quarter end was $3.6 billion, down from $3.9
billion at December 31, 2008.
-- Netbacks were down 46% from a year earlier, averaging $24.48/boe.
-- During the quarter, Talisman announced first gas production from the
Rev Field in Norway and first oil production from the Northern Fields
project in Southeast Asia.
-- Talisman's unconventional natural gas strategy in North America is on
track with 22 gross wells drilled during the quarter in the Marcellus
and Montney.
-- Talisman announced an agreement to sell non-strategic assets in
Saskatchewan for $720 million.
-- Talisman entered into an agreement for the sale of its Trinidad assets
for approximately $380 million.
-- The Company announced the appointment of Paul Smith as Executive
Vice-President, International Operations (West) and Richard Herbert as
Executive Vice-President, Exploration.
"Talisman's financial and operating performance in the quarter was very strong," said John A. Manzoni, President and CEO. "We continue to strengthen the Company's balance sheet, which gives us financial flexibility; we are driving down costs and improving efficiency; we are bringing development projects on stream; and, delivering on strategic implementation.
"It was a great quarter from an operations standpoint. Production from continuing operations was up 11% year over year. UK production increased by 28%, due in part to improvements in operating efficiency. Production in Scandinavia rose 26%, with contributions from the Rev Field and development drilling success. Production in Southeast Asia was 13% higher with increased sales from Corridor.
1 The terms "cash flow", "cash flow from continuing operations", "earnings from continuing operations" and "net debt" are non-GAAP measures. Please see the advisories and reconciliations elsewhere in this news release.
"The first quarter exceeded our internal projections for production and gives us a strong start to delivering our production target for the year. We are still early in the year and the guidance we provided in January of 430,000 boe/d, with downside of no greater than 5%, remains valid. As usual, production in the second and third quarters will be lower due to maintenance shutdowns.
"Cash generation was also strong during the quarter, up 6% to $1.3 billion, despite low commodity prices. The strong cash flow results in large part from the hedging program put in place during the last 12 months. We have hedges in place over the remainder of the year, although we expect lower cash contributions from these. Cash flow also benefited from higher production volumes and lower taxes.
"With higher cash flow and proceeds from non-core asset sales, we have improved upon our already strong financial position. Talisman's long-term debt is now at $3.6 billion (net of cash) versus $3.9 billion at year end and we have paid off our bank lines.
"Net income was down 2% compared to a year ago, totaling $455 million, largely due to lower realized prices, higher DD&A and dry hole costs, partly offset by gains on non-core asset sales. Excluding unusual items, earnings from continuing operations were $303 million, compared to $429 million a year earlier.
"Unit operating costs are down 6% versus a year ago. In the UK, unit costs are down 27%, due to production gains and improved efficiency, exchange rate movements and the disposal of some higher cost properties. In North America, underlying costs are also reducing, although the quarter included some one-off costs, which mask this reduction. We have a number of internal cost initiatives underway across all our businesses and we expect further reductions.
"The strategy is proving robust to lower commodity prices. We are making good progress on non-core asset sales. Including the Saskatchewan and Trinidad sales, we will generate proceeds of approximately $2.2 billion from non-core assets with associated volumes of about 25,000 boe/d.
"First oil from the Northern Fields oil development was achieved on schedule during the quarter. We announced first natural gas volumes in July of last year and expect to commission the dry gas facilities by mid-year. In Norway, we announced first production from the Rev Field in January. First production from Affleck in the UK is expected in the third quarter and we continue to progress projects at Auk, Burghley and Yme in the North Sea and Block 15-2/01, and the Corridor expansion in Southeast Asia.
"We spent approximately $250 million on unconventional gas plays in North America during the quarter. In the Marcellus Shale, we drilled four wells during the quarter, with each well performing better than the previous one. Improved drilling efficiency should now enable us to complete the 2009 program with a maximum of three rigs instead of five.
"We drilled 11 gross wells in the Montney Core where Talisman is achieving top tier performance on drilling and completion costs. We are encouraged by the results of ongoing pilot work in the Montney Shale and have drilled our fourth unconventional pilot well in Quebec.
