Energy Efficiency Program Administration

Programs are often administered by natural gas and electric utility companies, but also by governments and dedicated ‘energy efficiency utilities’. 

Alberta

 The Alberta government declared that the EEA would be completely shut down in June 2020. Some of the remaining EEA projects, as well as program areas in development, were transferred to Emissions Reductions Alberta, the Municipal Climate Change Action Centre, and Alberta Environment and Parks.

The Alberta Urban Municipalities Association (AUMA) leads a number of programs connected to energy efficiency and renewable energy. AUMA's owned subsidiary organization, the AMSC, was designated as the program administrator for the Clean Energy Improvement Program (CEIP) in February 2021. Funding for MCCAC and CEIP was sourced from the Alberta carbon levy and the Technology Innovation and Emissions Reduction Fund (TIER).

Last reviewed: September 2021

British Columbia

Electricity energy efficiency programs in BC are operated by BC Hydro (a crown corporation), under the PowerSmart brand. FortisBC also administers electricity efficiency programs in the Southern Interior Region of BC. Natural gas efficiency programs are administered by the FortisBC utility, as well as Pacific Northern Gas in northern regions. All programs are overseen by the British Columbia Utilities Commission and supported by ratepayer funds.

The Province of British Columbia also administers programs under the ‘CleanBC’ initiative. 

Some CleanBC programs are operated by the government, while others are administered on the government's behalf by BC Hydro. All programs are funded by taxpayers and the private sector through carbon taxes or certain energy sales. 

CleanBC is an online hub to access information on programs administered by BC Hydro, FortisBC, and BC Housing. A rebate search tool for homes and electric vehicles, a single application process, free energy coaching services, a search tool to find EnerGuide rating system advisors and contractor directories, and information hubs for the Better Buildings program, Industry programs, Clean Transportation, Emissions from Waste, and Clean Energy jobs are among the resources available

Last reviewed: September 2021

Manitoba

Electricity and natural gas efficiency programs have historically both been administered by Manitoba Hydro, the provincially-owned utility company, under the Power Smart brand name.

In 2017, the provincial govenrment introduced the Efficiency Manitoba Act, establishing a new crown corporation called Efficiency Manitoba, with a mandate to implement and support demand-side management programs to meet savings targets and reduce greenhouse gas emissions in both the electricity and natural gas sectors.

Efficiency Manitoba filed its first 3-year Efficiency Plan in October 2019, which was reviewed by the Public Utilities Board and received approval by the Minister of Conservation of Climate in early 2020.   Administration of energy efficiency programming in the province formally transferred to Efficiency Manitoba on April 1, 2020. 

Last reviewed: October 2021

New Brunswick

New Brunswick Power now serves as the delivery agency for both electric and non-electric efficiency programs (details found at Save Energy NB). Electric programs are largely funded by ratepayers and are subject to annual review by the Energy and Utilities Board (EUB).

Non-electric programs are currently supported through the Low-Carbon Economy Fund, and all-fuel low-income programs are funded by the Government for New Brunswick.                                                                                                                                  

Beginning in 2009, the Government of New Brunswick has developed a year-long strategic investment plan to improve energy efficiency in existing provincially owned buildings. 

Under the Department of Transportation and Infrastructure Buildings Division Energy Retrofit Program, projects resulting in cost avoidance to government facilities are funded or incentivized.

Last reviewed: October 2021

Newfoundland and Labrador

Energy efficiency programs are administered by two utility companies: Newfoundland Power (investor owned) and Newfoundland and Labrador Hydro (publicly owned).  Both utilities are regulated by the Newfoundland and Labrador Board of Commissioners of Public Utilities (the Public Utilities Board). 

The government also administers efficiency programs, such as the low-income Home Energy Savings administered by the Newfoundland and Labrador Housing Corporation, and other non-regulated fuels programs.  Government programs are supported with funds from the Government of Canada’s Low-Carbon Economy Leadership Fund.

Last reviewed: October 2021

Northwest Territories

The Arctic Energy Alliance administers energy efficiency programs, funded through the territorial government and federal contributions through the low-carbon economy leadership fund.

The NWT Public Utility Board (PUB) regulates all energy from public utilities. The programs offered by the AEA tackle both residential and commercial customers and offer both financial and non-financial incentives to help increase energy efficiency uptake in NWT.

Last reviewed: October 2021

Nova Scotia

Efficiency Nova Scotia administers electricity and non-regulated fuel programs in Nova Scotia. Efficiency Nova Scotia was established as an independent, non-profit corporation in 2010, becoming Canada's first 'energy efficiency utility'. In 2014, the government converted the role of demand-side administrator to a franchise, granted for the first 10 years to EfficiencyOne (the former Efficiency Nova Scotia corporation). 

Electricity efficiency programs are funded through rates, and subject to oversight by the Utility and Review Board (UARB). Non-electric programs are primarily funded by the provincial and federal governments, and are governed by a fee-for-service agreements with the Province.

Last reviewed: October 2o21

Nunavut

Efficiency strategies are run under the Climate Change Secretariat created in 2016.

The Qulliq Energy Corporation (QEC) operates standalone power systems sized to meet municipal demands. In 2005, QEC created the Nunavut Energy Center to run energy efficiency programs, which closed in 2009.

Last reviewed: October 2021

Ontario

Electricity

The IESO will centrally deliver the CDM Framework 2021-2024 under the Save on Energy brand. It will focus on fulfilling the demands of Ontario's electrical system in the most cost-effective way possible, including achieving statewide peak demand reductions as well as tailored measures to address regional and/or local energy system needs. 

With this framework, It  will continue to provide opportunities for electricity consumers to manage their electricity costs, as well as stability for partners and businesses involved in the delivery and administration of Save on Energy programs across the province, and will help to meet electricity system needs in a cost-effective manner.

 

Natural Gas

Natural gas “Demand Side Management” (DSM) programs in the Province of Ontario are administered by Enbridge Gas Inc., as mandated by the OEB. The Ontario Energy Board authorized a one-year extension of Enbridge Gas Inc.'s 2015-2020 DSM Plan in July 2020, to be carried over for 2021 to guarantee program continuity while a new DSM policy framework to guide future multi-year DSM plans is developed. A similiar extension was authorized for 2022. The Ontario Energy Board is now conducting a procedural assessment of Enbridge Gas Inc's 2023-2027 DSM Plan Application.

Last reviewed: October 2021

Prince Edward Island

In PEI, a crown corporation acts as an “energy efficiency utility” with an all fuels mandate. Funding is provided by both ratepayer contributions and government funds. Programs are implemented and branded under EfficiencyPEI.

