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In Situ

Data from 2009-2012 includes consolidated Petro-Canada and Suncor numbers for the 2009-2012 reporting years.

The In Situ Business Unit is comprised of MacKay River and Firebag operations — in previous years the In Situ Firebag data was included in the Oil Sands Business Unit. Due to this business reorganization, historical data prior to 2009 has not been included. Economic data for In Situ is included in Oil Sands.

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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 2009 2010 2011 2012
Production              
Net production million barrels of oil /year OG1 28.6 31.0 32.7 47.8

Footnote A:
For 2012 and going forward, production stated is net bitumen sales. Previously stated production was gross bitumen production and associated natural gas production internally consumed as well as losses through practices such as flaring. The net volume is used to calculate emission intensities since it represents emissions associated with total plant saleable product.

Net production million cubic metres (m3) of oil/year OG1 4.6 4.9 5.2 7.6

Footnote A:
For 2012 and going forward, production stated is net bitumen sales. Previously stated production was gross bitumen production and associated natural gas production internally consumed as well as losses through practices such as flaring. The net volume is used to calculate emission intensities since it represents emissions associated with total plant saleable product.

Air emissions              
Greenhouse gas (GHG) thousand tonnes carbon dioxide equivalent (CO2e) /year EN16 1,832 2,005 2,534 4,093

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 Steam Assisted Gravity Drainage (SAGD) process
• where no industry standard exists
API logic is applied in these circumstances. Other reference sources utilized to provide emission factors include:
• Environment Canada
• Canadian Fuels Association (CFA) (Economic and Environmental Impacts of Removing Sulfur from Canadian Gasolines and Distillate Production)
The data is consistent with Suncor's Specified Gas Emitter's Regulation (SGER) Bill 3 reported Total Annual Emission (TAE) value, with two exceptions. The reported TAE in the SGER Compliance report excludes CO2 emissions from total indirect sources, such as third party cogen from MacKay River.
For the purposes of Suncor's Report on Sustainability, we include all indirect cogen emissions associated with the power generation.   In addition, indirect emissions associated with the purchase of third party products (i.e., steam, electricity and heat) have been included.   Beginning in 2011, MacKay River implemented a new methodology for calculating these indirect emissions; therefore, 2011 emissions are higher than they were for previous years.  

GHG emission intensity tonnes CO2e/m3 production   EN16 0.40 0.41 0.49 0.54
Sulphur dioxide (SO2) thousand tonnes/year EN20 1.11 1.19 0.47 0.53

Footnote C:
In 2012, increase in SO2 emissions was due to increase in steam generation required to bring new wells online. Suncor installed a sulphur recovery unit (SRU) at Firebag in 2011, which lead to a decrease in SO2 emissions in 2011 compared to 2010. This decrease in intensity continued in 2012.

Sulphur dioxide emission intensity kilograms/m3 production   EN20 0.24 0.24 0.09 0.07
Nitrogen oxides (NOx) thousand tonnes/year EN20 0.75 1.03 1.91 2.03

Footnote D:
In 2012, increase in NOx emissions was due to increase in steam generation required to bring new wells online.

Nitrogen oxides emission intensity kilograms/m3 production   EN20 0.17 0.21 0.37 0.27
Volatile organic compounds (VOCs) thousand tonnes/year EN20 0.12 0.20 0.21 0.23

Footnote E:
In 2012, increase in total VOCs and specified VOC emissions were due to increase in steam generation required to bring new wells online.

     Benzene tonnes   EN20 9.62 11.01 13.53 16.62
     Toluene tonnes   EN20 6.75 7.26 8.33 18.03
     Ethylbenzene tonnes   EN20 0.19 0.23 0.37 0.25
     Xylene tonnes   EN20 3.36 3.55 3.74 11.46
VOC emission intensity kilograms/m3 production   EN20 0.03 0.04 0.04 0.03
National Pollutant Release Inventory (NPRI) on-site releases thousand tonnes/year   EN20 3.81 5.91 6.95 7.32
Flared gas million m3/year OG6 1.51 1.37 1.58 1.95

Footnote F:
Values include emergency and non-emergency flaring volumes.

Flared gas intensity m3/m3 production   EN20 0.33 0.28 0.30 0.26
Heating energy of gas flared million gigajoules EN20 45.04 45.00 45.00 45.00

Footnote F:
Values include emergency and non-emergency flaring volumes.

