Meeting Summer Peaks: The Need for Virtual Power Plants

View Full Document Requires name and email to access

Estimated reading time: 15 minutes

Why This Matters for Rural Electric Co-ops

As summertime peak demand is projected to grow by 38,000 MW nationally over the next five years, driven by data centers, EVs, and electrification, rural electric co-ops face real risk of capacity shortfalls and upward rate pressure if they rely solely on traditional generation or transmission infrastructure. VPPs offer a faster and lower-cost alternative: research cited in the brief finds VPPs can deliver resource adequacy at roughly 40% of the cost of a gas peaker, potentially avoiding $15–$35 billion in capital investment nationwide.

For co-ops already holding member-sited DERs (solar, batteries, smart thermostats) this resource provides a framework for turning those assets into dispatchable capacity. Co-op leaders can use this brief to make the case internally for VPP program investment and to engage state regulators on enabling policy.

Key Takeaways

Implementation Considerations

• Regulatory or Governance Considerations: VPP program design and compensation structures are shaped heavily by state regulatory environments. Co-ops in states without VPP-enabling policies may face barriers to fair compensation or value stacking. Engaging G&T cooperatives and state associations early, rather than pursuing standalone programs, may be the most practical entry point for distribution co-ops.
• Staffing or Technology Requirements: Effective VPP programs require cross-functional coordination across customer programs, distribution planning, and operations, which is a significant lift for smaller co-ops. Most rural co-ops will likely need a third-party program operator or aggregator (such as EnergyHub or Uplight) to manage enrollment, dispatch, and customer interfaces. Building this capacity internally is a multi-year effort.

Notable Examples

• Green Mountain Power (Vermont): Residential battery VPP providing both peak capacity and storm resilience backup; regulators lifted capacity caps to enable expansion.
• Holy Cross Energy (Colorado): DER-based VPP designed for wildfire-prone territory; Power+ program and Basalt Vista pilot provide dual-use peak support and backup power.
• Rocky Mountain Power (Utah): WattSmart Battery program dispatches batteries daily for multiple grid services; passed Utah PSC cost-benefit review.
• Ontario IESO: Enrolled 100,000 homes in 6 months via Save on Energy Peak Perks program, demonstrating rapid VPP deployment at scale.
• Portland General Electric (Oregon): Integrating VPPs into long-term planning, running an AI pilot with Utilidata, and projecting DERs will meet 25% of peak demand by 2030.
• PG&E + Sunrun (California): Dispatched 8,500 existing customer batteries within 6 months to manage summer evening peaks without new infrastructure.

View Full Document Requires name and email to access

Estimated reading time: 15 minutes