The 2016/2017 PEI Energy Strategy called for establishment of an independent energy efficiency utility with a mandate to pursue efficiency for all fuels. An Act to Amend the Electric Power Act, passed in December 2017, made the PEI Energy Corporation a public utility for the purposes of energy efficiency and demand side resources. The PEI Energy Corporation is a crown corporation under the department of Transportation, Infrastructure and Energy. The Corporation can submit energy efficiency plans to the province’s utility commission (The Island Regulatory and Appeals Commission), and the Act requires that each public utility affected by the commission’s approval of an energy efficiency plan pay relevant costs.

The PEI Energy Corporation has delegated EfficiencyPEI to act as the service agency for its efficiency and conservation. EfficiencyPEI commenced operations in 2008 as a government department, and was formerly known as the Office of Energy Efficiency. The changes noted above changed EfficiencyPEI’s parent company to the PEI Energy Corporation. A 2018-2021 demand side management plan included a consistent ramp-up in savings and required evaluation of program savings by a third-party (which was not previously the case).

Last reviewed: October 2021

Quebec

Hydro-Québec has operated electricity DSM programs since the early 1990s. The provincial energy board (Régie de l’énergie) approves efficiency initiatives as a component of rate cases and electricity supply plans. In October 2019, Hydro-Quebec announced the creation of a new subsidiary named Hilo, focused on smart energy management.

Énergir (formerly Gaz Métro) is the major natural gas distributor and natural gas energy efficiency administrator. Gazifère is a natural gas provider in Gatineau that also administers energy efficiency programs, under Gazifère Green branding.

A government energy efficiency agency has existed in Quêbec since the 1970s, originally named the “Bureau des économies d’énergie” (1977) and remamed “l’agence de l’efficacité énergetique” in 1996. In 2008, a “quote part” fuel charge on all fuel distributors was introduced to fund this agency. In 2011, the office was renamed the “Bureau de l’efficacité et l’innovation énergétiques” (BEIE) (Energy Efficiency and Innovation Office) and placed within the Ministry of Natural Resources. In December 2016, the BEIE was closed and a new state corporation with an executive director and board of directors was created, called Transition Énergétique Québec (TEQ). This was originally envisioned in the 2030 energy plan. TEQ is funded through the “quote part”, cap and trade revenues dispersed from the Green Fund, and an Energy Transition Fund supported by petroleum royalties. TEQ has developed a five year master plan on energy transition, innovation, and energy efficiency. In June 2019, the government announced that TEQ would be brought under the Ministry of Energy and Natural Resources, as part of a restructuring of the governance of the provincial Green Fund. The “Master Plan” will be maintained, but adopted to consider new goals on electrification and climate change.

Bill 44 tabled in October 2019 proposes to change the name of the Green Fund to the “Electrification and Climate Change Fund”, abolishing the Green Fund management council and transferring responsibilities to the Minister of the Environment and the fight against climate change, abolishing TEQ and placing the “master plan” under the responsibility of the Ministry of Energy and Natural Resources.

Last reviewed: October 2021

Saskatchewan

Natural gas programs are administered by SaskEnergy.  SaskPower administers some outreach and education programs, but does not target electricity savings.  Both are provincially-owned utilities.

Last reviewed: October 2021

Yukon

 

Yukon Government's Energy Branch provides a complete suite of incentive programs to residential, commercial, and institutional clients throughout the territory. The Good Energy program was expanded in 2020 to include clean mobility incentives, such as those for electric vehicles, e-bikes, and EV charging. These include assistance with new construction, building retrofits, energy-efficient appliances, and sustainable transportation.

Yukon Housing Corporation supports energy retrofits in buildings through low interest loans and a First Nation housing retrofit program.

Last reviewed: October 2021

Energy Efficiency Targets

Energy efficiency targets give clear direction to program administrators and energy system managers, pushing them to achieve higher savings than they might otherwise, and reinforcing the concept of efficiency as a quantifiable resource.

Alberta

There are no formal energy savings targets in Alberta. 

However, the Alberta Government stated that when fully subscribed, the Energy Savings for Business program has an emissions reduction objective of 1.1M tCO2e of net lifetime GHG savings. This goal is fuel neutral, although it will be pretty entirely driven by electricity or natural gas savings.

Last reviewed: October 2021

British Columbia

The 2010 Clean Energy Act established an objective to “to take demand-side measures and to conserve energy, including the objective of the authority reducing its expected increase in demand for electricity by the year 2020 by at least 66%” (Part 1, Section 2(b)). This target is mandated only for BC Hydro (‘the authority’), though FortisBC voluntarily adopted the target thereafter, and subsequently escalated its long-term DSM target to 80% of load growth offsetting. This legislated target ended in 2020. There are no legislated savings targets for natural gas. 

Section 44.1(2)(f) of the Utilities Commission Act requires utilities to submit resource plans which provide an explanation of why demand for energy is not planned to be replaced with demand-side measures. 

Last reviewed: Ocotober 2021

Manitoba

The Efficiency Manitoba Act of 2017 legislates long term energy efficiency savings targets over 15 years (2017-2032). The targets are:

  • Minimum net annual electricity savings at least equal to 1.5% of electricity consumption in the immediately preceding year
  • Minimum net annual natural gas savings equal to 0.75% of natural gas consumption in the immediately preceding year
  • Any shortfalls and surpluses in carry forward over the 15 year period to reach cumulative annual percentage savings equal to 22.5% for electricity and 11.25% for natural gas.

These targets apply to Efficiency Manitoba, not Manitoba Hydro.

Last reviewed: October 2021

New Brunswick

NB Power files its estimated annual incremental energy savings targets and associated budgets with the NB EUB as part of its annual General Rate Application.

NB Power planned budgets and energy savings are reported to the New Brunswick Energy and Utilities Board.

There are no legislated targets.  The Climate Action Plan, ‘Transitioning to a Low Carbon Economy’, released in December 2016, called for efficiency initiatives at “performance levels in leading jurisdictions”, quoting a range of 1.5 – 1.75% of sales per year, though no current formal target exists. 

Last reviewed: October 2021 

Newfoundland and Labrador

The utitilies’ TakeCHARGE program energy savings targets are approved by and reported to the Board of Commissioners of Public Utilities. The 2021-2025 CDM plan was submitted to the regulator in 2021. 

