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The document argues that the rapid growth of generative AI is driving a significant increase in electricity demand, which threatens climate goals by incentivising the continued use of fossil fuels and diverting clean energy resources. It highlights a lack of transparency in corporate emissions reporting, where 'market-based' accounting masks actual grid impacts, and warns that 'moonshot' technology promises like nuclear fusion may act as mitigation deterrence. Specific examples include data centre growth in Ireland and Malaysia, and the rising emissions profiles of companies like Microsoft and Google.

The U.S. iron and steel sector accounts for 1.0% of total U.S. greenhouse gas emissions, totaling 63 MMT CO2e. While 70% of U.S. steel is already produced via electric arc furnaces (EAFs), which emit 75–90% less CO2 than blast furnaces when using clean energy, the remaining 30% of production relies on coal-fired blast furnaces. Key decarbonization pathways include expanding EAF capacity, deploying carbon capture, utilization, and storage (CCUS) for existing blast furnaces, and scaling hydrogen-based direct reduced iron (H2-DRI). Recommended state-level policies include providing low-interest loans or grants for capital financing, setting low-carbon procurement standards for public projects, and supporting clean hydrogen hub development.

The memo advocates for a shift from traditional renewable energy procurement to a 'higher-impact' approach that matches electricity consumption with carbon-free generation on an hourly and regional basis. It argues that this method better incentivizes the deployment of firm carbon-free resources and energy storage, leading to greater actual carbon reductions than traditional annual matching. The authors recommend that the Biden Administration set targets for federal facilities to achieve 100% round-the-clock carbon-free electricity consumption.

The Clean Air Task Force (CATF) analysis finds that optimistic forecasts of clean hydrogen costs falling below $1/kg are unrealistic because they overemphasize electrolyzer capital cost reductions while ignoring the dominant impact of electricity prices. Electricity costs account for 50%–75% of the total production cost. Even with projected 2030 improvements in PEM electrolyzer efficiency and capital costs, the authors conclude that average production costs will likely remain above $3/kg (Real 2022 USD) due to the lack of realistic access to clean firm electricity below $40/MWh. The paper recommends that policymakers prioritize clean hydrogen for sectors lacking other viable decarbonization alternatives, such as steel manufacturing and chemical refining, and focus on decarbonizing the power grid to enable scale-up.

The policy brief identifies a "planning gap" in Europe where national 2030 plans are disconnected from geopolitical realities and the long-term goal of 2050 climate neutrality. It recommends that EU Member States use the June 2024 NECP update deadline to implement a more comprehensive planning approach. Key recommendations include diversifying technology bets beyond renewables to include carbon capture and advanced nuclear, integrating land-use and social analysis into infrastructure planning, providing financial transparency to attract investment, and coordinating cross-border energy import strategies.

The report outlines a three-phase roadmap for deploying Small Modular Reactors (SMRs) in Poland, emphasizing the need for cross-government coordination, diverse financing mechanisms, and a transition from first-of-a-kind projects to a standardized fleet. It highlights SMRs' potential to decarbonize energy-intensive industries, repurpose coal sites, and provide district heating. The document recommends utilizing tools such as Contracts for Difference (CfDs), Regulated Asset Base (RAB) frameworks, and Power Purchase Agreements (PPAs) to mitigate construction and market risks. It also stresses the importance of securing early supply chain capacity in Europe and developing a high-level radioactive waste repository to ensure long-term sustainability.

The report outlines a three-phase roadmap for deploying small modular reactors (SMRs) in Poland to support decarbonization and energy security. It emphasizes the need for inter-ministerial coordination, the adoption of diverse financial instruments such as Contracts for Difference (CfD) and the Regulated Asset Base (RAB) model, and the transition from single demonstration projects to a commercial fleet. The document also highlights the strategic importance of securing supply chains, managing high-level radioactive waste, and leveraging EU funding and the IPCEI framework to position Poland as a regional SMR leader in Central and Eastern Europe.

The report argues that the proposed 1.2 GW Karpowership gas power plants are not aligned with a least-cost investment pathway for South Africa. Drawing on a study by Meridian Economics and the CSIR, it finds that the grid should prioritize rapid renewable energy build-out and storage, with new gas capacity not being economically optimal until the mid-2030s. The document concludes that commissioning these plants by 2022 would create an unnecessary economic burden for ratepayers and that the procurement process (RMIPP) was biased against renewable energy options.

The report finds that Canadian provinces are generally underplanning for industrial electricity growth and lagging in transmission investment, though hydro-led jurisdictions possess a natural advantage in system flexibility. It recommends that the federal government support inter-provincial planning, provide strategic funding for grid build-out, implement flexible Clean Electricity Regulations, and prioritize system flexibility in investment programs.

FAST-Infra is a public-private partnership involving banks, asset managers, governments, and development banks aimed at accelerating private investment in sustainable infrastructure in developing countries. The initiative is developing a sustainable infrastructure labelling system to guide governments, developers, and institutional investors, alongside four pilot market mechanisms: a technology-enabled securitization platform, a global off-take/revenue guarantee provider, an open-sourced managed co-lending portfolio programme, and a sustainable financing facility for national development banks.

