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The guide outlines the landscape of renewable energy in South Africa, emphasizing the shift toward private procurement and the dominance of solar PV. It details two primary implementation models—embedded generation and wheeling—and provides a comprehensive breakdown of financing options, including bank-specific instruments and power purchase agreements. The document also highlights the strategic role of backup storage for peak shaving and load shifting, lists available South African tax incentives for energy efficiency and renewable assets, and identifies critical grid and regulatory hurdles businesses may encounter.

The report outlines a shift in South Africa's renewable energy sector from public procurement to private off-taker agreements, driven by electricity market liberalisation and corporate decarbonisation needs. It estimates a total investment potential of R132 billion for private renewable energy development and R16 billion for local component manufacturing by 2030. Key barriers include severe grid capacity constraints in high-resource provinces and policy uncertainty regarding the future of public procurement programmes.

The report finds that global progress toward SDG 7 is off track, particularly in Sub-Saharan Africa. While electricity access reached 92% in 2023, 666 million people remain unconnected. Clean cooking access stands at 74%, leaving 2.1 billion people dependent on polluting fuels. Renewable energy's share of total final energy consumption was 17.9% in 2022, and global energy intensity improved by 2.1% in 2022. International public financial flows to developing countries for clean energy reached USD 21.6 billion in 2023, though this remains below the 2016 peak of USD 28.4 billion.

The Production Gap Report 2025 finds that governments are planning more fossil fuel production than in 2023, with projected 2030 levels exceeding 1.5°C-consistent pathways by over 120%. While some countries are advancing clean energy transitions, 17 of 20 profiled major producers still plan to increase the production of at least one fossil fuel by 2030, undermining global climate commitments.

The document serves as an educational tool to explain the technical and economic aspects of Colombia's energy system and the transition toward a low-carbon economy. It distinguishes between energy sources and forms, details the electricity value chain, and explains the environmental necessity of decarbonization and 'Net-Zero' goals. The guide emphasizes that a 'just energy transition' requires both a shift in energy sources and a parallel economic transition to ensure labor reconversion and regional sustainability.

The author reflects on the mixed progress of 2024, noting record renewable deployment alongside rising global emissions and a political shift toward anti-climate positions. To overcome these hurdles, the author proposes a strategy focused on the lowest-cost electricity mix, including 'clean firm' technologies like nuclear and geothermal, and the use of carbon capture in heavy industry. The document emphasizes the need for regionally differentiated policies and a realistic acknowledgment of the long-term role of fossil fuels to build durable coalitions for action.

The report argues that a transatlantic electricity interconnector could enhance grid resilience and efficiency by leveraging the complementarity of time zones and weather patterns between Europe and North America. It highlights that a six-hour time difference creates arbitrage opportunities for solar production and demand, while uncorrelated or negatively correlated wind and temperature patterns can mitigate the impact of extreme weather. The author suggests that such an interconnector could be a more cost-effective tool for security of supply and decarbonisation than alternatives like nuclear power or hydrogen, though it would require significant government support and investment.

Ember modelling indicates that the UK can reduce biomass power generation by 55% to just 2% of total electricity generation by 2030 without compromising grid stability. This low-biomass pathway involves reducing biomass capacity by 2 GW—retaining only the equivalent of one unit at Drax—and replacing the lost generation primarily through increased power imports (6.9 TWh) and a slight increase in gas use (2.9 TWh). The report highlights that biomass power is significantly more expensive than gas or wind, costing £138/MWh under a Contract for Difference, and poses energy security risks due to its total reliance on imports, as Drax consumed 5.8 million tonnes of non-UK wood biomass in 2023. Despite the reduction in biomass, the UK would remain a net exporter of electricity, totaling 60 TWh annually.

In 2024, UK low-carbon renewables (wind, solar, and hydropower) are forecast to generate 37% of electricity (103 TWh), overtaking fossil fuels, which are set to provide 35% (97 TWh). Wind power is close to becoming the largest single source of UK power, forecast at 29% (82 TWh), just behind fossil gas at 30% (85 TWh). The year also marked the closure of the UK's last coal power plant, with gas power use set to decrease by 13% compared to 2023, reaching its lowest level since 1996. This decline in fossil fuel reliance is attributed to rising renewable generation, low electricity demand, and a 42% increase in net electricity imports.

The document introduces a novel five-step modelling framework designed to identify power infrastructure vulnerabilities and design cost-optimal decentralized renewable energy (DRE) solutions for islands and low-lying states. The framework involves identifying disruption hotspots, assessing disruptive potential, designing DRE systems using HOMER Pro, integrating local contextual factors, and evaluating resilience improvements. Testing the framework in Cuba revealed that municipalities with high electricity demand from industries and large buildings are most vulnerable to single-point failures. The results demonstrate that while DRE systems—incorporating solar PV, wind, battery storage, and biomass—improve power supply continuity, their effectiveness and cost are heavily influenced by local contexts, such as the US embargo on Cuba, which increased capital investment costs by 5-40% compared to global scenarios.

