Take a look at Suncor's refining and marketing performance data

Take a look at Suncor's refining and marketing performance data

Take a look at Suncor's refining and marketing performance data

Take a look at Suncor's refining and marketing performance data

View the latest Report on Sustainability

Terra Nova Floating, Production Storage and Offloading (FPSO) vessel

Refining & Marketing

We operate facilities in the Refining & Marketing (R&M) business segment in Alberta, Ontario, Quebec and Colorado. R&M also includes emissions data from Suncor’s Canadian terminals and pipelines, which account for a small percentage of the total R&M numbers and are deemed to be negligible. Suncor Montreal Sulphur Plant data is also included from the purchase date in July, 2014. Data from these R&M facilities are consolidated here for reporting purposes.

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Environment

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

Indicator Unit Footnote GRI
Disclosures
2011 2012 2013 2014 2015
Production                
Net production million cubic metres (m3)
saleable yield / year
OG1 26.32 27.21 27.09  26.91 27.37

Footnote A:
On a business unit level, net production is reported where interplant transfers 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 yield including light sweet synthetic crude oil (SCO), diesel, light sour SCO, bitumen and co-products, minus the transfers between R&M facilities. Terminals, Pipelines and the Montreal Sulphur Plant do not contribute to R&M production (denominator for GHG intensity), only absolute GHG emissions (numerator for GHG intensity) due to the definition of the corporate wide production metric.

Air emissions                
Greenhouse gas (GHG) thousand tonnes carbon dioxide equivalent (CO2e)

G4-EN15

G4-EN16

5,323 5,420 5,406  5,467 5,438

Footnote B:
Greenhouse gas (GHG) emissions are calculated using a facility-specific methodology which utilizes various reference methodologies that have been accepted by the relevant jurisdictions within which each facility is required to report its GHG emissions. Methodology has been followed where a jurisdiction has a prescribed one and if none exists, then the most applicable and accurate methods available are used to quantify each emission source.

R&M emissions are inclusive of emissions from the pipeline from Oil Sands to the Edmonton Refinery as well as the pipelines from Firebag to Oil Sands and Fort Hills to Oil Sands. In addition, R&M emissions include emissions from the Burrard terminal station and the Montreal Sulphur Plant (purchased in 2014). These emission sources are broken out separately from other R&M sites in the 2015 GHG Performance section, classified as “Other”.

For the Edmonton refinery, GHG emissions and emission intensity values are consistent with Suncor’s Specified Gas Emitters Regulation (SGER) Bill 3 reported Total Annual Emission (TAE) values, with the exception that total indirect emissions have been included here. The production metric used for the SGER emissions intensity is different than what is used here. SGER production is a Refinery Activity Index based value and the production used for our Report on Sustainability is saleable yield. For our operations in Quebec and Ontario, the data is consistent with the guidelines for those provinces which are aligned with Western Climate Initiative. The only exception applies to provincial reports for our facilities in Ontario and Quebec which use the Intergovernmental Panel on Climate Change’s (IPCC’s) third assessment global warming potentials (GWPs). Our 2013, 2014 and 2015 Reports on Sustainability use IPCC’s fourth assessment GWPs. For our Commerce City refinery, the data is consistent with the guidelines for the EPA’s Mandatory Reporting Rule, with the exception of the emissions reported in Sub-part MM.

Scope 2 indirect emissions include those associated with the purchases of electricity, steam, heat, and cooling. Emissions are calculated based on actual supplier data where possible and published literature where supplier data is unavailable. Prior to 2014, emissions associated with the purchase of hydrogen had been included as an indirect Scope 2 source; however, it was brought to our attention that industry best practice is to include these emissions as an indirect Scope 3 source and therefore they have been removed from all reported data points and included in the indirect Scope 3 GHG category. 

Carbon dioxide sold by the facilities is reported under indirect Scope 3 to be consistent with Ontario and Quebec regulatory guidance. Hydrogen purchased from third parties is also included in this category. These values are reported under indirect Scope 3 emissions in this table and in our Suncor-wide performance data.

