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The document highlights the escalating risk of wildfires in Canada, using the Jasper, Alberta fire as a case study to illustrate the dangers of fragmented governance and outdated policies. It proposes a three-pronged adaptation toolkit focusing on restricting new development in high-risk areas, retrofitting existing buildings with FireSmart materials, and implementing landscape-level risk reduction such as fuel thinning and Indigenous cultural burning.

The document highlights the urgent need for Canada to enhance wildfire preparedness, citing the Jasper fire as a critical warning. It identifies gaps in current zoning and governance and proposes a three-pronged adaptation toolkit involving land-use regulation, building retrofits, and landscape-level fuel management.

The document describes Canada's dual-track carbon pricing approach, distinguishing between consumer carbon taxes and industrial systems for large emitters. It details two primary industrial models—emissions-intensity based systems and cap-and-trade systems—and compares their application across different Canadian jurisdictions, highlighting the specific frameworks used in Alberta, Quebec, and the federal backstop system.

Canada employs a dual carbon pricing approach consisting of a consumer carbon price and an industrial carbon price for large emitters. To prevent carbon leakage and protect trade-exposed industries, Canada utilizes large-emitter trading systems (LETS), which primarily take the form of intensity-based systems or cap-and-trade. There are nine LETS across the country, including the federal output-based pricing system (OBPS) and Alberta's Technology Innovation and Emissions Reduction (TIER) Regulation, the latter being the largest due to Alberta's share of industrial emissions. Quebec operates the only cap-and-trade system in Canada, which is integrated with the Western Climate Initiative. The Northwest Territories uses a unique fuel levy with rebates rather than a trading system.

Small modular reactors (SMRs) are viewed as a potential source of reliable, emissions-free electricity in Canada, capable of replacing fossil-fuel baseload plants and diesel generators in remote areas. While Canada possesses an established nuclear industry and uranium reserves, SMRs are currently classified as 'wild cards' because they are not yet commercially viable and face significant technical, financial, and regulatory hurdles. Current Canadian efforts include a joint strategic plan by Ontario, New Brunswick, Saskatchewan, and Alberta, with specific projects such as a reactor at the Darlington site and a micro-reactor at Chalk River. However, global examples, such as cancelled projects in the United States, highlight a trend of mounting costs and lengthening timelines that challenge the technology's competitiveness against wind and solar power.

Advanced geothermal energy, including enhanced, closed-loop, and deep geothermal technologies, offers a potential source of emissions-free, dispatchable power and heat. While it faces high upfront costs and a lack of commercial scale, recent innovations and investments—such as the Canadian government's $90 million investment in Eavor Technologies—are moving the sector toward market readiness. The Canadian Climate Institute classifies it as a 'wild card' due to uncertainties regarding performance, reliability, and replicability at scale.

The document identifies concentrated carbon capture as a "safe bet" for industrial processes with high-concentration CO2 streams, such as cement and ammonia production, while categorizing non-concentrated applications (e.g., natural gas power) as "risky bets." It highlights the technology's potential role in Canada's net-zero pathways, noting that while it could reduce oil and gas emissions by 17 to 50 megatonnes by 2030, its large-scale deployment depends on long-term policy certainty and government financial support, including investment tax credits.

The document identifies smart grids as a 'safe bet' for Canada's energy transition, noting that while technologies like smart meters and virtual power plants are proven, their widespread adoption is hindered by regulatory barriers and consumer hesitation. It highlights existing provincial initiatives in Quebec, Ontario, and British Columbia as models for scaling digital grid infrastructure to manage increasing electricity demand and integrate variable renewable energy.

The document identifies smart grids as 'safe bets' for Canada's energy transition, capable of increasing efficiency and reducing costs by managing peak demand through supply-side solutions like battery storage and demand-side tools like virtual power plants. While provinces such as British Columbia, Quebec, and Ontario have implemented various smart grid applications, widespread adoption is hindered by regulatory barriers, outdated utility incentives, and consumer hesitancy. The author argues that provincial policymakers and regulators must update legislation and incentives to accelerate the deployment of digital grid infrastructure to meet growing electricity demand.

Small modular reactors (SMRs) are emerging nuclear energy technologies producing 300 MW or less, offering a potential source of reliable, emission-free electricity for Canada's energy transition. While Canada possesses a strong nuclear industry and uranium reserves, SMRs are currently classified as a 'wild-card' technology due to high costs, regulatory hurdles, and a lack of commercial viability. Despite these challenges, several Canadian provinces and the federal government are investing in SMR development, with projects planned for Ontario, Saskatchewan, and New Brunswick.

