Suncor Energy reports 2010 second quarter results- strategy on track
CALGARY, ALBERTA -- (Marketwire) -- 07/29/10 -- All financial figures are unaudited and in Canadian dollars unless noted otherwise. Certain financial measures referred to in this document are not prescribed by Canadian generally accepted accounting principles (GAAP). For a description of these measures, see Non-GAAP Financial Measures on pages 37 to 42 of our report to shareholders for the period ended June 30, 2010. Certain crude oil and natural gas liquid volumes have been converted to millions of cubic feet equivalent of natural gas (mmcfe) on the basis of one barrel to six thousand cubic feet (mcf). Also, certain natural gas volumes have been converted to barrels of oil equivalent (boe) on the same basis. Mmcfe and boe may be misleading, particularly if used in isolation. A conversion ratio of one barrel of crude oil or natural gas liquids to six thousand cubic feet of natural gas is based on an energy equivalency conversion method primarily applicable at the burner tip and does not necessarily represent value equivalency at the well head.
On August 1, 2009, Suncor Energy Inc. completed its merger with Petro-Canada. As such, the results for the three months ended June 30, 2010 reflect the results of the post-merger Suncor and the comparative figures for the three months ended June 30, 2009 reflect solely the results of legacy Suncor prior to the merger.
Suncor Energy Inc. today reported second quarter 2010 net earnings of $480 million ($0.31 per common share), compared to a net loss of $51 million ($0.06 per common share) for the second quarter of 2009. Operating earnings in the second quarter of 2010 were $781 million ($0.50 per common share), compared to $38 million ($0.04 per common share) in the second quarter of 2009.
The increase in operating earnings was primarily due to additional upstream production as a result of the August 2009 merger with Petro-Canada, as well as higher benchmark prices in the second quarter of 2010, compared to the second quarter of 2009. This was partially offset by the stronger Canadian dollar, relative to the U.S. dollar.
Cash flow from operations was $1.758 billion ($1.13 per common share) in the second quarter of 2010, compared to $295 million ($0.31 per common share) in the second quarter of 2009. The increase in cash flow from operations was primarily due to production volumes added as a result of the merger as well as higher realized prices.
Suncor's total upstream production during the second quarter of 2010 averaged 633,900 boe per day, compared to 336,100 boe per day in the second quarter of 2009, primarily reflecting additional upstream production resulting from the merger.
Oil Sands production (excluding proportionate production share from the Syncrude joint venture) contributed an average 295,500 barrels per day (bpd) in the second quarter of 2010, compared to second quarter 2009 production of 301,000 bpd. Second quarter 2010 production was impacted by planned maintenance at one of two oil sands upgraders in May and June.
'Prior to heading into planned maintenance this quarter, we achieved record monthly oil sands average production of 333,000 barrels per day in April,' said Rick George, president and chief executive officer. 'Even with the impacts of maintenance, we had one of our best quarters for oil sands production on record. Although we have some planned maintenance remaining, we're targeting a strong second half to the year.'
Cash operating costs for Suncor's oil sands operations (excluding Syncrude) increased to $35.90 per barrel in the second quarter of 2010, compared to $31.30 per barrel during the second quarter of 2009. The increase in cash operating costs per barrel was primarily due to the inclusion of MacKay River costs as a result of the merger, higher product purchase costs and additional maintenance in the second quarter of 2010 compared to the second quarter of 2009.
Suncor's proportionate production share from the Syncrude joint venture contributed an average of 38,900 bpd of production during the second quarter of 2010.
Production from the Natural Gas business averaged 586 mmcfe per day in the second quarter of 2010, compared to 211 mmcfe per day during the second quarter of 2009, primarily due to the addition of Petro-Canada natural gas assets.
Suncor's International and Offshore business contributed an average of 201,900 boe per day of production in the second quarter of 2010. Production rates were impacted by planned maintenance at the company's North Sea operations and by production quotas in Libya. These impacts were partially offset by strong production in East Coast Canada operations and new production from the Ebla gas project in Syria, which was commissioned in April.
