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Oil Sands

Historical environmental data in 2008 for Oil Sands includes our Firebag In Situ operation, where appropriate, as well as our mining operations.

In 2009 In Situ began reporting as its own business unit. Data for 2009 and 2010 include only Oil Sands mining operations (does not include Syncrude).

All economic data for Oil Sands includes our In Situ operations as well as the Oil Sands mining operations for alignment with our financial report.

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Environment

The A symbol () reflects data that has been assured by a third party. View a complete list of reviewed data to confirm the performance indicators that have been assured. In the "Footnote" column, click on the down-arrow symbol to display the footnote.

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Indicator Unit Footnote GRI indicator 2008 2009 2010 2011 2012
Production                
Net production million barrels of oil/year OG1 85.4 104.0 94.3 105.1 103.25

Footnote A:
Net synthetic crude oil production. This volume is used to calculate emission intensities since it represents emissions associated with total.

Net production million cubic metres (m3) of oil/year OG1 13.6 16.5 15.0 16.7 16.4

Footnote A:
Net synthetic crude oil production. This volume is used to calculate emission intensities since it represents emissions associated with total.

Air emissions                
Greenhouse gas (GHG) thousand tonnes carbon dioxide equivalent (CO2e) /year EN16 9,056 9,178 8,837 8,560 9,204

Footnote B:
Emissions have been calculated based on the methodology from the American Petroleum Institute (API) and modified:
• where necessary to accommodate the uniqueness of the oil sands processes and
• where no industry standard exists
API logic is applied in these circumstances. Other reference sources utilized to provide emission factors include:
• Environment Canada
• Canadian Industrial Energy End-Use Data and Analysis Centre (CIEEDAC)
• The "Draft Greenhouse Gas Emission Estimation Methodologies for the Oil Sands / Heavy Oil Upgrader Industry"
The data is consistent with Suncor's Specified Gas Emitters Regulation (SGER) Bill 3 reported Total Annual Emission (TAE) value, with two exceptions. The reported TAE in the SGER Compliance report excludes carbon dioxide emissions from biomass and total indirect emissions.
2012 emission methodology updated as required by Alberta Environment and Sustainable Resource Development (AESRD) and other historical years will also be updated in future reports.

GHG emission intensity tonnes CO2e/m3 production   EN16 0.67 0.56 0.59 0.51 0.56
Ozone-depleting substances kilograms of chlorofluorocarbon (CFC)11 equivalent/yr EN19 5.3 11.0 1.1 0.0 0.0

Footnote C:
Retrofitting of refrigeration systems currently using R-22 or any other hydrofluorocarbons (HCFCs) are part of Suncor's ongoing program to phase out the use of ozone depleting substances on-site. The conversion of all remaining R-22 systems with RS-44 with more than 10 kilograms in it is ongoing and will continue until complete. RS-44 is a non-ozone depleting substance.

Sulphur dioxide (SO2) thousand tonnes/year EN20 29.84 19.03 22.15 20.23 18.54

Footnote D:
Oil Sands does not consider sulphur oxide (SO2) emissions from mobile sources because it uses low or ultra low sulphur diesel in its mining.

Sulphur dioxide emission intensity kilograms/m3 production   EN20 2.20 1.15 1.48 1.21 1.13
Nitrogen oxides (NOx) thousand tonnes/year EN20 18.8 23.5 21.6 21.8 21.1

Footnote E:
Site-wide nitrogen oxide (NOx) emissions as reported to Alberta Environment. This also includes NOx emissions from mobile sources.

Nitrogen oxides emission intensity kg/m3 production   EN20 1.39 1.42 1.44 1.30 1.29
Volatile organic compounds (VOCs) thousand tonnes/year   EN20 27.7 27.9 28.9 16.5 16.1
     Benzene tonnes   EN20 86.3 81.2 89.6 21.5 11.5
     Toluene tonnes   EN20 1,357.20 1,428.1 1,551.8 198.2 127.2
     Ethylbenzene tonnes   EN20 507.8 539.1 593.1 86.0 70.0
     Xylene tonnes   EN20 2,654.9 2,803.2 3,085.9 315.1 188.5
VOC emission intensity kg/m3 production   EN20 2.04 1.69 1.93 0.99 0.98
National Pollutant Release Inventory (NPRI) on-site releases thousand tonnes/year   EN20 92.0 72.6 80.3 66.9 70.5
Flared gas million m3/yr OG6 135.7 101.7 35.1 43.6 60.3

Footnote F:
These values include both emergency and non-emergency flaring volumes.

