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Refining & Marketing

Suncor operates facilities in the Refining & Marketing (R&M) business unit in Alberta, Ontario, Quebec and Colorado. Data from Suncor's operations are consolidated for reporting purposes.

Historical information from 2008 includes combined data from Suncor R&M U.S. and Canadian operations, which had previously been reported separately. 2009 Data includes consolidated Petro-Canada and Suncor R&M assets for the 2009 reporting year. Beginning in 2009, data from the St. Clair ethanol plant was no longer included under the R&M business unit and is now reported separately. This data has been removed from historic R&M operations.

R&M also includes emissions data from Suncor's terminals and pipelines, which account for a small percentage of the total R&M numbers and are deemed to be negligible.

All significant data changes from 2008 are due to the 2009 merger of Petro-Canada and Suncor Energy whereby all data reported is from the combined company facilities for the full 2009 reporting year. The 2012 reporting year marks the third full year where a year over year comparison can be made with all facilities.

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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 cubic metres (m3)
refined product/year
OG1 9.8 25.7 26.3 26.32 27.21

Footnote A:
On a business unit level, net production is reported where interplant movements have been identified and removed from the facility production total. This value is calculated by adding each of the Refining & Marketing (R&M) production volumes, which include saleable product including fuels and co-products, minus the intra-company transfers between facilities.

Air emissions              

Footnote B:
All significant air emission increases from 2008 are due to the 2009 merger of Petro-Canada and Suncor Energy whereby all emissions reported are from the combined company facilities. All significant changes in intensity are also due to the combination of assets from the merger of Suncor Energy and Petro-Canada.

Greenhouse gas (GHG) thousand tonnes carbon dioxide equivalent (CO2e)
/year
EN16 1,931 6,245 6,020 5,849 5,963

Footnote C:
In general, GHG emissions have been calculated using the American Petroleum Institute (API) methodologies and sections of Canadian Fuels Association (CFA) guidelines (Economic and Environmental impacts of removing sulfur from Canadian Gasolines and Distillate Production). For the Edmonton refinery, the data is consistent with Suncor's Specified Gas Emitters Regulation (SGER) Bill 3 reported Total Annual Emission (TAE) value, with one exception. The reported TAE in the SGER Compliance report excludes CO2 emissions from biomass and total indirect emissions. Suncor did not report any emissions from hydroflourocarbons (HFCs), perflourocarbons (PFCs) or sulphur hexaflouride (SF6S). For our operations in Quebec and Ontario the data is consistent with the guidelines for those provinces which are aligned with Western Climate Initiative (WCI).
Scope 2 indirect emissions include those associated with the purchases of electricity, steam, heat, cooling and hydrogen. Carbon dioxide sold by the facilities are reported under Scope 3. These values are reported under Scope 3 emissions in our additional policies and procedures section of this report.

GHG intensity tonnes CO2e/m3 production   EN16 0.20 0.24 0.23 0.22 0.22
Sulphur dioxide (SO2) thousand tonnes/year EN20 2.81 10.26 7.20 8.75 5.77

Footnote D:
The SO2 emissions calculation methodology underwent a number of data and process improvements in 2012 which improved the understanding of site conditions for specific facilities. If the current methodology were applied to the 2011 SO2 inventory for R&M, using 2012 compositions, the 2011 value would increase by approximately 5%.

Sulphur dioxide emission intensity kilograms/m3 production   EN20 0.29 0.40 0.27 0.33 0.21
Nitrogen oxides (NOx) thousand tonnes/year   EN20 1.47 5.21 4.31 4.41 4.53
Nitrogen oxides emission intensity kilograms/m3 production   EN20 0.15 0.20 0.16 0.17 0.17
Volatile organic compounds (VOCs) thousand tonnes/year   EN20 0.75 6.35 4.50 4.36 4.25
     Benzene tonnes   EN20 12.51 50.32 37.49 48.14 46.37
     Toluene tonnes   EN20 26.31 119.52 121.09 125.93 123.86
     Ethylbenzene tonnes   EN20 9.29 13.79 11.40 11.19 10.51
     Xylene tonnes   EN20 32.17 81.77 69.72 64.57 62.27
VOC emission intensity kg/m3 production   EN20 0.08 0.25 0.17 0.17 0.16
TRI on-site releases tonnes/yr   EN20 54 46 38 56 66.90
National Pollutant Release Inventory Releases (NPRI)
on-site releases
thousand tonnes EN20 10.23 28.99 21.91 23.41 20.01

Footnote E:
Data includes terminal emissions.

