ESGBERT/environment_data · Datasets at Hugging Face

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We build internal capacity by ensuring dedicated employees have the knowledge and skills to coordinate a response in the event of an incident involving a water body, including making sure equipment that might be needed is available.
Months of planning using HRO principles involved more than representatives from government and regulatory agencies, to ensure the program would be completed safely and with minimal release of residual oil to the environment.
We employed mitigation measures that included weather limitations on wind and sea states, pre deployment of spill response equipment, the use of remotely operated underwater vehicles for response and surveillance, on-scene aerial surveillance and regular wildlife observations.
The drone uses thermal imaging to help with rescue and recovery activities, mapping high-traffic areas and improving scene management.
sheet, an Integrated Corridor that includes sizeable downstream and midstream assets, and Offshore operations that include long-term gas contracts in the Asia Pacific region.
We use fuel, electricity and steam in our operations and exclude all gases flared, vented or incinerated since the energy content is not used.
In more than 10 million gigajoules from 2018, primarily due to reduced fuel use.
This was largely due to the Alberta government-mandated production curtailment, which led to reduced production at the Sunrise Energy Project.
Reducing steam-oil ratios means using less steam for the same oil production, which lowers our energy intensity and reduces both operating costs and air emissions intensity, including GHGs.
Since at a rate greater than our energy use, resulting in overall declines in both total energy use intensity and Scope 1 emission intensity.
With our new membership in Canada’s Oil Sands Innovation Alliance (COSIA), we aim to maximize the benefit of our environmental work, along with that of other members, by cooperating to reduce GHG emissions, minimize water use and develop more efficient land reclamation.
We are a member of the Clean Resource Innovation Network (CRIN), which applies technology and innovation to making the oil and gas industry more effective, efficient and carbon competitive.
We are also a member of the Petroleum Technology Alliance of Canada (PTAC), collaborating on the research and development of technology solutions for industry challenges such as environmental stewardship, operational efficiencies and cost reduction.
Emissions Intensity A pilot program at three thermal projects in Saskatchewan that uses White Whale artificial intelligence to enhance steam utilization and improve our emissions intensity has been successful, reducing steam requirements by about by approximately 2%.
This results in greater operating profitability with less environmental intensity.
These networks focus on innovation and best practices in areas such as air emissions, water management, reservoir recovery, geoscience integration and business analytics.
Refinery, using reverse osmosis to remove impurities and recycling the water for use in the facility.
At our Sunrise Energy Project, we completed the Husky-patented diluent reduction pilot.
Environmental We take steps to minimize our impact on land and habitat, air and water, actively seeking ways to both mitigate and further reduce our environmental footprint.
We provide environmental expertise, standards, systems and oversight, through teams deployed in all areas of our operations.
risks, with the goal of reducing greenhouse gas emissions and other air pollutants through the development and application of new technology and energy efficiency measures.
Our operations generate greenhouse gases and other air emissions.
We recognize these emissions can affect local air quality and contribute to climate change.
Our emissions are generated by combustion equipment, venting to atmosphere, the flaring of waste gases, and fugitive emissions.
Air emissions management programs collect the data needed to meet regulatory requirements, manage risk and explore opportunities to economically improve emissions performance and minimize the impact on our neighbours.
Scope of CO2e/mboe 24 Climate-Related Risks and Air Emissions \| Environmental pricing and engagement.
The risks and opportunities inherent to a lower global emissions pathway are built into our Enterprise Risk Management process.
Husky believes there is a significant role for government to provide incentives and direct support in the development and commercialization of technologies that reduce industry emissions.
Revenues generated through carbon policy and regulation should be made available to support industry research, including the development and deployment of innovative practices and technology that improve efficiency and reduce carbon emissions.
Emission reduction regulations should apply a price on carbon and we support the development of a market for environmental attributes such as emissions offset credits.
Husky follows the Greenhouse Gas Protocol for Scope estimation methodology, adjusted using IPIECA guidance where relevant.
Under new regulatory reporting requirements, more than 2019 Scope 1 emissions will be assured by a third party, to a reasonable level.
The new power management systems on these vessels use fuel more efficiently, resulting in significantly lower fuel consumption and emissions than older power management systems.
We continue to monitor daily fuel use through Husky-developed database management, allowing us to optimize vessel operations and further reduce our impact on the environment.
Our Scope 1 GHG emissions intensity in 2019 was 37.44 tonnes of CO2e/mboe.
the Tucker Thermal Project will use both emission performance credits generated in previous years and emission offset credits to reduce total compliance costs.
These credits were earned by reducing Tucker’s GHG emissions below regulatory requirements.
assess opportunities to use renewable energy where it makes economic and operational sense.
Carbon Capture and Storage At the Lloydminster ethanol plant, we capture up to carbon dioxide (CO2) to aid in enhanced oil recovery, which involves CO2 being injected into reservoirs to increase oil production.
We continue to evaluate additional carbon capture technologies, including at our Pikes Peak South thermal project where we have been testing Svante technology that captures CO steam generator.
We believe these technologies have the potential to reduce carbon capture costs and reduce the carbon intensity of bitumen production.
Options to reduce GHG emissions from our upstream and downstream operations are compiled and evaluated using a Marginal Abatement Cost Curve (MACC).
The MACC catalogues the size of emissions reduction possible and return on investment for various options.
employs aerospace technology to combust methane at our CHOPS operations, instead of venting to atmosphere.
This project is partially funded by Emissions Reduction Alberta.
The MACC also helps different areas of the Company share information about emissions reduction options.