Flared gas intensity m3/m3 production   OG6 10 6.2 2.3 2.61 3.67
Heating energy of gas flared million gigajoules EN20 5.73 4.04 1.56 1.20 2.70

Footnote F:
These values include both emergency and non-emergency flaring volumes.

Energy consumption                
Total energy use million gigajoules EN3/4 116.8 111.9 108.6 109.4 112.8

Footnote G:
Includes combustion of petroleum coke, natural gas and internally produced fuels; diesel combusted as fuel in mine trucks; flaring and electrical power imports. Electrical energy produced by the Poplar Creek cogen that is sold externally to the provincial grid is deducted from direct energy use.

     Direct energy use million gigajoules EN3 116.8 110.6 107.7 111.7 114.9

Footnote H:
Direct energy is energy consumed on-site by Suncor operated facilities; sold electrical energy produced by the cogen is deducted from the direct energy. Indirect energy includes imported electricity, steam, heating and cooling duty from third parties.Beginning in 2011, the indirect energy calculation methodology was changed to credit operations for electricity exported to external users and/or other Suncor facilities. The facility that exports the electricity subtracts the export value from its indirect energy use. The facility that receives the electricity, counts it as a scope 2 indirect energy use, regardless of source. As such, the 2012 oil sands indirect energy figure is a negative because the amount of electricity exported was greater in value than the amount of electricity imported.    

     Indirect energy use million gigajoules EN4 0.02 1.27 0.94 -2.29 -2.38

Footnote H:
Direct energy is energy consumed on-site by Suncor operated facilities; sold electrical energy produced by the cogen is deducted from the direct energy. Indirect energy includes imported electricity, steam, heating and cooling duty from third parties.Beginning in 2011, the indirect energy calculation methodology was changed to credit operations for electricity exported to external users and/or other Suncor facilities. The facility that exports the electricity subtracts the export value from its indirect energy use. The facility that receives the electricity, counts it as a scope 2 indirect energy use, regardless of source. As such, the 2012 oil sands indirect energy figure is a negative because the amount of electricity exported was greater in value than the amount of electricity imported.    

Energy intensity gigajoules/m3 production   EN3/4 8.6 6.8 7.5 6.7 6.86
Water use                
Total water withdrawal millions m3 EN8 46.3 40.8 37.3 38.7 44.81

Footnote I:
Includes surface water, groundwater and industrial run-off water as per Alberta Environment and Water withdrawal licences.2011 water withdrawal metrics have been revised based on data and process improvements in 2012 which improved the understanding of site conditions for specific facilities.

Water withdrawal (surface water) million m3   EN8 45.9 40.6 35.6 27.7 26.6
Water withdrawal
       (groundwater)
millions m3   EN8 0.4 0.3 1.7 1.7 1.7
Water withdrawal intensity m3/m3 production   EN8 3.4 2.5 2.5 2.3 2.73
Water returned million m3 EN21 4 3.1 6.7 10.3 11.0

Footnote J:
The value in 2011 increased because the industrial run-off outfall volumes were included.

Water consumption million m3   42.3 37.8 30.6 28.4 33.79

Footnote K:
Total of both surface water and groundwater withdrawn minus the water returned. 2011 water consumption metrics have been revised based on data and process improvements in 2012 which improved the understanding of site conditions for specific facilities.

Water consumption intensity m3/m3 production     3.1 2.3 2.0 1.7 2.06
Water discharge quality                
Oil and grease in effluent tonnes EN21 1.6 6.0 14.6 17.7 7.67

Footnote L:
In 2011, the water quality discharge parameters increased or decreased due to the Pond C closure that occurred from April to December, and/or the inclusion of the industrial run-off water quality data. Additionally, Pond C was closed all of 2012 and pond E was also closed the majority of the year.

