Search Climate Insights Directory

Turkey needs to commission 8 GW of new wind and solar capacity annually to meet its 2035 goals, requiring an estimated $28 billion in additional grid investment. The report identifies critical bottlenecks in grid connection capacity, particularly for unlicensed and storage-based projects, and suggests accelerating permitting through the 2025 "super permit" legislation. It recommends diversifying energy sources via floating solar and offshore wind, leveraging hybrid solar installations at hydroelectric plants to mitigate drought risks, and increasing regional interconnection capacity to enhance grid flexibility. Additionally, it argues that the $8.7 billion purchase guarantee for domestic coal plants contradicts renewable goals and complicates system management.

Türkiye aims for 120 GW of wind and solar capacity by 2035, requiring an annual addition of 8 GW. The primary obstacle is limited grid capacity, which necessitates an estimated $28 billion in additional investment. The report recommends resolving permitting bottlenecks for 33 GW of storage-integrated projects, diversifying energy sources through floating solar and offshore wind auctions, and leveraging regional interconnections to enhance grid flexibility. It also highlights a policy contradiction in the $8.7 billion purchase guarantee for domestic coal plants, which may hinder renewable goals and system stability.

The European Union remains vulnerable to global energy shocks due to a high dependency on fossil fuel imports, nearly 60% of its primary energy supply. While the EU has reduced reliance on Russian gas, it has increased exposure to US LNG, which the report identifies as a significant political and economic risk. To achieve energy sovereignty, the report proposes five key actions: accelerating electrification (where 89% of demand is technically electrifiable), enhancing grid interconnectivity, deploying energy storage and demand flexibility, decarbonising heavy industry through green public procurement and product mandates, and leveraging the EU Methane Regulation (EU MER) to disincentivise high-emitting imports. Financing this transition will require an average of EUR1.5tn per year through 2050, primarily driven by private capital and the GSS+ bond market.

The Colombian electrical transmission sector faces a structural lag as generation capacity is projected to reach 38.9 GW by 2030. The National Interconnected System (SIN) is nearing operational limits, with less than 5% transport capacity available and 90% of substations expected to exhaust short-circuit interruption capacity within five years. Execution is a critical failure point, with 55% of the 20 active transmission projects delayed, including the Bacatá-Norte and Sogamoso Norte-Nueva Esperanza projects. These delays are attributed to socio-environmental factors, licensing difficulties, and poor coordination between national energy planning and land-use instruments. To address this, the 'Plan Maestro de Modernización y Expansión de la infraestructura de Transmisión Eléctrica' proposes 98 strategic works, 44 of which could resolve over 149 operational restrictions by 2037. Additionally, the UPME adopted the 'Modelo de Relacionamiento Territorial' in 2025 to better integrate socio-environmental and cultural criteria into planning.

The document examines how reliance on imported oil and liquefied natural gas (LNG) exposes Asian economies to price shocks and supply disruptions, particularly those stemming from conflicts in the Middle East. It analyzes the economic impacts on countries like Singapore, Thailand, and Japan, highlighting how fuel price volatility drives inflation and weakens currencies. The report argues that returning to coal as a short-term fallback is economically and environmentally risky compared to renewables. It recommends investing in regional connected grids and clean technology supply chains to build long-term resilience and energy security.

The EU significantly expanded its renewable energy capacity between 2022 and 2025, with solar PV reaching 406 GW and wind reaching 246 GW. This transition reduced the bloc's reliance on imported fossil fuels, saving an estimated EUR 58 billion in coal and gas import costs. While countries like Spain have successfully delinked electricity prices from gas costs, others like Italy remain highly vulnerable due to continued dependence on imported fossil fuels, particularly during the 2026 Strait of Hormuz blockade.

The report examines the risks of AI integration in the ASEAN power sector, highlighting data limitations, regulatory uncertainty, and cybersecurity vulnerabilities. It argues that while AI is a 'low-hanging fruit' for accelerating the energy transition, its success depends on strengthening data foundations, updating grid codes, and building AI-ready workforces through phased roll-outs and 'AI sandboxes'.

The document examines the trend of ASEAN countries increasing LNG import infrastructure, with planned investments of USD 20.4 billion. It argues that LNG fails to provide true energy security due to its sensitivity to geopolitical shocks, such as the Russia-Ukraine war and tensions in the Middle East, and competition for supply with Europe. The author suggests that Southeast Asian nations should instead prioritize domestic renewable energy, leverage their own solar manufacturing capacity, and accelerate the ASEAN Power Grid to enhance resilience and reduce import dependency.

The document positions renewable energy as a core pillar of Japan's national security, noting that the country's energy import dependency reached 87.4% in 2024. It argues that the current 7th Strategic Energy Plan is insufficient because it maintains high fossil fuel targets (30-40% by 2040) that conflict with 1.5°C climate goals. The author proposes a four-step policy framework—expanding grid capacity, accelerating permitting, expanding distributed energy, and utilizing long-term power purchase agreements—to achieve a clean energy ratio of 80% or more by 2040. This transition is estimated to potentially save up to 3.4 trillion yen in fossil fuel costs by 2035 and requires approximately 38 trillion yen in investment, which is roughly 25% of Japan's 150 trillion yen GX investment plan.

The report positions renewable energy expansion as a national security imperative for Japan, which had an energy import dependence of 87.4% in 2024. It argues that the current 7th Strategic Energy Plan is insufficient for the 1.5°C target and proposes a more ambitious pathway to reach 80-90% clean power by 2035-2040. Key recommendations include upscaling grid capacity, fast-tracking permitting, expanding distributed energy, and using long-term offtake agreements to lower capital costs. The document highlights Japan's potential in offshore wind, agrivoltaics, and perovskite solar cells as means to reduce reliance on imported fossil fuels and Chinese crystalline-silicon PV.

