IN Brief:
- NESO has procured nearly 700MW through the first zonal run of the Demand Flexibility Service.
- The updated service includes zonal procurement, bidirectional flexibility, and a lower eligibility threshold of 0.1MW.
- The model gives the GB electricity system a more localised tool for balancing renewable output and network constraints.
NESO has procured nearly 700MW through the first zonal run of its Demand Flexibility Service, moving the mechanism further into routine system operation.
The service allows participating households, businesses, and distributed assets to be rewarded through suppliers or aggregators for changing electricity use at specific times. The latest design extends the model beyond national demand reduction events and enables NESO to procure flexibility in defined zones where the system needs a more localised response.
The updated Demand Flexibility Service went live in April 2026 following regulatory approval. It introduced bidirectional flexibility, allowing both demand turn-down and demand turn-up, and lowered the eligibility threshold to 0.1MW. The changes also added zonal procurement, a primacy process, and a self-nominated baseline option.
The lower threshold opens the service to a wider pool of assets. Smaller commercial loads, aggregated portfolios, battery systems, electric vehicle charging, heat assets, and industrial processes can contribute where metering, control, and market arrangements are in place. The service no longer depends only on large single loads or broad domestic participation.
Zonal procurement gives NESO a sharper operating tool. The GB electricity system is increasingly shaped by local and time-specific conditions, including high renewable output, transmission constraints, low demand periods, and regional network limitations. A flexibility service that can target particular zones can help manage those conditions with greater precision than a single national dispatch.
Bidirectional flexibility is also central to the design. Demand reduction remains useful during peak periods, but a system with high renewable penetration also needs controllable demand that can increase consumption when power is abundant. Electric vehicle charging, storage, heating, and certain industrial loads can absorb surplus generation when conditions allow.
The service sits within a wider programme of balancing reform as Britain’s electricity mix becomes less dependent on conventional generation. Gas plant has historically provided controllability, inertia, and reserve alongside energy. As renewable output grows, the system needs other sources of response to manage short-term changes in demand, generation, and network flows.
Demand-side flexibility offers one part of that response. It can reduce peak stress, absorb excess generation, support local constraints, and lower balancing costs when it is available at the right location and time. Its value depends on reliable control, accurate baselining, customer participation, and clear commercial signals.
The first zonal procurement round gives NESO practical evidence on the availability of flexible demand in targeted areas. The next test will be repeatability. Flexibility markets must deliver dependable capacity across different seasons, weather conditions, and system events, particularly as renewable output becomes more variable and local constraints become more frequent.
The redesigned service reflects a power system moving away from broad, centralised interventions and towards more granular control. Flexible demand is no longer only a consumer engagement exercise. It is becoming part of the operating architecture used to balance a cleaner, more distributed electricity network.