The annually renewed carbon management plan helps us engage with our joint venture partner on options to improve emissions performance.
emissions from oil and gas operations in Alberta and Saskatchewan by 45% by 2025.
These regulations came into effect on January provide new methodologies on how to report fuel, flare and vent volumes, which will result in a change in our reported venting emissions for 2020.
Initiatives to reduce methane emissions include the conversion of pneumatic devices, gas conservation and incineration technology.
To further enhance our ability to manage and reduce methane emissions, we are gathering equipment data from our upstream operations in Western Canada.
This data is critical to determine how to effectively reduce methane from our operations and meet the intent of the new regulations.
air pollutants through regulations outlined under the U.S. Environmental Protection Agency.
This allows us to evaluate and manage emissions at the corporate and individual facility level, forecast emissions associated with future operations and achieve regulatory compliance.
Improved steam utilization helps to improve our emissions intensity.
Our facilities are designed to meet the ambient air quality objectives in Alberta and Saskatchewan for NOx, SO2 and particulate matter.
The sulphur recovery unit installed at the Rush Lake thermal project in mid- 60% of the 2019 over 2018 decrease.
increased sulphur emissions at two of our Saskatchewan thermal projects.
Emissions Management Program (FEMP) for upstream and midstream facilities, and the Leak Detection and Repair (LDAR) program for downstream facilities.
Fugitive emissions, including methane and VOCs, are gas and vapour leaks from valves, piping connections, pumps and compressor seals, and other piping system components which occur as part of the normal operation of a facility or plant.
These programs detect and ensure timely repair of fugitive emissions from equipment.
FEMP and the LDAR program improve safety through early detection and repair of emission sources, reducing exposure to potentially hazardous gases, reducing GHG emissions and VOCs, improving overall air quality, increasing operational efficiency and conserving marketable gas.
Practice for Fugitive Emissions, conducting surveys quarterly at all large gathering and processing facilities and at least once a year at others.
to responsibly reduce, recycle and re-use as much water as is economically feasible.
We manage water use throughout our operations by exploring and implementing innovative opportunities to responsibly reduce, recycle and re-use as much water as is economically feasible.
This reflects our progress on water security through water accounting, governance and stewardship activities.
where we operate, to ensure surface water and groundwater supplies are not affected negatively.
In considering a water source for our operations, we evaluate risks, including reliability of supply, technical feasibility, net environmental effect, economics, and regulatory and stakeholder concerns.
Mitigation plans are developed and implemented to manage the risk.
We monitor surface water and groundwater to ensure operations are not negatively impacting the environment.
We recycle produced water at the Sunrise Energy Project and the Tucker Thermal Project.
At Sunrise we use process-affected water from a neighbour’s tailings ponds as a water source, a mutually beneficial agreement that reduces our demand for groundwater.
Both strategies support UN SDG implement integrated water resource management.
Through PTAC’s Water Innovation Planning Committee, we participate in joint industry projects related to water management for hydraulic fracturing, part of the Alberta Upstream Petroleum Research Fund.
By participating in national and international water reporting programs we help drive better measurement and transparency of water use and issues across the industry.
We withdraw water for industrial use from saline and non-saline sources, including non-saline industrial wastewater.
Water Withdrawals for Industrial Use Million m Non-saline (fresh) water is defined as having a total dissolved solids concentration of less than 4,000 mg/L.
measures the ratio of total water withdrawals to available renewable surface and groundwater supplies.
Two percent (or about cubic metres) of Husky’s fresh water withdrawals for industrial use in 2019 occurred in areas of high baseline water stress, where water supplies may be limited.
More than for industrial use occur in areas with low to low-medium baseline water stress, where water availability is good.
Regulator and included in its Water Use Performance Report.
supplemented with two water sources that are considered alternatives to fresh water by the Alberta Energy Regulator: process-affected water from a neighbour’s tailings ponds and basal McMurray groundwater which is in contact with bitumen.
In of the total water used for steam generation.
The remaining the basal McMurray groundwater and process-affected water sources.
In metres) of the water used to generate steam, up from 82% in 2018.
Water licences for our thermal projects represent approximately the North Saskatchewan River annual average flow.
Water withdrawals under these licences were higher in compared to 15.9 million cubic metres in 2018.
This was due to the startup of the Dee Valley thermal project and the first full year of production at the Rush Lake decrease in water demand related to shutting in the Pikes Peak plant in 2019.
As a result, the overall water intensity for Lloyd thermal projects was comparable year-over-year.
Our detailed water sourcing risk assessment for this area, conducted in engineers, hydrogeologists and geochemists to better define water sourcing risks.
The water availability was determined to be more than sufficient to meet our current and future needs, through all seasons, while not affecting other users.
Water management plans for our Lloyd thermal projects are updated considering new water demands and water availability risks.
Potential sources of water for new thermal projects are assessed to ensure we select the most appropriate for each, considering a balance of factors.
We are advancing technologies to improve our water efficiency at current and future projects.
Water management plans for each area identify and mitigate water risks over the long term, promoting responsible water stewardship by evaluating re-use opportunities, source alternatives and wastewater disposal solutions.
Water risks are characterized in the context of reliability, technical feasibility, net environmental effects, regulatory and stakeholder interests and economics.
We also assess water management components, including transportation, storage and treatment.
The amount of water required for each resource play depends on the reservoir characteristics, as well as the amount and quality of water produced from the reservoir and the timing of operations.
We evaluate water re-use opportunities using these factors and implement them where possible.
The COSIA Water Technology Development Centre began operations in reduce water, land footprint, waste and GHG impacts at a thermal plant.