Total suspended sediment tonnes EN21 8.7 63.6 148.4 149.3 77.6

Footnote L:
In 2011, the water quality discharge parameters increased or decreased due to the Pond C closure that occurred from April to December, and/or the inclusion of the industrial run-off water quality data. Additionally, Pond C was closed all of 2012 and pond E was also closed the majority of the year.

Chemical oxygen demand tonnes   EN21 12.8 104.7 369.5 609.5 609.93
Phenol tonnes EN21 0 0.04 0.10 0.08 0.00

Footnote L:
In 2011, the water quality discharge parameters increased or decreased due to the Pond C closure that occurred from April to December, and/or the inclusion of the industrial run-off water quality data. Additionally, Pond C was closed all of 2012 and pond E was also closed the majority of the year.

Metals in effluent tonnes EN21 11.2 19.0 40.4 34.5 20.3

Footnote L:
In 2011, the water quality discharge parameters increased or decreased due to the Pond C closure that occurred from April to December, and/or the inclusion of the industrial run-off water quality data. Additionally, Pond C was closed all of 2012 and pond E was also closed the majority of the year.

Waste management              

Footnote M:
Beginning in 2011, in order to better align with the Global Reporting Initiative (GRI) standard, Suncor has expanded the number of indicators for which it collects and reports data in the Waste Management category.

Hazardous waste generated thousand tonnes EN22 54.2 3.5 4.2 3.9 0.38

Footnote N:
From 2008 to 2009, the evaporator blow down and ecopit waste was disposed of at an off-site hazardous waste facility. Reduction in hazardous waste volume in 2012 resulted from no sulphur being sent to landfill.

Hazardous waste
         incinerated
tonnes   EN22 -- -- -- 13.4 5.92
Hazardous waste
       deep well injected
tonnes   EN22 -- -- -- 44.1 7.42
Hazardous waste
         landfilled
tonnes EN22       3,792.3 352.0

Footnote N:
From 2008 to 2009, the evaporator blow down and ecopit waste was disposed of at an off-site hazardous waste facility. Reduction in hazardous waste volume in 2012 resulted from no sulphur being sent to landfill.

Hazardous waste
         otherwise disposed
tonnes   EN22       28.4 13.05
Non-hazardous waste generated thousand tonnes   EN22 46.0 30.0 39.0 40.5 84.4
Non-hazardous
         waste incinerated
tonnes   EN22 -- -- -- 0.7 0.18
Non-hazardous
         waste deep well
         injected
tonnes   EN22 -- -- -- 2.0 1.02
Non-hazardous
         waste landfilled
tonnes EN22 -- -- -- 40,477.9 84,334.3

Footnote O:
Non-hazardous volume in 2012 increased due to site activities and resulting waste including soil, gravel, wood and concrete.

Non-hazardous
         waste otherwise
         disposed
tonnes   EN22 -- -- -- 0.0 0.0
Waste reused/recycled/recovered off-site thousand tonnes EN22 16.3 11.5 45.1 25.3 29.5

Footnote P:
In 2012, a third party contractor transported used oil offsite for recycling; previous years this was done on-site.

Waste reused/recycled/recovered on-site thousand tonnes EN22 5.9 1.0 5.0 2.43 2.10

Footnote P:
In 2012, a third party contractor transported used oil offsite for recycling; previous years this was done on-site.

Land disturbance and reclamation                
Total land lease holdings for potential development                
      Mineable oil sands hectares EN11 99,576 70,263 70,263 70,263 70,263

Footnote Q:
The decrease in mineable oil sands area in 2009 is due to the method of calculation used. In previous years it was estimated from a map of the area, while in 2009 the area was calculated using numerical values of the actual area.

      Firebag hectares EN11 177,093 -- -- -- --

Footnote R:
Beginning in 2009, data collected for these indicators can be found in the In Situ business unit section.

Total land holdings approved for development                
      Mineable oil sand hectares   EN11 22,792 24,064 24,064 24,064 24,432
      Firebag hectares EN11 19,435 -- -- -- --

Footnote R:
Beginning in 2009, data collected for these indicators can be found in the In Situ business unit section.

      Firebag land approved
by Energy Resources
           Conservation Board
           for development
hectares   2,882 -- -- -- --

Footnote R:
Beginning in 2009, data collected for these indicators can be found in the In Situ business unit section.

