Take a look at Suncor's North America Onshore performance data

Take a look at Suncor's North America Onshore performance data

Take a look at Suncor's North America Onshore performance data

Take a look at Suncor's North America Onshore performance data

View the latest Report on Sustainability

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

North America Onshore

North America Onshore performance data reports on our operated North America Onshore assets, primarily in Western Canada. Social data is reported with East Coast Canada.

On Sept. 26, 2013, Suncor completed the divestiture of the majority of its conventional natural gas business in Western Canada. Environmental performance data for 2013 and 2014 reflects this divestiture.

A number of Suncor's natural gas assets were also divested in 2011.

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Environment1

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                
Processed volume million barrels of oil equivalent/year OG1 44.8 47 33.2 1.32 1.14

Footnote A:
Processed volume is the total amount of hydrocarbons processed at Suncor-operated facilities. This includes production owned by other companies and processed at Suncor-operated facilities. Processed volume is used to calculate intensities.

Barrels of oil equivalent and cubic metres of oil equivalent may be misleading indicators of value. See “Advisories”.

Processed volume million cubic metres (m3) of oil equivalent/year OG1 7.1 7.5 5.27 0.21 0.18

Footnote A:
Processed volume is the total amount of hydrocarbons processed at Suncor-operated facilities. This includes production owned by other companies and processed at Suncor-operated facilities. Processed volume is used to calculate intensities.

Barrels of oil equivalent and cubic metres of oil equivalent may be misleading indicators of value. See “Advisories”.

Air emissions                
Greenhouse gas (GHG) thousand tonnes CO2e G4-EN15
G4-EN16
1,035 995 630 42.46 20.13

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 exist then the most applicable and accurate methods available are used to quantify each emission source.

GHG emissions intensity tonnes CO2e /m3 production   G4-EN18 0.15 0.13 0.12 0.20 0.11
Sulphur dioxide (SO2) thousand tonnes G4-EN21 3.3 3.6 2.4 0 0

Footnote C:
Total SO2 emissions from Suncor-operated facilities. This total includes emissions from operated facilities required to report under regulatory reporting programs as well as those facilities not required to report under regulatory programs. 2013 emissions for divested properties were reported from Jan. 1 to Sep 26, 2013.

SO2 emissions intensity kilograms (kg) / m3 production   G4-EN21 0.47 0.48 0.46 0 0
Nitrogen oxides (NOx) thousand tonnes G4-EN21 7.6 6.9 5.2 0.39 0.21

Footnote D:
Total NOx emissions from Suncor-operated facilities. This total includes emissions from operated facilities required to report under regulatory reporting programs as well as those facilities not required to report under regulatory programs. 2013 emissions for divested properties were reported from Jan. 1 to Sep 26, 2013.

NOx emissions intensity kg/m3 production   G4-EN21 1.07 0.93 0.99 1.81 1.14
Volatile organic compounds (VOCs) thousand tonnes G4-EN21 0.49 0.45 0.34 0.01 0.01

Footnote E:
Total VOCs emissions from Suncor-operated facilities. This total includes emissions from operated facilities required to report under regulatory reporting programs as well as those facilities not required to report under regulatory programs.

  • Benzene
tonnes

 

G4-EN21 10.6 12.6 8.5 1.59 0.7
VOC emissions intensity kg/m3 production   G4-EN21 0.07 0.06 0.06 0.05 0.03
National Pollutant Release Inventory (NPRI) on-site releases thousand tonnes G4-EN21 14 13 0.55 0.20 0.20

Footnote F:
There was a decrease in NPRI releases in 2013 compared to 2012 as Suncor is not required to report facilities not operated as of Dec. 31 of the reporting year for NPRI. 

Total gas flaring million m3   OG6 8.4 10.2 4.9 0.49 0.18
Solution gas flaring million m3 OG6 0.3 1 -- --  --

Footnote G:
As a result of divestment that occurred in 2013, data for solution gas flaring and other flaring sources was unobtainable.

Other flaring sources million m3 OG6 8.02 9.23 -- -- --

Footnote G:
As a result of divestment that occurred in 2013, data for solution gas flaring and other flaring sources was unobtainable.

Flared gas intensity m3/m3 production   OG6 1.2 1.5 0.9 2.29  0.99
Energy consumption                
Total energy use million gigajoules (GJ) G4-EN3
G4-EN4
12.2 11.8 7.59 0.50 0.30

Footnote H:
Total energy is the sum of direct and indirect energy.

