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The report argues that meeting U.S. electricity demand growth through 2030 with a clean energy portfolio is more affordable and reliable than a fossil-fuel-heavy approach. Modeling shows that a clean energy scenario could save consumers $5.1 billion annually by 2030 and significantly reduce risks associated with volatile fuel prices and extreme weather. The analysis emphasizes the role of solar, wind, battery storage, and demand-side flexibility in reducing system costs and carbon emissions while maintaining grid resilience.

The briefing examines the potential of Energy Resource Interconnection Service (ERIS) to address load growth and high energy prices in the PJM region. Based on analysis by Aurora Energy Research, the document asserts that wind and solar resources electing ERIS are financially viable and could save ratepayers nearly $11 billion over a decade if 10 GW are deployed by 2028. It calls for PJM to decouple ERIS studies from Network Resource Interconnection Service (NRIS) tracks and minimize network upgrade requirements to accelerate deployment.

The US faces a critical bottleneck in connecting new electricity generation and storage to the grid, with over 2.2 terawatts of projects currently in queues. While the US Department of Energy has pushed for streamlined load interconnection for data centers, the author argues that this is insufficient without parallel reforms to generator interconnection. Current processes are characterized by long delays—averaging nearly five years from request to operation in 2024—and high network upgrade costs that often exceed 10% of project capex, leading to high attrition rates. The brief proposes several solutions: adopting advanced AI and automation software for studies, integrating Grid-enhancing technologies (GETs) to reduce costs, improving transparency in network upgrade construction, and implementing 'fast track' pathways such as energy-only interconnection, surplus interconnection service, and generator replacement.

PJM is facing a capacity crisis driven by surging demand from data centers and a slow interconnection process that takes over eight years to bring new generation online. This delay has caused capacity market prices to skyrocket, with the total capacity bill rising from $2.2 billion in December 2022 to $16.1 billion in the latest auction. The author identifies long study timelines and high transmission network upgrade costs as primary barriers, noting that PJM has connected fewer new resources relative to peak demand than ERCOT or CAISO. To fix this, the document recommends implementing third-party automation software, reforming Energy Resource Interconnection Service (ERIS) to be a faster pathway, integrating advanced transmission technologies (ATTs), and prioritizing proactive regional transmission planning.

The report examines how battery energy storage can enhance grid reliability—specifically resource adequacy, stability, and resilience—while reducing costs. It contrasts the successful deployment of batteries in Texas (ERCOT) and California (CAISO), where well-defined ancillary services and value stacking have lowered costs, with the PJM region, where high uplift costs and interconnection hurdles persist. The author recommends that regulators and planners define competitive ancillary service products, properly value resource adequacy, and modernize interconnection processes to replace expensive legacy fossil fuel generators.

The Union of Concerned Scientists (UCS) reports that utilities in seven PJM states passed over $4.3 billion in data center connection costs to all customers in 2024. This occurs because large data centers (100–1,000 MW) require high-voltage transmission infrastructure, which falls under federal FERC jurisdiction and is typically allocated across all customers, unlike low-voltage distribution connections. UCS finds that in 95% of cases, these costs are not paid by the data center owners. The brief recommends that FERC and state PUCs require utilities to track and assign these specific costs to the customers causing them.

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 policy brief advocates for 'clean repowering'—the strategy of siting new renewable energy projects at existing or retiring fossil fuel plant interconnection points—to reduce interconnection times from nearly five years to less than one year. RMI's analysis indicates this approach could enable 250 GW of new renewable energy without transmission upgrades, resulting in average national savings of $12.7 billion annually from 2025 to 2035. The brief highlights the role of the Inflation Reduction Act (IRA) and the Energy Infrastructure Reinvestment (EIR) program in making these projects financially viable and provides specific recommendations for regulators to ensure these savings reach customers through integrated resource planning and oversight.

The report examines the role of carbon-free energy in the PJM market and evaluates two proposed market designs—the Forward Clean Energy Market and the Integrated Clean Capacity Market—to improve the integration of clean resources. It argues that accurately accounting for the capacity value of clean energy reduces costs and emissions, and suggests that a regional, standardized clean energy procurement process could accelerate the retirement of fossil assets and the deployment of clean energy.

