Virtual Power Plants (VPP)
Distributed Grid Intelligence
Virtual Power Plants aggregate thousands of distributed sources (solar, batteries, electric vehicles, flexibility) orchestrated by artificial intelligence. Discover how this new infrastructure transforms electrical grids and creates revenue opportunities for decentralized producers.
What is a Virtual Power Plant (VPP)?
A Virtual Power Plant (VPP) is an energy aggregator that federates hundreds or thousands of distributed electricity sources and flexible loads, controlled by a centralized platform via IoT and cloud computing.
"A power plant that doesn't exist physically, but plays the role of a real power plant"
Fundamental principle
Instead of building a massive thermal or nuclear power plant, you aggregate thousands of small producers (residential solar panels, small wind turbines, home batteries, load shedding). This virtual aggregation reaches equivalent power and offers the same services as a real power plant, with more flexibility.
Concrete example
- Without VPP: 10,000 homes with 3 kWc solar each = total dispersion. Producers passive to grid. Uncoordinated production.
- With VPP: Platform aggregates these 30 MWc, adjusts battery discharge in real-time, optimizes collective self-consumption, accesses EPEX Spot markets. Power equivalent to a real power plant, but distributed and flexible.
Key point: VPP transforms passive producers into active market participants. Instead of selling electricity at fixed price to distributor, you can participate in market auctions and profit from price volatility.
How It Works: VPP Architecture
4-layer information flow
1. Assets Layer (distributed sources)
Solar panels, LiFePO4 batteries, EVs (V2G), electric heaters, flexible loads (small consumer aggregates).
2. Sensors/Smart Meters Layer
IoT modules measure production/consumption in real-time (15 min to 1 sec granularity depending on equipment). Communicate via 4G/5G/WiFi to central platform.
3. Aggregation Platform Layer (VPP Core)
Cloud computing + AI / machine learning. Analyzes real-time flows, predicts production (weather models), optimizes battery discharge, calculates price offers, controls load shedding. Sub-second decisions.
4. Markets/Grid Layer
Sells electricity on EPEX Spot, auxiliary services (FCR/aFRR/mFRR/voltage services), RTE adjustment mechanism. Buys/sells continuously based on market rates.
Simplified diagram
Response times
- Production forecasting: 15 min to 24h ahead (weather models)
- Battery optimization: Continuous (every minute)
- Load shedding reaction: 1 to 15 minutes (depends on market requested)
- System services (FCR/aFRR): Sub-second (dedicated equipment)
Types of Virtual Power Plants
3 main categories
1. Commercial VPP
Goal: Maximize market revenues (EPEX Spot, auxiliary services).
- Price arbitrage: Charge batteries when cheap, discharge when expensive
- Market load shedding: Reduces consumption during peak hours
- Reserves (FCR/aFRR/mFRR): Sells response capacity to RTE
- Typical: Independent aggregators (Next Kraftwerke, Voltalis), utilities (Engie, EDF)
2. Technical VPP (or Network)
Goal: Stabilize and optimize electrical grid.
- Voltage/frequency management in critical zones
- Congestion confinement (local discharge without transiting national network)
- Synthetic inertia (batteries react to frequency variations)
- Typical: Network operators (Enedis, RTE), local authorities (microgrids)
3. Hybrid VPP
Combines commercial + grid service objectives.
- Optimizes revenues while respecting grid constraints
- Controlled by bidirectional contracts with distributor
- Typical: Future dominant model (Tesla VPP, Engie Flexibility)
Use Cases: VPP in France (2024-2025)
Major operators
Next Kraftwerke (acquired by Shell, 2022)
Leading independent European aggregator. In France since 2018.
- Aggregates 35,000+ sites in Europe (12,000 in France). Mix: PV, batteries, EVs, heat, wind.
- Proprietary "Kiwi Power" platform: real-time optimization.
- Revenues: 50-150 €/MWh depending on market (EPEX Spot, RTE adjustment, FCR).
Engie Flexibility
Flexibility division of French giant. Multi-service VPP.
- Aggregates supply/demand mix: residential batteries, industrial load shedding, EVs, heaters.
- Contracts with RTE for auxiliary services (FCR, aFRR).
- Ambition: 5 GW aggregated flexibility by 2030.
Voltalis (formerly Adept)
French specialist in residential diffuse load shedding.
- Aggregates heaters, water heaters: short interruptions (20-30 min) imperceptible.
- Enedis partnership for local grid services.
- Load shedding revenues: 30-60 €/MW/h during calls.
Tesla Virtual Power Plant
Tesla strategy: residential Powerwall batteries + solar + EVs.
- USA (California): Already active. France: Rolling out 2025-2026.
- Real-time optimization: Charges on PV production/low prices, discharges on price spikes.
- Proprietary model: Tesla controls data, optimization.
Specialized PV aggregators
Small local operators aggregate solar producers.
- Offer simple web portal + market optimization for small producers.
- Challenge: EPEX Spot market access (high technical thresholds without aggregation).
VPP + Distributed Solar Synergies
A VPP transforms an isolated residential solar installation into an active system participant.
4 key synergies
- 1. PV surplus management: Without VPP, surplus PV = battery storage or grid rejection. With VPP, surplus coordinated with 1,000+ other producers: collective smoothing, fewer peaks, market access (direct EPEX sales).
- 2. Production smoothing: Solar intermittency (clouds) = grid challenge. VPP compensates with distributed batteries: produces during solar dips acting as virtual battery for collective.
- 3. Market access: Small producer alone = no EPEX Spot access (technical thresholds ~100 kW). Via VPP aggregator: participates directly in auctions. Can sell 1 kW if aggregated with 99 others.
