Solmar Insights
US utility Appalachian Power has announced a major request for proposals, seeking up to 800MW of energy storage resources across Virginia. Two new RFPs reflect the company’s intent to accelerate deployment of battery energy storage systems (BESS) as part of its supply mix, underscoring the growing role of grid-scale storage in meeting reliability and capacity needs.
Key figures
Up to 800MW BESS capacity
2 separate RFPs
Virginia statewide solicitation
Utility BESS procurement outlined
The headline procurement from Appalachian Power represents one of the largest utility solicitations for battery storage in the Virginia market to date. By seeking up to 800MW through two concurrent RFPs, the company is positioning itself to address future system flexibility and to comply with evolving state policy priorities.
The focus on BESS reflects surging regional demand for resources that can provide ancillary services, support renewable integration, and contribute to peaking capacity. Appalachian Power’s approach may encompass both standalone and hybrid storage assets, though specific technology configurations are to be determined through the RFP process itself.
This procurement arrives amid broader regional and national trends, as utilities and independent power producers look to replace fossil fuel peaking plants and enhance grid resilience using large-scale batteries. Appalachian Power’s solicitation is expected to attract a variety of project developers and integrators with experience in lithium-ion and alternative storage platforms.
With up to 800MW on offer, the solicitation could substantially increase the installed BESS footprint in Appalachian Power’s service territory and set a new benchmark for future procurements in the Commonwealth of Virginia.
Scope of RFP and eligibility
The two new RFPs laid out by Appalachian Power will define the parameters for participating projects, covers site locations within Virginia, and could support a combination of new-build sites or retrofit opportunities at existing substations or generation facilities.
Eligible participants will likely include independent developers, equipment manufacturers, and system integrators. The RFPs’ design is expected to ensure competitive bidding processes, with attention to project viability, interconnection readiness, and timeline commitments. These factors are often critical for utility solicitations, given the multi-year lead times that can be involved in permitting and grid integration.
By covering both greenfield and existing sites, Appalachian Power has a mechanism to evaluate a spectrum of technical and commercial proposals, potentially supporting both in-front-of-meter and co-located behind-the-meter storage solutions. However, precise eligibility criteria and evaluation rubrics will emerge as the RFP documentation is finalized and released to interested parties.
Project timelines, delivery obligations, and the structure of capacity payments or PPA terms are likely to be a principal focus for institutional investors and developers responding to the solicitation. Financing requirements, milestone schedules, and resource adequacy implications remain salient competitive factors among respondents.
Market drivers and regulatory backdrop
The move by Appalachian Power to procure a substantial tranche of energy storage coincides with wider shifts in Virginia’s energy policy and regulatory environment. The state has established aggressive targets for renewable energy and carbon reduction, placing pressure on utilities to modernize their generation portfolios and invest in flexible assets.
BESS procurement aligns with requirements under Virginia’s regulatory frameworks, with grid operators and utilities seeking to maintain system reliability as coal and gas retirements accelerate. Energy storage enables time-shifting of renewables, reduces curtailments, and provides a pathway to greater involvement in PJM’s ancillary service and capacity markets.
Strategic siting of large-scale battery systems can also address locational transmission constraints, further supporting grid reliability and deferring expensive infrastructure upgrades. The RFP signals Appalachian Power’s acknowledgment of these trends and its intention to remain competitive as regional energy markets transition to greater renewables penetration.
The regulatory context will shape project economics and risk allocation, particularly as stakeholders balance state mandates with FERC-jurisdictional market rules and transmission planning requirements. Successful bidders will need to demonstrate compliance with these evolving parameters.
Developer and investor considerations
The scale and structure of Appalachian Power’s RFPs will influence project size, financing structures, and potential offtake agreements. Developers will need to weigh site control, permitting pathways, and interconnection queue positions, as Virginia continues to experience significant grid interconnection congestion and permitting backlogs.
Project returns will hinge on contract terms as established under the procurement, with long-term revenue streams favored by institutional capital and infrastructure investors. The prioritization of BESS assets may result in higher competition for advantageous sites near load centers or critical substations.
Partnerships between technology OEMs, EPCs (engineering, procurement, and construction firms), and asset managers may prove essential to navigate complex technical, regulatory, and financial requirements. The RFPs offer a platform for both established and new entrants to scale operations in one of the US’s more active energy transition markets.
Secondary considerations around supply chain stability, technology risk, and lifecycle O&M (operations and maintenance) will also factor heavily in project evaluations and investor risk assessments. Respondents will likely emphasize experience, bankability, and the ability to execute on multi-hundred megawatt portfolios.
Implications for Virginia grid planning
Appalachian Power’s move is set to influence the load forecast and transmission planning not just within its own service area but potentially across neighboring PJM zones. The addition of up to 800MW of energy storage could alter resource adequacy metrics, improve renewable hosting capacity, and reshape nodal congestion profiles.
Virginia’s utilities and grid planners face an evolving landscape characterized by rapid distributed resource growth, stringent emissions reduction targets, and heightened reliability scrutiny. Battery storage, at scale, is central to addressing these overlapping challenges by reducing variability, lowering system peaks, and advancing compliance with renewable portfolio standards.
The outcomes of these RFPs may inform future regulatory proceedings, integrated resource planning, and broader industry advocacy on grid modernization. Lessons learned from siting, technology selection, and contracting frameworks will likely influence utility procurement practices elsewhere in the state and PJM footprint.
Over time, successful projects may be called to provide not just capacity and energy shifting, but also frequency regulation, voltage support, and participation in emerging market products as the suite of storage use cases expands.
What this means for buyers
Institutional buyers, investors, and developers should note Appalachian Power’s 800MW BESS procurement as a key signal of growing utility appetite for grid-scale storage in Virginia. Participation in this RFP will require careful attention to interconnection positions, project readiness, and contract terms as utilities place new emphasis on storage to secure system flexibility. Early engagement and robust project partnerships will be essential amid increasing competition for site control and capacity in the PJM region. The procurement may also set new precedents for risk allocation and long-term revenue models in the Commonwealth.