The Global Renewable Independent Power Supplier (Grips) is a proposed renewable energy service company designed to replace carbon-intensive diesel generators for industrial anchor clients in remote areas of developing countries. By utilizing an all-equity financing model and a diversified portfolio of hybrid energy plants, Grips aims to attract private-sector investment and offer shorter-term power purchase agreements (PPAs) that align with industrial planning horizons. The instrument targets a global off-grid diesel market estimated at 29 GW and seeks an initial USD 5 million for corporate governance and pilot project identification, with further requirements of USD 20-60 million for the first pilot location. Successful implementation is projected to avoid up to 2.5 million tonnes of CO2 per year through 2030.

The Rooftop Solar Private Sector Financing Facility aims to address the lack of high-quality debt capital in India's rooftop solar sector. By aggregating small projects into a structured investment, the facility intends to attract institutional investors and demonstrate the commercial viability of asset-backed securities. The proposed mechanism involves an aggregation phase using a warehouse line of credit, followed by a securitization phase to issue bonds to domestic and international investors. The facility targets the addition of 500 MW of capacity and 20,000 jobs by 2022, with an initial capital requirement of $100 million for its pilot stage.

The document details three community solar initiatives in Colorado, Iowa, and Minnesota. Grand Valley Power Cooperative developed a self-funded 17 kW array and a 24 kW low-income project with Grid Alternatives. Cedar Falls Utilities launched a 1.5 MW 'Simple Solar' program using a power purchasing agreement. Lake Region Electric Cooperative built a 25 kW array. All three utilized on-bill financing—adding lease payments to monthly utility bills—to remove upfront cost barriers, often substituting credit checks with utility payment history to expand eligibility.

The report examines the challenges associated with India's Firm & Dispatchable Renewable Energy (FDRE) tenders, noting that many have been cancelled or partially awarded due to developer struggles with their complexity. It argues that current discussions oversimplify the problem by focusing on relaxing demand requirements or finding complementary wind sites, while ignoring the critical role of power market volatility and risk management. The authors propose a transition from 'Developers 1.0'—who focused on levelized cost and CAPEX efficiency—to 'Developers 2.0,' who utilize market modeling, portfolio management, and active trading to handle price, volume, and cannibalization risks. This evolution is presented as essential for India to reach its 2030 goal of 50% installed capacity from renewable energy, including large hydro.

The document argues that the One Big Beautiful Bill Act (OBBBA) will negatively impact the U.S. economy by increasing energy bills and reducing GDP. To counter this, it urges state governments to accelerate the procurement and permitting of wind and solar projects to ensure they qualify for federal investment tax credits (ITC) and production tax credits (PTC) before the December 31, 2027 deadline, specifically noting a 'safe harbor' eligibility for projects beginning construction by July 4, 2026.

The document argues that the One Big Beautiful Bill Act (OBBBA) will negatively impact the U.S. economy, costing households $170 billion in energy bills and reducing GDP by $1.1 trillion by 2035. To counter this, it urges states to reduce clean energy costs by improving siting and permitting, optimizing existing transmission, promoting self-supply for large customers, and enhancing procurement practices.

The document examines the growth of embedded solar generation in South Africa, which reached over 3.2 GW of installed capacity in 18 months. It compares four primary procurement models: outright purchase, commercial debt, solar Power Purchase Agreements (PPAs), and embedded generation leasing. While outright purchases offer the best long-term return on investment, PPAs and leasing are increasing in popularity—accounting for 20% to 30% of new commercial and industrial projects—due to their ability to reduce upfront costs and system performance risks. The brief also details specific financial incentives, including the 12B tax allowance and feed-in tariffs, and provides a decision framework for businesses to select the most appropriate financing model based on their capital availability and risk appetite.

The document details a green finance mechanism where a solar developer finances, installs, and maintains a rooftop PV system on a commercial property. The property owner receives rental income, while the tenant purchases the generated electricity via a Power Purchase Agreement (PPA). A specific implementation for Pick n Pay in Brackenfell, Cape Town, resulted in a 22.12% reduction in the outlet's carbon footprint and created a new annual revenue stream of approximately R188,000 for the property owner.

The guideline outlines a three-step process for farmers to achieve energy resilience: conducting energy audits to identify efficiencies, evaluating alternative energy technologies based on specific production needs, and navigating the financial and quality assurance aspects of implementation. It highlights the critical role of energy efficiency as a prerequisite to reducing the capital requirements of renewable systems and provides detailed comparisons of technologies such as solar PV, biogas, and battery storage, alongside various South African financing mechanisms and tax incentives.

The document provides a guide for Western Cape businesses on adopting solar PV to reduce energy costs and carbon footprints. It details various financing models—including outright purchase, debt finance, and Power Purchase Agreements (PPAs)—and provides pricing benchmarks for 2025/26. The brief highlights the role of municipal feed-in tariffs and national tax incentives, while warning of risks related to changing utility tariff structures and policy shifts.