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The report examines the vulnerabilities of the US power grid to climate change, highlighting how extreme heat, wildfires, winter storms, and hurricanes cause widespread outages. It argues that current planning focuses on reliability under typical conditions rather than resilience to high-impact, low-frequency events. The authors emphasize that structural inequities, such as the legacy of redlining, leave low-income communities and people of color disproportionately vulnerable to the life-threatening consequences of power loss. The document recommends that regional transmission organizations (RTOs) and independent system operators (ISOs) adopt forward-looking climate risk assessments, integrate energy justice principles, and reform economic metrics like the Value of Lost Load (VOLL) to prioritize human vulnerability over economic activity.

The Union of Concerned Scientists calls for a fundamental shift in how electric transmission systems are planned and invested in to address the increasing frequency and severity of extreme weather events. The report emphasizes that current grid planning is unprepared for climate reality and risks perpetuating inequities in marginalized communities. It recommends that utilities, states, and regional transmission operators adopt forward-looking climate risk assessments projecting at least 30 years into the future and integrate energy justice principles—such as shared governance and community advisory boards—to ensure that resilience investments protect the most vulnerable populations.

The document introduces a three-part framework consisting of on-the-ground solutions, policy and market-enabling conditions, and state levers. It categorizes electricity system improvements into six areas: system-wide efficiency and demand management, utility-scale clean energy supply, community- and commercial-scale clean energy supply, clean distributed energy supply, improved grid management, and updated grid infrastructure. For each category, the guide suggests specific actions—such as implementing clean portfolio standards, expanding virtual power plants (VPPs), and adopting grid-enhancing technologies (GETs)—and provides sample implementation pathways combining different state levers and market conditions.

The report argues that the ASEAN Power Grid (APG) can unlock significant renewable energy potential and enhance energy security by connecting resource-rich countries with high-demand markets. It highlights specific planned solar and wind projects, the role of the ASEAN Interconnection Master Plan Study (AIMS), and the potential for 30 GW of additional renewable capacity to generate 109 TWh of electricity and create 182,000 jobs.

The report argues that ASEAN's transmission grid expansion must roughly double to align with IEA pathways, as current national plans for Indonesia, Viet Nam, the Philippines, and Thailand cover only about 45% of the required expansion. It highlights that 30 GW of solar and wind potential is located along planned interconnection routes in countries like Indonesia, Malaysia, Cambodia, and Brunei. To support this transition, the report proposes a six-pillar framework for future-ready grid planning—including smart modernisation, strategic expansion, and market reforms—and suggests learning from the integrated power systems of Europe and Southern Africa to move from bilateral to multilateral power trade.

The PELP 2023-2027 report outlines three development scenarios for Chile: Slow Recovery, Carbon Neutrality, and Accelerated Transition. It projects a significant shift toward renewable energy, primarily wind and solar photovoltaic, and identifies critical transmission expansion needs. A key innovation is the introduction of Electric Generation Development Poles (PDGE) in the provinces of Antofagasta and Tocopilla to optimize renewable energy deployment. The report also analyzes the role of green hydrogen, energy storage, and the phased retirement of coal-fired power plants to meet 2050 carbon neutrality goals.

The PELP 2023-2027 establishes three development scenarios—Slow Recovery, Carbon Neutrality, and Accelerated Transition—to project Chile's energy needs and supply through 2060. The plan emphasizes the expansion of wind and solar photovoltaic generation, the integration of energy storage, and the phased retirement of coal-fired power plants. A key innovation is the introduction of Electric Generation Development Poles (PDGE) in the provinces of Antofagasta and Tocopilla to optimize transmission and promote renewable energy. The report also analyzes the role of green hydrogen in decarbonizing industry and transport, and assesses the resilience of the National Electric System (NES) against climate-induced hydrological and wind variability.

The document identifies seven key intervention areas in the clean-energy sector: electricity generation, transmission and distribution, on-grid access, off-grid access, clean cooking, knowledge sharing, and policy reform. While utility-scale renewable generation has grown significantly, transmission bottlenecks and affordability constraints for end-users remain critical hurdles. The brief argues that while energy access is a necessary enabler for economic growth, it does not guarantee it, necessitating user-focused designs and long-term policy reforms to ensure sustainable impacts.

The Clean Air Task Force (CATF) asserts that the recent removal of CEQ's NEPA regulations by an interim final rule will hinder infrastructure deployment by increasing ambiguity and complicating interagency coordination. While intended to expedite permitting, CATF argues this action reverses recent trends in decreasing review timelines and removes essential tools like categorical exclusions and tiering frameworks. The document advocates for restoring these regulations or implementing data-driven reforms, such as increasing agency staffing and aligning jurisdictional requirements, to efficiently deploy clean energy infrastructure.

The report examines the potential of advanced transmission technologies (ATTs), including grid-enhancing technologies (GETs) and advanced conductors, to expand US grid capacity. While pilots have demonstrated success—such as increasing capacity by 40% in the Midwest—widespread adoption is hindered by risk aversion, financial disincentives, a lack of integration into planning processes, and poor cross-utility coordination. The author suggests that large corporate energy users can accelerate deployment through policy advocacy at federal and state levels and by leveraging their influence to catalyze collaboration across different utility service territories.