Flared gas million m3/yr   OG6 32.3 168.9 136.2 109.0 71.90
Flared gas intensity m3/m3 production   OG6 3.30 6.57 5.19 4.14 2.64
Energy consumption                
Total energy use million gigajoules EN3/4 35.68 86.78 83.25 84.24 83.23

Footnote F:
Energy consumption includes refinery fuel gas and natural gas firing, steam production and import of electrical power.

     Direct energy use million gigajoules EN3 25.1 71.7 71.7 72.9 71.5

Footnote G:
Direct energy is energy consumed on-site by Suncor operated facilities. Indirect energy includes imported electricity, steam, heating and cooling duty from third parties.

     Indirect energy use million gigajoules EN4 10.63 15.12 11.54 11.34 11.71

Footnote G:
Direct energy is energy consumed on-site by Suncor operated facilities. Indirect energy includes imported electricity, steam, heating and cooling duty from third parties.

Energy intensity gigajoules/m3 production   EN3/4 3.64 3.38 3.34 3.2 3.1
Electricity imports million gigajoules   EN3/4 2.67 8.95 10.24 5.96 6.08
Electricity import intensity gigajoules/m3 production   EN3/4 0.27 0.35 0.41 0.23 0.22
Steam imports million gigajoules   EN4 2.53 6.22 5.80 5.38 5.63
Steam import intensity gigajoules/m3 production   EN4 0.26 0.23 0.23 0.20 0.21
Energy saved through conservation and efficiency improvements thousand gigajoules   EN5 -- -- 674.20 874.53 1,387.18
Energy generation                
Installed wind capacity MW EN6 147 147 147 255 255

Footnote H:
By 2012, Suncor had developed six wind power projects:
• SunBridge, in partnership with a subsidiary of Enbridge Income Fund (commissioned in 2002, with a total installed wind capacity of 11 megawatts (MW)
• Magrath (commissioned in 2006 with a total capacity of 30 MW)
• Chin Chute (commissioned in 2006 with a total capacity of 30 MW) in partnership with Enbridge Income Fund and Acciona Wind Power Canada Inc.
• Ripley (commissioned in 2007 with a total capacity of 76 MW) in partnership with Acciona Wind Power Canada Inc.
• Wintering Hills (commissioned 2011 with a total capacity of 88 MW) in partnership with Teck. Operated briefly in 2011 at the same time as the performance measure systems were being implemented. 2012 performance data is included in the wind energy section.
• Kent Breeze (commissioned in 2011 with a total capacity of 20MW). Operated briefly in 2011 at the same time as the performance measure systems were being implemented. 2012 performance data is included in the wind energy section.
This is gross capacity of these wind power projects, not net to Suncor.

Water use                
Total water withdrawal million m3   EN8 32.356 77.20 69.65 79.95 82.33
Water withdrawal
       (surface water)
million m3 EN8 29.3 73.0 64.6 68.63 70.00

Footnote I:
Surface water:
• Sarnia: Estimated water withdrawal from the St. Clair River.
• Edmonton: North Saskatchewan River.
• Montreal: Beginning in 2010, water withdrawal from the St. Lawrence River is metered. For 2009, estimated withdrawal from the St. Lawrence River extrapolated using metered withdrawal data for Q4 2009.
• Mississauga: Water withdrawal from Lake Ontario was estimated assuming maximum pump capacity and a conservative estimate of pump operating hours. Based on professional judgment this value overestimates actual water withdrawal by up to 30%.

Water withdrawal
       (groundwater)
million m3   EN8 1.32 0.21 0.69 0.50 0.60
Water withdrawal
         (Municipality/
         City/District)
million m3 EN8 1.74 2.88 2.71 2.91 3.07

Footnote J:
Water purchased from municipality for domestic use with the exception of Commerce City where it is used for both domestic and process.

Water withdrawal
         (treated
         wastewater
         from external
         organizations)
million m3 EN8 -- 1.11 1.65 1.79 2.70

Footnote K:
Edmonton: Wastewater from Goldbar municipal treatment plant.

Water withdrawal (industrial run-off water) million m3 EN8 -- -- -- 6.12 5.95

Footnote L:
In 2011, a change in methodology occurred to capture industrial run-off as water withdrawn.This run-off volume is included as water returned or water consumed, as applicable to each facility.

Total water withdrawal intensity m3/m3 production   EN8 3.30 3.00 2.65 3.04 3.03
Water returned million m3   EN21 33.65 61.64 63.85 68.20 65.46
Water consumption million m3   -1.29 15.56 5.95 11.75 16.87

Footnote L:
In 2011, a change in methodology occurred to capture industrial run-off as water withdrawn.This run-off volume is included as water returned or water consumed, as applicable to each facility.