Total sales of refined petroleum products from the Refining and Marketing business averaged 89,000 cubic metres per day during the second quarter of 2010 compared to 33,900 cubic metres per day in the second quarter of 2009, reflecting additional sales volumes from the merger with Petro-Canada.
Strategy and Operational Update
Construction continued on the Firebag Stage 3 in situ oil sands project. The planned $3.6 billion expansion is expected to achieve first production during the second quarter of 2011, with volumes ramping up over an estimated 18 to 24 month period toward a planned production capacity of approximately 62,500 bpd of bitumen.
Spending on engineering for Firebag Stage 4 is expected to continue in 2010 with a target of first bitumen production in the fourth quarter of 2012. Construction of the project, which also has a planned production capacity of 62,500 bpd of bitumen, remains subject to Board of Directors approval.
To support current and future mine reclamation, Suncor applied for and received regulatory approval for a new tailings management plan using the company's proprietary TRO™ tailings management process. Capital spending for large scale implementation of TRO™ remains subject to Board of Directors approval.
In Suncor's renewable energy business, construction continued on expansion of the company's St. Clair Ethanol Plant. Work currently underway is expected to double the plant's production capacity, with completion targeted toward the end of 2010. The renewable energy business also received regulatory approval for construction of a new wind power project, Suncor's fifth, in southern Alberta.
As part of its strategic business alignment, Suncor continued with plans to divest of a number of non-core assets. In the second quarter, Suncor closed the sale of assets known as Rosevear and Pine Creek for net proceeds of $229 million and signed another agreement to sell non-core natural gas properties in Alberta for gross proceeds of $285 million, before closing adjustments. Suncor also reached an agreement to sell all of its shares in Petro-Canada Netherlands B.V. for gross proceeds of EUR445 million, before closing adjustments. It is anticipated that this sale will close in the third quarter of 2010. The sales that have not closed are subject to the satisfaction of customary closing conditions.
To date, Suncor has disposed of, or reached agreements to dispose of, assets for aggregate consideration of approximately $2.4 billion prior to closing adjustments. Additional assets planned for divestiture include certain natural gas assets in Western Canada as well as North Sea assets in the Scott/Telford and Triton areas.
'One year out from our historic merger with Petro-Canada, we're very pleased with the progress we've seen,' said George. 'Sales of non-core assets have proceeded well and our growth plans are on track. Every part of this business, from our core oil sands operations and conventional and offshore oil and gas production to our downstream refining and marketing division is delivering on strategy.'
Outlook
Suncor's outlook provides management's targets for 2010 in certain key areas of the company's business. Users of this forward-looking information are cautioned that actual results may vary materially from the targets disclosed. Readers are cautioned against placing undue reliance on this outlook.
The following operational outlook for 2010 has been revised from the operational outlook previously issued by management on May 4, 2010. The revisions are principally as follows:
-- the Syncrude production outlook has been adjusted to 36,000 bpd (+/-5%)
from 38,000 bpd (+/-5%) primarily due to operational issues at the
Syncrude facilities in the second quarter of 2010;
-- the Natural Gas production outlook related to remaining targeted
divestitures has been adjusted to 140 mmcfe per day from 180 mmcfe per
day as a result of completed dispositions of our Rosevear and Pine Creek
properties during the second quarter of 2010 and the change in the
assets targeted for potential sale; and
-- the East Coast Canada production outlook has been adjusted to 65,000 bpd
(+/-5%) from 60,000 bpd (+/-5%) primarily as a result of improved
performance to date.
These changes to the operational outlook have a corresponding impact on the total production outlook which has been adjusted to 610,000 boe per day (+/-5%) from 608,000 boe per day (+/-5%) and total production related to remaining targeted divestitures, which has been adjusted to 63,000 boe per day from 70,000 boe per day.