Last reviewed: October 2021

Nova Scotia

In Nova Scotia, electricity savings targets are approved by the Nova Scotia Utility and Review Board, under the current 2020-2022 demand side management plan. Non-electricity targets are published in the Efficiency Nova Scotia business plan.

There are no targets in policy or regulation.

Last reviewed: October 2021

Northwest Territories

The NWT’s 2030 Energy Strategy, released in May 2018, aims to increase commercial, residential, and institutional building energy efficiency by 15% by 2030. Reduce GHG emissions from transportation by 10% per capita, and reduce GHG  from electricity generation in diesel-powered communities by an average of 25%.

Last reviewed: October 2021

Nunavut

No targets identified.

Last reviewed: October 2021

Prince Edward Island

Annual electricity savings targets in the PEI Energy Corporation 2018-2021 Demand Side Management Resource Plan were approved by the Island Regulatory and Appeals Commission. A new three-year plan will be submitted to the regulator in 2021.

The 2016/17 provincial energy strategy calls for ramping up to annual electricity savings of 2% per year by 2020, or just under 30 GWh/year under a static load assumption. Savings would start at 0.4% of load in 2017 and ramp up.

Last reviewed: October 2021

Quebec

The government directive 537-2017 directed Transition énergétique Québec to create a 2018-2023 Master Plan. This directive aimed to improve energy efficiency at least 1% per year, on average, and to reduce by at least 5% the total consumption of petroleum products from a 2013 base year.. 

The resulting TEQ 2018-2023 Master Plan estimated an improvement in energy efficiency by about 1.2% per year, on average. This is an economy-wide target, which includes indirect changes from technological improvements and structural changes as well as the impact of initiatives outside of Québec. The Province states that the initiatives within the plan are expected to improve efficiency by 0.6% per year (9.9 petajoules), which is higher than the 0.4% or 7.3 petajoules achieved from 2012 to 2017.

The plan also aims to reduce petroleum use by 12% in 2023 compared to 2013 levels - more than the government’s directive to reduce consumption by 5% by 2023 as a first step towards the 2030 Energy Plan’s target of a 40% reduction in 2030.

The 2018-2023 Master Plan is a major policy tool of the 2030 Energy Plan, which calls for a 2030 objective to improve energy efficiency 15% from a 2013 base year.

In November 2020, the Province of Quebec unveiled its Plan for a Green Economy.. The plan reiterates the government’s commitment to reduce greenhouse gas (GHG) emissions by 37.5% by 2030 compared to their 1990 level.. 

Hydro- Québec will contribute to this Plan and has raised its energy savings objectives to support the electrification of the economy. The utility’s revised objectives are available in the 2020 Progress Report of the 2020-2029 Supply Plan. (see http://publicsde.regie-energie.qc.ca/projets/529/DocPrj/R-4110-2019-B-0106-Demande-PieceRev-2020_11_16.pdf)

Énergir 2019-2023 plan targets natural gas savings equivalent to about 0.7% of sales, rising to 0.9% in 2023.

Last reviewed:  October 2021

Saskatchewan

SaskEnergy has internal natural gas savings targets. SaskPower no longer pursues electricity savings.

Last reviewed: October 2021

Yukon

Yukon’s energy strategy, released in 2009, has a target to increase energy efficiency in Yukon by 20% by 2020.

Last reviewed: October 2021

Energy Efficiency as a Resource

Energy efficiency is a quantifiable resource just like natural gas, oil or wind turbine. This section describes policies and procedures in each jurisdiction that formalize energy efficiency in energy resource planning.

Alberta

Alberta is one of few jurisdictions in North America in which energy conservation is not incorporated into utility resource planning. One exception is the Medicine Hat Electric and Natural Gas Utility, which does offer ratepayer-funded programs

Discussions with utilities are taking place to understand the barriers they face to implement energy efficiency programs. Viable programs that addressed energy efficiency in an effective manner that don't increase the cost of energy to consumers would be considered by the Government of Alberta.

Last reviewed: October 2021

British Columbia

The BC Utilities Commission Act requires public utilities to file with the Utilities Commission a long-term resource plan that includes a plan to reduce demand by taking cost-effective measures (Sect 44.1(2)(b)).  Sect. 44.1(2)(f) of the Act requires utilities planning infrastructure to serve load to explain why demand is not planned to be met through DSM.  The Act also gives the appropriate Minister the ability to make regulations regarding whether a demand-side measure is cost-effective and adequate (Sect 125.1 (4)(3).

BC Hydro was once exempt from the requirement to explain why demand could not be met through DSM, but Bill 19-2019 ("Energy Statutes Amendment Act") removed this exemption. 

Last reviewed: October 2020

Manitoba

 

The Efficiency Manitoba Act gives Efficiency Manitoba the responsibility to execute and promote demand side management programs in Manitoba. The Act defines the mandate as to “mitigate the impact of rate increases and delay the point at which capital investments in major new generation and transmission projects will be required by Manitoba Hydro to serve the needs of Manitobans” (Section 4(1)(c)). 

The Efficiency Manitoba Act mandates annual savings equal to 1.5% of prior year sales for electricity, and 0.75% of prior year sales for natural gas volume, which is reflected in Efficiency Manitoba's first three-year plan (2020/21 to 2022/23).

 

Manitoba Hydro provides system marginal cost information to Efficiency Manitoba for their use in developing energy efficiency programs. Efficiency Manitoba provides annual capacity and energy savings to Manitoba Hydro, which are incorporated into the resource planning process as a reduction to the load forecast.  

Manitoba is moving towards an Integrated Resource Planning process.  It is anticipated that various energy efficiency initiatives, among other options, will be included in the Integrated Resource Planning process.

Manitoba Hydro annually prepares a supply and demand analysis document with updated load forecast, energy efficiency forecast, and existing resource assumptions to determine the potential requirement for additional resources beyond the committed energy efficiency resources. The most recent version of this document, the 2020 Resource Planning Assumptions and Analysis is attached.  

The need for new resources in Manitoba is driven by Manitoba Hydro’s planning criteria which specifies a planning reserve margin above peak load net of energy efficiency. In addition to the capacity criterion, as a predominately hydro system, Manitoba Hydro has an energy criterion which requires that Manitoba Hydro plan to have adequate energy resources to supply its firm energy demand in the event of a design drought. 

Manitoba Hydro is developing the framework, processes and tools to prepare an Integrated Resource Plan.    

The most recent market potential study (covering both electric and natural gas market potential) was completed in 2013.

Last reviewed: October 2021

New Brunswick

In 2014, the responsibility for efficiency programs was transferred from Efficiency New Brunswick to New Brunswick Power.