"In international exploration, we drilled a successful sidetrack on Block 15-2/01 in Vietnam. Talisman has made a discovery with the Godwin well in the Central Graben in the UK. We are also encouraged by a new discovery in Norway, which is preparing to test. Early indications are promising in Colombia; however, we still have a couple of months before the well is completed and we are drilling a well on Block 64 in Peru. Results from our first well in the Kurdistan region of northern Iraq were also encouraging, but inconclusive due to operational difficulties in completing the well. And we have also added new blocks in Peru and offshore Vietnam.
"In summary, it was a strong quarter, both operationally and financially. The Company is in excellent financial shape and we are making good progress on our strategy for profitable long-term growth."
Financial Results
March 31 Three Months Ended
2009 2008
Cash flow ($ million) 1,309 1,232
Cash flow per share2 1.29 1.21
Cash flow from continuing operations ($ million) 1,295 1,136
Net income ($ million) 455 466
Net income per share 0.45 0.46
Earnings from continuing operations($ million) 303 429
Earnings from continuing operations per share2 0.30 0.42
Average shares outstanding (million) 1,015 1,019
Cash flow increased 6% year over year to $1.3 billion, as higher production volumes and cash received on commodity hedges ($436 million after tax) offset a 46% drop in netbacks.
Net income was 2% below last year. Income for the quarter included a $519 million after tax gain on the sale of non-core assets.
Total DD&A expense was $733 million, an increase of $226 million compared to the first quarter of 2008. The increase is primarily from downward reserve revisions as a result of low oil prices, increased production and capital expenditures.
Dry hole expense was $246 million in the quarter compared to $65 million a year ago. This includes $59 million for exploration wells in the North Sea and $46 million in Vietnam. Dry hole expense totalled $128 million in North America, where writeoffs occurred due to changes in natural gas price forecasts and a number of unsuccessful deep wells drilled last year.
Total tax expense fell by $400 million compared to the first quarter of 2008 with lower netbacks, higher operating, dry hole and DD&A expenses.
Earnings from continuing operations were $303 million compared to $429 million a year earlier. Earnings from continuing operations adjust for significant one-time events and non-operational items such as the mark-to-market effect of changes in share prices on stock-based compensation expense and mark-to-market changes of commodity derivatives.
Talisman continued to strengthen its balance sheet. Net debt at March 31 was $3.6 billion down from $3.9 billion at December 31, 2008.
2 The terms "cash flow per share" and "earnings from continuing operations per share" are non-GAAP measures. Please see the advisories and reconciliations elsewhere in this news release.
The Company spent $1,099 million on exploration and development during the quarter (including $106 million of non-cash costs). This includes $390 million in North America (primarily unconventional natural gas) and $361 million in the North Sea, including the Rev and Yme projects, as well as development drilling at Auk North, Claymore, Clyde, Gyda and Brage. Spending in Southeast Asia was $277 million, including capitalization of the Floating Storage Offloading (FSO) vessel as part of the Northern Fields startup.
Production
March 31 Three Months Ended
2009 2008
Oil and liquids (bbls/d) 234,876 216,625
Natural gas (mmcf/d) 1,291 1,216
Total (mboe/d) 450 419
Continuing operations (mboe/d) 436 393
Production from continuing operations averaged 436,000 boe/d, an increase of 11% over last year. UK oil and liquids production increased 25%, in part due to steps taken to improve operating efficiency. Production in Scandinavia increased 26% with the startup of the Rev Field and new wells on production at Brage and better base production at Varg. Natural gas production in Southeast Asia increased 22%, with a 25% increase in Indonesia as sales to West Java continue to grow.
Netbacks
March 31 Three Months Ended
$/boe 2009 2008
Sales 44.17 73.01
Hedging gain (loss) - (0.26)
Royalties 5.93 12.87
Transportation 1.40 1.14
Operating expenses 12.36 13.08
Netback 24.48 45.66
Oil & liquids netback ($/bbl) 29.68 58.76
Natural gas netback ($/mcf) 3.14 5.28
Netbacks in the first quarter averaged $24.48/boe, down 46% from a year ago and 6% below the previous quarter. WTI oil prices averaged US$43/bbl, down 56% from the first quarter of 2008. NYMEX natural gas prices averaged US$4.86/mmbtu, a decrease of 36%.