We build internal capacity by ensuring dedicated employees have the knowledge and skills to coordinate a response in the event of an incident involving a water body, including making sure equipment that might be needed is available.

Months of planning using HRO principles involved more than representatives from government and regulatory agencies, to ensure the program would be completed safely and with minimal release of residual oil to the environment.

We employed mitigation measures that included weather limitations on wind and sea states, pre deployment of spill response equipment, the use of remotely operated underwater vehicles for response and surveillance, on-scene aerial surveillance and regular wildlife observations.

The drone uses thermal imaging to help with rescue and recovery activities, mapping high-traffic areas and improving scene management.

sheet, an Integrated Corridor that includes sizeable downstream and midstream assets, and Offshore operations that include long-term gas contracts in the Asia Pacific region.

We use fuel, electricity and steam in our operations and exclude all gases flared, vented or incinerated since the energy content is not used.

In more than 10 million gigajoules from 2018, primarily due to reduced fuel use.

This was largely due to the Alberta government-mandated production curtailment, which led to reduced production at the Sunrise Energy Project.

Reducing steam-oil ratios means using less steam for the same oil production, which lowers our energy intensity and reduces both operating costs and air emissions intensity, including GHGs.

Since at a rate greater than our energy use, resulting in overall declines in both total energy use intensity and Scope 1 emission intensity.

With our new membership in Canada’s Oil Sands Innovation Alliance (COSIA), we aim to maximize the benefit of our environmental work, along with that of other members, by cooperating to reduce GHG emissions, minimize water use and develop more efficient land reclamation.

We are a member of the Clean Resource Innovation Network (CRIN), which applies technology and innovation to making the oil and gas industry more effective, efficient and carbon competitive.

We are also a member of the Petroleum Technology Alliance of Canada (PTAC), collaborating on the research and development of technology solutions for industry challenges such as environmental stewardship, operational efficiencies and cost reduction.

Emissions Intensity A pilot program at three thermal projects in Saskatchewan that uses White Whale artificial intelligence to enhance steam utilization and improve our emissions intensity has been successful, reducing steam requirements by about by approximately 2%.

This results in greater operating profitability with less environmental intensity.