  • Direct energy use
million GJ G4-EN3 11.8 11.5 7.31 0.50 0.29

Footnote I:
Direct energy is primary 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 GJ G4-EN4 0.4 0.3 0.28 0

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

Energy intensity GJ / m3 production   G4-EN5 1.71 1.58 1.44 2.35 1.63
Energy saved through conservation and efficiency improvements thousand GJ   G4-EN6 395 36 26 0 0
Water use                
Total water withdrawal million m3   G4-EN8 0.55 0.54 0.66 0.06 0
Water withdrawal intensity m3/m3 production   G4-EN8 0.08 0.07 0.13 0.26 0
Water returned million m3   G4-EN22 0 0 0 0 0
Water consumption million m3     0.55 0.54 0.66 0.06 0
Water consumption intensity m3/m3 production     0.08 0.07 0.13 0.26  0
Produced water million m3 OG5 2.12 1.77 1.03 0.01 0.01

Footnote J:
Produced water is all formation and other water brought to the surface during the normal course of our natural gas production process.

Waste management                

Total hazardous waste generated

thousand tonnes G4-EN22 5.2 4 3.5 0.06 0.13

Footnote K:
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 separately as an aggregated total. Beginning in 2014, in order to provide more detail of the waste streams created due to our operations, we have included this category of waste in total hazardous waste generated.

In 2011, North America Onshore compiled all waste data from our major receivers.

  • Hazardous waste incinerated
tonnes   G4-EN22 17.1 19.5 17.4 2.65 0
  • Hazardous waste deep well injected
tonnes G4-EN22 3,617.8 85.6 0 0

Footnote L:
This is variable year-to-year, based on operations conducted.

  • Hazardous waste landfilled
tonnes   G4-EN22 75 91.5 2,313.5 5.35 1.38
  • Hazardous waste otherwise disposed
tonnes   G4-EN22 1,492.0 3,764.7 1,182.5 51.0  1.24
  • Hazardous waste recycled, recovered or reused
tonnes G4-EN23 -- -- -- 9.67  10.77

Footnote K:
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 separately as an aggregated total. Beginning in 2014, in order to provide more detail of the waste streams created due to our operations, we have included this category of waste in total hazardous waste generated.

In 2011, North America Onshore compiled all waste data from our major receivers.

Total non-hazardous waste generated

thousand tonnes G4-EN22 80.3 178.3 49.7 2.45 0.31

Footnote M:
An increased volume of non-hazardous waste generated in 2012 is primarily due to remediation and reclamation activities, including biopile removal.

  • Non-hazardous waste incinerated
tonnes   G4-EN22 2.7 0 0 0 0
  • Non-hazardous waste deep well injected
tonnes   G4-EN22 922.3 549.1 512.9 0
  • Non-hazardous waste landfilled
tonnes   G4-EN22 57,008.60 148,980.30 26,105.80 2,322.83 88.25
  • Non-hazardous waste otherwise disposed
tonnes   G4-EN22 22,351.70 28,800.00 23,041.90 129.8 0
  • Non-hazardous waste recycled, recovered or reused
tonnes G4-EN22 -- -- -- -- 225

Footnote K:
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 separately as an aggregated total. Beginning in 2014, in order to provide more detail of the waste streams created due to our operations, we have included this category of waste in total hazardous waste generated.

In 2011, North America Onshore compiled all waste data from our major receivers.

Drilling waste disposed or treated tonnes OG7 -- 465 9,832.30 1,974.16 55

Footnote N:
Inclusive of drilling mud waste from drilling operations. This value has not been captured in the hazardous waste generated and non-hazardous waste generated values. Value increased in 2013 reflective of drilling that halted in 2012 due to the Altares incident in B.C.

Waste reused, recycled or recovered (off-site) tonnes G4-EN23 133.1 164.8 210.8 -- --

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

Land disturbance and reclamation                
Total number of producing wells   #   4,840 4,902 67 30 28

Footnote O:
Both public and regulatory agency databases were mined and compared with Suncor wells with associated yearly production volumes. The number of producing wells decreased significantly in 2013 due to a large divestment of assets in late 2013.

Suncor-operated producing wells   #   4,716 4,797 63 23 25

Footnote P:
The number of Suncor producing wells decreased significantly in 2013 due to the large divestment of assets in late 2013 and is reflective of ownership at Dec. 31, 2014.