GHG emissions intensity tonnes CO2e / m3 production   G4-EN18 0.2 0.2 0.2  0.2 0.2
Indirect (Scope 3)
GHG emissions
thousand tonnes CO2e G4-EN17 1,360 1,473 1,523  1,369 1,462

Footnote C:
Indirect Scope 3 GHG emissions reported here include emissions related to purchased hydrogen and CO2 streams that are sold to third parties. In 2013 it was brought to our attention that industry best practice for disclosing emissions associated with the purchasing of hydrogen should be classified as a Scope 3 indirect source as they do not fall under the Scope 2 indirect emission categories of purchased electricity, purchased steam, purchased heating or purchased cooling. Therefore purchased hydrogen emissions are reported as a Scope 3 source and have been removed from the Scope 2 indirect emissions category.

Sulphur dioxide (SO2) thousand tonnes G4-EN21 8.75 5.77 6.13  5.86 5.36

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.

SO2 emissions intensity kilograms (kg) / m3 production   G4-EN21 0.33 0.21 0.23  0.22 0.20
Nitrogen oxides (NOx) thousand tonnes   G4-EN21 4.41 4.53 4.55  4.00 3.83
NOx emissions intensity kg / m3 production   G4-EN21 0.17 0.17 0.17  0.15 0.14
Volatile organic compounds (VOCs) thousand tonnes   G4-EN21 4.36 4.25 4.68  4.38 4.37
  • Benzene
tonnes   G4-EN21 48.14 46.37 46.48  40.09 39.62
  • Toluene
tonnes   G4-EN21 125.93 123.86 115.85  116.91 104.31
  • Ethylbenzene
tonnes   G4-EN21 11.19 10.51 10.16  9.63 10.03
  • Xylene
tonnes   G4-EN21 64.57 62.27 58.91  59.42 57.30
VOC emissions intensity kg / m3 production   G4-EN21 0.17 0.16 0.17  0.16 0.16
National Pollutant Release Inventory (NPRI) on-site releases thousand tonnes G4-EN21 23.41 20.01 20.84  20.32 19.79

Footnote E:
Data includes terminal emissions. More information about the Toxic Release Inventory (TRI) can be found on the Environmental Protection Agency website. Beginning in 2015, TRI releases are no longer reported in our Report on Sustainability.

Flared gas million m3   OG6 109 71.9 100.7  101.87 110.12
Flared gas intensity m3/m3 production   OG6 4.14 2.64 3.72  3.79 4.02
Energy consumption                
Total energy use million gigajoules (GJ)

G4-EN3

G4-EN4

84.24 83.23 84.37  86.18 88.07

Footnote F:
Total energy is the sum of direct and indirect energy. Data includes terminal and pipeline emissions.

  • Direct energy use
million GJ

G4-EN3

72.9 71.5 72.5  74.03 75.99

Footnote G:
Direct energy is primary energy consumed on-site by Suncor-operated facilities; consumption includes refinery fuel gas, purchased natural gas and other internally produced fuels.

Indirect energy includes imported electricity, steam, heating, and cooling duty.

  • Indirect energy use
million GJ G4-EN4 11.34 11.71 11.83  12.14 12.08

Footnote G:
Direct energy is primary energy consumed on-site by Suncor-operated facilities; consumption includes refinery fuel gas, purchased natural gas and other internally produced fuels.

Indirect energy includes imported electricity, steam, heating, and cooling duty.

Energy intensity GJ / m3 production   G4-EN5 3.2 3.1 3.1  3.2 3.2
Electricity imports million gigajoules   G4-EN3 5.96 6.08 6.25  5.97 5.07
Electricity import intensity GJ / m3 production   G4-EN3 0.23 0.22 0.23  0.22  0.23
Steam imports million gigajoules   G4-EN3 5.38 5.63 5.59  6.17  5.76
Steam import intensity GJ / m3 production   G4-EN3 0.2 0.21 0.21  0.23  0.21
Energy saved through conservation and efficiency improvements thousand GJ   G4-EN6 874.53 1,387.18 515.45  200.78  640.38
Water use                
Total water withdrawal million m3   G4-EN8 79.95 82.33 77.83  83.05 