The document examines the potential of 'flexible demand'—shifting the timing of electricity use—to support a clean energy transition. It contrasts this with traditional demand response, highlighting how advanced metering and smart technology can align consumption with renewable energy production, reduce the need for natural gas 'ramp' plants, and avoid costly infrastructure upgrades. The author identifies key flexible end uses, such as electric vehicle charging and space heating, and proposes three mobilization models: behavioral, price-exposed, and subscription-enrolled. It concludes with recommendations for regulators to align utility incentives and ensure equitable program design.

The research note analyzes four implementation scenarios for the DOE's Grid Resilience Notice of Proposed Rulemaking (NOPR), which would compensate coal and nuclear plants for costs not recovered in wholesale markets. The analysis finds that annual customer costs could range from $311 million to $10.6 billion, with a high concentration of benefits accruing to a small number of companies, particularly in the PJM region.

Goldman Sachs became the first U.S. bank to sign a large-scale, off-site renewable energy PPA for a 68 MW wind project in Pennsylvania. The bank utilized a virtual PPA structure within the PJM grid to align clean energy generation with its U.S. consumption while managing commodity risks through its J. Aron business. This deal supports the firm's goal of 100 percent renewable electricity by 2020 and a target of $150 billion in clean energy investments by 2025.

The report analyzes the Eastern Interconnection Planning Collaborative (EIPC) study to demonstrate that aggressive carbon reductions in the U.S. electric sector are achievable with minimal additional cost. By re-evaluating EIPC data, Synapse Energy Economics found that a 'Carbon Reduction' scenario—featuring massive wind build-out and coal retirements—costs approximately the same as a 'Business as Usual' scenario when carbon revenues are recycled. The analysis shows that this path would allow the MISO and PJM regions to significantly over-comply with the Clean Power Plan's emissions targets while maintaining grid reliability.

Ohio is transitioning from coal to natural gas for electricity generation, but this shift maintains significant risks. The report advocates for a more diverse energy mix, highlighting the success of the Alternative Energy Portfolio Standard in reducing costs and creating jobs through wind, solar, and energy efficiency.

The document outlines how data centers can increase electricity demand flexibility by shifting workloads, reducing operations, or using onsite storage. It highlights that without policy changes, data center growth could lead to 25-50 GW of additional fossil generation by 2030. Conversely, curtailing just 0.5 percent of annual electricity use could allow 100 GW of load to be added nationwide without new peak resources. Proposed policy tools include tying tax incentives to demand response participation, enabling faster interconnection for flexible facilities, and implementing utility rates that align costs with system impact.

The report explores automated emissions reduction (AER), a software-based technology that modulates the electricity use of internet-connected devices based on real-time grid emissions data. Based on a pilot in Chicago and a stakeholder workshop, the report finds that AER can reduce pollution by 5–40% for specific loads and lower customer acquisition costs for utility demand response programs. It proposes five priority near-term initiatives: institutional and residential pilots, device certification, integration into GHG accounting protocols, and the creation of open-source infrastructure.

The document evaluates the EIPC's Carbon Reduction Scenario, which aims to reduce carbon emissions in the Eastern Interconnection by 42% below 2005 levels by 2030. Analysis by Synapse Energy Economics indicates that this scenario achieves these reductions with cumulative ratepayer costs through 2040 nearly identical to a 'Business-as-Usual' approach. The scenario relies on a combination of wind energy, energy efficiency, and expanded interregional transmission, specifically projecting 103 GW of new wind in MISO states to support the broader region. The report argues that regional cooperation and updated, lower costs for wind and solar make these targets highly achievable and potentially 30% cheaper than business-as-usual when carbon costs are valued uniformly.

The document argues that U.S. cities and counties are underrepresented in wholesale energy markets despite being large energy purchasers with a stake in market structure. It outlines three primary engagement pathways: public statements, the Federal Energy Regulatory Commission (FERC), and Regional Transmission Organizations (RTOs)/Independent System Operators (ISOs). To overcome barriers such as limited staff capacity and high education needs, the paper suggests collaborative efforts and learning from similar stakeholders, citing a coalition of local governments within the PJM territory as an example.

The PJM Cities and Communities Coalition (PJMCCC) Charter outlines the governance, membership, and strategic goals of a coalition of local governments and communities within the PJM territory. The coalition aims to remove barriers to decarbonization in the regional wholesale electricity market through capacity building, partnerships, and collective action.