- 4. Intermittency mutualization: 1 solar site fluctuates ±20%. 100 sites = smoothed curve (standard deviation ±3%). VPP plays on this smoothing to sell more reliable electricity = price premium on markets.
Concrete case: You have 6 kWc solar + 10 kWh battery. Alone: 40% self-consumption, surplus rejected. Via VPP: coordinated self-consumption 60%, EPEX market access, +150-300 €/year revenue. Battery pays for itself faster.
Economic Model: VPP Revenues
Three revenue streams for aggregator
1. PV Aggregation - EPEX Spot Market
Wholesale electricity sales. Price fluctuates hourly.
- PV aggregation premium (for predictability value): +5-15 €/MWh above spot price
- Example: 80 €/MWh spot + 10 €/MWh premium = 90 €/MWh. VPP buys PV at 88 €/MWh, sells 90 €/MWh = 2 €/MWh margin.
- Magnitudes: Lone producer sells at 60 €/MWh (basic network rate). Via VPP: access 85-95 €/MWh prices.
2. Diffuse Load Shedding - Adjustment Mechanism Market
Reduces consumption during peak hours. RTE requests, VPP provides offer.
- Load shedding compensation: 30-60 €/MW/h in France (varies by urgency)
- Example: VPP aggregates 500 homes. Reduces heating 30 min during peaks = 100 kW shed. Revenue: 100 kW × 50 €/MW/h = 5 €. Split: ~0.01 € per home this half-hour, but cumulative 100-200 h/year = 10-20 € individual revenue + electricity savings.
3. Storage Arbitrage - Distributed Battery
Charge battery at low prices (night), discharge at high (evening peak).
- Price spread: Typical 30-100 €/MWh (night/evening gap)
- Round-trip efficiency: 85% (charge/discharge losses). Net revenues ~30-50 €/MWh after losses.
- Example: 10 kWh battery. Day cycle: charge 50 €/MWh, discharge 120 €/MWh. Revenue = (10 kWh × (120-50) €/MWh × 85% efficiency) = 60 € per cycle. 200 cycles/year = 12,000 € for 10 MWh aggregated = fast payback.
Grid auxiliary services (RTE)
- FCR (Frequency Containment Reserve): 50 Hz frequency stability. Compensation: 5-8 €/MWh/h (continuous).
- aFRR (Automatic Frequency Restoration Reserve): Faster recovery. 10-15 €/MWh/h.
- mFRR (Manual Frequency Restoration Reserve): RTE + manual intervention. 15-30 €/MWh/h.
Small producer revenue summary
| Service | Annual revenue (6 kWc + 10 kWh battery) |
| PV Aggregation (EPEX) | +80-150 € |
| Load Shedding (RTE adjustment) | +50-100 € |
| Battery Arbitrage | +150-300 € |
| Total VPP | 280-550 € |
Regulatory Framework in Europe and France
European directive (Clean Energy Package, 2019)
- Directive 2019/944: Recognizes producer right to aggregate and sell directly. Defines independent aggregator as neutral third party.
- Directive 2019/941: Framework for flexibility market rules and system services. Requires DSO/TSO to respect aggregator offers.
- Impact: Europe must transpose. Timeline: 2024-2025 for full applications.
France - Energy Code (AGEC Law, 2021)
- Independent aggregator status: Legalized. But strict obligations: price transparency, non-discrimination, balancing responsibility.
- EPEX Spot market: Small producer can participate via aggregator (article L. 311-5 Energy Code).
- Auxiliary services: RTE access for aggregators (FCR, aFRR, mFRR) governed by negotiated contracts.
- Bidirectional metering: Enedis obligation for surplus injection (injections > 3 kWc). Costs: free or 100-200 € depending on situation.
NEBEF (Notification Échange Blocs Effacement)
French diffuse load shedding mechanism. Aggregators notify RTE available "blocks" for reduction. Light administrative process.
- Minimum threshold: 100 kW shedding capacity (admin cost reason). Small producer alone cannot. Via VPP = yes.
- Compensation: 30-60 €/MW/h per RTE/Enedis decision.
Caution: VPP/aggregation regulation very fragmented by country. Aggregator contract = critical reading. Verify: commission taken, price transparency, easy exit clause, civil liability insurance coverage.
Learn More
Decision making
- Join a VPP? Recommended if you have battery (storage) or large solar (> 9 kWc). Small producers alone (< 3 kWc): weak gains but no additional costs.
- Which aggregator? Compare commissions (typical 5-15%), price transparency, France location, financial stability. Next Kraftwerke and Engie Flexibility: references.
- Technical vs commercial VPP: Commercial (EPEX) = revenue, but market risk. Technical (Enedis) = stable, low revenue, grid services. Hybrid = best compromise 2025+.
Key resources
- IRENA (2022): "Renewable Power Generation Costs in 2022" - Costs and VPP potential.
- IEA (2021): "Energy Storage Integration with the Power Sector" - Global VPP roadmap.
- RTE (2024): "Forecast Balance 2024-2035" - France flexibility needs.
- EU Commission (2022): "REPowerEU" - Flexibility and aggregation acceleration plan.
- Next Kraftwerke: European VPP case studies (nextko.com).
- Voltalis: French diffuse load shedding specialist (voltalis.com).
- Enedis: Bidirectional metering documentation and local services.
Conclusion: VPP represents major shift from centralized (big power plants) to distributed and flexible (thousands of coordinated small assets). In France, deployment accelerating 2024-2025. Small solar producer benefits from joining VPP to maximize revenues (300-600 €/year additional vs. fixed-rate sales), with moderate market risk. Horizon: VPP becomes standard, not exception, by 2030.