91.17

  • Surface water withdrawal
million m3 G4-EN8 68.63 70 64.72  71.33  79.27

Footnote H:
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.
• Mississauga: Estimated water withdrawal from Lake Ontario

  • Groundwater withdrawal
million m3   G4-EN8 0.5 0.6 0.6  0.3 0.3
  • Municipality, city or district water withdrawal
million m3 G4-EN8 2.91 3.07 2.95  2.44  3.18

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

  • Treated wastewater from external organizations
million m3 G4-EN8 1.79 2.7 1.54  1.29 1.51

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

  • Industrial run-off water withdrawal
million m3 G4-EN8 6.12 5.95 8.02  7.67 6.89

Footnote K:
Industrial run-off includes water withdrawn. This run-off volume is included as water returned or water consumed, as applicable to each facility. Water return destination for Refining & Marketing operations varies by facility (North Saskatchewan River, St. Lawrence River, Lake Ontario, St. Clair River and Sand Creek).

Total water withdrawal intensity m/ m3 production   G4-EN8 3.04 3.03 2.87  3.09 3.33
Water returned million m3   G4-EN22 68.2 65.46 61.39  72.21 73.88
Water consumption million m3   11.75 16.87 16.44  10.92 17.28

Footnote K:
Industrial run-off includes water withdrawn. This run-off volume is included as water returned or water consumed, as applicable to each facility. Water return destination for Refining & Marketing operations varies by facility (North Saskatchewan River, St. Lawrence River, Lake Ontario, St. Clair River and Sand Creek).

Water consumption intensity m/ m3 production   0.45 0.62 0.61  0.41 0.63

Footnote K:
Industrial run-off includes water withdrawn. This run-off volume is included as water returned or water consumed, as applicable to each facility. Water return destination for Refining & Marketing operations varies by facility (North Saskatchewan River, St. Lawrence River, Lake Ontario, St. Clair River and Sand Creek).

Water discharge quality                

Oil and grease

tonnes   G4-EN22 18.53 24.52 16.81  14.84 16.76

Total suspended sediment

tonnes   G4-EN22 153.78 360.24 116.47  118.60 117.97

Phenol

tonnes   G4-EN22 0.09 0.08 0.25  0.34 0.19

Ammonia

tonnes   G4-EN22 9.44 14.47 6.56  7.84 6.66
Waste management              

Footnote L:
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

Prior to 2014, waste that was reused, recycled and recovered was not included in the totals for hazardous and non-hazardous waste generated and was reported as an aggregated total. Beginning in 2014, in order to provide a more detailed breakdown of the waste streams created due to our operations, we have included this category of waste in both hazardous and non-hazardous total waste generated.

Total hazardous waste generated thousand tonnes G4-EN23 19.9 1,317.07 1,239.30 1,283.91 1,062.27

Footnote L:
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

Prior to 2014, waste that was reused, recycled and recovered was not included in the totals for hazardous and non-hazardous waste generated and was reported as an aggregated total. Beginning in 2014, in order to provide a more detailed breakdown of the waste streams created due to our operations, we have included this category of waste in both hazardous and non-hazardous total waste generated.

  • Hazardous waste incinerated
tonnes   G4-EN23 2,235.00 1,977.62 1,245.08  2,940.08 2,244.37
  • Hazardous waste deep well injected
tonnes G4-EN23 1,082.10 1,302,958.00 1,231,221.23 1,232,852.00  961,873.43

Footnote M:
Hazardous waste to deep well injection is dependent on throughput volume, which influences water use.

  • Hazardous waste landfilled
tonnes G4-EN23 15,296.10 7,205.94 1,907.53  734.19  3,265.96

Footnote L:
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

Prior to 2014, waste that was reused, recycled and recovered was not included in the totals for hazardous and non-hazardous waste generated and was reported as an aggregated total. Beginning in 2014, in order to provide a more detailed breakdown of the waste streams created due to our operations, we have included this category of waste in both hazardous and non-hazardous total waste generated.