A July 23, 2018 mandate letter between the Minister of Energy and Resource Development and NB Power includes the following responsibility, “strengthening existing, and developing new cost-effective energy efficiency programs that result in direct savings to customers and NB Power, and support business development through contractor and consultant networks”.

The letter also mandates NB Power to protect and improve the environment through the Energy Smart NB plan and the reinstatement and expansion of “home energy efficiency retrofit programs to reduce energy use and lower costs for consumers of all-fuels”.

Last reviewed: October 2021

Newfoundland and Labrador

The utilities complete 5-year conservation and demand management plans. A new 2021-2025 plan was submitted to the regulator in 2021. 

This plan incorporates electrification initiatives. The Plan is currently being reviewed by the Board of Commissioners of Public Utilities. 

The most recent potential study was completed in 2019, covering the 2020-2034 time period.

Last reviewed: October 2021

Nova Scotia

An Act Respecting Electricity Efficiency and Conservation (2014) established Efficiency Nova Scotia as an “energy efficiency utility” that acts as an independent franchise with the exclusive right to supply electricity and conservation to Nova Scotia Power Incorporated.

The act states that Nova Scotia Power “shall undertake cost-effective electricity efficiency and conservation activities that are reasonably available in an effort to reduce costs for its customers” (Section 79(I)(1).  This does not mean all cost-effective DSM. The Act further states that the utility board takes into account “affordability” to customers (Sect 79L(9)). Affordability (i.e. rate versus bill impacts) is not defined.

Varying levels of DSM investment in the near to mid-term are examined during the development of an Integrated Resource Plan (IRP).  There is no fixed schedule for IRPs in Nova Scotia, but they are generally completed every 3-5 years.  Efficiency Nova Scotia supports the IRP process by developing DSM Potential Studies in advance of each IRP.

In early 2021, Nova Scotia Power released its final Integrated Resource Plan, which included deep decarbonization scenarios.

Last reviewed: October 2021

Northwest Territories

No policies identified.

Last reviewed: October 2021

Nunavut

No activities identified.

Last reviewed: October 2021

Ontario

Electricity

The Ministry of Energy creates Long-Term Energy Plans under the Energy Statute Law Amendment Act, 2016. The latest plan was released in October 2017.

Ontario also engages in Regional Energy Planning, which brings transmitters, distributors, and the Independent Electricity System Operator (IESO) together to identify solutions to regional electricity needs. Regional plans have been completed for 21 electricity regions in Ontario. 

Natural Gas

The OEB approved a new  framework for natural gas integrated resource planning in 2021. The plan restricts non-pipe alternatives to large infrastructure projects, and excludes consideration of electricity-based alternatives. 

 

Last reviewed: October 2021

Prince Edward Island

Section 16.1 of the Electric Power Act states that the utility commission may order a utility to submit an energy efficiency demand side resources plan or that a public utility may submit one for approval.  There is no mandate requiring PEI utilities to pursue energy efficiency.

Last reviewed: October 2020

Quebec

The government directive 537-2017 orders Transition énergétique Québec to develop a master plan for the years 2018-2023 that prioritizes energy efficiency as the first resource. This is a guiding philosophy rather than a specific directive to optimize all possible energy efficiency as a supply option.

Regulated energy distributors submit “supply plans” (Plan d’approvisionnement) that describe how to meet Québec market demands (art. 72 de la Loi sur la Régie de l'énergie). These plans include energy efficiency and demand side measures.

Hydro-Québec's latest 2020-2029 Supply Plan notably incorporates energy savings and power management forecasts and was filed with the Régie in November 2019 and can be viewed here.

 The supply plan is submitted for authorization every three years to the Régie de l'énergie. A progress report for this plan is submitted for the interim years.

Last reviewed: October 2021

Saskatchewan

There is no provincial mandate to pursue energy efficiency in Saskatchewan.

Last reviewed: October 2021

Yukon

No activities identified.

Last reviewed: October 2021

Efficiency Potential Study and Energy Planning

This section catalogues studies to estimate energy efficiency savings potential and the integration of efficiency into energy planning.

Alberta

The Energy Efficiency Alberta Act 2016 mandates Energy Efficiency Alberta to annually complete and provide to the Minister of Environment and Parks a multi-year business plan approved by the board. These plans must include:

  • The budget for the fiscal years to which the plan relates
  • The goals, objectives, and targets for the fiscal years to which the plan relates
  • Any additional information requested by the Minister

An Efficiency Potential study for the years 2019-2038 was prepared for Energy Efficiency Alberta in October 2018.

Last reviewed: October 2021

British Columbia

 

Under the Clean Energy Act, BC Hydro is required to submit an Integrated Resource Plan (IRP) to the BC Utilities Commission every five years (Sect 3). The most current IRP for BC Hydro was published in November 2013. In 2016, a review of this strategy was undertaken. A revised CPR has been developed and will be included in the utility's next IRP, scheduled for release in 2021.

BC Hydro will file its next Integrated Resource Plan with the BC Utilities Commission in December 2021.

FortisBC released a long-term electricity resource plan in 2016 and a long-term natural gas resource plan in 2017. Their latest natural gas Conservation Potential Review (CPR) is appended to its 2017 long-term gas resource plan, and its electric CPR was issued in two parts: the Technical/Economic potential was filed with the 2016 LTERP; and the Market potential was filed with its 2019-2022 DSM plan. 

FortisBC will be completing an updated CPR for both gas and electric utilities in 2021. The electric utility will be completing the LTERP in 2021 and the long-term gas resource plan is to be submitted by March 2022.

Last reviewed: October 2021

New Brunswick

Every three years, New Brunswick Power's Integrated Resource Plans are revised. 

The most recent plan was published in 2020.

The plan follows three core principles which include:

  • least-cost planning 
  • economic and environmental   sustainability
  • risk management  

The most recent 2020-2045 integrated resource / long-term energy plan was completed in 2020, and is scheduled to update every 3 years.

Last reviewed: October 2021

Newfoundland and Labrador

Newfoundland Power filed the Five-Year Electrification, Conservation, and Demand Management Plan 2021–2025 with the Board on December 16, 2020, and it is still being reviewed. Following the acceptance of Newfoundland Power's submission, Newfoundland Hydro expects to file its application for the implementation of initiatives outlined in the Five-Year Electrification, Conservation, and Demand Management Plan 2021–2025. 

The next potential study is expected to be completed in 2024 to create the following five year plan (2026-2030).

Last reviewed: October 2021

Northwest Territories

No potential studies or energy efficiency plans identified.