Total land disturbed cumulative hectares EN12 17,749 17,161 19,737 20,023 21,303

Footnote S:
The decrease in total land disturbed for the 2009 reporting year is because the In Situ business unit began reporting separately in 2009.

Land reclaimed cumulative hectares EN13 930 1,095 1,303 1,439 1,542

Footnote T:
Reclaimed lands have not been certified by government regulators. Following Alberta Environment's issuance of standards for Geographic Information System (GIS) spatial data reporting, issued in 2010, Suncor annually re-evaluates permanent reclamation areas and recalculates historical reclamation totals.Disturbance feature types (such as roads, power lines, pipelines, etc.) that occurred post-reclamation are removed and any new areas of reclamation are added. As such, the reclamation areas for each year and the total area permanently reclaimed to the end of 2012 have been updated to reflect these changes.  

Combined surface area of tailings ponds hectares EN12 3,182 3,154 2,689 2,761 2,712

Footnote U:
The tailings pond area calculation is based on fluids area only and does not include solid structures such as beaches and dykes. As of 2009, Pond 1 was classified as a reclamation area and not included in the tailings pond calculation.

Compliance                
Major incidents   LA7, SO8 1 0 0 0 0

Footnote V:
Major incidents are environment, health or safety incidents that result in a permanent disability or fatality, punitive action by government, having catastrophic environmental impact, or significant impact to the company's reputation.

Regulatory contraventions   EN28 81 28 14 11 9

Footnote W:
A regulatory contravention is an environmental incident that breaches a regulatory limit (prescribed threshold required by legislation, approval or permit from a regulatory authority) or requirement (any law, act, regulation, license, standard, approval, directive and/or permit applicable to Suncor's activities"  and that triggers formal regulatory reporting.

Air quality exceedances   EN28 356 -- -- 0 0

Footnote X:
Suncor continues to investigate and evaluate changes that may improve air quality. Beginning in 2009, ambient ground level concentration exceedances are not provided as other reduced sulphur compounds and possibly non-sulphur containing compounds may interfere with hydrogen sulphide (H2S) analyzers, leading to results that are not accurate reflections of the actual H2S concentrations in the ambient air.

Number of industrial wastewater limit exceedances     EN28 1 3 2 2 1
Total number of reportable spills   EN23 42 50 17 9 7

Footnote Y:
A reportable spill is an unplanned or accidental event resulting in a release of material either into the environment or into a location that does not usually contain the material, as specified by Alberta regulation.

Number of spills to natural water bodies     EN23 1 1 0 0 0
Total volume of reportable spills m3 EN23 164 1.44 0 0 1,058

Footnote Z:
All recovered spill volumes are discounted from final spill volumes. Spills are also discounted when the material was spilled into a containment system that was intended for the material, or into a system that would fully recover the material. In 2010 and 2011, the entire estimated spill volume was recovered resulting in 0 net spill volume.

Regulatory fines $ thousands EN28 0 179 237 475 0

Footnote AA:
Data includes regulatory fines related to environmental, health and safety contraventions paid during the stated year.
2009 "  In March 2006, Suncor received and Alberta Environment (AENV) notice that the Crown has processed and sworn charges against Suncor regarding the incident. On April 2, 2009, Suncor pled guilty to one charge of exceeding approval limits and received a penalty of $175,000 of which $131,000 was directed to a creative sentence (e.g., scholarship for Alberta Water and Waste Water Operator Association).
2009 "  AENV has concluded its investigation reported on Oct. 2, 2007 of the upgrader coker (52C-314) fire. And it has assessed an administrative penalty. Suncor has paid the $4,000 penalty.
2010 "  Suncor's regulatory fines that were paid in 2010 are related to incidents that occurred in 2008.
2011 " 
  1. Suncor paid a $275,000 fine in 2011 for violations of Section 142(1)(e) of the Water Act that occurred between May and September 2008.   The violation was a result of Suncor failing to comply with a term of its approval relating to the adherence to the water management plan applicable to the East Tank Farm site.  
  2. A $150,000 fine was paid pursuant to Sections 40(2) and 79.2(f) of the Fisheries Act relating to a June 23, 2008 rain event which overwhelmed Suncor's sedimentation ponds at the North Steepbank Extension, and resulted in discharges into the Athabasca River which contained elevated levels of total suspended solids.
  3. A $50,000 fine was paid pursuant to Sections 40(2) and 79.2(f) of the Fisheries Act relating to rain events on Aug. 2, 2008 and from Aug. 11 to 13, 2008, which overwhelmed Suncor's sedimentation ponds at the North Steepbank Extension, and resulted in discharges into the Athabasca River which contained elevated levels of total suspended solids.