Six Months Actual Ended 2010 Full Year Outlook
June 30, 2010
----------------------------------------------------------------------------
Total production (boe 599,600 610,000 (+/-5%)
per day) - before
remaining targeted
divestitures(1)
Total production (boe N/A 63,000
per day) - related to
remaining targeted
divestitures(1)
----------------------------------------------------------------------------
Oil Sands(2)
Production (bpd) 249,300 280,000 (+/-5%)
Sales
Diesel 9% 9%
Sweet 31% 36%
Sour 44% 46%
Bitumen 16% 9%
Realization on crude WTI @ Cushing less WTI @ Cushing less
sales basket(3)
Cdn$9.37 per barrel Cdn$7.00 to Cdn$8.00 per
barrel
Cash operating costs(4) $43.50 per barrel $38 to $42 per barrel
----------------------------------------------------------------------------
Syncrude production 35,600 36,000 (+/-5%)
(bpd)
----------------------------------------------------------------------------
Natural Gas
Production (mmcfe per 659 580 (+/-5%)
day) - before
remaining targeted
divestitures(1)
Production (mmcfe per N/A 140
day) - related to
remaining targeted
divestitures(1)
Natural gas 90% 91%
Crude oil and liquids 10% 9%
----------------------------------------------------------------------------
East Coast Canada
Production (bpd) 72,600 65,000 (+/-5%)
----------------------------------------------------------------------------
International
Production (boe per 132,300 133,000 (+/-5%)
day) - before
targeted
divestitures(1)
Production (boe per N/A 40,000
day) - related to
remaining targeted
divestitures(1)
Crude oil and 82% 84%
liquids(5)
Natural gas(5) 18% 16%
----------------------------------------------------------------------------
(1) Actual production results will be impacted by the timing of planned divestitures of assets.
(2) Excludes Suncor's proportionate production share from the Syncrude joint venture.
(3) Excludes the impact of hedging activities.
(4) Cash operating cost estimates (excluding Syncrude) are based on the following assumptions: (i) production volumes and sales mix as described in the table above; and (ii) an average natural gas price of $5.28 per mcf at AECO.
(5) Pre-divestment.
This outlook is based on Suncor's current estimates, projections and assumptions for the 2010 fiscal year and is subject to change. Assumptions are based on management's experience and perception of historical trends, current conditions, anticipated future developments and other factors believed to be relevant. Assumptions for the Oil Sands 2010 full year outlook include reliability and operational efficiency initiatives which we expect to minimize further unplanned maintenance in 2010.
Assumptions for the Natural Gas, East Coast Canada and International 2010 full year outlook include reservoir performance, drilling results, facility reliability, changes in production quotas and successful execution of planned maintenance turnarounds.
Risk Factors Affecting Performance
Factors that could potentially impact Suncor's operational outlook for 2010 include, but are not limited to:
-- Bitumen supply. Ore grade quality, unplanned mine equipment and
extraction plant maintenance, tailings storage and in situ reservoir
performance could impact 2010 production targets.
-- Performance of recently commissioned facilities. Production rates while
new equipment is being lined out are difficult to predict and can be
negatively impacted by unplanned maintenance.
-- Unplanned maintenance. Production estimates could be negatively impacted
if unplanned work is required at any of our mining, production,
upgrading, refining, pipeline, or offshore assets.
-- Planned turnarounds. Production estimates could be negatively impacted
if planned turnarounds are not effectively executed.
-- Planned divestitures. Our inability to execute planned divestitures
could impact our debt management and capital expenditure plans.
-- Commodity prices. Significant declines in natural gas commodity prices
could result in the shut-in of some of our natural gas production.
-- Foreign operations. Suncor's foreign operations and related assets are
subject to a number of political, economic and socio-economic risks.
Suncor's operations in Libya may be constrained by production quotas.
Notice - Forward-Looking Information
This news release contains certain forward-looking statements and other information that are based on Suncor's current expectations, estimates, projections and assumptions that were made by the company in light of its experience and its perception of historical trends.