Last reviewed: October 2021

Nova Scotia

NS Power completed an Integrated Resource Planning process, which began in 2019 and ended in 2020. The documents connected with this IRP Process are available here. 

This IRP delved further into Distributed Energy Solutions, Electrification Activities, and Demand Response. Base DSM levels (about 130 GWh per year) were used to produce the resource plan with the lowest income demand. Demand Response levels of around 70 MW were also chosen.

Since an IRP was just completed, current expectations in Nova Scotia are for another IRP to be completed within the next 3-5 years.

Last reviewed: October 2021

Nunavut

No potential studies or energy efficiency plans identified.

Last reviewed: October 2020

Ontario

Potential Study
On September 30, 2019, the IESO and the Ontario Energy Board completed the first integrated electricity and natural gas conservation achievable potential study (2019 APS). The 2019 APS identifies and quantifies energy (electricity and natural gas) and demand savings, GHG emissions reduction, and associated costs from energy efficiency measures for the period of 2019-2038.

Energy Planning
Ontario’s Long-Term Energy Plan was completed in 2017. This document is informed by the IESO Planning Outlook, published on September 11, 2016. Forecasts were updated by the IESO during a September 13, 2018 Technical Planning Conference.

In January 2020, the IESO released a 20-year forecast for Ontario's electricity system, the Annual Planning Outlook (APO). The APO includes projected electricity demand, a resource adequacy assessment, transmission considerations, and performance indicators, such as an emissions outlook, and identifies the province's energy and capacity needs.

Enbridge IRP transition plan was submitted to the Ontario Energy Board during the mid-term review. The OEB issued its mid-term review report in November 2018, noting that the transition plan was at an early stage, and called for the utilities to conduct a rigourous evaluation of conservation and energy efficiency.

Bulk system planning

Bulk system planning focuses on the electricity resources that transmit energy from the generation source to local distribution companies across the province. The IESO’s bulk system planning processes address provincial electricity needs and consider the impacts of various factors on the electricity system, including policy directions, the supply/demand balance, operability requirements and others.

(a) Reliability Outlook

The Reliability Outlook guides operational planning in Ontario. The report presents Ontario’s demand forecast and associated drivers, resource adequacy projections and the assumptions that inform them, as well as an assessment of operability and the province’s transmission assets. Published quarterly, this Outlook provides insights over an 18-month planning horizon, extending the time frame an additional 42 months to five years biannually. Published every June and December, these extended versions address the drivers that can affect resource adequacy, and require the IESO to address associated reliability risks through outage management.  

The quarterly reports are available here: https://www.ieso.ca/en/Sector-Participants/Planning-and-Forecasting/Reliability-Outlook

(b) Annual Planning Outlook

The Annual Planning Outlook is a 20-year forecast for Ontario's electricity system and includes projected electricity demand, a resource adequacy assessment, transmission considerations, and performance indicators, and identifies the province's energy and capacity needs. The report provides these long-term adequacy requirements to inform investment and asset management decisions. The APO incorporates Energy Efficiency program frameworks into the demand forecast, including existing IESO-funded conservation frameworks, committed IESO-funded conservation frameworks, programs funded by the federal and municipal governments as well as assumed long-term conservation frameworks.

The 2020 APO is available here: https://www.ieso.ca/en/Sector-Participants/Planning-and-Forecasting/Annual-Planning-Outlook  

Regional Planning

Regional planning considers local electricity priorities within each of the province’s 21 electricity planning regions. This process considers each region’s unique needs, priorities and preferences. Options to satisfy local demand may include generation, transmission and distribution, and/or other innovative resources or solutions.

Last reviewed: October 2021

Prince Edward Island

efficiencyPEI commissioned Dunsky Energy Consulting to conduct a ten-year Electricity Only Potential Study, which was completed in the spring of 2021. This research will be used to inform the next three-year demand side management strategy, which will be published in the third quarter of 2021.

The Potential Study was completed and submitted to the regulator in March of 2021.

Last reviewed: October 2021

Quebec

The techno-economic potential study on the reduction of petroleum product consumption in the Quebec transport secto was completed in November 2013.

The last natural gas efficiency potential study was completed in 2017 by Energir.

Énergir will have to develop a 2024-2026 EMPP and submit it to the Régie de l'énergie for budget approval in spring 2023.

Hydro Quebec's most recent electricity supply plan was completed in November 2019, and includes forecasts for energy savings and power management.  An updated efficiency potential study (to 2029) will be submitted to the regulator in 2021. 

An updated study will be filed to the Regulator in 2022-2023.

Last reviewed: October 2021

Saskatchewan

At the end of 2017, SaskPower conducted a Conservation Potential Review that identified the electricity savings and demand reductions available in Saskatchewan. There have been no updates since this review. 

In 2020, SaskPower performed a beneficial electrification study to determine the potential fuel switching from fossil fuels to electricity for residential, commercial, and industrial technologies. The research included cost savings for consumers and SaskPower, the feasibility of technology deployment, possible GHG reductions, and anticipated load increase.

Last review: October 2021

Yukon

Yukon conducted a Electricity Conservation and Demand Management Potential Review in January of 2012.

Building on YEC’s 2019 5-year strategic plan and the Government of Yukon’s 2020 Our Clean Future strategy, Yukon Energy’s 2020 10-Year Renewable Electricity Plan outlines a portfolio of key projects and partnerships needed by 2030 to address the substantial demand for renewable electricity that will result from the ongoing economic growth of the territory, and from the policies and actions outlined in Our Clean Future.

Last reviewed: October 2021

Cost-Effectiveness Testing

Utility regulators and other policymakers can require that the benefits of energy efficiency program portfolios outweigh their costs. There are 5 principle cost-effectiveness tests, according to the California Standard Practice Manual, each including different costs and benefits.

Alberta

Energy Efficiency Alberta uses a variety of cost-effectiveness tests, including Societal Abatement Cost, Program Abatement Cost and Total Resource Cost. The tests are used at all levels (portfolio, program and measure). While the tests are not used from a pass/fail perspective, they do inform program and portfolio planning.

Last reviewed: October 2021

British Columbia

Tests used: Modified Total Resource Cost (mTRC) test with non-energy benefits and/or 15% benefit adder; Utility Cost Test

The “Demand Side Measures Regulation” (BC Reg 117/2017) to the Utilities Commission Act establishes rules for cost-effectiveness testing for all utilities. Cost-effectiveness can be assessed at the level of an individual measure, a portfolio of measures, or the portfolio as a whole (Section 4 (1)).