Royalty expenses fell $62 million compared to last year, but rates increased slightly due to increased sales in Algeria, which has a relatively high royalty rate. Royalty rates in North America and Southeast Asia were lower.
Unit operating costs were down 6% compared to the first quarter of 2008. The biggest drop was in the UK, where unit costs were down 27%, due in part to production efficiencies, with the remainder coming from the sale of higher cost properties and foreign exchange rates. In Norway, unit operating costs are down 24%, largely due to higher volumes and the startup of the Rev Field. North American unit costs have increased due to one-time charges associated with the Company's agreement with Hallwood Partners, higher property taxes and increased processing fees associated with additional volumes through third party infrastructure. In Southeast Asia, costs were up with increased maintenance expenses in Malaysia/Vietnam.
The Company may choose to designate derivative instruments as hedges for accounting purposes. To date, the Company has elected not to designate any commodity price derivative contracts entered into since January 1, 2007 as hedges.
North America
In North America, production averaged 179,000 boe/d for the first quarter, down 2% from a year ago. Production from continuing operations was relatively unchanged from the same period in 2008. Oil and liquids volumes were down 3%, due largely to natural declines. Natural gas volumes increased 1% with increases in unconventional areas (Appalachia, Outer Foothills, Montney), as well as in Monkman and the Northern Alberta Foothills, which more than offset declines in other conventional areas.
Capital spending included $250 million in unconventional areas for development and piloting activities, plus $140 million on other properties. This other spending was comprised mainly of carry-in capital from the 2008 capital program, with some excellent results. A well in Monkman, BC tested at 40 mmcf/d raw gas and a Greater Ojay, BC well tested at 23 mmcf/d raw gas.
Talisman participated in 61 gross (32.4 net) wells in the quarter, with 53 gross wells in unconventional plays.
In the Marcellus Shale, the Company continues to focus on Pennsylvania. Talisman drilled four gross wells (four net) in the quarter and has now moved to pad drilling. Two rigs are currently operating and the Company now expects it will be able to complete its 36 well program for the year with a maximum of three rigs instead of five as originally planned.
Each well is performing better than the previous well. The latest producing well in the program achieved rates of 4.5 mmcfe/d over an initial 30-day period, with the most recent pad well on target to cost US$4.3 million (C$ 5.2 million) to drill and complete. These costs are down more than 25% from the 2008 average and drilling cycle times have been reduced by 50% compared to the first wells in the program.
In the Montney Core, Talisman drilled 11 gross (9.9 net) wells in the quarter out of a planned 35 well program. The most recent five horizontal wells have averaged initial 30-day production rates of over 3 mmcfe/d. Talisman has made significant strides in reducing costs in the Montney. A recent well was drilled and completed at a cost of $3.8 million, which is top tier performance and a 50% reduction from the Company's average 2008 drilling costs in the area. Talisman is also achieving best in class completion costs in the area.
Talisman continues to progress piloting in the Montney Shale, with seven gross (four net) wells drilled in the quarter. Results are encouraging and the Company recently completed its first horizontal shale well. Talisman is evaluating egress options for the area and plans to build gathering and processing facilities later this year.
In Quebec, the Company is currently drilling the fourth well in the earning phase of a four-well program. Completion and testing of the last two wells is expected to take place later this year. The program is focused on gathering test and core data to evaluate the potential for commercial gas production.
During the quarter, Talisman announced the sale of its southeast Saskatchewan and Daniels County, Montana assets for approximately $720 million. The sale is expected to close in June 2009.
UK
Production from continuing operations in the UK averaged 108,000 boe/d over the quarter, up 28% from the same period in 2008, primarily due to increased production at Tweedsmuir, which was ramping up in the first quarter last year, and a full quarter's production from the Montrose-Arbroath complex, which was shutdown in the first quarter of 2008.
UK development expenditures during the quarter were $131 million, which included drilling in the Auk North, Claymore and Clyde fields.
During the quarter, the Company continued to progress development at Auk North, with three wells being batch drilled. The non-operated Affleck development is due onstream at the start of the third quarter. Engineering work at the Auk South redevelopment is advancing.
The Tweedsmuir water injection plant came onstream on March 11 and the plant was tested at its capacity of 30,000 bbls/d of water.