  • Hazardous waste otherwise disposed
tonnes G4-EN23 1,303.20 4,932.98 4,925.45  5,248.60 3,920.04

Footnote L:
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

Prior to 2014, waste that was reused, recycled and recovered was not included in the totals for hazardous and non-hazardous waste generated and was reported as an aggregated total. Beginning in 2014, in order to provide a more detailed breakdown of the waste streams created due to our operations, we have included this category of waste in both hazardous and non-hazardous total waste generated.

  • Hazardous waste recycled, recovered or reused
tonnes G4-EN23 -- -- -- 42,134.50  90,964.36

Footnote L:
Beginning in 2011, in order to better align with the Global Reporting Initiative guidelines, Suncor 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

Prior to 2014, waste that was reused, recycled and recovered was not included in the totals for hazardous and non-hazardous waste generated and was reported as an aggregated total. Beginning in 2014, in order to provide a more detailed breakdown of the waste streams created due to our operations, we have included this category of waste in both hazardous and non-hazardous total waste generated.

Total non-hazardous waste generated thousand tonnes G4-EN23 60 84.7 44.7  48.70 46.13

Footnote L:
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

Prior to 2014, waste that was reused, recycled and recovered was not included in the totals for hazardous and non-hazardous waste generated and was reported as an aggregated total. Beginning in 2014, in order to provide a more detailed breakdown of the waste streams created due to our operations, we have included this category of waste in both hazardous and non-hazardous total waste generated.

  • Non-hazardous waste incinerated
tonnes   G4-EN23 223 145.05 158.1 174.00  660.00
  • Non-hazardous waste deep-well injected
tonnes G4-EN23 0 460.98 2,496.24  1,210.00  801.00

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

  • Non-hazardous waste landfilled
tonnes   G4-EN23 41,968.70 39,475.28 16,672.11  22,785.54 26,239.54
  • Non-hazardous waste otherwise disposed
tonnes G4-EN23 17,827.60 18,173.55 25,407.47  3,241.22 3,587

Footnote O:
Changes in water management strategy were made in 2012 that resulted in the creation of a waste stream that had not previously required active management. These changes were in place for all of the 2013 reporting year and thus contributed to a higher value for this metric in comparison to the previous year.

Beginning in 2014, waste water is no longer reported in waste disposal but is captured under the water return category of this report.

  • Non-hazardous waste recycled, recovered or reused
tonnes G4-EN23 -- -- -- 21,287.77 14,841.59

Footnote L:
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

Prior to 2014, waste that was reused, recycled and recovered was not included in the totals for hazardous and non-hazardous waste generated and was reported as an aggregated total. Beginning in 2014, in order to provide a more detailed breakdown of the waste streams created due to our operations, we have included this category of waste in both hazardous and non-hazardous total waste generated.

Waste reused, recycled, or recovered (off-site) thousand tonnes G4-EN23 86 69.16 55.23  -- --

Footnote L:
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

Prior to 2014, waste that was reused, recycled and recovered was not included in the totals for hazardous and non-hazardous waste generated and was reported as an aggregated total. Beginning in 2014, in order to provide a more detailed breakdown of the waste streams created due to our operations, we have included this category of waste in both hazardous and non-hazardous total waste generated.

Waste reused, recycled, or recovered (on-site) thousand tonnes G4-EN23 40.4 21.48 9.49  -- --

Footnote L:
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

Prior to 2014, waste that was reused, recycled and recovered was not included in the totals for hazardous and non-hazardous waste generated and was reported as an aggregated total. Beginning in 2014, in order to provide a more detailed breakdown of the waste streams created due to our operations, we have included this category of waste in both hazardous and non-hazardous total waste generated.

Products and services                
Ethanol blended into gasoline thousand m3 G4-EN27 927.9 979 828  1,000 1,027

Footnote P:
Refineries that blend ethanol into gasoline are Sarnia, Montreal, Commerce City and Edmonton.