These networks focus on innovation and best practices in areas such as air emissions, water management, reservoir recovery, geoscience integration and business analytics.

Refinery, using reverse osmosis to remove impurities and recycling the water for use in the facility.

At our Sunrise Energy Project, we completed the Husky-patented diluent reduction pilot.

Environmental We take steps to minimize our impact on land and habitat, air and water, actively seeking ways to both mitigate and further reduce our environmental footprint.

We provide environmental expertise, standards, systems and oversight, through teams deployed in all areas of our operations.

risks, with the goal of reducing greenhouse gas emissions and other air pollutants through the development and application of new technology and energy efficiency measures.

Our operations generate greenhouse gases and other air emissions.

We recognize these emissions can affect local air quality and contribute to climate change.

Our emissions are generated by combustion equipment, venting to atmosphere, the flaring of waste gases, and fugitive emissions.

Air emissions management programs collect the data needed to meet regulatory requirements, manage risk and explore opportunities to economically improve emissions performance and minimize the impact on our neighbours.

Scope of CO2e/mboe 24 Climate-Related Risks and Air Emissions | Environmental pricing and engagement.

The risks and opportunities inherent to a lower global emissions pathway are built into our Enterprise Risk Management process.

Husky believes there is a significant role for government to provide incentives and direct support in the development and commercialization of technologies that reduce industry emissions.

Revenues generated through carbon policy and regulation should be made available to support industry research, including the development and deployment of innovative practices and technology that improve efficiency and reduce carbon emissions.

Emission reduction regulations should apply a price on carbon and we support the development of a market for environmental attributes such as emissions offset credits.

Husky follows the Greenhouse Gas Protocol for Scope estimation methodology, adjusted using IPIECA guidance where relevant.

Under new regulatory reporting requirements, more than 2019 Scope 1 emissions will be assured by a third party, to a reasonable level.

The new power management systems on these vessels use fuel more efficiently, resulting in significantly lower fuel consumption and emissions than older power management systems.

We continue to monitor daily fuel use through Husky-developed database management, allowing us to optimize vessel operations and further reduce our impact on the environment.

Our Scope 1 GHG emissions intensity in 2019 was 37.44 tonnes of CO2e/mboe.

the Tucker Thermal Project will use both emission performance credits generated in previous years and emission offset credits to reduce total compliance costs.

These credits were earned by reducing Tucker’s GHG emissions below regulatory requirements.

assess opportunities to use renewable energy where it makes economic and operational sense.

Carbon Capture and Storage At the Lloydminster ethanol plant, we capture up to carbon dioxide (CO2) to aid in enhanced oil recovery, which involves CO2 being injected into reservoirs to increase oil production.

We continue to evaluate additional carbon capture technologies, including at our Pikes Peak South thermal project where we have been testing Svante technology that captures CO steam generator.

We believe these technologies have the potential to reduce carbon capture costs and reduce the carbon intensity of bitumen production.

Options to reduce GHG emissions from our upstream and downstream operations are compiled and evaluated using a Marginal Abatement Cost Curve (MACC).

The MACC catalogues the size of emissions reduction possible and return on investment for various options.

employs aerospace technology to combust methane at our CHOPS operations, instead of venting to atmosphere.

This project is partially funded by Emissions Reduction Alberta.

The MACC also helps different areas of the Company share information about emissions reduction options.

The annually renewed carbon management plan helps us engage with our joint venture partner on options to improve emissions performance.

emissions from oil and gas operations in Alberta and Saskatchewan by 45% by 2025.

These regulations came into effect on January provide new methodologies on how to report fuel, flare and vent volumes, which will result in a change in our reported venting emissions for 2020.

Initiatives to reduce methane emissions include the conversion of pneumatic devices, gas conservation and incineration technology.

To further enhance our ability to manage and reduce methane emissions, we are gathering equipment data from our upstream operations in Western Canada.

This data is critical to determine how to effectively reduce methane from our operations and meet the intent of the new regulations.

air pollutants through regulations outlined under the U.S. Environmental Protection Agency.

This allows us to evaluate and manage emissions at the corporate and individual facility level, forecast emissions associated with future operations and achieve regulatory compliance.

Improved steam utilization helps to improve our emissions intensity.

Our facilities are designed to meet the ambient air quality objectives in Alberta and Saskatchewan for NOx, SO2 and particulate matter.

The sulphur recovery unit installed at the Rush Lake thermal project in mid- 60% of the 2019 over 2018 decrease.

increased sulphur emissions at two of our Saskatchewan thermal projects.

