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					</table>The Pennsylvania-New Jersey-Maryland (PJM) interconnection must deploy at least 16 GW of energy storage by 2032 and 23 GW by 2040 to ensure system reliability, according to a new report from the <a href="https://www.energystorage.org/" target="_blank" rel="noopener">U.S. Energy Storage Coalition</a>.
The report finds that energy storage will be essential for addressing tight supply conditions, mitigating reliability risks during extreme weather, and supporting the integration of renewable generation resources.
<a href="https://mercomindia.s3.ap-south-1.amazonaws.com/wp-content/uploads/2025/10/PJM-1.png"><img loading="lazy" decoding="async" class="aligncenter wp-image-85703 size-full" src="https://mercomindia.s3.ap-south-1.amazonaws.com/wp-content/uploads/2025/10/PJM-1.png" alt="PJM 1" width="516" height="254" srcset="https://mercomindia.s3.ap-south-1.amazonaws.com/wp-content/uploads/2025/10/PJM-1.png 516w, https://mercomindia.s3.ap-south-1.amazonaws.com/wp-content/uploads/2025/10/PJM-1-300x148.png 300w" sizes="auto, (max-width: 516px) 100vw, 516px" /></a>
The PJM Interconnection is a regional transmission organization in the U.S. It is part of the Eastern Interconnection grid operating an electric transmission system serving all or parts of Delaware, Illinois, Indiana, Kentucky, Maryland, Michigan, New Jersey, North Carolina, Ohio, Pennsylvania, Tennessee, Virginia, West Virginia, and the District of Columbia.
The report states that PJM faces a period of significant strain as peak electricity demand is forecast to grow by 19% between 2025 and 2030.
The region’s summer peak load is projected to increase by 16 GW by 2028 and by 30 GW by 2032.
Over the next decade, total summer and winter peaks are expected to rise by about 56 GW and 62 GW, respectively, driven largely by data center expansion and electrification of heating and transportation.
Interconnection queue backlogs constrain PJM’s ability to add new supply, lengthy approval timelines for new gas capacity, and trade barriers affecting renewable and storage equipment.
Demand for gas turbines currently exceeds manufacturing capacity, and project delays could further restrict resource adequacy.
The report assumes that by 2028, up to 7.4 GW of new gas capacity, 10 GW of battery storage, 3 GW of wind, and 20 GW of solar could be deployed from the current queue. By 2032, an additional 10.5 GW of new gas capacity could come online if supply conditions improve.
The report indicates that PJM must also delay most planned fossil retirements until between 2033 and 2036 to accommodate load growth. Even with these delays, both new gas generation and storage are required to prevent capacity shortages.
The report identifies four-hour duration storage as the only cost-effective option under PJM’s projected conditions, with six-hour and eight-hour storage found to be uneconomical at less than 50% renewable penetration.
The cost of four-hour lithium-ion battery systems could <a href="https://www.mercomindia.com/li-ion-battery-prices-could-drop-to-108-kwh-in-2050-nrel/" target="_blank" rel="noopener">decline</a> from $334/kWh in 2024 to as low as $108/kWh or remain as high as $307/kWh by 2050.
Without battery storage, the analysis shows that PJM would experience large-scale reliability violations and forced load shedding, especially during winter cold snaps similar to Winter Storm Elliott.
The study estimates that without 16 GW of storage, PJM could face up to 14,000 MWh of load shedding over a three-day cold event in 2032, resulting in costs between $400 million and $1.2 billion.
In contrast, storage deployment can prevent up to 15 GW of load shed risk in 2032 and maintain compliance with PJM’s resource adequacy standards.
<a href="https://mercomindia.s3.ap-south-1.amazonaws.com/wp-content/uploads/2025/10/PJM-2.png"><img loading="lazy" decoding="async" class="aligncenter wp-image-85704 size-full" src="https://mercomindia.s3.ap-south-1.amazonaws.com/wp-content/uploads/2025/10/PJM-2.png" alt="PJM 2" width="564" height="319" srcset="https://mercomindia.s3.ap-south-1.amazonaws.com/wp-content/uploads/2025/10/PJM-2.png 564w, https://mercomindia.s3.ap-south-1.amazonaws.com/wp-content/uploads/2025/10/PJM-2-300x170.png 300w" sizes="auto, (max-width: 564px) 100vw, 564px" /></a>
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The report also finds that customer costs would be about 30% higher between 2028 and 2045 if storage is not available. The calculation excludes transmission and distribution impacts, which currently amount to under $50 billion per year in PJM.
Without storage, PJM would have to rely on more expensive or insufficient alternatives, leading to a higher dependence on alternative compliance payments to meet state renewable portfolio standards.
The report assumes that PJM’s states will continue to pursue renewable and clean energy mandates, resulting in growing shares of wind, solar, and nuclear generation.
By 2045, renewables and nuclear together are projected to provide about 50% of PJM’s total generation, with solar, wind, and nuclear each contributing roughly one-third of the clean energy mix. The remaining 50% of generation is expected to come from fossil fuels.
The report further notes that battery storage can generate between $20/kW and $65/kW annually in real-time energy and ancillary service revenues, primarily from synchronized reserves.
In the longer term, as renewable energy deployment expands, the value of storage will continue to increase through enhanced energy arbitrage and operational flexibility. By 2045, PJM is projected to rely on around 43 GW of battery storage, 40 GW of new gas capacity, and expanded renewable generation to maintain reliability and meet policy targets.
The report recommends reforms to PJM’s interconnection queue process, improvements in capacity accreditation for storage, and the establishment of clear procurement goals to support timely storage deployment.
The U.S. energy storage market <a href="https://www.mercomindia.com/us-energy-storage-installations-hit-5-6-gw-in-q2-2025/" target="_blank" rel="noopener">achieved</a> its strongest ever quarter in the second quarter of the financial year 2025, with total installations reaching 5.6 GW/17.8 GWh.