Water consumption intensity m3/m3 production   -0.13 0.61 0.24 0.45 0.62

Footnote L:
In 2011, a change in methodology occurred to capture industrial run-off as water withdrawn.This run-off volume is included as water returned or water consumed, as applicable to each facility.

Water discharge quality                
Total suspended sediment tonnes   EN21 76.17 155.40 160.66 153.78 360.24
Oil and grease tonnes   EN21 14.53 83.46 21.42 18.53 24.52
Phenol tonnes   EN21 0.71 0.34 0.19 0.09 0.08
Ammonia tonnes   EN21 19.67 35.56 21.22 9.44 14.47
Waste management              

Footnote M:
In order to better align with the Global Reporting Initiative (GRI) standard for the 2011 report and going forward, Suncor has expanded the number of indicators for which it collects and reports data in the Waste management category.Volume of waste varies from year to year due to periodic equipment maintenance including:
• changing catalyst in reactors and waste water treatment tank
• lagoon cleanouts
• operation shutdowns
• location-specific recycling programs  

Hazardous waste generated thousand tonnes EN22 3.7 15.6 22.7 19.9 1,317.07

Footnote N:
Volume of waste varies from year to year due to periodic equipment maintenance including:
• changing catalyst in reactors and waste water treatment tanks
• lagoon cleanouts
• operation shutdowns
• location specific recycling programs

Hazardous waste incinerated tonnes   EN22 -- -- -- 2,235.0 1977.62
Hazardous waste deep well injected tonnes EN22 -- -- -- 1,082.1 1,302,958.00

Footnote O:
In 2012, hazardous waste to deep well injection increased due to high throughput volume, resulting in more water use.

Hazardous waste landfilled tonnes   EN22 -- -- -- 15,296.1 7,205.94
Hazardous waste otherwise disposed tonnes   EN22 -- -- -- 1,303.2 4932.98
Non-hazardous waste generated thousand tonnes   EN22 22.5 20.8 50.6 60.0 84.7
Non-hazardous
         waste incinerated
tonnes   EN22 -- -- -- 223.0 145.05
Non-hazardous
         waste deep well
         injected
tonnes EN22 -- -- -- 0.0 460.98

Footnote P:
In 2012, experimentation of sending downhole water to external wastewater treatment plant required injection of non-compatible water downhole.

Non-hazardous
         waste landfilled
tonnes   EN22 -- -- -- 41,968.7 39,475.28
Non-hazardous
         waste otherwise       disposed
tonnes EN22 -- -- -- 17,827.6 8,232.10

Footnote Q:
Changes in water management strategy, to eliminate overflow to ponds as required for site approval, resulted in the creation of a waste stream that had not previously required active management.

Waste reused/
recycled/recovered
off-site
thousand tonnes   EN22 1.6 66.5 145.1 86.0 69.16
Waste reused/recycled /recovered on-site thousand tonnes   EN22 3.5 953.5 1,048.1 40.4 21.48
Products and services                
Ethanol blended into gasoline thousand m3 EN26 299.4 412.7 521.3 927.9 979.0

Footnote R:
Refineries that blend ethanol into gasoline are Sarnia, Montreal, Commerce City and Edmonton.The Edmonton Refinery began blending ethanol into gasoline in April 2011.

Sulphur content of gasoline parts per million (ppm)   20.65 18.9 18.5 24.9 25.8

Footnote S:
The volume is an annual average for Sarnia, Commerce City, Montreal and Edmonton refineries. Historically, data was calculated as the weighted average.

Compliance                
Major incidents   LA7, SO8 0 0 0 1 0

Footnote T:
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 51 59 28 32 18

Footnote U:
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 30 48 41 74 81
Water effluent exceedances     EN28 1 11 2 0 0
Total number of reportable spills     EN23 12 67 55 91 99
Total volume of reportable spills m3   EN23 34.5 134 791 1,217 71.78
Leaks from underground storage systems     EN23 0 0 0 1 0
Number of air qualifications     EN28 7 -- -- -- --
Number of spills     EN28 -- 162 221 102 99
Regulatory fines Cdn$ thousands EN28 493 625 810 245 2,354

Footnote V:
$1,956,194.45 was in settlement of Case No. 2011-049; $249,404.73 was in settlement of Case No. 2011-034; and $148,637.42 was in settlement of Case No. 2012-087.  $1,361,329.65 of this total was paid in supplemental environmental projects.