Energy consumption              
Total energy use million gigajoules EN3/4 39.70 45.33 45.46 67.26

Footnote G:
Includes combustion of natural gas and internally produced fuels; flaring and electrical power imports. For MacKay River, the exported electricity to the grid is not claimed as an indirect, only the power consumed by Suncor Operations since the cogen is independently operated by Trans Canada.For Firebag, the exported electricity to the grid is deducted from the total energy use since the cogen is operated by Suncor. Beginning in 2011, direct energy consumption was calculated using lower heating value (LHV) in order to be consistent with all other operating facilities.

     Direct energy use million gigajoules EN3 33.92 38.51 37.40 63.94

Footnote H:
Direct energy is energy consumed on-site by Suncor operated facilities.Firebag sold electrical energy is deducted from the total energy   use. 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 value from their indirect energy use.   The facility that receives the electricity counts it as a scope 2 indirect energy use, regardless of source.   As such, the 2011 and 2012 Firebag indirect energy figures are negative, because the amount of electricity exported was higher in value than the amount of electricity imported.   However, the negative Firebag indirect energy figures for 2011 and 2012 are lower than the MacKay River indirect energy figures, which is why the In Situ total indirect energy figures are positive for 2011 and 2012

     Indirect energy use million gigajoules EN4 5.78 6.82 8.06 3.32

Footnote H:
Direct energy is energy consumed on-site by Suncor operated facilities.Firebag sold electrical energy is deducted from the total energy   use. 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 value from their indirect energy use.   The facility that receives the electricity counts it as a scope 2 indirect energy use, regardless of source.   As such, the 2011 and 2012 Firebag indirect energy figures are negative, because the amount of electricity exported was higher in value than the amount of electricity imported.   However, the negative Firebag indirect energy figures for 2011 and 2012 are lower than the MacKay River indirect energy figures, which is why the In Situ total indirect energy figures are positive for 2011 and 2012

Energy intensity gigajoules/m3 production   EN3/4 8.73 9.18 8.75 8.83
Energy saved through conservation and efficiency improvements thousand gigajoules   EN5 1,059.76 644.63 513.37 0.00
Water use              
Total water withdrawal millions m3 EN8 1.78 2.09 0.27 0.83

Footnote I:
Total water withdrawal includes water from:
• surface water
• groundwater
• treated wastewater from external organizations
• industrial run-off water  
In 2011, as per Global Reporting Initiative (GRI) guidance, the volume of treated wastewater that Oil Sands sent to our Firebag In Situ facility was removed from Firebag's water withdrawal volume and was accounted for in the Oil Sands' withdrawal volume.   As such, there was a decrease in the 2011 value.

Water withdrawal
         (surface water)
million m3   EN8 0.00 0.00 0.00 0.00
Water withdrawal
       (groundwater)
millions m3   EN8 0.67 0.62 0.20 0.61
Water Withdrawal
         (treated wastewater
         from external
         organizations)
millions m3 EN8 1.03 1.38 0.00 0.00

Footnote I:
Total water withdrawal includes water from:
• surface water
• groundwater
• treated wastewater from external organizations
• industrial run-off water  
In 2011, as per Global Reporting Initiative (GRI) guidance, the volume of treated wastewater that Oil Sands sent to our Firebag In Situ facility was removed from Firebag's water withdrawal volume and was accounted for in the Oil Sands' withdrawal volume.   As such, there was a decrease in the 2011 value.

Water withdrawal
           (industrial
           run-off water)
millions m3   EN8 0.07 0.09 0.06 0.23
Total water withdrawal intensity m3/m3 production EN8 0.39 0.42 0.05 0.11

Footnote I:
Total water withdrawal includes water from:
• surface water
• groundwater
• treated wastewater from external organizations
• industrial run-off water  
In 2011, as per Global Reporting Initiative (GRI) guidance, the volume of treated wastewater that Oil Sands sent to our Firebag In Situ facility was removed from Firebag's water withdrawal volume and was accounted for in the Oil Sands' withdrawal volume.   As such, there was a decrease in the 2011 value.

Water returned million m3   EN21 0.00 0.00 0.01 0.01
Water consumption million m3   1.78 2.09 1.97 2.34

Footnote J:
Total Firebag and MacKay River water consumption is comprised of water withdrawn from licensed groundwater wells, treated wastewater and industrial run-off water, minus the water returned.

Water consumption intensity m3/m3 production     0.39 0.42 0.38 0.31
Produced water million m3   OG5 -- -- -- 24.86
Average annual water recycling rate %   EN2 94.20 93.10 92.48 94.50
Waste management            

Footnote K:
Beginning in 2011, in order to better align with the GRI reporting 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 77.9 81.6 437.2 764.9

Footnote L:
In 2012, increase reflected increased production.