The regulation specifies that utility commissions apply a modified Total Resource Cost (mTRC) test.  The avoided cost of electricity is set to the long-run marginal cost of clean electricity (i.e., rather than spot market prices) as well.   Up to 40% of a natural gas DSM portfolio can use the mTRC as the primary cost-effectiveness test (provided it passes the Utility Cost Test). The benefits of the mTRC may also be increased to account for participant or non-energy benefits (Sect 4(1.1)(c)(i). Measures without non-energy benefits are assigned a uniform 15% benefit adder, and the entire portfolio must receive a 15% benefit adder or greater if non-energy benefits warrant it (Section 4(1.1)(c)(ii).

There are limits to the extent to which programs passing screening due to non-energy benefits are included in portfolios (section 4(1.5)). The commission can also determine that a program is not cost-effective if it fails the utility cost test (Section 4(1.8)). The regulation prohibits the screening of programs based on the ratepayer impact measure test (Section 4(6)).

Last reviewed: October 2021

Manitoba

Primary Test: Program Administrator Cost Test
Secondary Test: Lifecycle Revenue Impact Metric

The Efficiency Manitoba Act allows for additional reductions above mandated savings targets, if those reductions can be achieved in a cost-effective manner (Sect 4(1)(b)).  It requires the public utility board to review cost-effectiveness (Sect 11(4)), and gives it the ability to make regulations on the rules determining cost-effectiveness (Sect 40(3)(b)).

Efficiency Manitoba’s first 3-year plan uses the program administrator cost test to measure cost-effectiveness of the plan, as prescribed by regulation. The lifecycle revenue impact metric is used as a simplified indicator of the rate impacts of the plan, and the plan provides both a rate and bill impact assessment.

Manitoba Hydro's primary cost-effectiveness test was the TRC. Some initiatives are pursued with a  TRC <1 as exceptions - for example programs supporting targeted sectors such as lower income,  natural gas programs where support is required in order to move the market overall for both electric and natural gas opportunities (e.g. new home construction), and where Manitoba Hydro may be piloting initiatives in emerging sectors to better understand the market.  Manitoba Hydro's secondary tests are the levelized utility cost, the societal cost test, the levelized resource cost, the program administrator cost and the rate impact measure. Manitoba Hydro applies its tests at the program and portfolio level.

Last reviewed: October 2021

New Brunswick

NB Power uses the Program Administrator Cost Test as its primary screening test, applied at the program level. The participant cost test is used as a secondary test.

Last reviewed: October 2021

Newfoundland and Labrador

The Five-Year Conservation Plan 2016-2020 screens programs based on the Total Resource Cost Test (primary) and the Program Administrator Cost Test (secondary).

Last reviewed: October 2020

Nova Scotia

Primary test: Total Resource Cost Test
Secondary test: Program Administrator Cost Test 

The Total Resource Cost Test, at the program level, is the principal screening tool for cost-effectiveness, and the Program Administrator Cost test is reported for informational purposes in DSM plans.  

Non-energy benefits are not included in the TRC.  The Nova Scotia Utility and Review Board has ruled (M08888, Letter 80859) that it does not possess the jurisdiction to allow inclusion of non-energy benefits in the TRC.

Last reviewed: October 2020

Northwest Territories

No cost-effectiveness testing information identified.

Last reviewed: October 2020

Nunavut

No cost effectiveness testing information identified.

Last reviewed: October 2020

Ontario

The Total Resource Cost Test is the principal test for electricity conservation and demand management, applies at the program level. The Program Administrator Cost test is also reported, as well as the Levelized Unit Energy Cost. A 15 per cent benefit adder to the TRC accounts for non-energy benefits. These remain the cost-effectiveness guidelines under the 2019-2020 Interim Framework.

Under the 2015-2020 framework for natural gas utilities programs are screened using the Total Resource Cost-Plus Test, at the program level, which applies a 15% non-energy benefit adder. In the Ontario Energy Board's Mid-Term Review Report, the Board directed the gas utility to add the cost of carbon (i.e. federal price) to the TRC+ cost effectiveness test. The Program Administrator Cost Test is used as a secondary reference.

Last reviewed: October 2020

Prince Edward Island

Primary Cost-Effectiveness Test: Program Administrator Cost Test

PEI used the Program Administrator Cost Test, at the portfolio level, in its proposed 2018-2021 DSM Resource Plan.

The PEI Energy Strategy called for a cost-effectiveness screening framework that considers a societal perspective, including non-energy benefits.

The Total Resource Cost (TRC) test is used at the measure level as a secondary test.

Last reviewed: October 2020

Quebec

Electricity
Principal test: Total Resource Cost test and participant test, applied at program level. 

Secondary use of rate impact test.

Natural Gas
Principal test: Total Resource cost test, applied at a mix of program and measure levels. One program might involve a single measure (e.g. thermostats), and some program categorizations are high level. 

The participant test and rate impact measure is also reported.

Last reviewed: October 2020

Saskatchewan

Primary test: Utility cost test
Secondary test: Total resource cost test

SaskPower conducts testing at the program level to guide decision-making, and tests are reported internally at the portfolio level.

Last review: October 2020

Yukon

The Yukon Five Year Demand Side Management Plan (2013) screened each program using the total resource cost test, program administrator cost test, participant cost test, and rate impact measure.

Last reviewed: October 2020

Evaluation, Measurement and Verification

EM&V is important for demonstrating program effectiveness, increasing transparency and building support for energy efficiency programming.

Alberta

The following programs were evaluated for the 2017-18 FY: (1) Business, Non-Profit and Institutional (BNI); (2) Home Improvement Rebates (HIR); (3) Instant Savings; (4) Online Rebates, and; (5) Residential and Commercial Solar (RCSP). The primary objective of the evaluation was to verify claimed program energy savings, although the evaluator also reviewed project samples and internal controls, assessed program data tracking and management, and validated savings methodologies. The evaluation reports provided program-specific recommendations, which were implemented wherever possible during the 2018-19 fiscal year.

The following programs were evaluated for the 2018-19 FY: (1) Business, Non-Profit and Institutional (BNI); (2) Home Improvement Rebates (HIR); (3) Instant Savings; (4) Online Rebates; (5) Residential and Commercial Solar (RCSP); (6) Home Energy Plan (HEP); (7) Residential No-Charge Energy Savings (RNCES); (8) Affordable Housing Energy Solutions; (9) Non-profit Energy Efficiency Transition (NEET); (10) Custom Energy Solutions (CES), and; (11) Methane Energy Reduction (MER). The primary objective of the evaluation was to verify claimed program energy savings, although the evaluator also reviewed project samples and internal controls, assessed program data tracking and management, and validated prescriptive savings methodologies. This evaluation was expected to be completed by August 2019.