Environment, Health & Safety (EH&S) management                
EH&S professionals on staff     EN30 35 118 126 75 69
Oil Sands environment footnotes
A Net synthetic crude oil production. This volume is used to calculate emission intensities since it represents emissions associated with total.
B Emissions have been calculated based on the methodology from the American Petroleum Institute (API) and modified:
• where necessary to accommodate the uniqueness of the oil sands processes and
• where no industry standard exists
API logic is applied in these circumstances. Other reference sources utilized to provide emission factors include:
• Environment Canada
• Canadian Industrial Energy End-Use Data and Analysis Centre (CIEEDAC)
• The "Draft Greenhouse Gas Emission Estimation Methodologies for the Oil Sands / Heavy Oil Upgrader Industry"
The data is consistent with Suncor's Specified Gas Emitters Regulation (SGER) Bill 3 reported Total Annual Emission (TAE) value, with two exceptions. The reported TAE in the SGER Compliance report excludes carbon dioxide emissions from biomass and total indirect emissions.
2012 emission methodology updated as required by Alberta Environment and Sustainable Resource Development (AESRD) and other historical years will also be updated in future reports.
C Retrofitting of refrigeration systems currently using R-22 or any other hydrofluorocarbons (HCFCs) are part of Suncor's ongoing program to phase out the use of ozone depleting substances on-site. The conversion of all remaining R-22 systems with RS-44 with more than 10 kilograms in it is ongoing and will continue until complete. RS-44 is a non-ozone depleting substance.
D Oil Sands does not consider sulphur oxide (SO2) emissions from mobile sources because it uses low or ultra low sulphur diesel in its mining.
E Site-wide nitrogen oxide (NOx) emissions as reported to Alberta Environment. This also includes NOx emissions from mobile sources.
F These values include both emergency and non-emergency flaring volumes.
G Includes combustion of petroleum coke, natural gas and internally produced fuels; diesel combusted as fuel in mine trucks; flaring and electrical power imports. Electrical energy produced by the Poplar Creek cogen that is sold externally to the provincial grid is deducted from direct energy use.
H Direct energy is energy consumed on-site by Suncor operated facilities; sold electrical energy produced by the cogen is deducted from the direct energy. Indirect energy includes imported electricity, steam, heating and cooling duty from third parties.Beginning in 2011, the indirect energy calculation methodology was changed to credit operations for electricity exported to external users and/or other Suncor facilities. The facility that exports the electricity subtracts the export value from its indirect energy use. The facility that receives the electricity, counts it as a scope 2 indirect energy use, regardless of source. As such, the 2012 oil sands indirect energy figure is a negative because the amount of electricity exported was greater in value than the amount of electricity imported.    
I Includes surface water, groundwater and industrial run-off water as per Alberta Environment and Water withdrawal licences.2011 water withdrawal metrics have been revised based on data and process improvements in 2012 which improved the understanding of site conditions for specific facilities.
J The value in 2011 increased because the industrial run-off outfall volumes were included.
K Total of both surface water and groundwater withdrawn minus the water returned. 2011 water consumption metrics have been revised based on data and process improvements in 2012 which improved the understanding of site conditions for specific facilities.
L In 2011, the water quality discharge parameters increased or decreased due to the Pond C closure that occurred from April to December, and/or the inclusion of the industrial run-off water quality data. Additionally, Pond C was closed all of 2012 and pond E was also closed the majority of the year.
M Beginning in 2011, in order to better align with the Global Reporting Initiative (GRI) standard, Suncor has expanded the number of indicators for which it collects and reports data in the Waste Management category.
N From 2008 to 2009, the evaporator blow down and ecopit waste was disposed of at an off-site hazardous waste facility. Reduction in hazardous waste volume in 2012 resulted from no sulphur being sent to landfill.
O Non-hazardous volume in 2012 increased due to site activities and resulting waste including soil, gravel, wood and concrete.
P In 2012, a third party contractor transported used oil offsite for recycling; previous years this was done on-site.