Sulphur content of gasoline parts per million (ppm) OG8 24.9 25.8 25.3  18.7 15.7

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

Compliance                
Regulatory contraventions # G4-EN29 32 18 23  13 19

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, licence, standard, approval, directive and/or permit applicable to Suncor’s activities) and that triggers formal regulatory reporting.

Regulatory fines $ thousands G4-EN29 245 2,354 130  2,257 894

Footnote S: Data includes regulatory fines paid during the stated year:
The total fines paid in 2015 by our R&M business was $894,349. The breakdown of our downstream fines are as follows:

Commerce City refinery (fines paid for Commerce City are in $US):
In September 2015, our Commerce City refinery paid a penalty payment of $222,000 as a result of 2013-2014 air inspections. The total fine was broken down as follows:

• $214,050 Administrative penalty to Colorado Department of Public Health and Environment (CDPHE)
     • $42,810 in Cash Administrative Penalty to CDPHE
     • $171,240 went to Supplemental Environmental Projects. 

• $7,950 in stipulated penalties related to Consent Decree violations
     • $3,975 to Environmental Protection Agency (United States)
     • $3,975 to CDPHE

On December 15. 2015 we also paid a $500,000 fine to the CDPHE in connection with the settlement of penalties related to the 2011 release of material to Sand Creek. Additionally, on or about December 30, 2015 a $5,500 fine was paid to the Federal Railroad Administration as settlement for an alleged violation of the Hazardous Materials Regulations in connection with rail car use at the Commerce City refinery.

Montreal refinery:
A fine was paid In March, 2015 for the following:

• Spill in the St-.Lawrence River - Statement of Offence paid in March 2015
• In 2014, Suncor received a 250K plus costs (total 272K) charge in connection with the September 28, 2010 spill in the St-Lawrence river. The total volume of diesel spilled was 950 barrels of which 880 barrels were contained and recovered at the site. Of the 35 barrels that reached the river, 30 barrels were contained and recovered at the site. Of the 35 barrels that reached the river, 30 barrels were contained in booms and recovered and the majority of the remaining five barrels that travelled downstream were recovered using absorbent materials and by cleaning up the north riverbank.‎ Following negotiations with the Crown Prosecutor, a joint settlement was filed and approved by the Quebec courts on March 25, 2015 in which Suncor was held liable for offences to the Québec Environment Act and was fined  $161,470.72 ( 140K plus costs).  Payment of same was made accordingly in March 2015.

Sarnia:
On April 23, 2015 our Sarnia refinery paid a $5,378.25 fine to the Government of Ontario for an environmental penalty related to an incident that occurred on Dec 4, 2014, wherein our waste water effluent exceeded MISA limits for dissolved organic carbon and ammonia.

2014: On February 27, 2014, a Consent Decree entered into by Suncor Energy (U.S.A.) Inc. (“SEUSA”), was approved by the U.S. District Court for the District of Colorado. The Consent Decree related to alleged natural resource damages (NRD), including to groundwater, caused by a release of hydrocarbons from SEUSA’s Commerce City Refinery into and around Sand Creek. SEUSA paid $1,887,000 ($US) to compensate for these alleged damages in exchange for a release from liability. In 2014, SEUSA also paid certain penalties to settle alleged violations resulting from an annual air audit of the Commerce City Refinery by the Colorado Department of Health & Environment (CDPHE), an Environmental Protection Agency (EPA) inspection, and under existing Clean Air Act Consent Decrees.

2013: In 2013, SEUSA paid certain penalties to settle alleged violations resulting from an annual air audit of the Commerce City Refinery by the Colorado Department of Health & Environment (CDPHE). Our Sarnia refinery was also ordered to pay an environmental penalty of $10,950 for a test failure in process effluent water. The test from the combined stream that enters the river passed, but the test of effluent water did not. In response to this, the refinery has established performance monitoring metrics for various waste water treatment parameters to allow for early indication of potential issues in the waste water treatment facility.

