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The document explores the potential of superhot rock energy in North America, estimating that 13% of the land area has potential at depths below 12.5 km. It argues that this resource could provide massive amounts of carbon-free electricity, leverage existing oil and gas expertise, and require significantly less land than other energy sources, with mature costs potentially as low as $25-40 per MWh.

The document argues that Oceania possesses significant superhot rock energy potential, with modeling suggesting that 15% of the region's land area has resources at depths below 12.5 km. It highlights that just 1% of this resource could provide 1.1 terawatts of energy capacity. The report suggests that the region's existing oil and gas expertise could be leveraged to commercialize this technology, which offers high energy density and low land-use requirements compared to other renewables. While not expected to meet 2030 climate goals, it is presented as a long-term solution for decarbonization and grid stability.

The report argues that the UK is currently off track to meet its 2030 NDC and sixth carbon budget, necessitating a shift toward 'accountability and implementation'. It advocates for a systems-based approach that complements electrification with carbon capture and storage (CCS), low-carbon hydrogen, nuclear energy, and aggressive methane mitigation. Key recommendations include establishing a Methane Action Plan, creating a 'producer responsibility' policy for CO2 storage, and prioritising low-carbon hydrogen for 'no-regrets' industrial sectors like refining and ammonia production. The document also emphasises the need for international collaboration, particularly with the EU and emerging economies, to scale these technologies and maintain the UK's global climate leadership.

The report argues that Poland, as one of Europe's most carbon-intensive economies, must adopt a diversified technology portfolio to achieve climate neutrality. It recommends a shift from coal (currently 70% of the power mix) toward a combination of renewables, nuclear energy, carbon capture and storage (CCS), clean hydrogen, and superhot rock geothermal energy. The authors emphasize that restricting technology options would significantly increase system costs and infrastructure needs. Key policy recommendations include implementing 'carbon contracts for difference' to advance CCS, prioritizing clean hydrogen for 'no regrets' industrial sectors, and reforming the nuclear industry through standardized, product-based business models. Additionally, the report calls for urgent action to reduce methane emissions from the oil and gas sector and the mapping of thousands of abandoned wells. Public polling indicates strong Polish support for advanced nuclear (63%) and superhot rock energy (66%).

The report argues that next-generation geothermal technologies, specifically Enhanced Geothermal Systems (EGS) and closed-loop systems, can expand U.S. geothermal resource potential from 40 GW to over 5,000 GW by engineering reservoirs in ubiquitous hot rock. It outlines a two-phase pathway: reaching 'liftoff' by 2030 through 2-5 GW of deployment across 5-10 geologic settings, followed by scaling to 90-132 GW by 2050. Key barriers identified include high up-front capital costs, long federal permitting timelines (7-10 years), and the need for power purchase agreements (PPAs) that value clean firm and flexible power. The report highlights that the industry can leverage the existing oil and gas workforce and supply chain to accelerate deployment.

The report presents a preliminary techno-economic model for superhot rock energy, estimating that Nth-of-a-kind (NOAK) plants could achieve a levelized cost of electricity (LCOE) between $20-35 per megawatt-hour (MWh). The model categorizes costs into well field development, power plant construction, and project financing, assuming a 250 MWe plant capacity and a 30-year lifetime. Key findings indicate that flow rate is the most significant driver of LCOE, while reductions in drilling costs alone have a relatively minor impact on overall capital expenditures. The analysis compares two technology regimes: one based on current drilling and casing technology and another assuming advanced 'energy drilling' that eliminates the need for casing. The report emphasizes that commercialization depends on breakthroughs in high-temperature materials, such as casing and cementing, and thermal reservoir creation.

The Clean Air Task Force (CATF) recommends that the EU prioritise 'no regrets' industrial sectors for hydrogen deployment, utilize all clean production pathways (including 'blue' hydrogen), and site production close to consumption to minimize transport inefficiencies. The report emphasizes that public funding should be matched to projects that provide socio-economic benefits to local communities and that a comprehensive EU database should be established to ensure transparency and collaboration.

RMI provides recommendations for Indonesia's coal transition based on a model applied to the Java-Bali grid, emphasizing the integration of coal retirement and clean energy deployment to ensure financial feasibility and emissions reductions.

The report finds that importing large quantities of low-carbon hydrogen to Europe is expensive and energy-inefficient due to hydrogen's low volumetric energy density. Pipeline transport is consistently more cost-effective than maritime shipping, with Norway and Algeria identified as the most competitive pipeline sources. Among maritime options, ammonia is the lowest-cost carrier, with the Arabian Gulf being the most economical exporter. The analysis suggests that importing LNG to produce hydrogen at the point of import may be more feasible than long-distance hydrogen transport. CATF recommends that the European Commission re-examine its 2030 target of 20 million tonnes of clean hydrogen per year, as it may lack a clear basis.

The study identifies biochar as a viable land-based mitigation technology in Colombia, estimating that 10% of agricultural residual biomass could be converted to biochar, with each tonne avoiding 1 to 2.2 t of CO2eq over 100 years. However, production is hindered by high investment costs and inadequate policies, with raw feedstock costs accounting for 33% to 74% of total expenses depending on the pyrolysis technology used.

The report examines the use of energy service agreements (ESAs) to overcome financial and structural barriers to decarbonizing affordable multifamily housing in California, specifically addressing split incentives and upfront costs.

