PJM Interconnection, the operator of the largest power grid in the United States, is currently navigating a critical period of infrastructure transition as it faces a projected capacity shortfall of nearly 7 gigawatts (GW) by 2028. This looming deficit has catalyzed a series of urgent regulatory shifts, market reforms, and expedited project approvals designed to integrate new generation resources before reliability issues translate into operational failures. Central to this strategy is the implementation of the Expedited Interconnection Track (EIT), a temporary measure launched on July 31 to fast-track large-scale energy projects that can achieve commercial operation within a three-year window. This initiative marks a significant departure from traditional, often sluggish, interconnection queues, allowing individual states within the PJM footprint to prioritize specific projects essential to their resource adequacy requirements.
As the energy landscape shifts from traditional thermal generation toward a more diversified mix, the grid operator is under immense pressure to manage rapid load growth driven by the proliferation of data centers, the electrification of the transport sector, and industrial expansion. Late last week, PJM signaled the first successes of the EIT program by accepting the first three projects under the new track: two massive battery energy storage systems (BESS) and a natural gas generator upgrade. These projects represent a combined nameplate capacity of more than 2,100 megawatts (MW) and are scheduled to be fully operational by mid-2029.
The Push for Storage Parity: PJM vs. CAISO and ERCOT
The acceptance of two major BESS projects from ENGIE is particularly noteworthy, as they are set to add 1,660 MW of storage capacity to the PJM system. Historically, PJM has lagged behind its peers in energy storage deployment. Currently, the grid operator manages only about 686 MW of utility-scale battery storage across 42 projects, with an additional 90 MW of behind-the-meter capacity. This total is a small fraction of the capacity seen in other major U.S. markets.
In contrast, California’s CAISO and Texas’s ERCOT have emerged as the dominant leaders in the domestic storage sector, together housing approximately two-thirds of all U.S. battery capacity. CAISO has seen an unprecedented expansion, growing from 500 MW in 2020 to a projected fleet of more than 16 GW by 2026. ERCOT has followed a similar trajectory, with its installed BESS capacity eclipsing 15 GW—nearly doubling its 8 GW footprint from the start of 2025. While California relied heavily on policy mandates and long-term capacity contracts to spur this growth, Texas utilized its merchant market structure to incentivize rapid private investment. Despite these differing regulatory paths, the result has been a measurable increase in grid reliability and the ability to mitigate the intermittency of renewable energy sources.
The broader U.S. market is following this trend. At the end of 2025, total domestic battery capacity stood at 43.6 GW. That figure has already surpassed 52 GW, with an additional 54 GW projected to come online through 2028. For PJM, the stakes are high; a recent report by the Brattle Group for the U.S. Energy Storage Coalition suggests that the region will require 16 GW of storage by 2032 and as much as 43 GW by 2045 to maintain a stable and reliable grid.
Regional Project Milestones: ContourGlobal’s Expansion
While PJM focuses on its interconnection queue, global independent power producer (IPP) ContourGlobal is reaching significant milestones in the Western United States. The company recently announced the completion of the second phase of the Black Hollow Sun project near Severance, Colorado. Developed in partnership with the Platte River Power Authority, Black Hollow Sun is now the largest solar project in northern Colorado.
The complex features a 324 MWp (257 MWac) solar facility capable of generating 608 gigawatt-hours (GWh) of clean electricity annually. This output is sufficient to power more than 73,000 homes across the communities of Fort Collins, Estes Park, Longmont, and Loveland. The project overcame significant hurdles, including global supply chain disruptions and inflationary pressures, to reach completion. Phase I entered commercial operation in September 2025, while Phase II was finalized in September 2026, four months ahead of its original schedule.
Simultaneously, ContourGlobal has broken ground on Project Sterling in Mohave County, Arizona. This hybrid facility is set to be one of the most ambitious in the company’s portfolio, combining 509 MWp of solar PV with a 360 MW / 1.4 GWh battery storage system. Located in the Mojave Desert, the project will utilize more than 760,000 solar modules and 300 advanced lithium iron phosphate (LFP) battery containers. Once operational in 2028, Sterling is expected to generate 1.1 terawatt-hours (TWh) of electricity annually. A long-term power purchase agreement (PPA) with Tesla covers approximately 90% of the plant’s output, representing one of the largest corporate solar-plus-storage contracts ever signed for a single hybrid facility.