Hazardous waste
         incinerated
tonnes   EN22 -- -- 4.5 2.3
Hazardous waste
       deep well injected
tonnes EN22 -- -- 382,767.0 704,829.0

Footnote L:
In 2012, increase reflected increased production.

Hazardous waste
         landfilled
tonnes   EN22 -- -- 1,764.4 877.50
Hazardous waste
         otherwise disposed
tonnes EN22 -- -- 52,623.4 59,222.9

Footnote M:
Includes cavern and ecopit disposal.

Non-hazardous waste generated thousand tonnes   EN22 115.4 125.5 97.5 111.47
Non-hazardous
       waste landfilled
tonnes   EN22 -- -- 59,852.0 55,803.64
Non-hazardous waste
         otherwise disposed
tonnes EN22 -- -- 37,634.0 55,345.54

Footnote N:
Includes sewage sent to Fort McMurray.

Drilling waste disposed or treated tonnes OG7 -- -- -- 62,723.95

Footnote O:
This is hazardous and non-hazardous drilling waste. In previous years, drilling waste with >8% bitumen content that was hauled to mine for re-processing was reported as waste reused on-site but has been included here with the introduction of the OG7 indicator in 2012. This value has not been captured in the hazardous waste generated and non-hazardous waste generated values.

Waste reused/recycled/recovered off-site thousand tonnes     1.03 2.3 6.41 2.8
Waste reused/recycled/recovered on-site thousand tonnes   3.34 4.95 81.60 0.00

Footnote P:
Beginning in 2012, drilling waste with >8% bitumen content, hauled to the mine for re-processing, is no longer reported as waste reused onsite but has been captured in the OG7 indicator.

Land disturbance and reclamation              
Total land lease holdings for potential development              
     Mineable oil sands hectares   EN11 -- -- -- --
     In situ hectares   EN11 112,684 181,684 181,053 181,053
Total land holdings approved for development              
     Mineable oil sand hectares   EN11 -- -- -- --
     In situ hectares   EN11 22,272 22,272 24,003 24,537
     Firebag land approved
by Energy Resource
     Conservation Board
         for development
hectares     2,880 2,880 2,880 2,880
Total land disturbed cumulative hectares   EN12 1,053 1,072 990 1,172
Land reclaimed hectares   EN13 46 46 46 33
Total number of producing wells     EN12 97 96 123 168
Number of shut-in/suspended production wells       0 1 4 4
Number of wells undergoing reclamation     EN13 0 0 0 0
Number of reclamation certificates received     EN13 9 0 0 0
Compliance              
Major incidents   LA7, SO8 0 0 0 0

Footnote Q:
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 98 74 57 91

Footnote R:
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     EN28 12 5 16 16
Number of industrial wastewater limit exceedances     EN28 1 0 0 0
Total number of reportable spills   EN23 45 23 24 28

Footnote S:
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 0 0 0 0
Total volume reportable spills m3 EN23 28 131 111 1,081

Footnote T:
97 m3 of the total volume of spills recorded for MacKay River In Situ in 2010 is attributed to overflow of the landfill run-off control pond recorded during five events.

Regulatory fines $ thousands EN28 675 0 0 0

Footnote U:
Data includes regulatory fines related to environmental, health and safety contraventions paid during the stated year.
2009 - In August 2007, Alberta Environment (AENV) did an investigation on hydrogen sulphide (H2S) emissions and vapour recovery unit at Firebag, the investigation concluded. Discussion has concluded between Suncor and Alberta Justice potential penalties. On April 2, 2009, Suncor pled guilty to two charges and received a total penalty of $675,000 of which $390,000 was directed towards a creative sentence, (e.g., $315,000 to the University of Calgary business school to fund a case study and $75,000 to Keyano College).