Scandinavia
Production from continuing operations averaged 43,000 boe/d, up 26% from the same period in 2008. The production increase over 2008 was due to commencement of production from the Rev Field and new wells brought onstream at Brage and better base production at Varg.
The Company spent $115 million on development, which included the Rev and Yme projects and development drilling in the Yme, Gyda, Veslefrikk and Brage fields.
The Rev Field came on production on January 24. The field is expected to produce at a plateau rate of 100 mmcf/d of natural gas and 6,000 bbls/d of condensate and natural gas liquids from two subsea wells. A third producing well is expected to be brought onstream later in 2009.
During the quarter, Talisman reached an agreement to sell a 10% equity interest in the Yme Field. Construction at the Yme field redevelopment project continues and first oil is now scheduled for around the middle of 2010.
The Company also reached an agreement to sell a 40% interest in PL301 in Norway.
Southeast Asia
In Southeast Asia, production averaged 101,000 boe/d, 13% higher than the same period last year. Indonesian production averaged 63,000 boe/d, 19% higher than the same period last year, primarily due to increased gas takes in Corridor. Production from Malaysia averaged 27,000 boe/d, 22% lower than the previous period, mainly due to a planned shutdown at PM-3 CAA to complete final tie-ins prior to the startup of oil production from the Northern Fields and natural declines in PM 305/314.
In Indonesia, Corridor produced 296 mmcf/d during the quarter, an increase of 63 mmcf/d over the same period last year, mainly due to increased West Java gas sales.
First gas was introduced into the Tangguh Train 1 facility on January 27, marking the startup of the Liquefied Natural Gas (LNG) processing facilities, with first commercial shipments scheduled for the second quarter.
In PM-3 CAA in Malaysia/Vietnam, the FSO vessel was installed in early March 2009 at the Northern Fields development. First oil production began on March 25 at 6,000 bbls/d (gross) from the initial two oil wells and production is expected to reach 40,000-50,000 boe/d (gross sales) by early 2010. Commissioning of dry gas facilities is scheduled for mid-2009.
Gas production from Northern Fields averaged 92 mmcf/d (gross sales gas) during the quarter. To date, 20 wells (five oil, 13 gas and two injectors) have been drilled and completed in Northern Fields with a 100% success rate. The Company plans to drill up to 16 development wells in the Northern Fields in 2009, with an additional 13 planned for 2010.
In the Southern Fields in PM-3 CAA, the first of the six-well Bunga Kekwa infill program spudded in March and was completed in mid-April, while at PM-305, an infill well drilled in the first quarter came onstream and is currently producing 1,300 bbls/d (gross).
Production in Vietnam averaged 8,000 bbls/d as Song Doc came onstream in November 2008. In Block 15-2/01, pre-engineering work is underway with project sanction of the Hai Su Trang development and the Hai Su Den Early Production Scheme expected later in the year.
Production in Australia was 3,200 bbls/d, 60% higher than the same period last year, primarily due to installation of the new flowline at Corallina and reinstatement of the Lam-2 well, which were completed in mid-March. A field development plan for the Kitan discovery is being prepared and is scheduled to be submitted in May.
Other Areas
In North Africa, production from continuing operations averaged 15,000 boe/d, down 8% from the same period in 2008, mainly due to OPEC production restrictions and natural declines. In Algeria, new production and injection wells were tied in as part of the Greater MLN Phase 2 project. The Phase 2 expanded gas injection facilities are being commissioned. The El Merk project in Algeria was sanctioned during the quarter. The Company participated in two wells, with a third well drilling over the quarter end.
Talisman entered into an agreement for the sale of its Trinidad and Tobago assets for approximately $380 million.
International Exploration
International exploration spending in the first quarter was approximately $247 million.
Southeast Asia
In September 2008, Talisman entered into a farm-in agreement in Blocks 133 and 134 offshore Vietnam with a 38% working interest. The amended licence was approved by the Government of Vietnam in February 2009 and represents the Company's first step into the Nam Con Son Basin. The Company continues the appraisal of the Hai Su Den discovery in Block 15-2/01 in the Cuu Long Basin, with further wells planned later in the year.
Kurdistan Region of Northern Iraq
In the Kurdistan region of northern Iraq, the Sarqala-1 well has been suspended. A rig move is underway to the Kurdamir location. In addition, seismic processing of Block K39 data is ongoing.