Environment, Health & Safety (EH&S) management                
EH&S professionals on staff     EN30 26 80 59 81 85
Environmental capital expenditures Cdn$ million   EN30 46.2 30.6 37.3 56.1 59.24
Refining & Marketing environment footnotes
A On a business unit level, net production is reported where interplant movements have been identified and removed from the facility production total. This value is calculated by adding each of the Refining & Marketing (R&M) production volumes, which include saleable product including fuels and co-products, minus the intra-company transfers between facilities.
B All significant air emission increases from 2008 are due to the 2009 merger of Petro-Canada and Suncor Energy whereby all emissions reported are from the combined company facilities. All significant changes in intensity are also due to the combination of assets from the merger of Suncor Energy and Petro-Canada.
C In general, GHG emissions have been calculated using the American Petroleum Institute (API) methodologies and sections of Canadian Fuels Association (CFA) guidelines (Economic and Environmental impacts of removing sulfur from Canadian Gasolines and Distillate Production). For the Edmonton refinery, the data is consistent with Suncor's Specified Gas Emitters Regulation (SGER) Bill 3 reported Total Annual Emission (TAE) value, with one exception. The reported TAE in the SGER Compliance report excludes CO2 emissions from biomass and total indirect emissions. Suncor did not report any emissions from hydroflourocarbons (HFCs), perflourocarbons (PFCs) or sulphur hexaflouride (SF6S). For our operations in Quebec and Ontario the data is consistent with the guidelines for those provinces which are aligned with Western Climate Initiative (WCI).
Scope 2 indirect emissions include those associated with the purchases of electricity, steam, heat, cooling and hydrogen. Carbon dioxide sold by the facilities are reported under Scope 3. These values are reported under Scope 3 emissions in our additional policies and procedures section of this report.
D The SO2 emissions calculation methodology underwent a number of data and process improvements in 2012 which improved the understanding of site conditions for specific facilities. If the current methodology were applied to the 2011 SO2 inventory for R&M, using 2012 compositions, the 2011 value would increase by approximately 5%.
E Data includes terminal emissions.
F Energy consumption includes refinery fuel gas and natural gas firing, steam production and import of electrical power.
G Direct energy is energy consumed on-site by Suncor operated facilities. Indirect energy includes imported electricity, steam, heating and cooling duty from third parties.
H By 2012, Suncor had developed six wind power projects:
• SunBridge, in partnership with a subsidiary of Enbridge Income Fund (commissioned in 2002, with a total installed wind capacity of 11 megawatts (MW)
• Magrath (commissioned in 2006 with a total capacity of 30 MW)
• Chin Chute (commissioned in 2006 with a total capacity of 30 MW) in partnership with Enbridge Income Fund and Acciona Wind Power Canada Inc.
• Ripley (commissioned in 2007 with a total capacity of 76 MW) in partnership with Acciona Wind Power Canada Inc.
• Wintering Hills (commissioned 2011 with a total capacity of 88 MW) in partnership with Teck. Operated briefly in 2011 at the same time as the performance measure systems were being implemented. 2012 performance data is included in the wind energy section.
• Kent Breeze (commissioned in 2011 with a total capacity of 20MW). Operated briefly in 2011 at the same time as the performance measure systems were being implemented. 2012 performance data is included in the wind energy section.
This is gross capacity of these wind power projects, not net to Suncor.
I Surface water:
• Sarnia: Estimated water withdrawal from the St. Clair River.
• Edmonton: North Saskatchewan River.
• Montreal: Beginning in 2010, water withdrawal from the St. Lawrence River is metered. For 2009, estimated withdrawal from the St. Lawrence River extrapolated using metered withdrawal data for Q4 2009.
• Mississauga: Water withdrawal from Lake Ontario was estimated assuming maximum pump capacity and a conservative estimate of pump operating hours. Based on professional judgment this value overestimates actual water withdrawal by up to 30%.
J Water purchased from municipality for domestic use with the exception of Commerce City where it is used for both domestic and process.
K Edmonton: Wastewater from Goldbar municipal treatment plant.
L In 2011, a change in methodology occurred to capture industrial run-off as water withdrawn.This run-off volume is included as water returned or water consumed, as applicable to each facility.
M In order to better align with the Global Reporting Initiative (GRI) standard for the 2011 report and going forward, Suncor has expanded the number of indicators for which it collects and reports data in the Waste management category.Volume of waste varies from year to year due to periodic equipment maintenance including:
• changing catalyst in reactors and waste water treatment tank
• lagoon cleanouts
• operation shutdowns
• location-specific recycling programs  
N Volume of waste varies from year to year due to periodic equipment maintenance including:
• changing catalyst in reactors and waste water treatment tanks
• lagoon cleanouts
• operation shutdowns
• location specific recycling programs
O In 2012, hazardous waste to deep well injection increased due to high throughput volume, resulting in more water use.
P In 2012, experimentation of sending downhole water to external wastewater treatment plant required injection of non-compatible water downhole.
Q Changes in water management strategy, to eliminate overflow to ponds as required for site approval, resulted in the creation of a waste stream that had not previously required active management.
R Refineries that blend ethanol into gasoline are Sarnia, Montreal, Commerce City and Edmonton.The Edmonton Refinery began blending ethanol into gasoline in April 2011.
S The volume is an annual average for Sarnia, Commerce City, Montreal and Edmonton refineries. Historically, data was calculated as the weighted average.
T 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
U 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.
V $1,956,194.45 was in settlement of Case No. 2011-049; $249,404.73 was in settlement of Case No. 2011-034; and $148,637.42 was in settlement of Case No. 2012-087.  $1,361,329.65 of this total was paid in supplemental environmental projects.
   