Shut-in or suspended production wells   #   1,143 1,339 27 15 16

Footnote Q:
A shut-in well is taken out of production by shutting off flow at the wellhead, often with the expectation of resuming production in the future. A suspended well is a shut-in well on which additional subsurface isolation procedures have been performed, and which is usually taken out of production due to poor economics. If a suspended well is not brought back into production, it is taken out of service as per regulatory requirements. The inactive and suspended well lists from the Western Canadian regulatory agencies (Alberta Energy Regulator, Government of Saskatchewan Energy and Resources, and British Columbia Oil and Gas Commission) were utilized in determining this total.

The number of shut-in wells decreased significantly in 2013 due to the large divestment of assets in 2013.

Wells undergoing reclamation   # G4-EN13 285 270 0 11 11

Footnote R:
For the purpose of the Report on Sustainability, the number of wells undergoing reclamation include abandoned sites in the care and custody of North America Offshore Surface, Land, Logistics and Construction Liability Management group that are categorized (i.e., site status) as Phase I, Phase II, Remediation and Reclamation. Sites categorized with the status Pre-Screening were not included. Further explanation of each category is detailed in Suncor’s Draft Remediation - Reclamation Framework document. These are sites we are actively working on in some form or another, with the end goal being closure/obtaining closure through a reclamation certificate or alternative certification. See “Advisories”

Reclamation certificates received   #   G4-EN13 0 2 0 0 0
Compliance              

Footnote S:
The downward trend in compliance data in 2013 and 2014 is reflective of maturing our operational discipline and the reductions of our operations in this business segment, due to divestment activity.

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.

Regulatory contraventions   # G4-EN29 26 32 32 8 0

Footnote S:
The downward trend in compliance data in 2013 and 2014 is reflective of maturing our operational discipline and the reductions of our operations in this business segment, due to divestment activity.

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.

Regulatory fines $ G4-EN29 2,120 12,080 0 0 0

Footnote T:
Regulatory fines associated with late production accounting filings.

Reportable spills   # G4-EN24 16 15 13 2 0

Footnote U:
Reportable spills are defined in accordance with federal and provincial regulations.

Spills to watercourses   #   G4-EN24 0 0 0 0 0
Total volume of spills m3   G4-EN24 46 204.85 68.85 20.03  0
Air quality exceedances   #   G4-EN29 3 4 1 0
Environment, Health & Safety (EH&S) management                
Projects to reduce GHG emissions and reductions achieved thousand tonnes
CO2e per year
  G4-EN6 29,324.00 24,937.43 1,561.00 0
EH&S professionals on staff   G4-EN31 38 41 43  -- --

Footnote Y:
Professionals dedicated to environment, health or safety matters. Professional Services Agreements (PSA’s) and non-positioned contractors are not included in this total. Beginning in 2014, this indicator is reported in our East Coast Canada performance data, and reflects our Exploration & Production business segment.

North American Onshore environment footnotes
1 Reported North America Onshore data reflects assets owned throughout the reporting year, as well as divested assets up to their date of sale. In 2013 and 2014 we divested the majority of our conventional natural gas business in western Canada (including Wilson Creek in 2014), therefore performance data reflects significant decreases.
A

Processed volume is the total amount of hydrocarbons processed at Suncor-operated facilities. This includes production owned by other companies and processed at Suncor-operated facilities. Processed volume is used to calculate intensities.

Barrels of oil equivalent and cubic metres of oil equivalent may be misleading indicators of value. See “Advisories”.

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 exist then the most applicable and accurate methods available are used to quantify each emission source.
C Total SO2 emissions from Suncor-operated facilities. This total includes emissions from operated facilities required to report under regulatory reporting programs as well as those facilities not required to report under regulatory programs. 2013 emissions for divested properties were reported from Jan. 1 to Sep 26, 2013.
D Total NOx emissions from Suncor-operated facilities. This total includes emissions from operated facilities required to report under regulatory reporting programs as well as those facilities not required to report under regulatory programs. 2013 emissions for divested properties were reported from Jan. 1 to Sep 26, 2013.
E Total VOCs emissions from Suncor-operated facilities. This total includes emissions from operated facilities required to report under regulatory reporting programs as well as those facilities not required to report under regulatory programs.
F

There was a decrease in NPRI releases in 2013 compared to 2012 as Suncor is not required to report facilities not operated as of Dec. 31 of the reporting year for NPRI. 