South America
The Situche Central-3X appraisal well on Block 64 in Peru spud in late December 2008 and is currently drilling. Talisman was awarded an interest in Block 158 in April.
In Colombia, the Huron-1 well exploration on the Niscota Block continued drilling through the quarter. The Company expects drilling to be completed in the second quarter. In the El Caucho Blocks, a 3D seismic program is underway in El Sancy. Planning is underway to drill an exploration well in the El Eden Block late in 2009. Talisman was successful in acquiring interests in Block 09 in late January.
North Sea
In the UK North Sea, Talisman made a modest oil discovery at Godwin in Block 22/17 and the highly productive reservoir tested at 7,500 bbls/d. The Company is reviewing options to develop the Godwin discovery via the Montrose-Arbroath facilities. The rig has completed operations at Godwin and has spud the Shaw exploration well on Block 22/22a.
Talisman is encouraged by a recent discovery in Norway and is preparing to test. Subsequent to the quarter end, the Canon well was plugged and abandoned.
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.
For further information,
please contact:
Media and General Inquiries: Shareholder and Investor Inquiries:
David Mann, Vice-President Christopher J. LeGallais, Vice-President
Corporate & Investor Investor Relations
Communications
Phone: 403-237-1196 Phone: 403-237-1957 Fax: 403-237-1210
Fax: 403-237-1210
E-mail: Email: tlm@talisman-energy.com
tlm@talisman-energy.com
11-09
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:
-- planned maintenance shutdowns and expected reductions in production
volumes;
-- expected reduction in cash contributions from hedges;
-- expected cost reductions;
-- expected timing of facilities commissioning at Northern Fields;
-- planned drilling at Northern Fields, Cuu Long, Niscota Block and EI
Eden Block;
-- expected first production from Affleck in the UK;
-- expected completion of the 2009 Marcellus Shale drilling program;
-- plans to build gathering and processing facilities in the Montney
Shale;
-- expected completion and testing of wells in Quebec;
-- expected timing of closing of dispositions in southeast Saskatchewan,
Daniels County, Montana and Trinidad and Tobago;
-- expected production rates at the Rev Field and at Northern Fields;
-- expected timing of first oil at the Yme Field;
-- expected timing of the first commercial shipment from Tangguh;
-- expected timing of project sanctioning in Vietnam;
-- expected submission of a field development plan for the Kitan
discovery; and
-- other expectations, beliefs, plans, goals, objectives, assumptions,
information and statements about possible future events, conditions,
results of operations or performance.
With the exception of the timing of closing dispositions in southeast Saskatchewan, Daniels County, Montana and Trinidad and Tobago, each of the forward-looking information listed above are based on Talisman's 2009 capital program announced on January 13, 2009. The material assumptions supporting the 2009 capital program are: (1) 2009 annual production of approximately 430,000 boe/d; (2) a US $40/bbl WTI oil price for 2009 and (3) a US $5/mmbtu NYMEX natural gas price for 2009. 2009 production estimates are subject to the timing of development activities and include the anticipated completion of planned dispositions. The completion of any planned disposition is contingent on various factors including market conditions, the ability of the Company to negotiate acceptable terms of sale and receipt of any required approvals of such dispositions.
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;
-- 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 and credit crisis 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; 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.
Oil and Gas Information
Throughout this news release, the calculation of barrels of oil equivalent (boe) is at a conversion rate of six thousand cubic feet (mcf) of natural gas for one barrel of oil (bbl) and the calculation of mcfe is at a conversion rate of one bbl for six mcf of natural gas. Boes and mcfes may be misleading, particularly if used in isolation. A boe conversion ratio of 6 mcf:1 bbl and a mcfe conversion ratio of 1 bbl:6 mcfe are based on an energy equivalence conversion method primarily applicable at the burner tip and do not represent a value equivalence at the wellhead.
Talisman makes reference to production volumes throughout this news release. Where not otherwise indicated, 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.
Canadian Dollars and GAAP
Dollar amounts are presented in Canadian dollars unless otherwise indicated. Unless otherwise indicated, financial information is presented in accordance with Canadian generally accepted accounting principles that may differ from generally accepted accounting principles in the US. Talisman's Consolidated Financial Statements as at and for the year ended December 31, 2008, which were filed with Canadian and US securities authorities on March 5, 2009, contain information concerning differences between Canadian and US generally accepted accounting principles.