Onshore wind is a mature, low-cost technology central to Canada's energy transition, though its rapid expansion is hindered by slow regulatory approvals and local resistance.

The document describes onshore wind energy as a mature, cost-effective technology essential for the decarbonization of Canada's electrical grid. It highlights Canada's position as a global leader in installed capacity and identifies regulatory hurdles and social acceptance as the primary barriers to faster deployment.

The document distinguishes between 'safe bet' concentrated-stream carbon capture and 'wild card' unconcentrated applications, noting that while the former is commercially viable for certain heavy emitters, the overall sector has a history of underperformance and high costs. In Canada, the technology is projected to contribute between 17 and 50 megatonnes of emissions reductions in the oil and gas sector by 2030, supported by federal investment tax credits of up to 50%. However, the author cautions that deployment depends on policy durability and prudent use of public funds, particularly as demand for oil and gas is expected to decline during the energy transition.

The document examines advanced geothermal energy, categorizing it as a 'risky bet' due to high capital costs and unproven large-scale reliability, despite its potential to provide carbon-neutral, dispatchable power and heat globally. It highlights three primary technologies: advanced geothermal (using hydraulic fracturing), closed-loop systems, and deep geothermal. While companies like Calgary-based Eavor Technologies and Fervo Energy are launching commercial projects in Germany and the US, the technology must significantly reduce costs—potentially by 90% by 2035 according to US Department of Energy goals—to compete with gas and nuclear power.

Canada's total emissions in 2023 were estimated at 702 megatonnes of carbon dioxide-equivalent (Mt), a 0.8 per cent decrease from 2022 and 7.8 per cent below 2005 levels. While the electricity sector has seen a 62 per cent reduction since 2005, oil and gas emissions have risen by 12.1 per cent in the same period, now accounting for 31 per cent of the national total. Despite economic growth and a population increase of 1.16 million people in 2023, emissions fell due to climate policy and market drivers, though a 7 per cent annual reduction in emissions per unit of GDP is required to meet the 2030 target of a 40–45 per cent reduction below 2005 levels.

The report details a spatial modelling approach to assess climate risks for new housing in Canada, focusing on flood and wildfire hazards under current and 2030 RCP 4.5 scenarios. It describes the allocation of new units across 5,161 census subdivisions and the specific estimation methods used to determine average annual loss (AAL) for these new developments.

The analysis finds that complying with revised Clean Electricity Regulations (CER) is technically achievable for SaskPower without jeopardizing grid reliability. While the Saskatchewan government previously claimed rates would double by 2035, this modelling indicates that residential electricity rates would only increase by 6–9% relative to a baseline scenario. The CER would significantly reduce cumulative greenhouse gas emissions between 2025 and 2050 by accelerating the adoption of carbon capture and storage and increasing imports of clean electricity from Manitoba.

The report concludes that Saskatchewan can comply with a revised version of the federal Clean Electricity Regulations (CER) without compromising grid reliability and with only a marginal increase in residential electricity rates (6% to 9% by 2035) compared to SaskPower's reference scenario. Using the COPPER model, the analysis shows that while the CER would require additional capital investments of $4 billion to $6.5 billion by 2035, it would significantly reduce cumulative greenhouse gas emissions between 2025 and 2050 compared to the province's current plans. The report emphasizes the central role of wind power and the importance of federal investment tax credits in maintaining affordability during the transition to net-zero electricity by 2050.

The Canadian Climate Institute asserts that continuing the expansion of gas infrastructure for building heating creates financial risks for ratepayers and hinders climate targets. It advocates for an incremental transition to electric heat pumps and updated regulatory frameworks that consider alternatives to gas expansion, arguing that low-carbon gases like hydrogen and biomethane cannot realistically replace fossil gas for building heat due to cost and supply constraints.

The Canadian Climate Institute responds to criticisms from the Canadian Gas Association, asserting that a gradual transition to electric heating is necessary to avoid costly stranded assets. The Institute argues that continuing to expand gas infrastructure by default risks burdening taxpayers for decades, as these assets may become obsolete before their 40-year lifespan ends. It dismisses the idea that low-carbon gases like hydrogen and biomethane can fully replace fossil gas due to limited supply and high costs, advocating instead for energy-efficient electric heat pumps and better regulatory planning to ensure a just transition.