RED III's vehicle-grid integration provisions: what is actually in the directive
The revised Renewable Energy Directive — Directive (EU) 2023/2413, commonly referred to as RED III — entered into force in November 2023, replacing and amending the previous RED II (2018/2001/EU). It sets an overall EU renewable energy target of 42.5% by 2030 (with an aspirational target of 45%) and introduces sector-specific sub-targets for heating and cooling, industry, and transport. Article 22a specifically addresses vehicle-grid integration (VGI) and smart charging in the context of renewable energy uptake.
Article 22a requires member states to assess the potential of smart charging infrastructure — including bidirectional charging (vehicle-to-grid) — for contributing to renewable energy integration. It obliges member states to ensure that smart charging access is not subject to regulatory barriers that would prevent fleet operators and other EV users from participating in demand response programmes and providing balancing services to the grid. The article does not mandate specific V2G deployment targets, but it does create the regulatory obligation to remove barriers that would otherwise prevent bidirectional charging from being commercially feasible.
For fleet operators, the key implication is not an immediate compliance requirement but a medium-term strategic signal: the European regulatory framework is explicitly moving toward enabling fleet batteries as distributed grid assets. Depot operators who build their charging infrastructure to support bidirectional energy flows today will be positioned to participate in ancillary services markets as those markets mature and V2G-capable hardware becomes more widely available.
The market framework that RED III enables: FCR, aFRR, and demand response
To understand what RED III's VGI provisions unlock, it helps to understand the ancillary services markets that large fleet battery aggregates could access.
Frequency Containment Reserve (FCR)
FCR — called Primärregelleistung in Germany — is the fastest-responding balancing service, activated automatically within 30 seconds of a frequency deviation exceeding ±200 mHz from 50 Hz. FCR providers must offer symmetric ±MW capacity (equal capacity to increase and decrease consumption or generation) with full delivery within 30 seconds. For a fleet of BEV trucks connected overnight, providing FCR means the battery systems must be capable of both absorbing additional power (demand increase) and discharging back to the grid (V2G discharge) within 30 seconds of a grid frequency trigger. This requires bidirectional on-board chargers (OBCs) supporting ISO 15118-20 AC bidirectional or CCS DC bidirectional (V2G) capability, combined with a low-latency grid frequency monitoring system integrated with the charging management software.
FCR qualification in Germany requires a minimum 1 MW of contracted capacity, which a fleet of 50+ BEV trucks with 400 kWh batteries and 22 kW bidirectional charging capability could theoretically aggregate. The market value of FCR in Germany has ranged from €10–80/MW per week in recent years, with significant volatility driven by renewable generation variability. However, the FCR delivery constraint — symmetric response at any point during the contracted window — conflicts directly with the fleet's departure readiness requirement. A vehicle providing FCR at 23:00 that is also scheduled for 05:30 departure cannot be discharged below a safe SoC floor, which limits the symmetric capacity it can reliably offer.
Automatic Frequency Restoration Reserve (aFRR)
aFRR (Sekundärregelleistung in Germany) operates on a slower response timescale — full activation within 5 minutes — and can be provided asymmetrically (upward-only or downward-only capacity). The asymmetric capability makes aFRR more compatible with fleet charging operations: a depot can offer downward aFRR (increased consumption) during overnight charging windows without requiring V2G capability, by shifting charging demand upward when the system operator requests additional consumption. This is equivalent to demand response: the scheduling engine responds to an aFRR dispatch signal by increasing the per-vehicle charging current setpoints above the cost-optimised schedule. The fleet's battery capacity absorbs the additional energy; the fleet's electricity cost may increase slightly for that window, but the aFRR revenue compensates and typically exceeds the tariff premium.
Interruptible load demand response
Below the formal ancillary services markets, Article 22a also supports participation in DSO-level demand response programmes — the German §14a EnWG framework being one example. Rather than curtailment (the DSO reducing load as a congestion management tool), proactive demand response contracts allow depot operators to voluntarily shift charging windows in exchange for reduced network tariff charges under the Netzentgeltverordnung (StromNEV). This is sometimes called a "netzdienliche Steuerung" arrangement — grid-serving control. It's a commercial relationship between the depot and its DSO, and its viability depends entirely on the depot having scheduling software that can receive and act on external dispatch signals.
The V2G technology readiness gap: where the market actually is in 2026
The regulatory framework established by RED III and the enabling markets described above are ahead of the technology readiness curve for V2G at fleet scale. This is the most important nuance in any discussion of RED III and VGI for depot operators.
