Virtual power plants are becoming one of the fastest ways to add flexible capacity to the grid. Data center growth, rising renewable penetration, and lagging transmission buildout are pushing utilities and grid operators toward these flexible, rapidly deployable resources.
As the name implies, VPPs effectively act as power plants, except they draw not from a single generation source but from many distributed energy resources (DERs). These can include both supply-side resources like batteries that inject power during peak times, as well as demand-side resources like curtailable load.
VPPs effectively act as power plants, except they draw not from a single generation source but from many distributed energy resources.
This guide covers what a virtual power plant is, how it differs from demand response, the two main VPP models operating today, and why accurate forecasting sits at the center of both.
Why virtual power plants matter
Three forces make VPPs valuable:
VPPs support grid stability. Utilities and ISOs need dispatchable capacity to manage peak demand and sudden supply shifts. A VPP turns a portfolio of smaller assets like batteries, thermostats, EVs, and curtailable load into a single resource that operators can call on much like a traditional power plant, but deployable in months rather than years.
VPPs support renewable integration. Solar and wind output shifts by the hour, and renewable energy curtailment is rising as generation can temporarily outstrip transmission capacity. VPPs can help absorb that variability by shifting demand toward periods of high renewable output and away from periods of grid stress, reducing solar and wind curtailment and easing reliance on fossil peaker plants.
VPPs generate profits for providers and participants. Enrolled customers get paid for the flexibility they provide, whether that's an individual or business allowing access to their EV chargers or an industrial operation shifting production schedules to avoid peak times. VPP providers and DR aggregators earn revenue from wholesale markets, capacity payments, and utility programs, and they pass along some of that revenue to program participants.
Enrolled customers get paid for the flexibility they provide.
VPPs vs. demand response
The two terms get used loosely, so it helps to separate them cleanly.
Demand response pays customers to reduce or shift electricity use during specific events, typically periods of high demand or grid stress. Demand response predates VPPs by decades and traditionally centers on load reduction, targeting primarily commercial buildings who can change things like thermostat setpoints with minimal disruption. With sufficient foresight and planning, industrial operations can increasingly participate in demand response as well.
A demand response aggregator bundles that curtailable load across many commercial and industrial customers and bids it into utility or ISO demand response programs. An aggregator's job involves enrollment, dispatch logistics, and measurement and verification against a baseline, since payment usually depends on proving that a reduction actually happened.
A virtual power plant operator aggregates a broader mix of distributed energy resources, batteries, EVs, rooftop solar, and smart thermostats alongside curtailable load, and coordinates them to behave like a single dispatchable asset.
A VPP can shed load the way a demand response program does, and it can also shift load, inject power back to the grid, or provide services like frequency regulation and voltage support.
The practical difference comes down to asset diversity and market reach. A DR aggregator manages one lever and typically bids into a specific utility program. A VPP orchestrates a portfolio of consuming and generating assets and increasingly bids directly into wholesale energy, capacity, and ancillary service markets.
How VPPs work
Types of VPPs
Most VPPs today fall into one of two categories.
Demand response-focused VPPs concentrate mainly on curtailable C&I and data center load, even as they adopt VPP branding. Voltus, CPower, and Enel X are prominent examples. They aggregate flexible load across large customer portfolios and bid it into capacity and demand response markets. All have leaned into VPP language as investment and data center deals have shifted toward that category.
VPPs orchestrating multi-asset DERs manage a genuinely diverse mix of distributed energy resources which include home batteries, electric vehicles, rooftop solar, and smart thermostats alongside curtailable load. Tesla and Sunrun are visible examples, aggregating Powerwall and solar-plus-storage fleets into utility-backed programs across multiple states.
VPP operating models
Aside from asset types, VPPs also differ in how they reach the market.
Under the LSE intermediary model, a load-serving entity like a utility sits between the DER portfolio and the wholesale market. The LSE decides when to call on the resource, usually to manage its own supply obligation or a specific program it runs, and the DER participates in the wholesale market through that relationship.
Under direct wholesale participation, the VPP bids its own portfolio into ISO and RTO markets and receives dispatch instructions straight from the system operator. This model carries more market exposure and more revenue potential, since the VPP can access energy, capacity, and ancillary service markets simultaneously rather than depending on a single utility program.
This second category exists at scale largely because of FERC Order 2222, a 2020 rule that requires regional grid operators to let DER aggregations participate directly in wholesale markets as their own class of market participant. Before this rule, most DERs reached wholesale markets only through a utility or load-serving entity acting as intermediary. Order 2222 opened the door for aggregators to bid a heterogeneous mix of assets directly, and implementation continues rolling out region by region through the late 2020s.
Why VPP providers need accurate grid forecasting
A VPP provider, whether DR-focused or a full DER orchestrator, depends on accurate grid forecasting the same way a trading desk does.
Grid demand and net demand forecasts help VPP providers understand what the system will need. They use this information to size dispatch decisions, calling enough enrolled accounts to hit a capacity commitment without over-calling and burning customer goodwill.
Price forecasts help VPP providers in the direct wholesale participation model bid optimally into power markets.
Coincident peak forecasts focus on the peak demand periods specific to each region's CP program, where applicable. Providers need to call events ahead of the utility's or ISO's own peak signal, since customers need lead time to respond.
Download Amperon for VPP Providers for a closer look at how forecasting supports dispatch timing and market bidding.
Why VPP participants need grid forecasting
Enrolled C&I customers and data centers depend on the same forecasting inputs as VPP providers, but for different reasons.
Grid demand and net demand forecasts can help VPP participants understand the likelihood of being called on by their VPP operator or DR aggregator.
Price forecasts help customers on variable day-ahead and real-time electric rates make informed price avoidance decisions by weighing expected revenue against projected electricity prices.
Coincident peak forecasts give participants ample lead time to reduce load during likely coincident peak events, helping them reduce transmission and demand charges which can account for 30-70% of a large commercial or industrial customer's electric bill.
Explore Amperon's Demand Management Solutions to see how AI-powered forecasting supports load flexibility programs for C&I and data center customers.
Additional reading
- How Forecasting Helps C&I Operations Cut Energy Bills, on the various ways commercial, industrial, and data center customers leverage load flexibility to improve profitability.
- 6 Grid Trends to Watch in 2026, on the shift of VPPs and demand response from niche programs to core grid resources.
- Navigating ERCOT's 4CP Program, a closer look at coincident peak alerts in practice for ERCOT market participants.
- How Amperon Performed During the July 2026 Heat Wave, a look at how demand response and VPP dispatch shaped the gap between forecast and metered peak during a record heat event.
Frequently Asked Questions
What is a Virtual Power Plant? A virtual power plant is an aggregation of distributed energy resources like batteries and curtailable load that, together, can be called upon to inject power or create extra capacity on the grid.
What are the disadvantages of a Virtual Power Plant? VPP participants may be asked to reduce their load or discharge their batteries during peak times, or they may have their thermostats, EV chargers, batteries, or other assets automatically controlled. Advance notice for these events varies widely by program, but forecasting can help customers understand the likelihood of an event being called.
Is a VPP worth it? VPP operators pay participants for accessing their distributed energy resources. The economics depend on business needs and specific program details, but many commercial and industrial operations with any significant amount of load flexibility find it worthwhile to participate in virtual power plant programs.
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