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

Reportable spills   G4-EN24 91 99 103 107 91
Total volume of reportable spills m3   G4-EN24 1,217 71.78 2,082.02  124 1,208.54
Air quality exceedances   G4-EN29 74 81 43 45  65
Water effluent exceedances   G4-EN29 0 0 0 2 5
Leaks from underground storage systems   G4-EN24 1 0  0 0
Environment, Health & Safety (EH&S) management                
EH&S professionals on staff G4-EN31 81 85 92 94 --

Footnote T:
Professionals dedicated to environment, health or safety matters. Professional Services Agreements (PSAs) and non-positioned contractors are not included in this total. Beginning in 2015, this indicator is reported on a Suncor-wide basis.

Environmental capital expenditures $ millions   G4-EN31 56.1 59.24 68.45 32.7 32.17
Refining & Marketing environment footnotes
A

On a business unit level, net production is reported where interplant transfers 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 yield including light sweet synthetic crude oil (SCO), diesel, light sour SCO, bitumen and co-products, minus the transfers between R&M facilities. Terminals, Pipelines and the Montreal Sulphur Plant do not contribute to R&M production (denominator for GHG intensity), only absolute GHG emissions (numerator for GHG intensity) due to the definition of the corporate wide production metric.

B

Greenhouse gas (GHG) emissions are calculated using a facility-specific methodology which utilizes various reference methodologies that have been accepted by the relevant jurisdictions within which each facility is required to report its GHG emissions. Methodology has been followed where a jurisdiction has a prescribed one and if none exists, then the most applicable and accurate methods available are used to quantify each emission source.

R&M emissions are inclusive of emissions from the pipeline from Oil Sands to the Edmonton Refinery as well as the pipelines from Firebag to Oil Sands and Fort Hills to Oil Sands. In addition, R&M emissions include emissions from the Burrard terminal station and the Montreal Sulphur Plant (purchased in 2014). These emission sources are broken out separately from other R&M sites in the 2015 GHG Performance section, classified as “Other”.

For the Edmonton refinery, GHG emissions and emission intensity values are consistent with Suncor’s Specified Gas Emitters Regulation (SGER) Bill 3 reported Total Annual Emission (TAE) values, with the exception that total indirect emissions have been included here. The production metric used for the SGER emissions intensity is different than what is used here. SGER production is a Refinery Activity Index based value and the production used for our Report on Sustainability is saleable yield. For our operations in Quebec and Ontario, the data is consistent with the guidelines for those provinces which are aligned with Western Climate Initiative. The only exception applies to provincial reports for our facilities in Ontario and Quebec which use the Intergovernmental Panel on Climate Change’s (IPCC’s) third assessment global warming potentials (GWPs). Our 2013, 2014 and 2015 Reports on Sustainability use IPCC’s fourth assessment GWPs. For our Commerce City refinery, the data is consistent with the guidelines for the EPA’s Mandatory Reporting Rule, with the exception of the emissions reported in Sub-part MM.

Scope 2 indirect emissions include those associated with the purchases of electricity, steam, heat, and cooling. Emissions are calculated based on actual supplier data where possible and published literature where supplier data is unavailable. Prior to 2014, emissions associated with the purchase of hydrogen had been included as an indirect Scope 2 source; however, it was brought to our attention that industry best practice is to include these emissions as an indirect Scope 3 source and therefore they have been removed from all reported data points and included in the indirect Scope 3 GHG category. 

Carbon dioxide sold by the facilities is reported under indirect Scope 3 to be consistent with Ontario and Quebec regulatory guidance. Hydrogen purchased from third parties is also included in this category. These values are reported under indirect Scope 3 emissions in this table and in our Suncor-wide performance data.

C

Indirect Scope 3 GHG emissions reported here include emissions related to purchased hydrogen and CO2 streams that are sold to third parties. In 2013 it was brought to our attention that industry best practice for disclosing emissions associated with the purchasing of hydrogen should be classified as a Scope 3 indirect source as they do not fall under the Scope 2 indirect emission categories of purchased electricity, purchased steam, purchased heating or purchased cooling. Therefore purchased hydrogen emissions are reported as a Scope 3 source and have been removed from the Scope 2 indirect emissions category.

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.