As of early 2026, CCS DC bidirectional charging (the relevant standard for commercial vehicles is ISO 15118-20 combined with IEC 61851-23 for DC) is not yet widely available in production commercial truck BMS and OBC designs. Most commercial BEV trucks shipping in 2025–2026 use unidirectional AC or DC charging only. The light commercial vehicle (LCV) segment has more bidirectional-capable models in the market — the Nissan Leaf V2G-capable variant and some Japanese LCV BEV models with CHAdeMO bidirectional — but CHAdeMO is not the dominant connector standard in European fleet infrastructure, which standardised on CCS.
We're not saying that V2G for European fleets is distant or speculative — it is coming, and the regulatory framework has anticipated it correctly. What we're saying is that a depot operator making infrastructure investment decisions today should build for V2G readiness, not V2G delivery. The practical readiness checklist is different from a live V2G operation.
What V2G readiness means for depot charging infrastructure decisions today
Building V2G-ready infrastructure now — before bidirectional commercial trucks are widely available — involves a set of decisions that are low-incremental-cost relative to non-ready alternatives:
AC bidirectional charger selection. For LCV fleets with ISO 15118-AC capable vehicles, select AC bidirectional EVSE now rather than standard unidirectional AC hardware. The cost premium for bidirectional AC EVSE over unidirectional AC is narrowing; units supporting ISO 15118-20 AC bidirectional are available in the 11–22 kW power class from European hardware manufacturers. For medium-duty trucks, the relevant standard is ISO 15118-20 combined with DC charging, which requires DC infrastructure (150–350 kW CCS DC capable of bidirectional flow) — these systems are significantly more expensive but the infrastructure lifetime is 15–20 years.
OCPP 2.0.1 adoption. ISO 15118-20 bidirectional charging control relies on the communication between vehicle and charge point. The charge point to CPMS communication for bidirectional sessions is specified in OCPP 2.0.1's Smart Charging annexes. Deploying OCPP 2.0.1-capable charge points now ensures that when bidirectional vehicles arrive in the fleet, the CPMS integration layer does not require hardware replacement — only firmware updates and software changes.
Energy management system architecture for signal reception. Participation in FCR, aFRR, or demand response requires the depot's charging management software to receive external dispatch signals and act on them within the response time required by the market. For FCR (30-second response), this requires a real-time grid frequency monitoring input and a low-latency control loop. For aFRR and demand response (5-minute to 15-minute response), a standard SCADA/EMS integration via OpenADR 2.0 or USEF protocol is sufficient. Building the architecture to receive these signals — even before participating in any market — means that market access is a software configuration change, not a hardware addition, when the time comes.
A plausible 2028 scenario: 80-truck depot providing aFRR via smart charging
To make the RED III VGI provisions tangible, consider a depot operating 80 BEV medium-duty trucks with 350 kWh usable batteries, each equipped with a 50 kW DC CCS bidirectional charger (hypothetical production models arriving in the 2027–2028 timeframe at scale). The depot has a 4 MW grid connection. All 80 vehicles are connected overnight from 18:00 to 06:00.
The theoretical aFRR downward capacity during the 22:00–04:00 cheap overnight window: 80 vehicles × 50 kW = 4,000 kW of controllable load available for upward aFRR dispatch (increasing consumption on signal). The scheduling engine constrains available aFRR capacity to vehicles that have not yet reached their departure SoC target, ensuring that committed aFRR capacity is only drawn from vehicles with room to absorb additional energy. Realistically, 60 of the 80 vehicles will be in their active charging phase at any given time during this window — 3,000 kW of aFRR downward capacity available for 5-minute response, minus a 20% operational reserve, giving a net contracted capacity of approximately 2,400 kW (2.4 MW).
At an aFRR market clearing price of €15–25/MW per hour (directional order, downward), the depot's aFRR participation generates €36–60 per hour of contracted operation, or roughly €360–600 per overnight window. Annualised across 250 contracted nights, this represents €90,000–150,000 in ancillary service revenue — sufficient to meaningfully offset the infrastructure cost premium of bidirectional chargers and the software integration cost of market participation. The departure readiness guarantee is maintained throughout: the scheduling engine treats departure SoC targets as inviolable and only offers aFRR capacity from vehicles that can absorb the additional energy without compromising their assigned departure window.
This is the future that Article 22a of RED III is designed to enable. The distance between today's fleet charging operations and that scenario is not principally regulatory — the framework is already being built. It is primarily technological (bidirectional commercial vehicles at scale) and commercial (aggregation business models for depot operators who are not directly registered as balancing market participants). Fleet operators who instrument their infrastructure now for bidirectional readiness will have the shortest path to that market when it materialises.