The report evaluates the potential for offshore carbon capture and storage (CCS) in the US mid-Atlantic to compensate for limited onshore capacity. Using the SimCCS modeling toolset, the study identifies 199 facilities across 15 industry sectors with a total of 31.47 Mt of annual capturable CO2. It finds that while offshore storage capacity is vast—estimated at 621,221 MtCO2 across 125 candidate sites—the costs are significantly higher than onshore benchmarks, ranging from 95.5 to 147.9 $/tCO2. This cost disparity is primarily driven by offshore pipeline installation and storage expenses. The analysis suggests that capturing the full 31.47 MtCO2 would require a 7,789 km branched pipeline network and that emission prices between $95.5 and $103.5 per tonne could incentivize initial capture efforts.

The document asserts that nuclear energy is essential for a decarbonized global energy system to provide 'clean firm' power, reducing reliance on over-built variable renewables and expensive long-duration storage. It identifies a 'profoundly dysfunctional' current delivery model characterized by high costs and delays, exemplified by the Vogtle 3 and 4 projects in Georgia. To achieve a target build rate of hundreds of Gigawatts per year, the author proposes transitioning from bespoke construction projects to standardized, commoditized 'products' with capital costs below $4,000/kw and delivery times of 3-5 years. Key recommendations for U.S. policy include reforming the Nuclear Regulatory Commission (NRC) to adopt performance-based licensing, establishing a 'sandbox' for testing new designs, creating an International Bank for Nuclear Infrastructure, and ensuring the domestic availability of high assay low enriched uranium (HALEU).

The report presents a preliminary techno-economic model for superhot rock energy, estimating that NOAK plants could achieve a competitive LCOE of $20-35 per megawatt-hour (MWh). The model categorizes costs into well field development, power plant construction, and project financing, assuming the commercial availability of innovations in deep drilling and reservoir creation. Sensitivity analysis identifies mass flow rate as the most critical driver of economics, followed by plant capacity and the drilling learning curve. The analysis emphasizes that while drilling costs are a significant part of well field expenses, they have a relatively small impact on overall LCOE compared to the power output per well.

Low-temperature industrial heat (up to 165C) accounts for approximately 35 percent of U.S. industrial process heat demand and produced 171 million metric tons of CO2 in 2021. Industrial heat pumps are identified as the most efficient and cost-effective zero-carbon solution for this range, outperforming alternatives like electrolytic hydrogen, bioenergy, and carbon capture and sequestration. Modeling suggests that a full transition to heat pumps by 2050 would reduce industry GHG emissions by 284 MMT (16 percent) relative to a business-as-usual case and prevent over 3,000 premature deaths by 2050. Economically, this shift could increase U.S. GDP by over $42 billion in 2030 and create 275,000 jobs in 2030. While heat pumps have higher capital costs than natural gas technologies, the gap is small and likely narrowing due to rising natural gas prices and falling electricity costs. The report recommends federal financial support via the DOE's AMMTO and IEDO offices, as well as the implementation of technology-neutral energy efficiency and GHG emission standards.

The Netherlands aims to reduce industrial GHG emissions by 59% by 2030 and reach climate neutrality by 2050. The government employs a 'carrot-and-stick' approach, using a National CO2 Tax as a floor price and the SDE++ subsidy scheme to support low-carbon technologies. CCS is currently prioritized as a cost-effective transition technology, with projects like Porthos nearing final investment decisions. Hydrogen strategy involves a transition from grey to blue and eventually green hydrogen, supported by plans for a national 'hydrogen backbone' utilizing existing gas infrastructure. However, the report notes that current policy is insufficient to enable gigawatt-scale green hydrogen projects, and the SDE++ scheme tends to favor mature technologies over long-term innovation.

South Africa has the technical potential to produce 3.2 to 4.5 billion litres of SAF annually, depending on the use of green hydrogen. The most cost-efficient route is the first-generation (1G) alcohol-to-jet (AtJ) pathway using sugarcane A-molasses, while the largest volume potential comes from invasive alien plants (IAPs) and garden waste via gasification and Fischer-Tropsch (GFT) synthesis. A domestic SAF industry could create over 100,000 direct green jobs, improve the national balance of trade by up to R159.5 billion per year, and provide alternative livelihoods for coal truckers in mining regions.

The report evaluates zero-emission alternatives to natural gas-driven pneumatic controllers, which are known to release methane. It focuses on electric controllers and solar-powered instrument air systems, finding that both are cost-effective compared to the social cost of methane. The analysis highlights that electric controllers generally offer the lowest abatement costs and that recent technological advancements, such as vertical solar panel stacking and new failsafe systems for Emergency Shut Down (ESD), have expanded the viability of these technologies.

The report outlines a strategic policy framework to accelerate the transition to electric vehicles (EVs) in the U.S., aiming for 100% new EV sales by 2030-2035. It emphasizes the need for strong national fuel economy and emissions standards, equity-focused incentives, expanded charging infrastructure, and the growth of domestic battery and vehicle manufacturing. The document also details technical and regulatory requirements for grid integration, including streamlined interconnection, updated building codes, and smart electricity rate designs to ensure a reliable and equitable energy transition.

The report argues that transitioning the U.S. transportation sector to 100 percent electric vehicle (EV) sales by 2030-2035, paired with a 90 percent clean grid by 2035, is technologically feasible and economically beneficial. It outlines a strategic framework focusing on national emission standards, targeted financial incentives, the expansion of charging infrastructure, and the growth of domestic manufacturing. The authors emphasize that this transition must prioritize environmental justice and social equity, specifically targeting low-to-moderate-income communities and those disproportionately affected by transportation pollution. Key recommendations include reforming the federal EV tax credit into a point-of-sale rebate, implementing 'made in America' policies for battery production, and streamlining grid interconnection and building codes to support rapid EVSE deployment.