Advancements in the Canadian Storage Market
North of the border, the Canadian energy sector is also seeing record-breaking storage deployments. Northland Power recently announced the start of commercial operations at its 80 MW / 160 MWh Jurassic BESS in Cypress County, Alberta. The facility now stands as Alberta’s largest battery energy storage project.
The Jurassic BESS is part of a larger $500 million energy hub that includes a 220 MW solar project. According to Northland Power, the storage facility was delivered ahead of schedule and under budget, with a perfect safety record of zero lost-time incidents across 75,000 hours of construction labor. The project’s capacity is fully committed under a 15-year offtake agreement with the Alberta Schools Commodities Purchasing Consortium, providing price stability for educational institutions across the province.
Virtual Power Plants and Demand-Side Management
The effort to close the capacity gap is not limited to physical power plants. Voltus, a leading developer of distributed energy resource (DER) software, recently secured $225 million in an oversubscribed Series D financing round. Led by Generation Investment Management, the funding will be used to scale the company’s virtual power plant (VPP) platform.
Voltus aims to reach 20 GW of flexible capacity by 2030, largely through its "Bring Your Own Capacity" (BYOC) program within the PJM and MISO territories. By aggregating the latent capacity of batteries, industrial cooling systems, and manufacturing processes, Voltus can dispatch energy back into the grid during times of peak demand. This demand-side flexibility is increasingly viewed as a cost-effective alternative to building new fossil-fuel "peaker" plants. As data centers and AI infrastructure increase the baseline demand for power, the ability to shift or reduce load in real-time becomes a foundational requirement for grid stability.
Utility-Scale Solar and the Rise of Agrivoltaics
In the Midwest, Doral Renewables is finalizing the commercialization of its massive Mammoth Solar project in Indiana. The company is celebrating the imminent operation of the Mammoth South and Mammoth Central phases, which add 900 MWac to the grid. When combined with previous phases, the total site capacity reaches 1.3 GW, making it one of the largest operational solar installations in the United States.
The construction of Mammoth Solar was a monumental logistical feat, employing 1,800 workers at its peak and seeing the installation of up to 20,000 panels per day. Beyond its sheer scale, the project is a flagship for "agrivoltaics"—the dual use of land for both solar energy production and agriculture. Doral Renewables has partnered with Purdue University to explore sheep and cattle grazing as well as specialty crop cultivation within the project boundaries. This approach addresses common concerns regarding the loss of agricultural land to energy development, demonstrating that the two industries can coexist and even provide mutual benefits.
Community Solar and Distributed Infrastructure Financing
The shift toward a decentralized grid is also supported by new financing structures for community-scale projects. Pivot Energy recently closed a $173 million term loan facility to support a portfolio of 51 community solar projects totaling 135 MWdc across six states. This transaction, supported by First Citizens Bank, Huntington Bank, and BankUnited, represents Pivot’s first term loan financing and consolidates several portfolios into a single structure.
Community solar remains a vital component of the energy transition, offering renewable energy access to renters and businesses that cannot install rooftop panels. By refinancing these projects, Pivot Energy is able to free up capital for further construction, maintaining the momentum of distributed generation.
Analysis of Future Grid Stability
The rapid influx of capacity requests in PJM—exceeding 60 GW of storage in the first cycle of the reformed interconnection process—highlights a market in the midst of a radical transformation. However, the challenge remains in the "conversion rate" of these requests. While the pipeline is full, the actual deployment of assets must accelerate to meet the 2028 reliability deadlines.
The transition is fraught with technical and regulatory hurdles. The retirement of coal-fired power plants is occurring faster than the interconnection of new resources, creating a "reliability gap" that storage and VPPs are rushing to fill. The success of programs like PJM’s EIT and the continued influx of private capital into projects like Mammoth Solar and Project Sterling suggest that while the 7 GW shortfall is a significant threat, the industry is responding with a level of scale and speed previously unseen in the American power sector. The next three years will be a defining period for the U.S. electric grid, as operators and developers race to build the infrastructure required for a high-demand, low-carbon future.