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.

India's tracked green finance for mitigation reached INR 3,712 billion (USD 50 billion) per annum in FY 2021/22, a 20% increase from 2019/20. However, this represents only approximately 30% of the annual finance needed to meet the country's Nationally Determined Contributions (NDC). Mitigation finance is primarily domestic (83%), with clean energy receiving the largest share (47%). Adaptation finance saw a nearly threefold increase to INR 1,092 billion (USD 15 billion) per year, dominated by government budgetary expenditure (98%) and focused on disaster risk management. The report highlights significant investment gaps, particularly in electric vehicles and on-farm agricultural adaptation, and recommends the development of a green finance taxonomy and enhanced private sector mobilization.

The document introduces energy parks as a strategy to meet rising electricity demand by integrating wind, solar, and storage with co-located loads like hydrogen electrolyzers and data centers. It outlines the evolution from simple solar farms to complex hybrids and identifies key barriers, including interconnection queues and utility monopolies. The authors propose a 'digital resource' paradigm shift and new state legal frameworks to enable these projects.

Canada has reduced power sector greenhouse gas emissions by 60% since 2005, primarily through phasing out coal. To reach net-zero, the country must mitigate another 47 Mt of CO2e while potentially doubling or tripling electricity generation by 2050. The transition relies on scaling wind, solar, and hydroelectric power, which are now often cheaper than fossil fuel alternatives. A net-zero grid is projected to reduce average household energy spending by 12% by 2050 and save households CAD 15 billion annually. Beyond economics, the shift reduces local pollutants like sulphur dioxide and mercury, which are linked to premature deaths and cognitive impairment. Key recommendations include implementing federal clean electricity regulations, facilitating interprovincial grid connections (interties), and streamlining provincial permitting processes.

The report examines how risk mitigation and transfer (RMT) instruments, such as political risk insurance and guarantees from development finance institutions (DFIs), help utility-scale renewable energy projects reach financial close in West and Central Africa. While these tools are critical for addressing offtaker and political risks, the authors argue they are insufficient to overcome structural macroeconomic barriers, including high sovereign debt and insolvent state-owned utilities. The report highlights innovative models, such as the re-deployable modular solar solution in Cameroon and the use of viable businesses as anchor loads in Ghana, as potential pathways for deployment in high-debt contexts.

The document introduces a framework to transition island states from vulnerable centralized grids to resilient decentralized renewable energy systems. Using Cuba as a test case, it demonstrates how identifying 'disruption hotspots' and applying context-specific modelling can maintain power supply during extreme weather events, though it notes that such resilience often requires higher upfront capital investments.

The report finds a significant gap between renewable energy targets and actual projects in development across the Caucasus and Central Asia (CCA) region. While six CCA countries have targets totaling 43 GW of renewable additions by 2030–2040, only 30 GW are in development, leaving a 13 GW deficit. Fossil fuel expansion remains dominant, with more than three times as much fossil capacity under construction (11.8 GW of oil and gas plus coal) as wind and utility-scale solar (3.5 GW). Azerbaijan, the COP29 host, is highlighted for limited ambition, with no wind or solar projects in development beyond 2027, calling into question its commitment to a 30% renewable share by 2030.

Zero Carbon Analytics finds that Japanese households with rooftop solar panels would have saved nearly 135% compared to those without in FY 2020, resulting in a net benefit of JPY 37,422 (USD 353). The report argues that Japan, which has the lowest clean energy share among G7 countries, can accelerate its energy transition by leveraging rooftop solar to overcome mountainous terrain constraints. It highlights the role of policy incentives like feed-in-tariffs (FiT) and tax credits in driving adoption in the US, EU, and UK, and suggests that Japan needs low-cost finance to reduce upfront costs and avoid diverting support toward unproven technologies like hydrogen.

Ember argues that the EU must accelerate the deployment of wind, solar, and clean flexibility solutions to achieve energy self-sufficiency and security. The response emphasizes the need for a "Smart Electrification" Action Plan, the complete cessation of Russian fossil fuel imports by 2027, and the modernization of grid infrastructure and cross-border interconnections, particularly in Central and Eastern Europe.

National renewable energy targets for 2030 currently aim for a collective doubling of capacity rather than the tripling agreed upon at COP28, despite market forecasts suggesting such a goal is achievable, particularly for solar and battery storage.