PJM Must Deploy 16 GW Energy Storage to Meet Peak Demand by 2032: Report

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					</table>U.S.-based Appalachian Power (<a href="https://www.appalachianpower.com/" target="_blank" rel="noopener">APCo</a>) has issued three requests for proposals (RfP) to procure power and renewable energy certificates (RECs) from wind and solar power projects, along with co-located and standalone battery energy storage systems (BESS).
The last day to submit the bids for all the RfP is July 16, 2024.
RfP 1
APCo seeks to acquire wind and solar projects and or co-located standalone BESS up to 800 MW through one or more purchase and sale agreements.
The minimum acceptable project size is:
<ul>
<li>PJM Resources: 50 MW minimum for wind, solar, and solar with co-located battery energy storage systems, and 10 MW minimum for standalone BESS.</li>
<li>APCo Distribution Resources: 10 MW minimum for solar, solar with co-located battery energy storage systems, and standalone BESS.</li>
</ul>
APCo is looking for projects in the development stage and completed projects that are expected to be operational by December 15, 2028.
The projects must qualify for the full Federal Production Tax Credit or Federal Investment Tax Credit.
To qualify for consideration, projects must interconnect to the PJM Interconnection, Regional Transmission Organization (RTO) or the APCo distribution system, and be located within the PJM footprint, with a preference for projects located in Virginia or West Virginia on eligible sites.
Projects must be connected to PJM and have a completed PJM System Impact Study.
PJM Interconnection is a RTO that coordinates the movement of electricity through all or parts of Delaware, Illinois, Indiana, Kentucky, Maryland, Michigan, New Jersey, North Carolina, Ohio, Pennsylvania, Tennessee, Virginia, West Virginia and the District of Columbia.
RfP 2
APCo intends to procure power and environmental attributes (including RECs) from wind and solar projects of up to 300 MW through one or more power purchase agreements (PPA).
The minimum project size for this RfP is 5 MW for solar projects and 50 MW for wind projects.
APCo seeks renewable energy products from a low-cost project delivering energy into PJM Interconnection or the APCo system via a PPA, including energy, capacity, environmental attributes (including RECs), and ancillary services (if available).
Projects should be operational by December 31, 2028.
The PPA term must be 20 or 30 years, with bidders allowed to offer alternative term proposals.
Proposals may include an option for APCo to purchase the project at fair market value at the end of the PPA term.
Projects must be located within the PJM Interconnection.
RfP 3
APCo has invited proposals for unbundled RECs from renewable resources.
RECs must meet the Virginia Renewable Portfolio Standard, evidenced by a verified certificate number in PJM’s Generation Attribute Tracking System (PJM-GATS).
Proposals must be for at least five years, but no more than thirty years, starting January 1, 2027, with bidders allowed to offer alternative proposals.
Eligible renewable resources include:
<ul>
<li>Solar or wind located within the PJM region.</li>
<li>Non-utility-owned falling water resources less than 65 MW, operational after December 31, 1979, or with incremental generation over 50% of the original capacity after December 31, 1979, located in the Commonwealth or within the PJM region.</li>
<li>Waste-to-energy or landfill gas-fired resources in the Commonwealth, operational by January 1, 2020, not using waste heat from fossil fuel combustion or forest/woody biomass.</li>
<li>Biomass-fired facilities in the Commonwealth, operational by January 1, 2020, supply no more than 10% of their annual net generation to the grid or 15% of their total useful energy to entities other than the interconnected manufacturing facility.</li>
</ul>
RECs must be produced from a unit-contingent resource and delivered to APCo by the 15th day following the month they are generated. REC deliveries must occur through the PJM-GATS system into an APCo-designated account.
In 2022, American Electric Power Service Corporation, on behalf of Appalachian Power, <a href="https://www.mercomindia.com/tender-issued-to-procure-power-in-west-virginia" target="_blank" rel="noopener">issued</a> an RfP to procure power from 150 MW of solar projects with optional BESS in West Virginia.
In the same year, Entergy Arkansas, an energy utility in the U.S., <a href="https://www.mercomindia.com/entergy-arkansas-tender-1-gw-renewable-energy" target="_blank" rel="noopener">issued</a> an RfP to procure 1 GW of solar and wind energy.