All statements and other information that address expectations or projections about the future, including statements and information about Suncor's strategy for growth, expected and future expenditures, commodity prices, costs, schedules, production volumes, operating and financial results and expected impact of future commitments, are forward-looking statements. Some of the forward-looking statements and information may be identified by words like 'expects,' 'anticipates,' 'estimates,' 'plans,' 'scheduled,' 'intends,' 'believes,' 'projects,' 'indicates,' 'could,' 'focus,' 'vision,' 'goal,' 'outlook,' 'proposed,' 'target,' 'objective,' and similar expressions. These statements and information are not guarantees of future performance and involve a number of risks and uncertainties, some that are similar to other oil and gas companies and some that are unique to Suncor. Suncor's actual results may differ materially from those expressed or implied by its forward-looking statements and information and readers are cautioned not to place undue reliance on them.
Suncor's outlook includes a production range based on our current expectations, estimates, projections and assumptions. Uncertainties in the estimating process and the impact of future events may cause actual results to differ, in some cases materially, from our estimates. Assumptions are based on management's experience and perception of historical trends, current conditions, anticipated future developments and other factors believed to be relevant.
The risks, uncertainties and other factors that could influence actual results include but are not limited to, market instability affecting Suncor's ability to borrow in the capital debt markets at acceptable rates; availability of third-party bitumen; success of hedging strategies, maintaining a desirable debt to cash flow ratio; changes in the general economic, market and business conditions; fluctuations in supply and demand for Suncor's products; commodity prices, interest rates and currency exchange rates; Suncor's ability to respond to changing markets and to receive timely regulatory approvals; the successful and timely implementation of capital projects including growth projects and regulatory projects; effective execution of planned turnarounds; the accuracy of cost estimates, some of which are provided at the conceptual or other preliminary stage of projects and prior to commencement or conception of the detailed engineering needed to reduce the margin of error and increase the level of accuracy; the integrity and reliability of Suncor's capital assets; the cumulative impact of other resource development; the cost of compliance with current and future environmental laws; the accuracy of Suncor's reserve, resource and future production estimates and its success at exploration and development drilling and related activities; the maintenance of satisfactory relationships with unions, employee associations and joint venture partners; competitive actions of other companies, including increased competition from other oil and gas companies or from companies that provide alternative sources of energy; labour and material shortages;
uncertainties resulting from potential delays or changes in plans with respect to projects or capital expenditures; actions by governmental authorities including the imposition of taxes or changes to fees and royalties, changes in environmental and other regulations (for example, the Government of Alberta's review of the unintended consequences of the proposed Crown royalty regime, the Government of Canada's current review of greenhouse gas emission regulations); the ability and willingness of parties with whom we have material relationships to perform their obligations to us (including in respect of any planned divestitures); uncertainties relating to the ability of closing conditions to be met in respect of any planned divestitures in a timely manner, or at all; political, economic and socio-economic risk associated with foreign operations (including OPEC production quotas); the occurrence of unexpected events such as fires, blowouts, freeze-ups, equipment failures and other similar events affecting Suncor or other parties whose operations or assets directly or indirectly affect Suncor; failure to realize anticipated synergies or cost savings; risks regarding the integration of the two businesses after the merger; and incorrect assessments of the values of the other entity. The foregoing important factors are not exhaustive.
Many of these risk factors and other assumptions related to Suncor's forward-looking statements and information are discussed in further detail throughout our report to shareholders for the period ended June 30, 2010 and in Suncor's Annual Information Form/Form 40-F on file with Canadian securities commissions at www.sedar.com and the United States Securities and Exchange Commission (SEC) at www.sec.gov. Readers are also referred to the risk factors and assumptions described in other documents that Suncor files from time to time with securities regulatory authorities. These risk factors and assumptions are incorporated herein by reference. Copies of these documents are available without charge from the company.
For more information about Suncor Energy Inc. please visit our web site at www.suncor.com.
For more information on the TRO tailings management process, wind power projects and other elements of Suncor's environmental, economic and social performance, see our 2010 Report on Sustainability at www.suncor.com/sustainability.
A full copy of Suncor's second quarter 2010 Report to Shareholders and the financial statements and notes (unaudited) can be obtained at www.suncor.com/financialreporting or by calling 1-800-558-9071 toll-free in North America.
To listen to the conference call discussing Suncor's second quarter results, visit www.suncor.com/webcasts.
Contacts:
Investor inquiries
Helen Kelly
403-693-2048
Media inquiries
403-920-8332