The following programs were evaluated for the 2019-20 FY: Affordable Housing Energy Solutions (AHES), Business Energy Solutions (BES), Custom Energy Solutions (CES), Methane Emissions Reduction (MER), Residential and Commercial Solar (RCSP), Residential Retail Products Program (RRPP) (Online Rebates, Home Energy Plan & Home Improvement Rebates) and Strategic Energy Management (SEM) (Cohort 1,2,3) and On-Site Energy Manager (OEM). The primary objective of the evaluation was to verify claimed program energy savings, although the evaluator also reviewed project samples and assessed program data tracking and management.

Last reviewed: October 2020

British Columbia

BC Hydro's savings are evaluated through its internal EM&V department with support by third party entities, overseen by internal evaluation committee including two external evaluation advisors. Evaluation Milestone Reports are filed with the BC Utilities Commission.

FortisBC Inc's (FBC) individual DSM programs are evaluated on rotation, primarily by 3rd party consultants according to industry best practicies. The annual savings for the entire portfolio reported in FBC's DSM Annual Reports are not specifically evaluated. The Annual Reports, including summary Evaluation reports, are submitted to the BC Utilities Commission.

Last reviewed: October 2020

Manitoba

Some electric and natural gas programs were evaluated by a third-party in 2016/17 and 2017/18.  The others were evaluated internally. No third-party evaluations were undertaken for 2018/19 and 2019/20 program activity as DSM was transitioning from Manitoba Hydro to Efficiency Manitoba.

Programs evaluated externally are listed below.

Electricity
2016/17

  • Commercial Refrigeration Program
  • Affordable Energy Program

2017/18

  • Power Smart Shops (currently named the Small Business Program)
  • Commercial HVAC Program

Natural Gas
2016/17

  • Natural Gas Optimization Program
  • Affordable Energy Program

2017/18

  • Power Smart Shops (current name is Small Business Program)
  • Commercial HVAC Program

Last reviewed: October 2020

New Brunswick

NB Power's individual programs are typically evaluated by a 3rd party on a 3 year cycle. They consist of interviews with staff and stakeholders (contracted parties, distributers, and participants), site visits, EM&V analysis, design and implementation analysis, and savings analysis.

Last reviewed: October 2020

Newfoundland and Labrador

Evaluation of federal-provincial funded programs is conducted as specified in the federal-provincial funding agreement, and is anticipated to include internal (including Auditor General) and third party audits.

Newfoundland Power's Home Energy Report program is evaluated annually by an external consultant. Other programs receive internal or external evaluations on a cycle basis..

Last reviewed: October 2020

Northwest Territories

No information available.

Last reviewed: October 2020

Nova Scotia

Savings for Efficiency Nova Scotia Electricity programs are evaluated by a third-party, and verified by a Nova Scotia Utility and Review Board appointed Verification Consultant. Evaluation reports are publicly available on the  Nova Scotia Utility and Review Board website

NRF programs are evaluated by a third-party, evaluation reports are not publicly available.  

Last reviewed: October 2020

Nunavut

No information on evaluation, measurement and verification available.

Last reviewed: October 2020

Ontario

Electricity
The IESO conducts impact, process and cost effectiveness evaluation. Impact evaluation aims to verify reported energy and demand savings and to measure free-ridership and spillover attributed to the program.  It consists of conducting site visits, desk reviews and document reviews as well as attribution surveys.  Process evaluation is an empirical examination of program design, development, delivery, and administration. It consists of doing surveys and interviews with program participants, non-participants, contractors, vendors and other key market actors.  Cost effectiveness evaluation determines whether program benefits outweighs the program costs.  It consists of estimating the total resource cost (TRC), program administrative cost (PAC) and levelized unit energy cost (LUEC) of a program. Program evaluation is done in accordance with the IESO EM&V Protocols and requirements. This protocol together with the Evaluation Reports published from 2007 to 2017 are found on the IESO website.

Natural Gas
Ontario Energy Board (OEB) staff coordinate the impact evaluation of DSM programs in Ontario. An Evaluation Contractor (EC) is selected to undertake this work with input and guidance from an Evaluation Advisory Committee comprised of stakeholders and industry experts. A combination of desk reviews and onsite verifications are conducted to verify the savings claimed by the utilities and the corresponding amounts in DSM accounts.

Last reviewed: October 2020

Prince Edward Island

Savings for EfficiencyPEI programs are evaluated by an external evaluator.

Last reviewed: October 2020

Quebec

Utility programs
Each program or program category is evaluated by an independent firm every 3-4 years.

Elecricity and natural gas efficiency reports are submitted to the Régie de l’énergie, and after an examination the Régie produces a report. Evaluation reports are available under "Suivis des résultats d'évaluation du PGEÉ” (1, 2). 

Transition energetique Quebec
 TEQ programs are evaluated by an external firm according to an established schedule:. Review of EcoPerformance and Forest Biomass programs initiated in 2019-2020;  review of the  Roulez vert started in 2020-2021.

Last reviewed: October 2020

Saskatchewan

No activities identified.

Last reviewed: October 2020

Yukon

No activities identified.

Last reviewed: October 2020

Support for Low-Income Energy Efficiency Programs

Specific policy goals and supports are required to overcome challenges in reaching low-income populations with energy efficiency programming.

Alberta

There are no known legislative or regulatory requirements that encourage delivery of energy efficiency programs to low-income or hard-to-reach populations.

Energy Efficiency Alberta administered the Affordable Housing Energy Solutions program in conjunction with the Ministry of Seniors and Housing. This program was closed in October 2019.

Other low-income initiatives include a Home Upgrade pilot program, in conjunction with Empower Me.  Various EEA grants also target new Canadians, urban Indigenous, seniors and affordable housing tenants.

The Government of Alberta also administered the Indigenous Energy Efficiency (Retrofit) Program.

The All One Sky Foundation operates the Energy Angels Program for low-income seniors in Calgary.

Last reviewed: October 2020

British Columbia

The “Demand Side Measures Regulation” (BC Reg 117/2017) to the Utilities Commission Act requires a public utility’s portfolio to include programs for low-income households and rental accommodations in order to be considered adequate (Section 3). The regulation requires regulators to consider participant and non-energy benefits and increase the benefits of particular programs (including low-income) by 40%. (Section 4(2)).