G

As a result of divestment that occurred in 2013, data for solution gas flaring and other flaring sources was unobtainable.

H

Total energy is the sum of direct and indirect energy.

I

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

J

Produced water is all formation and other water brought to the surface during the normal course of our natural gas production process.

K

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 separately as an aggregated total. Beginning in 2014, in order to provide more detail of the waste streams created due to our operations, we have included this category of waste in total hazardous waste generated.

In 2011, North America Onshore compiled all waste data from our major receivers.

L

This is variable year-to-year, based on operations conducted.

M

An increased volume of non-hazardous waste generated in 2012 is primarily due to remediation and reclamation activities, including biopile removal.

N

Inclusive of drilling mud waste from drilling operations. This value has not been captured in the hazardous waste generated and non-hazardous waste generated values. Value increased in 2013 reflective of drilling that halted in 2012 due to the Altares incident in B.C.

O

Both public and regulatory agency databases were mined and compared with Suncor wells with associated yearly production volumes. The number of producing wells decreased significantly in 2013 due to a large divestment of assets in late 2013.

P The number of Suncor producing wells decreased significantly in 2013 due to the large divestment of assets in late 2013 and is reflective of ownership at Dec. 31, 2014.
Q

A shut-in well is taken out of production by shutting off flow at the wellhead, often with the expectation of resuming production in the future. A suspended well is a shut-in well on which additional subsurface isolation procedures have been performed, and which is usually taken out of production due to poor economics. If a suspended well is not brought back into production, it is taken out of service as per regulatory requirements. The inactive and suspended well lists from the Western Canadian regulatory agencies (Alberta Energy Regulator, Government of Saskatchewan Energy and Resources, and British Columbia Oil and Gas Commission) were utilized in determining this total.

The number of shut-in wells decreased significantly in 2013 due to the large divestment of assets in 2013.

R For the purpose of the Report on Sustainability, the number of wells undergoing reclamation include abandoned sites in the care and custody of North America Offshore Surface, Land, Logistics and Construction Liability Management group that are categorized (i.e., site status) as Phase I, Phase II, Remediation and Reclamation. Sites categorized with the status Pre-Screening were not included. Further explanation of each category is detailed in Suncor’s Draft Remediation - Reclamation Framework document. These are sites we are actively working on in some form or another, with the end goal being closure/obtaining closure through a reclamation certificate or alternative certification. See “Advisories”
S

The downward trend in compliance data in 2013 and 2014 is reflective of maturing our operational discipline and the reductions of our operations in this business segment, due to divestment activity.

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.

T Regulatory fines associated with late production accounting filings.
U Reportable spills are defined in accordance with federal and provincial regulations.
V Professionals dedicated to environment, health or safety matters. Professional Services Agreements (PSA’s) and non-positioned contractors are not included in this total. Beginning in 2014, this indicator is reported in our East Coast Canada performance data, and reflects our Exploration & Production business segment.

Economic

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 14.2 12.4 18.9 0.8 0.3

Footnote W:
For 2010 to 2013, includes the Deep Gas Royalty Holiday Program and Alberta Royalty Tax Credit. For 2014, includes the Deep Gas Royalty Holiday Program only; Alberta Royalty Tax Credit is not included because the amount is not expected to be material due to minimal drilling activity.

Investments                
Capital and exploration expenditures $ millions   G4-EC1 137 154 114 62 3
Purchases                
Goods and services $ millions     260 327 228 103 11
Goods and services purchased in or from:                
  • Canada
$ millions     260 326 227 102 11
  • Local businesses and suppliers
$ millions G4-EC9 237 311 214 -- --

Footnote X:
Local businesses and suppliers are those established in the region of operations (2010 to 2014 data includes Alberta and British Columbia operations). Beginning in 2014, local spend is only reported on a Suncor-wide basis.

North America Onshore economy footnotes
W For 2011 to 2013, includes the Deep Gas Royalty Holiday Program and Alberta Royalty Tax Credit. For 2014, includes the Deep Gas Royalty Holiday Program only; Alberta Royalty Tax Credit is not included because the amount is not expected to be material due to minimal drilling activity.
X Local businesses and suppliers are those established in the region of operations (2011 to 2014 data includes Alberta and British Columbia operations). Beginning in 2014, local spend is only reported on a Suncor-wide basis.