Emissions Management Program (FEMP) for upstream and midstream facilities, and the Leak Detection and Repair (LDAR) program for downstream facilities.

Fugitive emissions, including methane and VOCs, are gas and vapour leaks from valves, piping connections, pumps and compressor seals, and other piping system components which occur as part of the normal operation of a facility or plant.

These programs detect and ensure timely repair of fugitive emissions from equipment.

FEMP and the LDAR program improve safety through early detection and repair of emission sources, reducing exposure to potentially hazardous gases, reducing GHG emissions and VOCs, improving overall air quality, increasing operational efficiency and conserving marketable gas.

Practice for Fugitive Emissions, conducting surveys quarterly at all large gathering and processing facilities and at least once a year at others.

to responsibly reduce, recycle and re-use as much water as is economically feasible.

We manage water use throughout our operations by exploring and implementing innovative opportunities to responsibly reduce, recycle and re-use as much water as is economically feasible.

This reflects our progress on water security through water accounting, governance and stewardship activities.

where we operate, to ensure surface water and groundwater supplies are not affected negatively.

In considering a water source for our operations, we evaluate risks, including reliability of supply, technical feasibility, net environmental effect, economics, and regulatory and stakeholder concerns.

Mitigation plans are developed and implemented to manage the risk.

We monitor surface water and groundwater to ensure operations are not negatively impacting the environment.

We recycle produced water at the Sunrise Energy Project and the Tucker Thermal Project.

At Sunrise we use process-affected water from a neighbour’s tailings ponds as a water source, a mutually beneficial agreement that reduces our demand for groundwater.

Both strategies support UN SDG implement integrated water resource management.

Through PTAC’s Water Innovation Planning Committee, we participate in joint industry projects related to water management for hydraulic fracturing, part of the Alberta Upstream Petroleum Research Fund.

By participating in national and international water reporting programs we help drive better measurement and transparency of water use and issues across the industry.

We withdraw water for industrial use from saline and non-saline sources, including non-saline industrial wastewater.

Water Withdrawals for Industrial Use Million m Non-saline (fresh) water is defined as having a total dissolved solids concentration of less than 4,000 mg/L.

measures the ratio of total water withdrawals to available renewable surface and groundwater supplies.

Two percent (or about cubic metres) of Husky’s fresh water withdrawals for industrial use in 2019 occurred in areas of high baseline water stress, where water supplies may be limited.

More than for industrial use occur in areas with low to low-medium baseline water stress, where water availability is good.

Regulator and included in its Water Use Performance Report.

supplemented with two water sources that are considered alternatives to fresh water by the Alberta Energy Regulator: process-affected water from a neighbour’s tailings ponds and basal McMurray groundwater which is in contact with bitumen.

In of the total water used for steam generation.

The remaining the basal McMurray groundwater and process-affected water sources.

In metres) of the water used to generate steam, up from 82% in 2018.

Water licences for our thermal projects represent approximately the North Saskatchewan River annual average flow.

Water withdrawals under these licences were higher in compared to 15.9 million cubic metres in 2018.

This was due to the startup of the Dee Valley thermal project and the first full year of production at the Rush Lake decrease in water demand related to shutting in the Pikes Peak plant in 2019.

As a result, the overall water intensity for Lloyd thermal projects was comparable year-over-year.

Our detailed water sourcing risk assessment for this area, conducted in engineers, hydrogeologists and geochemists to better define water sourcing risks.

The water availability was determined to be more than sufficient to meet our current and future needs, through all seasons, while not affecting other users.

Water management plans for our Lloyd thermal projects are updated considering new water demands and water availability risks.

Potential sources of water for new thermal projects are assessed to ensure we select the most appropriate for each, considering a balance of factors.

We are advancing technologies to improve our water efficiency at current and future projects.

Water management plans for each area identify and mitigate water risks over the long term, promoting responsible water stewardship by evaluating re-use opportunities, source alternatives and wastewater disposal solutions.

Water risks are characterized in the context of reliability, technical feasibility, net environmental effects, regulatory and stakeholder interests and economics.

We also assess water management components, including transportation, storage and treatment.

The amount of water required for each resource play depends on the reservoir characteristics, as well as the amount and quality of water produced from the reservoir and the timing of operations.

We evaluate water re-use opportunities using these factors and implement them where possible.

The COSIA Water Technology Development Centre began operations in reduce water, land footprint, waste and GHG impacts at a thermal plant.