Environment, Health & Safety (EH&S)management              
EH&S professionals on staff     EN30 13 21 24 23
In Situ environment footnotes
A For 2012 and going forward, production stated is net bitumen sales. Previously stated production was gross bitumen production and associated natural gas production internally consumed as well as losses through practices such as flaring. The net volume is used to calculate emission intensities since it represents emissions associated with total plant saleable product.
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 Steam Assisted Gravity Drainage (SAGD) process
• where no industry standard exists
API logic is applied in these circumstances. Other reference sources utilized to provide emission factors include:
• Environment Canada
• Canadian Fuels Association (CFA) (Economic and Environmental Impacts of Removing Sulfur from Canadian Gasolines and Distillate Production)
The data is consistent with Suncor's Specified Gas Emitter's Regulation (SGER) Bill 3 reported Total Annual Emission (TAE) value, with two exceptions. The reported TAE in the SGER Compliance report excludes CO2 emissions from total indirect sources, such as third party cogen from MacKay River.
For the purposes of Suncor's Report on Sustainability, we include all indirect cogen emissions associated with the power generation.   In addition, indirect emissions associated with the purchase of third party products (i.e., steam, electricity and heat) have been included.   Beginning in 2011, MacKay River implemented a new methodology for calculating these indirect emissions; therefore, 2011 emissions are higher than they were for previous years.  
C In 2012, increase in SO2 emissions was due to increase in steam generation required to bring new wells online. Suncor installed a sulphur recovery unit (SRU) at Firebag in 2011, which lead to a decrease in SO2 emissions in 2011 compared to 2010. This decrease in intensity continued in 2012.
D In 2012, increase in NOx emissions was due to increase in steam generation required to bring new wells online.
E In 2012, increase in total VOCs and specified VOC emissions were due to increase in steam generation required to bring new wells online.
F Values include emergency and non-emergency flaring volumes.
G Includes combustion of natural gas and internally produced fuels; flaring and electrical power imports. For MacKay River, the exported electricity to the grid is not claimed as an indirect, only the power consumed by Suncor Operations since the cogen is independently operated by Trans Canada.For Firebag, the exported electricity to the grid is deducted from the total energy use since the cogen is operated by Suncor. Beginning in 2011, direct energy consumption was calculated using lower heating value (LHV) in order to be consistent with all other operating facilities.
H Direct energy is energy consumed on-site by Suncor operated facilities.Firebag sold electrical energy is deducted from the total energy   use. 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 value from their indirect energy use.   The facility that receives the electricity counts it as a scope 2 indirect energy use, regardless of source.   As such, the 2011 and 2012 Firebag indirect energy figures are negative, because the amount of electricity exported was higher in value than the amount of electricity imported.   However, the negative Firebag indirect energy figures for 2011 and 2012 are lower than the MacKay River indirect energy figures, which is why the In Situ total indirect energy figures are positive for 2011 and 2012
I Total water withdrawal includes water from:
• surface water
• groundwater
• treated wastewater from external organizations
• industrial run-off water  
In 2011, as per Global Reporting Initiative (GRI) guidance, the volume of treated wastewater that Oil Sands sent to our Firebag In Situ facility was removed from Firebag's water withdrawal volume and was accounted for in the Oil Sands' withdrawal volume.   As such, there was a decrease in the 2011 value.
J Total Firebag and MacKay River water consumption is comprised of water withdrawn from licensed groundwater wells, treated wastewater and industrial run-off water, minus the water returned.
K Beginning in 2011, in order to better align with the GRI reporting standard, Suncor has expanded the number of indicators for which it collects and reports data in the Waste Management category.
L In 2012, increase reflected increased production.
M Includes cavern and ecopit disposal.
N Includes sewage sent to Fort McMurray.
O This is hazardous and non-hazardous drilling waste. In previous years, drilling waste with >8% bitumen content that was hauled to mine for re-processing was reported as waste reused on-site but has been included here with the introduction of the OG7 indicator in 2012. This value has not been captured in the hazardous waste generated and non-hazardous waste generated values.
P Beginning in 2012, drilling waste with >8% bitumen content, hauled to the mine for re-processing, is no longer reported as waste reused onsite but has been captured in the OG7 indicator.
Q 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  
R 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.
S 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.
T 97 m3 of the total volume of spills recorded for MacKay River In Situ in 2010 is attributed to overflow of the landfill run-off control pond recorded during five events.
U Data includes regulatory fines related to environmental, health and safety contraventions paid during the stated year.
2009 - In August 2007, Alberta Environment (AENV) did an investigation on hydrogen sulphide (H2S) emissions and vapour recovery unit at Firebag, the investigation concluded. Discussion has concluded between Suncor and Alberta Justice potential penalties. On April 2, 2009, Suncor pled guilty to two charges and received a total penalty of $675,000 of which $390,000 was directed towards a creative sentence, (e.g., $315,000 to the University of Calgary business school to fund a case study and $75,000 to Keyano College).

Social

In Situ social footnotes
V 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.
W Recordable injuries include lost-time injuries as well as medical aid injuries. Medical aid injuries require medical attentions 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.
X In July 2011, a Flint Transfield Services employee died at the Firebag site during the removal of an end cap from piping at one of the production pads.
Y Compares In Situ full-time base wage to the province of Alberta's minimum wage. In 2012 we used $9.75/hour.
Z Any externally hired regular full-time or regular part-time employee whose permanent start date falls within the reporting period.
AA In 2012, this number is reported on a Suncor-wide level and the breakdown is not available.