The North Plains Connector (NPC) is a $3.2 billion, 420-mile high-voltage direct current transmission project designed to connect the western and eastern electric grids. The developer, North Plains Connector LLC, has adopted a "landowner-first approach," prioritizing voluntary agreements over eminent domain and modifying the route by adding 50 miles to accommodate local siting requests. Community benefits include $3.9 million in grants distributed via local foundations, over $62 million in federal TSED grants secured for local infrastructure, and the creation of approximately 800 construction jobs. The project also facilitates expanded wind energy exports for the Standing Rock Sioux. While this high-upfront-investment model has reduced local opposition, the document notes it requires "patient capital" and its long-term financial efficiency compared to traditional development remains unproven.

The U.S. may need to triple its transmission capacity by 2050, requiring over $40 billion in annual investment by 2031. Relying on private, for-profit utility financing risks increasing consumer rates and reducing political support for the energy transition. Research commissioned by the Clean Air Task Force (CATF) in California suggests that public or public-private financing using low-cost public debt could save ratepayers up to $3 billion annually, or $123 billion over 40 years. To achieve these savings, the document recommends that policymakers employ new institutional models, such as dedicated transmission authorities, and utilize low-cost public debt like bonds and loans. It highlights the roles of existing authorities in New Mexico and Colorado as examples. Key recommendations for state transmission authorities include using planning processes to test alternative financing, appointing coordinators to speed up implementation, utilizing credit enhancements, and issuing general obligation or revenue bonds to alleviate costs for ratepayers.

The report finds that large-scale transmission projects in the US are cost-effective, with analyzed projects delivering benefits that exceed their costs and often surpass original expectations and regulatory standards.

The U.S. clean energy sector saw record solar and battery storage installations in 2024, with renewables accounting for approximately 90% of new capacity. However, progress is hindered by grid interconnection backlogs, rising local opposition, high interest rates, and supply chain shortages. The report also notes a slowdown in EV sales growth and warns that the Trump administration's policies may create further roadblocks to decarbonization.

RMI introduces the "Power Couples" model, which pairs large electricity consumers, such as AI data centers, with new-build wind, solar, and battery resources located near existing generators with approved grid interconnections. This approach aims to bypass long grid access wait times—which can reach five years for generation and eight years for transmission—while ensuring that the costs of new demand are borne by the users rather than general ratepayers. RMI's analysis indicates that this strategy could satisfy over 50 GW of new load at an average of 88% carbon-free energy, with significant opportunities concentrated in the PJM, ERCOT, and Southeast regions.

The briefing examines the components of grid reliability—resource adequacy, operational reliability, and resilience—within the context of the U.S. transition to clean energy. It argues that while load growth and fossil fuel retirements create short-term risks, a diverse portfolio of wind, solar, batteries, and demand-side resources can maintain reliability. The document emphasizes the need for interconnection reform, updated market rules for inverter-based resources, and the scaling of demand-response programs to avoid unnecessary supply-side costs.

The report examines the technical and institutional challenges of maintaining grid reliability in the United States as fossil fuel plants retire and demand grows from data centers and electrification. It argues that reliability does not require traditional baseload power but can be achieved through a combination of wind, solar, battery storage, and demand-side flexibility. The authors highlight that while 80-90% clean electricity is achievable with current technology, reaching 100% may require 'clean firm' resources like enhanced geothermal or advanced nuclear. Key recommendations include reforming interconnection queues, expanding interregional transmission, and implementing performance-based incentives for utilities to prioritize demand-side solutions.

India achieved a record 34.7 GW of power capacity additions in 2024, driven largely by solar PV. However, the report finds that replicating this record annual deployment would leave India short of its 500 GW non-fossil capacity target by 2030. To close this gap, annual wind and solar additions must grow by approximately 15% year-on-year, effectively doubling current record levels by the end of the decade. While renewables are on track to overtake operating coal capacity in total volume within two years, fossil fuels still contributed over two-thirds of the increase in power generation in 2024.

The report addresses the surge in US electricity demand, noting that utility integrated resource plans covering 48% of sales expect load to grow 20% from 2023 to 2035. It argues that traditional forecasting is inadequate for new large loads—specifically data centers and industrial reshoring—which possess unique load shapes, high uncertainty, and 'flight risk'. The authors recommend that regulators shift toward scenario-based forecasting, increase the frequency of updates (e.g., quarterly), and implement 'least-regrets' capital investments and risk-shifting tariffs to protect ratepayers from the costs of forecast errors.

The SOO Green HVDC Link is a 350-mile, 2,100-MW underground transmission line connecting wind energy from MISO jurisdiction states to the PJM market. By co-locating the line within existing railroad rights of way and utilizing undergrounding, the project has significantly reduced community opposition and simplified siting. The developer has implemented a variety of benefits, including 'good neighbor payments' to adjacent landowners, municipal franchise agreements that fund local infrastructure like broadband expansion, and apprenticeship programs for underserved youth. While the project faces skepticism regarding the higher upfront costs of undergrounding compared to overhead lines, the developer argues that lifecycle costs are competitive, particularly when accounting for extreme weather resilience and reduced siting delays.