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                
Refined product sales thousand m3 refined product/day OG1 31.5 54.9 87.3* 83.1 85.6

Footnote W:
Refined product sales consist of refinery production and other product purchased for resale. Figures are as reported in Suncor's annual reports.
Data for 2009 and prior years is presented in accordance with previous GAAP standard.All values are consistent with Suncor's annual reports.    

Financials              

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

Net earnings $ millions   EC1 -22 407 819* 1,726 2,129
Cash flow from operations $ millions   EC1 220 921 1,538* 2,574 3,150
Tax and royalty credits earned $ millions       1.2 1.3 1.6 4.7
Investments                
Capital and exploration expenditures $ millions   EC1 207 380 667 633 646
Purchases              

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

Goods and services $ millions     529 1,914 1,900 1,790 1,715
Goods and services purchased in or from: $ millions   EC6          
     Canada       233 1,608 1,533 1,355 1,302
     Local     331 1,536 1,464 1,178 1,354

Footnote Z:
Local is defined as spend with businesses/suppliers based in Ontario, Quebec, Alberta and Colorado. 2009 to 2012 data includes all local spend from Suncor's Refining & Marketing operations.

Refining & Marketing economy 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.  
W Refined product sales consist of refinery production and other product purchased for resale. Figures are as reported in Suncor's annual reports.
Data for 2009 and prior years is presented in accordance with previous GAAP standard.All values are consistent with Suncor's annual reports.    
X For complete disclosure and additional information see our 2012 annual report (PDF, 139 pp., 776 KB).
Y Purchases in 2010 represent the first year over year comparison since the Petro-Canada and Suncor merger in 2009.
Z Local is defined as spend with businesses/suppliers based in Ontario, Quebec, Alberta and Colorado. 2009 to 2012 data includes all local spend from Suncor's Refining & Marketing operations.

Social

Refining & Marketing social footnotes
AA Our U.S. operations use the Occupational Health and Safety Administration (OSHA) definitions to classify their injuries, which differ slightly from Canadian standards. For the most part, OSHA is a more rigorous classification standard than current Canadian standards.
BB 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.
CC 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.
DD In 2012, we used $10.25 for minimum wage in Ontario and $9.75 in Alberta. In 2011 we used $9.40 in Alberta. In 2009 we used $9.50/hour for minimum wage that compares lowest fulltime base wage to Ontario.
Historical U.S.A. data compares lowest full-time base wage to Colorado and Wyoming minimum wage. For 2008 the minimum wage was $7.02/hour.
Historical Canada data compares Refining & Marketing's full-time base wage to Ontario's minimum wage. In 2008 we used $8.75/hour.
EE Total training and development dollars for combined Refining & Marketing Canada and U.S.A. 2009 data excludes Petro-Canada information due to differences in the systems that report this data.
FF 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.
GG Employee and Family Assistance Program (EFAP) for Refining & Marketing U.S.A. is offered through CIGNA. CIGNA has been the provider since Jan. 1, 2010. LifeWorks EFAP, offered through Ceridian, was the provider until December 2009.
HH Employee is defined as regular full-time, regular part-time, students, casuals or temporary. Leaves, other than Long Term Disability (LTD), such as maternity, paternity, personal leave, as well as short-term disabilities, are considered active and are included.
II Historical U.S.A. data long-term contractors include contractors at the refinery, based on full-time equivalent staff in the Denver office.
JJ Beginning in 2011, this number is reported on a Suncor-wide level and the breakdown is not available.