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In 2024, global prospective utility-scale solar and wind capacity grew by over 20% to 4.4 TW, though this remains only half of the 9 TW required to meet COP28's tripling renewables goal. While at least 240 GW of capacity became operational in 2024, project completion rates vary significantly: 76% in G7 countries, 55% in China, and 52% in other non-G7 countries. China leads in both operating capacity (at least 891 GW) and prospective projects, planning over two-thirds of all future utility-scale solar and wind projects. Conversely, G7 countries hold 45% of global GDP but are building only 10% of planned projects.

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.

Thermal batteries store renewable electricity as high-temperature heat in abundant materials like graphite or bricks, providing a cost-effective alternative to fossil fuels for industrial processes requiring temperatures over 1,000°C. The technology supports grid stability by reducing renewable curtailment and offers a lower-risk alternative to hydrogen for industrial decarbonization. While facing challenges in wholesale electricity market access and infrastructure integration, the sector saw investment spike to over $350 million in 2024.

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.

Ember argues that the draft FNA methodology focuses too narrowly on "surplus" renewable power rather than the broader goal of decarbonising the electricity system. The organization advocates for renaming flexibility needs to "non-fossil flexibility network needs" to signal a shift away from fossil assets and avoid stranded investments. Ember also calls for greater data transparency, the inclusion of cost-efficiency metrics, and the integration of the FNA into the existing ERAA/NRAA modelling process to better optimize the dispatch between fossil and non-fossil assets.

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.

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.

The document asserts that traditional grid modeling assumptions are outdated for grids integrating high levels of renewables and distributed energy resources. It identifies three critical model types—capacity expansion, production cost, and resource adequacy models—that require updated assumptions to ensure reliability and affordability. Furthermore, it emphasizes that technical modeling must be paired with an energy equity lens to account for human impacts, such as health and distributional equity, particularly for vulnerable communities.

ASEAN's electricity demand grew by 3.6% in 2023, a rise entirely met by fossil fuels, leading to a 6.6% increase in power sector emissions. While solar and wind costs are falling, the region remains heavily dependent on coal and gas, and hydropower has become less reliable due to climate-induced droughts. The report argues that scaling renewable capacity by 3-5x by 2035, implementing direct power purchase agreements, and expanding the ASEAN Power Grid are essential to meet rising demand and climate goals. It also highlights the potential for a regional compliance carbon market and the importance of a just transition to secure social acceptance.

India's power grid is facing increased strain from record-breaking heatwaves and power demand, as seen in May 2024 when nationwide demand hit 250 GW. While battery energy storage systems (BESS) costs in India have dropped 65 percent over the last two years, investment is hindered by market rules that only recognize 'energy only' dispatch strategies. The document asserts that if regulators recognize a 'full value stack'—including resource adequacy, ancillary services, and transmission and distribution (T+D) deferral—BESS profit margins could range from 24 to 70 percent. To unlock this market, the document recommends that the Forum of Regulators provide valuation guidance, state regulators incorporate BESS into long-term resource adequacy planning, and the Central Electricity Authority (CERC) increase transparency and access to ancillary service markets.

The report analyzes the relationship between battery cost declines and the feasibility of phasing down coal in India. It identifies three stages of coal phase-down: slowing growth, plateauing, and absolute decline. Using a least-cost optimized (LCO) model, it finds that while solar can meet up to 83% of daytime demand by 2032, storage is the primary bottleneck for non-solar hours. To limit coal capacity additions to the National Electricity Plan (NEP) levels of 260 GW, BESS costs must decline by 15% annually. If costs fall by 7% annually, coal generation may plateau, but new capacity will still be needed. The report emphasizes that BESS costs must drop to approximately Rs 6 million/MWh (a >50% reduction from current levels) to potentially eliminate the need for new coal additions.