Appalachian Power Issues Tenders to Procure 1.1 GW of Renewable Energy

AEP Energy Partners (<a href="https://www.aep.com/about/businesses/aepenergypartners" target="_blank" rel="noopener">AEPEP</a>), a subsidiary of <a href="https://www.aep.com/" target="_blank" rel="noopener">American Electric Power</a>, has issued a request for proposal (RfP) to procure power from new or repowered wind and solar plants and battery energy storage systems (BESS). The projects must be located within the Pennsylvania, New Jersey, and Maryland (PJM) market in the United States.
The total capacity to be contracted is expected to be between 300 MW to 500 MW. The last day to submit the bids is October 13, 2021.
PJM is a regional transmission organization that coordinates the movement of wholesale electricity in all or parts of 13 states and the District of Columbia. It acts as a neutral entity to operate a competitive wholesale electricity market and manages the high-voltage electricity grid to ensure reliability for more than 65 million people.
In the case of wind and solar projects, the bidders must pay bid security of $50/KW. Once commercial operation of the projects commences, the bidders will have to pay $100/KW.
The BESS should be up to 50 MW/200 MWh capacity with guaranteed performance and output of 4,000 hours per annum.
For the PJM sited projects, the company is seeking renewable energy purchase agreements of 10, 12, or 15 years for solar and wind facilities, including incremental power from repowering and BESS that begin operation between 2021 and 2024.
AEPEP intends to offtake power from wind and solar projects located in AEPOHIO_RESID_AGG, AEPOHIO_RESID_AGG, DOMINION ZONE, DOMINION HUB, WESTERN HUB, and COMED_ZONE in PJM territory. The standalone BESS projects can be located anywhere in PJM territory.
In February this year, Appalachian Power, another subsidiary of American Electric Power, <a href="https://mercomindia.com/us-electric-bids-300-mw-solar-wind/" target="_blank" rel="noopener">invited</a> bids to develop 300 MW of solar and wind projects. The request for bids is the first in a series of RfPs that the company has planned for this year to comply with the Virginia Clean Economy Act.
AEPEP had <a href="https://mercomindia.com/project-finance-brief-atlas-solar-project/" target="_blank" rel="noopener">signed</a> a letter of intent with BQ Energy Development to purchase a 100% offtake of the Columbus Solar Park developed southwest of downtown Columbus, Ohio. The solar project is scheduled to be operational by December 2022.

AEP Energy Issues Tender to Buy Power from Solar, Wind, Storage Projects in the PJM Market

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