Electricity
BC Hydro and Fortis BC collaborate to administer the Energy Conservation Assistance Program (ECAP), the Energy Saving Kit (ESK) Program, and the Social Housing Retrofit Support Program (SHRSP).

Natural Gas
The ECAP and ESK also apply to natural gas customers.    FortisBC Energy also offers ‘top-ups’ to both their commercial space heat and water heater program for buildings owned or operated by a charity providing assistance to low-income persons, or a non-profit housing provider (including housing co-operatives and Indigenous Bands). The province, through the CleanBC Better Homes Program, co-funds FortisBC’s Income-Qualified incentives for energy efficient gas equipment.

Other
The CleanBC Social Housing Incentives Program provides funding to support custom electrification projects in the social housing sector.

Last reviewed: October 2020

Manitoba

Manitoba has an Affordable Energy Fund. Under the Energy Savings Act, Manitoba Hydro would contribute a proportion of its gross revenue from electricity exports to this fund, and the fund would ensure people with low-income, seniors, and people living in rural and northern Manitoba have access to programs. This fund supported historical low income programming.

In July 2007, the Public Utilities Board Order 99/07 required Central Gas Manitoba Inc. to contribute to the fund to support high-efficiency furnaces for low-income households and fixed income seniors. Manitoba Hydro also operated the Indigenous Energy Efficiency Program. Through this program, an energy efficiency specialist from Manitoba Hydro worked collaboratively with the Band Housing Manager from each Indigenous community to identify qualifying homes in the community for energy efficiency upgrades.

The Efficiency Manitoba Regulation directs that if it is practical to do so, at least 5% of Efficiency Manitoba's budget for demand-side management initiatives is allocated to initiatives targeting low-income or hard-to-reach customers. This would include Indigenous customers who qualify for the low-income programming.

Last reviewed: October 2020

New Brunswick

NB Power administers the Low Income Energy Efficiency program on behalf of the Department of Social Development.  The program is fully funded by the provincial government in the order of $2m annually.  It focuses on weatherization and some elements of heating system upgrades and direct install components.

NB Power also administers a Community Outreach Program, that works with non-profit and community organizations to help clients improve energy efficiency. 

Last reviewed: October 2020

Newfoundland and Labrador

There are no legislative or regulatory requirements regarding low-income programs, and neither utility administers any.

The Newfoundland and Labrador Housing Corporation administers a Home Energy Savings Program, targeting homeowners with incomes below $32,500/per year.

Last reviewed: October 2020

Northwest Territories

The NWT’s 2030 Energy Strategy, released in May 2018, planned to support a “Low-Income Home Energy Assistance” program.

Last reviewed: October 2020

Nova Scotia

EfficiencyOne’s 2020-2022 DSM plan includes “low income performance indicators”, which estimates low-income participants and resulting budgets and savings figures for a variety of programs. Participation is estimated using geographic census information, amongst other methods.

Programs include the HomeWarming program administered by Clean Foundation and Efficiency Nova Scotia; the Affordable Multi-Family Housing, the Efficient Product Installation, and First Nations programs administered by Efficiency Nova Scotia. 

The 2014 Electricity Efficiency and Conservation Plan committed to retrofit all low-income homes over 10 years. 

Last reviewed: October 2020

Nunavut

The Nunvaut Housing Corporation administers a Home Renovation Program.

Last reviewed: October 2020

Ontario

In 2017, as part of the Ontario Fair Hydro Plan, the government launched the Affordability Fund with $100 million in funding from the tax base. The program is overseen by an independent Trust and is designed to provide energy efficiency measures to households who are struggling to pay their electricity bills and who do not qualify for low income conservation programs.

Electricity
The Conservation First Framework 2015-2020 required that the province’s electricity Local Distribution Companies deliver of portfolio of energy savings programs to various customer sub-segments, including low-income customers. An August 2017 directive from the Minister of Energy required the IESO to design an deliver low-income programs across the province. In March 2019, the IESO received Ministerial directives to wind down the Conservation First Framework and implement the Interim Framework ("IF") over the April 2019 to December 2020 period.

Under IF, the IESO continues to centrally operate a province-wide Home Assistance Program ("HAP") and regionally targeted Indigenous energy efficiency programs. Similar to the CFF low income program, the IF HAP and indigenous programs are not required to pass cost-effectiveness tests.

Natural Gas
Under the 2015-2015 DSM framework Low-income programs by natural gas utilities are screened using a 0.70 benefit-cost threshold, using the TRC test, with a 15% benefit adder. The Board further states that low-income programs not passing this threshold can be proposed and approved on merit. The 2015-2020 DSM framework includes specific low-income targets under the program scorecard, which include energy savings or and project applications.

Natural gas low-income programs include Residential retrofit, Multi-residential retrofit, Indigenous (Legacy Union Gas) and New Construction (Legacy Enbridge Gas).

Last reviewed: October 2020

Prince Edward Island

There are no legislative or regulatory requirements for low-income energy efficiency programming.

EfficiencyPEI dedicated a significant share of its budget to programs targeting low-income populations, through program such as the Home Energy Low-Income Program (HELP), Home Insulation Rebates, Energy Efficiency Equipment Rebates, and the Home Comfort Program.

Last reviewed: October 2020

Quebec

There are no policies to support low-income programming, such as minimum budgets, adjustments to cost-effectiveness tests, or specific funds.

Econologis is a program administered by TEQ in partnership with Hydro-Québec.

Hydro-Québec offers “Rénovation énergétique, offree aux ménages à faibles revenue”. Hydro-Québec signs agreements with social and community organizations, such as social and co-op housing providers and municipalities.

Énergir offers supplementary financial assistance to low-income households, under program title “Soutine aux ménages à faible revenue”.

Last reviewed: October 2020

Saskatchewan

There are no legislative or regulatory requirements regarding programing for low-income and/or hard-to-reach populations.

SaskPower administered a Home Assistance Pilot Program with Saskatchewan Housing Corporation to deliver energy kits to low income households between 2015 and 2017/18. In 2019, SaskPower launched the Energy Assistance Pilot Program, targeting income qualified households in Regina and Saskatoon.

SaskEnergy operates the Tune-Up Assistance Program which delivers a home heating ‘tune-up’ to homeowners free of charge.  The program is open to households with a combined income of less than $68,000.

Last reviewed: October 2020

Yukon

No requirements or mandates for energy efficiency programs for low income or hard-to-reach populations identified.

Last reviewed: October 2020

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