E

Data includes terminal emissions. More information about the Toxic Release Inventory (TRI) can be found on the Environmental Protection Agency website. Beginning in 2015, TRI releases are no longer reported in our Report on Sustainability.

F

Total energy is the sum of direct and indirect energy. Data includes terminal and pipeline emissions.

G

Direct energy is primary energy consumed on-site by Suncor-operated facilities; consumption includes refinery fuel gas, purchased natural gas and other internally produced fuels.

Indirect energy includes imported electricity, steam, heating, and cooling duty.

H

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.
  • Mississauga: Estimated water withdrawal from Lake Ontario
I

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

J

Edmonton: Wastewater from Goldbar municipal treatment plant.

K

Industrial run-off includes water withdrawn. This run-off volume is included as water returned or water consumed, as applicable to each facility. Water return destination for Refining & Marketing operations varies by facility (North Saskatchewan River, St. Lawrence River, Lake Ontario, St. Clair River and Sand Creek).

L

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

Prior to 2014, waste that was reused, recycled and recovered was not included in the totals for hazardous and non-hazardous waste generated and was reported as an aggregated total. Beginning in 2014, in order to provide a more detailed breakdown of the waste streams created due to our operations, we have included this category of waste in both hazardous and non-hazardous total waste generated.

M

Hazardous waste to deep well injection is dependent on throughput volume, which influences water use.

N

Beginning in 2012, experimentation of sending downhole water to external wastewater treatment plant required injection of non-compatible water downhole.

O

Changes in water management strategy were made in 2012 that resulted in the creation of a waste stream that had not previously required active management. These changes were in place for all of the 2013 reporting year and thus contributed to a higher value for this metric in comparison to the previous year.

Beginning in 2014, waste water is no longer reported in waste disposal but is captured under the water return category of this report.

P

Refineries that blend ethanol into gasoline are Sarnia, Montreal, Commerce City and Edmonton.

Q

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

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, licence, standard, approval, directive and/or permit applicable to Suncor’s activities) and that triggers formal regulatory reporting.

S

Data includes regulatory fines paid during the stated year:
The total fines paid in 2015 by our R&M business was $894,349. The breakdown of our downstream fines are as follows:

Commerce City refinery (fines paid for Commerce City are in $US):
In September 2015, our Commerce City refinery paid a penalty payment of $222,000 as a result of 2013-2014 air inspections. The total fine was broken down as follows:

  • $214,050 Administrative penalty to Colorado Department of Public Health and Environment (CDPHE)
    • $42,810 in Cash Administrative Penalty to CDPHE
    • $171,240 went to Supplemental Environmental Projects. 
  • $7,950 in stipulated penalties related to Consent Decree violations
    • $3,975 to Environmental Protection Agency (United States)
    • $3,975 to CDPHE

On December 15. 2015 we also paid a $500,000 fine to the CDPHE in connection with the settlement of penalties related to the 2011 release of material to Sand Creek. Additionally, on or about December 30, 2015 a $5,500 fine was paid to the Federal Railroad Administration as settlement for an alleged violation of the Hazardous Materials Regulations in connection with rail car use at the Commerce City refinery.

Montreal refinery:
A fine was paid In March, 2015 for the following:

  • Spill in the St-.Lawrence River - Statement of Offence paid in March 2015
  • In 2014, Suncor received a 250K plus costs (total 272K) charge in connection with the September 28, 2010 spill in the St-Lawrence river. The total volume of diesel spilled was 950 barrels of which 880 barrels were contained and recovered at the site. Of the 35 barrels that reached the river, 30 barrels were contained and recovered at the site. Of the 35 barrels that reached the river, 30 barrels were contained in booms and recovered and the majority of the remaining five barrels that travelled downstream were recovered using absorbent materials and by cleaning up the north riverbank.‎ Following negotiations with the Crown Prosecutor, a joint settlement was filed and approved by the Quebec courts on March 25, 2015 in which Suncor was held liable for offences to the Québec Environment Act and was fined  $161,470.72 ( 140K plus costs).  Payment of same was made accordingly in March 2015.