Q The decrease in mineable oil sands area in 2009 is due to the method of calculation used. In previous years it was estimated from a map of the area, while in 2009 the area was calculated using numerical values of the actual area.
R Beginning in 2009, data collected for these indicators can be found in the In Situ business unit section.
S The decrease in total land disturbed for the 2009 reporting year is because the In Situ business unit began reporting separately in 2009.
T Reclaimed lands have not been certified by government regulators. Following Alberta Environment's issuance of standards for Geographic Information System (GIS) spatial data reporting, issued in 2010, Suncor annually re-evaluates permanent reclamation areas and recalculates historical reclamation totals.Disturbance feature types (such as roads, power lines, pipelines, etc.) that occurred post-reclamation are removed and any new areas of reclamation are added. As such, the reclamation areas for each year and the total area permanently reclaimed to the end of 2012 have been updated to reflect these changes.  
U The tailings pond area calculation is based on fluids area only and does not include solid structures such as beaches and dykes. As of 2009, Pond 1 was classified as a reclamation area and not included in the tailings pond calculation.
V Major incidents are environment, health or safety incidents that result in a permanent disability or fatality, punitive action by government, having catastrophic environmental impact, or significant impact to the company's reputation.
W A regulatory contravention is an environmental incident that breaches a regulatory limit (prescribed threshold required by legislation, approval or permit from a regulatory authority) or requirement (any law, act, regulation, license, standard, approval, directive and/or permit applicable to Suncor's activities"  and that triggers formal regulatory reporting.
X Suncor continues to investigate and evaluate changes that may improve air quality. Beginning in 2009, ambient ground level concentration exceedances are not provided as other reduced sulphur compounds and possibly non-sulphur containing compounds may interfere with hydrogen sulphide (H2S) analyzers, leading to results that are not accurate reflections of the actual H2S concentrations in the ambient air.
Y A reportable spill is an unplanned or accidental event resulting in a release of material either into the environment or into a location that does not usually contain the material, as specified by Alberta regulation.
Z All recovered spill volumes are discounted from final spill volumes. Spills are also discounted when the material was spilled into a containment system that was intended for the material, or into a system that would fully recover the material. In 2010 and 2011, the entire estimated spill volume was recovered resulting in 0 net spill volume.
AA Data includes regulatory fines related to environmental, health and safety contraventions paid during the stated year.
2009 "  In March 2006, Suncor received and Alberta Environment (AENV) notice that the Crown has processed and sworn charges against Suncor regarding the incident. On April 2, 2009, Suncor pled guilty to one charge of exceeding approval limits and received a penalty of $175,000 of which $131,000 was directed to a creative sentence (e.g., scholarship for Alberta Water and Waste Water Operator Association).
2009 -  AENV has concluded its investigation reported on Oct. 2, 2007 of the upgrader coker (52C-314) fire. And it has assessed an administrative penalty. Suncor has paid the $4,000 penalty.
2010 -  Suncor's regulatory fines that were paid in 2010 are related to incidents that occurred in 2008.
2011 - 
  1. Suncor paid a $275,000 fine in 2011 for violations of Section 142(1)(e) of the Water Act that occurred between May and September 2008.   The violation was a result of Suncor failing to comply with a term of its approval relating to the adherence to the water management plan applicable to the East Tank Farm site.  
  2. A $150,000 fine was paid pursuant to Sections 40(2) and 79.2(f) of the Fisheries Act relating to a June 23, 2008 rain event which overwhelmed Suncor's sedimentation ponds at the North Steepbank Extension, and resulted in discharges into the Athabasca River which contained elevated levels of total suspended solids.
  3. A $50,000 fine was paid pursuant to Sections 40(2) and 79.2(f) of the Fisheries Act relating to rain events on Aug. 2, 2008 and from Aug. 11 to 13, 2008, which overwhelmed Suncor's sedimentation ponds at the North Steepbank Extension, and resulted in discharges into the Athabasca River which contained elevated levels of total suspended solids.