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, cash flow per share, cash flow from continuing operations, earnings from continuing operations, earnings from continuing operations per share and net debt. These terms are not defined by GAAP in either Canada or the US. Consequently, these are referred to as non-GAAP measures. Talisman's reported cash flow, cash flow per share, cash flow from continuing operations, earnings from continuing operations, earnings from continuing operations per share and net debt may not be comparable to similarly titled measures by other companies.
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 that use 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 Canadian GAAP 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. A reconciliation of cash provided by operating activities to cash flow follows.
($ million) Three months ended
March 31, 2009 2008
Cash provided by operating activities 1,086 1,312
Changes in non-cash working capital 223 (80)
Cash flow 1,309 1,232
Cash provided by discontinued operations1 (14) (96)
Cash flow from continuing operations 1,295 1,136
Cash flow per share 1.29 1.21
Cash flow from continuing operations 1.28 1.11
1. Comparative restated for operations classified as discontinued subsequent to March 31, 2008.
Earnings from continuing 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 continuing operations per share are earnings from continuing operations divided by the average number of common shares outstanding during the period. A reconciliation of net income to earnings from continuing operations follows.
($ million, except per share amounts)
Three months ended
March 31, 2009 2008
Net income 455 466
Operating income from discontinued operations 20 56
Gain (loss) on disposition 519 (2)
of discontinued operations
Net income from discontinued operations1 539 54
Net income (loss) from continuing operations (84) 412
Mark-to-market changes in commodity 387 51
derivatives2(tax adjusted)
Stock-based compensation expense 23 (7)
(recovery)3(tax adjusted)
Future tax recovery of unrealized (23) (27)
foreign exchange
gains (losses) on foreign denominated debt4
Earnings from continuing operations5 303 429
Per share 5 0.30 0.42
1. Comparatives restated for operations classified as discontinued subsequent to March 31, 2008.
2. Changes in mark-to-market commodity derivatives relate 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.
3. Stock-based compensation expense relates principally to the mark-to-market value of the Company's outstanding stock options and cash units at March 31. The Company's stock-based compensation expense is based principally on the difference between the Company's share price and its stock options or cash units exercise price.
4. Tax adjustments reflect future taxes relating to unrealized foreign exchange gains and losses associated with the impact of fluctuations in the Canadian dollar on foreign denominated debt.
5. This is a non-GAAP measure.
This calculation does not reflect differing accounting policies and conventions between companies. All amounts are reported on an after-tax basis.
Net debt is calculated by adjusting the Company's long-term debt per the financial statements for bank indebtedness, and cash and cash equivalents. The Company uses this information to assess its true debt position since cash could potentially be used to pay down long-term debt.
($ million) Three months ended
March 31, 2009 2008
Long-term debt 3,717 3,961
Bank indebtedness 22 81
Cash and cash equivalents (181) (93)
Net Debt 3,558 3,949
Talisman Energy Inc.
Highlights
(unaudited)
Three months ended
March 31
2009 2008
Financial
(millions of C$ unless otherwise stated)
Cash flow (1) 1,309 1,232
Net income 455 466
Exploration and development expenditures 1,099 1,013
Per common share (C$)
Cash flow (1) 1.29 1.21
Net income 0.45 0.46
Production
(daily average)
Oil and liquids (bbls/d)
North America 40,758 40,089
UK 102,688 84,013
Scandinavia 34,874 33,335
Southeast Asia 37,341 37,226
Other 19,215 21,962
Total oil and liquids 234,876 216,625
Natural gas (mmcf/d)
North America 829 850
UK 30 35
Scandinavia 50 19
Southeast Asia 382 312
Total natural gas 1,291 1,216
Total mboe/d (2) 450 419
Prices (3)
Oil and liquids (C$/bbl)
North America 42.65 80.79
UK 56.36 97.33
Scandinavia 56.50 99.30
Southeast Asia 52.69 99.66
Other 59.04 102.48
Total oil and liquids 53.64 95.49
Natural gas (C$/mcf)
North America 5.51 7.86
UK 5.93 8.52
Scandinavia 9.88 5.78
Southeast Asia 5.35 9.07
Total natural gas 5.64 8.16
Total (C$/boe) (2) 44.17 73.01
(1) Cash flow 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.
