EDF widens flexibility access for metered assets

EDF is supporting wider participation in Great Britain’s flexibility markets after industry rule change P483 removed a barrier for homes and small businesses with standard electricity meters.

P483, introduced by Elexon in November 2025, allows flexibility from assets at sites with non-half-hourly metering systems to be measured through dedicated asset meters. Devices such as EV chargers and batteries can therefore participate in flexibility markets even where the main site meter has not yet moved to half-hourly settlement.

Before the rule change, flexibility providers were restricted to customers who were half-hourly settled, reducing the number of domestic and small-business assets able to take part. The new route opens participation to more customers connected through standard electricity meters, provided the flexible asset itself can be measured accurately.

Controllable technologies are central to the change. EV chargers can shift demand away from peak periods, batteries can charge when power is abundant and discharge when the system is tighter, and heat pumps can be operated around comfort limits and thermal storage. Dedicated asset metering allows the system to distinguish the action of the device from the rest of the property’s consumption.

EDF is applying the change across a flexibility portfolio that includes domestic and commercial assets. Renewable generation growth, rising electricity demand, and the expansion of controllable distributed technologies are increasing the need for measured flexibility that can be dispatched and settled with confidence.

The technical requirement is visibility. System operators and flexibility platforms need accurate data on what an asset did, when it acted, and how much power it provided or reduced. A dedicated asset meter gives a more precise basis for settlement than estimating behaviour through whole-site consumption, while allowing flexibility to develop before the full smart meter and half-hourly settlement transition is complete.

Distribution networks are already moving toward more localised flexibility models. E.ON’s firm battery proposal for constrained substations uses household storage to target pressure on specific parts of the local grid. P483 works from a different mechanism, but both approaches rely on asset-specific data rather than broad assumptions about household demand.

Greater participation can help manage reinforcement pressure where assets are visible, dependable, and located where constraints occur. A large national pool of flexible devices does not automatically solve a local feeder or substation constraint. Asset metering improves the quality of data, but network value still depends on coordination between suppliers, aggregators, platforms, and network operators.

Market operation is another practical hurdle. Flexibility requires registration, baselining, dispatch, measurement, settlement, cyber-secure communications, and clear customer consent. A battery or EV charger may be technically flexible, but its market value depends on accurate metering, reliable controls, and the ability to respond at the right time.

Customer participation also needs a clear commercial route. Flexibility providers must aggregate enough assets to justify integration, registration, trading, and support costs, while customers need simple onboarding and visible value. Automated settlement and standardised asset processes will be essential if participation is to extend beyond early adopters.

P483 gives EV chargers, batteries, heat pumps, and other distributed technologies a clearer route into flexibility markets. It does not replace the need for half-hourly settlement, smarter controls, or stronger network coordination, but it widens the asset base available to support a power system with more renewable generation and more electrified demand.