Economic

In the "Footnote" column, click on the down-arrow symbol to display the footnote.

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Indicator Unit Footnote GRI indicator 2008 2009 2010 2011 2012
Production                
Net production thousand barrels of oil/day OG1 228.0 290.6 283 304.7 324.8

Footnote BB:
Net production is product available for sale. Figures are consistent with those found in Suncor's 2012 annual reports.

Net production thousand of m3 of oil/day OG1 36.2 46.2 45.0 48.4 51.6

Footnote BB:
Net production is product available for sale. Figures are consistent with those found in Suncor's 2012 annual reports.

Financials              

Footnote CC:
For complete disclosure and additional information, download our 2012 annual report (PDF, 139 pp., 776 KB).

Net earnings $ millions   EC1 2,875 557 1,520* 2,603 458
Cash flow from operations $ millions   EC1 3,507 1,251 2,777* 4,572 4,407
Tax and royalty credits earned $ thousands EC4 5,000 5,000 12,500 6,100 14,500

Footnote DD:
Investment Tax Credit on Scientific Research and Experimental Development Expenditures.

Investments                
Capital and exploration expenditures $ millions   EC1 7,413 2,831 3,709 5,100 4,957
Purchases              

Footnote EE:
Purchases in 2010 represent the first year over year comparison since the Petro-Canada and Suncor merger in 2009.

Goods and services $ millions     3,038 3,862 3,643 4,315 4,194
Goods and services purchased in or from $ millions              
     Canada       2,919 3,670 3,455 4,139 4,076
     Local businesses/
suppliers
  EC6 1,314 1,851 1,844 2,056 1,929

Footnote FF:
Local is defined as businesses/suppliers based in the Regional Municipality of Wood Buffalo. Data from 2009 to 2012 includes Oil Sands mining and In Situ spend from consolidated Petro-Canada and Suncor.

     Aboriginal      businesses/suppliers   EC6 187 252 182 152 -        

Footnote GG:
For 2012, this indicator has been rolled up into Suncor-wide.

Oil Sands economic footnotes
*
Data for 2009 and prior years is presented in accordance with previous Generally Accepted Accounting Principles (GAAP) standard.All values are consistent with Suncor's annual reports.    
BB Net production is product available for sale. Figures are consistent with those found in Suncor's 2012 annual reports.
CC For complete disclosure and additional information, download our 2012 annual report (PDF, 139 pp., 776 KB).
DD Investment Tax Credit on Scientific Research and Experimental Development Expenditures.
EE Purchases in 2010 represent the first year over year comparison since the Petro-Canada and Suncor merger in 2009.
FF Local is defined as businesses/suppliers based in the Regional Municipality of Wood Buffalo. Data from 2009 to 2012 includes Oil Sands mining and In Situ spend from consolidated Petro-Canada and Suncor.
GG For 2012, this indicator has been rolled up into Suncor-wide.

Social

Oil Sands social footnotes
HH A lost-time injury requires medical attention and results in an employee being absent from work on the next regularly scheduled work day or any subsequent work day. Lost-time injury frequency is the number of such injuries per 200,000 hours worked.
II Recordable injuries include lost-time injuries as well as medical aid injuries. Medical aid injuries require medical attention but do not result in an employee being absent from work. Recordable injury frequency is the sum of lost-time and medical aid injuries per 200,000 hours worked.
JJ Kevin Grocutt, a Finning Canada employee, died at the Millennium mine in July 2008 when a haul truck was being towed to the maintenance shop for repairs.
KK Compares Oil Sands full-time base wage to the province of Alberta's minimum wage. In 2012, we used $9.75/hour.
LL Includes the educational assistance plan that reimburses tuition upon successful completion of a course or program. 2009 data excludes Petro-Canada information due to differences in the systems that report this data. Beginning in 2010, the educational assistance is based on tuition refunds.
MM
Any externally hired regular full-time or regular part-time employee whose permanent start date falls within the reporting period. No historical data available prior to 2012 as this is the first year this new GRI 3.1 indicator is being reported.
NN Beginning in 2011, this number is reported on a Suncor-wide level and the breakdown is not available.