Sarnia:
On April 23, 2015 our Sarnia refinery paid a $5,378.25 fine to the Government of Ontario for an environmental penalty related to an incident that occurred on Dec 4, 2014, wherein our waste water effluent exceeded MISA limits for dissolved organic carbon and ammonia.

2014: On February 27, 2014, a Consent Decree entered into by Suncor Energy (U.S.A.) Inc. (“SEUSA”), was approved by the U.S. District Court for the District of Colorado. The Consent Decree related to alleged natural resource damages (NRD), including to groundwater, caused by a release of hydrocarbons from SEUSA’s Commerce City Refinery into and around Sand Creek. SEUSA paid $1,887,000 ($US) to compensate for these alleged damages in exchange for a release from liability. In 2014, SEUSA also paid certain penalties to settle alleged violations resulting from an annual air audit of the Commerce City Refinery by the Colorado Department of Health & Environment (CDPHE), an Environmental Protection Agency (EPA) inspection, and under existing Clean Air Act Consent Decrees.

2013: In 2013, SEUSA paid certain penalties to settle alleged violations resulting from an annual air audit of the Commerce City Refinery by the Colorado Department of Health & Environment (CDPHE). Our Sarnia refinery was also ordered to pay an environmental penalty of $10,950 for a test failure in process effluent water. The test from the combined stream that enters the river passed, but the test of effluent water did not. In response to this, the refinery has established performance monitoring metrics for various waste water treatment parameters to allow for early indication of potential issues in the waste water treatment facility.

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

T

Professionals dedicated to environment, health or safety matters. Professional Services Agreements (PSAs) and non-positioned contractors are not included in this total. Beginning in 2015, this indicator is reported on a Suncor-wide basis.

Economic1

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

Indicator Unit Footnote GRI
Disclosures
2011 2012 2013 2014 2015
Tax and royalty credits earned $ millions   G4-EC4 1.6 4.7 1.9 3.3  2.3
Investments                
Capital and exploration expenditures $ millions   G4-EC1 633 644 890 1,021  821
Purchases                
Goods and services $ millions   1,790 1,715 2,309 2,815 2,638
Goods and services purchased in or from:            
  • Canada
 $ millions   1,355 1,302 1,845  2,356 2,103
  • Local businesses and suppliers
 $ millions G4-EC9  1,178 1,354 1,821  2,290 2,071

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

Refining & Marketing economy footnotes
1 For complete disclosure of financial information, see our 2015 Annual Report (PDF, 136 pp. 2.80MB)
U Local is defined as spend with businesses/suppliers based in Ontario, Quebec, Alberta and Colorado. Data includes all local spend from Suncor's Refining & Marketing operations.

Social

Refining & Marketing social footnotes
V 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. Beginning in 2014, R&M health and safety data reported here includes our St. Clair ethanol plant.
W 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, divided by the number of exposure hours.
X 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, divided by the number of exposure hours.
Y Fees for professional development courses taken by Suncor employees.
Z Compares full-time base wage to the province of Alberta’s minimum wage ($11.20/hour in 2015). Beginning in 2014, Alberta’s minimum wage was used across our operations for this metric for comparison purposes due to the minimal variances of minimum wage across Canada.
AA Beginning in 2014, this indicator is reported Suncor-wide.
BB Any externally-hired regular full-time or regular part-time employee whose permanent start date falls within the reporting period.
CC

Employee is defined as regular full-time, regular part-time, students, casuals or temporary employees. Leaves, other than long-term disability, such as maternity, paternity, personal leave, as well as short-term disabilities, are considered active and are included.

Historical U.S.A. data long-term contractors include contractors at the refinery, based on full-time equivalent staff in the Denver office.

DD

Certain operating regions prohibit collecting information on gender, therefore data presented here may not be reflective of our entire workforce due to data availability.

Workforce diversity is calculated based on information provided voluntarily by employees. Indicators referring to ethnicity and disability reflect only those employees who consent for release of this information have been included.

EE Beginning in 2014, salary comparison data between women and men is reported on a Suncor-wide basis as position levels are corporately administered and do not differ based on operating areas.