China is significantly leading global renewable energy deployment, with utility-scale wind and solar projects under construction totaling 339 GW—double the combined total of all other countries. While China is on track to meet its 2030 target of 1.2 billion kW of wind and solar capacity years ahead of schedule, it faces critical challenges regarding grid stability, reliance on coal for intermittency regulation, and high curtailment rates in northern and northwestern provinces.

The Virtual Power Plant Flipbook provides a resource for utilities to implement VPPs—aggregations of distributed energy resources like batteries and electric vehicles—to enhance grid reliability and decarbonization. It offers case studies on various technologies, compensation frameworks, and partnership models to serve as a starting point for program managers and grid operators.

The document argues that the U.S. coal fleet is already in a sustained economic decline, making the EPA's emissions rules a catalyst for prudent utility planning rather than a source of economic or reliability risk. It asserts that the 2032 compliance timeline is sufficient for utilities to procure replacement resources, citing hundreds of gigawatts of 'shovel-ready' projects in interconnection queues. The authors maintain that 'baseload' coal is no longer necessary for grid stability, as portfolios of wind, solar, battery storage, and low-utilization gas can meet peak loads and growing demand without compromising reliability.

The briefing proposes "clean repowering" as a strategy to overcome the US grid interconnection backlog, which currently sees over 2 TW of clean energy projects delayed. By utilizing existing interconnection points through surplus interconnection or generator replacement processes, the time to reach commercial operation can be reduced from an average of five years to less than one year. RMI analysis suggests this could deploy 250 GW of new clean energy, saving regulated utilities $46 billion over 30 years and reducing US carbon emissions by 25 percent relative to business as usual through 2035. The document highlights Xcel Energy's Sherco project in Minnesota as a model for this transition, combining solar, storage, and workforce retention.

The report examines the potential for direct electrification to decarbonize China's industrial process heating, which accounts for nearly three-quarters of the manufacturing sector's CO2 emissions. It focuses on industrial heat pumps for low-temperature needs (up to 165 °C) and thermal batteries for high-temperature needs (up to 1,700 °C). A techno-economic analysis reveals that while coal-fired boilers currently have the lowest levelized cost, industrial heat pumps become the cheapest option for low-temperature heat when 2030 carbon pricing is included. The report identifies significant barriers, including the high cost of electricity relative to coal and limited equipment availability, and recommends policies such as equipment rebates, carbon pricing expansion, and the optimization of Green Electricity Certificates to accelerate the transition.

The report highlights that EU power system flexibility needs are expected to double by 2030 as renewables are projected to reach 66% of electricity generation. It identifies battery storage and demand side flexibility (DSF) as critical but under-utilised tools to replace fossil fuel backup and reduce renewable curtailment. While battery capacity doubled to 16 GW in 2023, the report notes a significant lack of explicit 2030 targets for storage and DSF in national policy documents. It calls for improved data transparency, the removal of regulatory barriers for distributed energy resources, and the inclusion of flexibility targets in National Energy and Climate Plans (NECPs).

The policy brief highlights a disconnect between European transmission system operator (TSO) grid plans and actual energy policy targets or market outlooks. It argues that current regulatory requirements, which force TSOs to rely on outdated national legislation, lead to under-planned capacity and increased grid congestion. The author recommends that the European Commission provide guidance on anticipatory planning and that national regulators expand their oversight to assess the adequacy of grid plans beyond mere cost implications.

The report argues that reconductoring existing transmission lines with advanced conductors can rapidly increase grid capacity and reduce costs, but is hindered by utility incentive structures, rigid equipment standards, and planning gaps. It recommends aligning utility incentives, updating regional planning horizons, establishing efficiency standards, and expanding federal funding and workforce training to overcome these hurdles.

The briefing outlines a three-pronged strategy to modernize the US power grid to accommodate increasing electricity demand from data centers, manufacturing, and electric vehicles. It advocates for 'Big Wires' (high-voltage transmission and grid-enhancing technologies), 'Small Wires' (distribution upgrades for diffuse loads like EVs), and 'Non-Wires' solutions (virtual power plants) to ensure a reliable and affordable transition to a fully electrified economy.