(3) Prices are before hedging.
Includes the results from continuing and discontinued operations.
Talisman Energy Inc.
Consolidated Balance Sheets
(unaudited)
March 31 December 31
(millions of C$) 2009 2008
(restated)
Assets
Current
Cash and cash equivalents 181 93
Accounts receivable 2,075 2,434
Inventories 148 181
Prepaid expenses 32 16
Assets of discontinued operations 30 204
2,466 2,928
Other assets 259 235
Goodwill 1,308 1,264
Property, plant and equipment 19,386 19,005
Assets of discontinued operations 888 843
21,841 21,347
Total assets 24,307 24,275
Liabilities
Current
Bank indebtedness 22 81
Accounts payable and 1,797 1,916
accrued liabilities
Income and other taxes payable 278 468
Future income taxes 201 300
Liabilities of discontinued 14 53
operations
2,312 2,818
Deferred credits 56 51
Asset retirement obligations 2,055 1,998
Other long-term obligations 313 173
Long-term debt 3,717 3,961
Future income taxes 3,982 4,032
Liabilities of discontinued 81 92
operations
10,204 10,307
Shareholders' equity
Common shares, no par value
Authorized: unlimited
Issued and outstanding:
2009 - 1,015 million (December 2,373 2,372
2008 - 1,015 million)
Contributed surplus 96 84
Retained earnings 9,421 8,966
Accumulated other comprehensive loss (99) (272)
11,791 11,150
Total liabilities and 24,307 24,275
shareholders' equity
Prior period balances have
been restated to reflect
the financial position of
discontinued operations
Talisman Energy Inc.
Consolidated Statements of Income
(unaudited)
Three months ended
March 31
(millions of C$) 2009 2008
(restated)
Revenue
Gross sales 1,840 2,345
Hedging loss - (10)
Gross sales, net of hedging 1,840 2,335
Less royalties 298 360
Net sales 1,542 1,975
Other 34 25
Total revenue 1,576 2,000
Expenses
Operating 521 429
Transportation 57 43
General and administrative 81 64
Depreciation, depletion and amortization 733 507
Dry hole 246 65
Exploration 68 56
Interest on long-term debt 45 44
Stock-based compensation (recovery) 33 (10)
(Gain) loss on held-for-trading (73) 68
financial instruments
Other, net 11 (16)
Total expenses 1,722 1,250
Income (loss) from continuing (146) 750
operations before taxes
Taxes
Current income tax 128 235
Future income tax (recovery) (204) 56
Petroleum revenue tax 14 47
(62) 338
Net income (loss) from continuing operations (84) 412
Net income from discontinued operations 539 54
Net income 455 466
Per common share (C$):
Net income (loss) from continuing operations (0.08) 0.40
Diluted net income (loss) from (0.08) 0.40
continuing operations
Net income from discontinued operations 0.53 0.05
Diluted net income from discontinued operations 0.53 0.05
Net income 0.45 0.46
Diluted net income 0.45 0.45
Average number of common shares 1,015 1,019
outstanding (millions)
Diluted number of common shares 1,015 1,036
outstanding (millions)
Prior period balances have been restated to reflect
the results of discontinued operations
14. Segmented Information
Three months ended March 31
North America (1) UK Scandinavia Southeast Asia (2) Other (3) Total
(millions of Canadian dollars) 2009 2008 2009 2008 2009 2008 2009 2008 2009 2008 2009 2008
Revenue
Gross sales 540 845 529 798 242 203 390 511 139 (12) 1,840 2,345
Hedging - - - (10) - - - - - - - (10)
Royalties 84 153 1 4 - - 145 203 68 - 298 360
Net sales 456 692 528 784 242 203 245 308 71 (12) 1,542 1,975
Other 26 18 7 5 1 2 - - - - 34 25
Total revenue 482 710 535 789 243 205 245 308 71 (12) 1,576 2,000
Segmented expenses
Operating 150 124 211 216 74 56 68 33 18 - 521 429
Transportation 12 16 13 8 12 9 17 8 3 2 57 43
DD&A 271 252 235 144 103 63 109 48 15 - 733 507