The study finds that while solar PV is the backbone of Nigeria's net-zero electricity system, the lowest-cost and most reliable pathways require a technology-neutral approach that includes nuclear power and natural gas with carbon capture and storage (CCS). Restricting these firm low-carbon technologies increases total installed capacity by approximately 50% and annual investment requirements by about 7%. Under baseline demand, net-zero timelines require average annual investments of US$7–10 billion, but a high-demand scenario aligned with Nigeria Agenda 2050 would increase average annual investment to US$35.8 billion and nearly triple total system costs.

The document advocates for demand-side flexibility in Canada to manage increasing electricity demand from electrification and AI data centers. It highlights that relying solely on new production capacity is costly and inefficient. By using tools like smart thermostats, EV charging management, and virtual power plants, the grid can reduce peak loads (peak shaving) or shift consumption to off-peak hours (load shifting). This approach benefits utilities by delaying infrastructure upgrades and benefits consumers through lower bills. The text cites successful pilot programs in Quebec, British Columbia, and Ontario, while urging federal and provincial governments to integrate demand flexibility into clean energy policies and regulations.

The report argues that flexible demand—the ability to shift or reduce electricity use during peak periods—can significantly lower system costs and defer expensive infrastructure upgrades in Canada. While some provinces like Ontario, Quebec, and British Columbia are implementing demand-side management (DSM) programs, the report finds that these resources remain under-deployed due to outdated regulatory frameworks, misaligned financial incentives for utilities and consumers, and a tendency for planners to treat DSM as a passive load reduction rather than an active grid resource.

The COP30 summit in Belém concluded with the "Mutirão global" agreement, which maintained negotiations but postponed key decisions on fossil fuels and adaptation finance. While the summit saw record indigenous participation and significant funding commitments for tropical forests and energy infrastructure, it failed to establish a clear mechanism to limit warming to 1.5°C and lacked a process for reviewing Nationally Determined Contributions (NDCs). The document urges reporters to translate these diplomatic results into human-centric stories focusing on vulnerable communities and territorial rights.

The report finds that the EU is not on track to meet its 2030 interconnection targets, with 80% of the power system expected to miss the goal. To reach an optimal grid by 2040, Europe needs to nearly double its interconnection capacity, adding 151 GW. This expansion requires an estimated €150 billion in investment, leaving a €30 billion public funding gap in the proposed 2028-2034 Connecting Europe Facility for Energy (CEF-E) budget.

The joint statement argues that while the Industrial Accelerator Act (IAA) can transform Central and Eastern Europe (CEE) into clean industry hubs, it risks exacerbating regional disparities due to the CEE's narrower fiscal margins and higher energy costs compared to other EU states. To prevent industrial decline driven by 'subsidy races', the authors recommend combining EU content requirements with carbon and circularity criteria, establishing common EU labels for green steel, cement, and chemicals, and implementing Green Public Procurement (GPP) mandates. Specifically, the statement suggests that GPP mandates for low-carbon materials in infrastructure could increase public procurement budgets in CEE by between +0.11% in Austria and +1.35% in Romania. The authors also call for equitable access to EU-level funding and streamlined permitting for cross-border hydrogen and CO2 infrastructure to address the region's high energy costs.

The Canadian Climate Institute asserts that the Clean Electricity Regulations (CER) are critical for providing the long-term predictability needed by risk-averse utilities and regulators to invest in clean energy. By setting emission limits for fossil fuel-burning generation that reach zero tonnes per gigawatt hour by 2050, the CER complements industrial carbon pricing and Investment Tax Credits to lower the cost of capital for decarbonization. The author emphasizes that while the CER allows for provincial flexibility and equivalency agreements, a stable federal standard is necessary to prevent provincial rollbacks—such as Saskatchewan's decision to extend coal plant life—from undermining Canada's overall emissions targets.

The Canadian Climate Institute asserts that the Clean Electricity Regulations (CER) provide a critical foundation of certainty for utility providers and regulators, encouraging the massive capital investments required to decarbonize Canada's power grids. The document highlights how the CER complements other policies, such as industrial carbon pricing and investment tax credits, to lower costs for consumers and ensure a competitive advantage for industries seeking clean energy. It emphasizes that while the CER sets national goals—including a target of zero tonnes of emissions per gigawatt-hour by 2050—it maintains flexibility for provinces to implement equivalent solutions and manage their own resource planning.

COP30 achieved agreements to triple adaptation finance and launch the Tropical Forest Forever Facility, but failed to formally establish roadmaps for transitioning away from fossil fuels and halting deforestation due to lobbying from petrostates. The summit saw record participation from Indigenous Peoples and significant commitments from 14,000 local governments to reduce emissions.

The document outlines three priority areas for the upcoming EU Grid Package to resolve electricity grid bottlenecks in Europe: coordinating planning across borders and time horizons, accelerating permitting processes, and modernising existing infrastructure using grid-enhancing technologies. It highlights that Europe requires approximately half a trillion euros in grid investments by 2030 and notes that over 40% of distribution grids are over 40 years old. The text emphasizes that current fragmented planning and permitting delays, which account for about 25% of total investment time, hinder the integration of renewable capacity. It proposes extending planning horizons from 10 to 20 years and implementing 'one-stop shops' for permitting to improve efficiency. Additionally, it suggests that grid-enhancing technologies could increase network capacity by 20-40%.