Dry hole 128 20 31 21 28 24 51 (1) 8 1 246 65
Exploration 23 26 2 2 6 7 15 7 22 14 68 56
Other 4 (3) 4 7 1 - (2) 2 7 (5) 14 1
Total segmented expenses 588 435 496 398 224 159 258 97 73 12 1,639 1,101
Segmented income before taxes (106) 275 39 391 19 46 (13) 211 (2) (24) (63) 899
Non-segmented expenses
General and administrative 81 64
Interest 45 44
Stock-based compensation 33 (10)
Currency translation (3) (17)
(Gain)/Loss on held-for-trading financial instruments (73) 68
Total non-segmented expenses 83 149
Income (loss) from continuing
operations before taxes (146) 750
Capital expenditures
Exploration 205 175 46 50 59 37 81 85 61 18 452 365
Development 105 225 131 124 115 140 196 86 3 11 550 586
Midstream 35 6 - - - - - - - - 35 6
Exploration and development 345 406 177 174 174 177 277 171 64 29 1,037 957
Property acquisitions 66 111
Proceeds on dispositions (33) -
Other non-segmented 10 9
Net capital expenditures (4) 1,080 1,077
Property, plant and equipment 8,697 8,703 4,693 4,738 1,919 1,745 3,189 2,984 888 835 19,386 19,005
Goodwill 223 223 308 306 640 602 133 129 4 4 1,308 1,264
Other 816 840 316 253 133 154 370 304 165 138 1,800 1,689
Discontinued operations 550 534 - 165 104 93 - - 264 255 918 1,047
Segmented assets 10,286 10,300 5,317 5,462 2,796 2,594 3,692 3,417 1,321 1,232 23,412 23,005
Non-segmented assets 895 1,270
Total assets (5) 24,307 24,275
(1) North America 2009 2008 (2) Southeast Asia 2009 2008
Canada 447 663 Indonesia 138 202
US 35 47 Malaysia 60 96
Total revenue 482 710 Vietnam 36 11
Canada 7,880 7,902 Australia 11 (1)
US 817 801 Total revenue 245 308
Property, plant and equipment (5) 8,697 8,703 Indonesia 1,060 990
Malaysia 1,374 1,277
4 Excluding corporate acquisitions. Vietnam 491 470
5 Current year represents balances as at March 31, prior year represents balances as at December 31. Australia 264 247
Property, plant and equipment (5) 3,189 2,984
(3) Other 2009 2008
Algeria 68 -
Tunisia 3 (12)
Total revenue 71 (12)
Algeria 215 221
Tunisia 24 21
Other 649 593
Property, plant and equipment (5) 888 835
Talisman Energy Inc.
Consolidated Statements of Cash Flows
(unaudited)
Three months ended
March 31
(millions of C$) 2009 2008
(restated)
Operating
Net income (loss) from continuing operations (84) 412
Items not involving cash 1,311 668
Exploration 68 56
1,295 1,136
Changes in non-cash working capital (223) 80
Cash provided by continuing operations 1,072 1,216
Cash provided by discontinued operations 14 96
Cash provided by operating activities 1,086 1,312
Investing
Capital expenditures
Exploration, development and other (941) (967)
Property acquisitions (28) (97)
Proceeds of resource property dispositions 33 -
Changes in non-cash working capital (257) 99
Discontinued operations, net of capital expenditures 584 (56)
Cash used in investing activities (609) (1,021)
Financing
Long-term debt repaid (690) (1,167)
Long-term debt issued 370 538
Deferred credits and other 4 9
Common shares issued 1 -
Changes in non-cash working capital 1 1
Cash used in financing activities (314) (619)
Effect of translation on foreign currency (16) 9
cash and cash equivalents
Net increase (decrease) in cash and cash equivalents 147 (319)
Cash and cash equivalents net of bank 12 521
indebtedness, beginning of period
Cash and cash equivalents net of 159 202
bank indebtedness, end of period
Cash and cash equivalents 181 217
Bank Indebtedness 22 15
Cash and cash equivalents net of 159 202
bank indebtedness, end of period
Prior period balances have been restated to reflect
the cash flows of discontinued operations
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