SSEN Distribution is seeking up to 708MW of flexibility across 178 areas, in a market designed to pay providers for shifting electricity demand, generation or storage when the local network is under pressure. The auction points to a larger issue for Scotland: how a more electrified economy can be managed while the grid adapts to rising demand, renewable generation and new low carbon technologies.
Scottish and Southern Electricity Networks Distribution will open a new long term flexibility auction at 09:00 on Tuesday 26 May 2026, seeking up to 708MW from flexibility service providers across 178 areas in its north and south network regions.
The market window will remain open until 11:00 on 9 June 2026 and will be run through the ElectronConnect platform. SSEN said it has already procured close to 1GW of flexibility during the current ED2 price control period, the five year regulatory settlement running from 2023 to 2028.
Flexibility, in this context, means paying providers to alter how and when electricity is generated, stored or consumed. That may involve battery storage, generation, aggregated demand, electric vehicle charging, heat pumps or other assets being adjusted to help manage local constraints on the grid. SSEN describes flexibility as a way to prevent local networks being overloaded while supporting the connection of low carbon technologies.
The auction is not only a procurement exercise. It is part of a wider shift in how Britain’s electricity networks are being operated. As more homes, vehicles and heating systems become electric, distribution networks are moving from passive wires to active systems that must balance power flows in real time. For Scotland, where renewable generation, rural geography, island networks and network constraints already shape the energy debate, flexibility is becoming an important part of the net zero transition.
For most households, electricity networks remain largely unseen until something goes wrong. A light comes on, a kettle boils, a charger works in the hallway. Behind those ordinary moments sits a system that was built around predictable demand, large power stations and one way flows of electricity from generation to customer.
That system is changing.
Electric vehicles, heat pumps, rooftop solar, batteries, wind farms and local generation have altered the character of electricity networks. Power is no longer simply sent from central generation to customers. It moves through local networks in more complicated patterns, sometimes arriving in places that were not designed for heavy generation, and sometimes creating new demand in streets, villages and industrial sites that were not built for mass electrification.
SSEN’s latest auction is a response to that shift. The company’s distribution network serves more than 3.9 million homes and businesses across the north of Scotland and central southern England. In Scotland, its teams operate across some of the most geographically difficult parts of the country, including the Highlands and Islands, where distance, weather, sparse population and island infrastructure make electricity networks more complex.
Flexibility markets are intended to help the network cope without always building new physical infrastructure first. Instead of immediately reinforcing a cable, substation or local network, a distribution operator can buy services from providers able to reduce demand, increase demand, export power, store electricity or shift use at particular times and locations.
In practice, the grid operator is not only asking how much electricity exists. It is asking where it is, when it is needed, and whether consumption or generation can be moved by a few minutes, hours or days to avoid a constraint.
The principle is not new. SSEN has been developing flexibility services for several years and says it led work on Constraint Managed Zones from 2015, using flexibility in constrained areas as an alternative to traditional reinforcement during peak demand.
What is changing is scale. During the current ED2 period, SSEN says it has already procured close to 1GW of flexibility. The new auction seeks a further 708MW, far larger than the 46MW sought in a previous long term window announced in January 2026.
That increase shows how local flexibility is moving from experiment to operating tool.
Ofgem’s RIIO ED2 price control runs from 1 April 2023 to 31 March 2028 and sets what electricity distribution network operators can earn and what they are expected to deliver in return. It is the regulatory backdrop to much of this work. The settlement places pressure on network companies to enable decarbonisation, maintain reliability and demonstrate value for consumers rather than defaulting to more expensive reinforcement in every case.
There is a financial logic to that approach. Reinforcement is sometimes unavoidable. Scotland will need major investment in transmission and distribution infrastructure as more renewable generation connects and as demand rises through electrification. But not every constraint requires immediate new infrastructure. Some can be managed by changing behaviour, storage patterns or generation output.
Energy Networks Association describes a flexibility provider as a user who provides flexibility services by making temporary changes to how they consume, generate or store electricity. In the local market, those services can be highly geographical, because a constraint may exist on one part of the network while another nearby area has capacity.
That geography is especially important in Scotland. The country’s electricity challenge is no longer only about producing more renewable power. It is also about whether that power can be moved, stored, used locally, or prevented from overwhelming parts of the network at the wrong time.
The tension has already become visible at transmission level. Scotland’s renewable generation is growing, but grid capacity has not always kept pace. The Financial Times reported that Scottish wind farms were paid to curtail 37 per cent of their potential output in the first half of 2025, with grid limitations preventing power being used locally or moved elsewhere. The same report said 86 per cent of curtailed UK wind energy came from northern Scotland.
Distribution flexibility is not the same as national wind curtailment. It operates at a different layer of the system. But the underlying problem is related. A cleaner electricity system needs not only generation, but timing, location and capacity.
The north of Scotland is central to that problem. SSEN Transmission has said the north of Scotland is expected to need 40GW of renewable energy capacity by 2050 to achieve net zero, compared with around 8GW of renewable generation connected today.
Those figures describe the scale of the build out expected over coming decades. They also help explain why flexibility has become increasingly important inside the energy sector. It offers one way of getting more useful capacity from existing networks before every physical upgrade is complete.
For consumers, the idea can sound distant. Flexibility service providers are not necessarily ordinary households acting alone. Many services are delivered through aggregators, commercial assets, battery operators, generators or larger energy users. SSEN’s earlier flexibility communications have referred to owners, operators or aggregators of generation, storage or demand assets with flexibility capacity over 50kW being able to provide services in return for payment.
But the boundary between large provider and household system is beginning to blur. Electric vehicles, heat pumps and domestic batteries can be grouped by suppliers or aggregators. National Energy System Operator’s Demand Flexibility Service has already shown how homes and businesses can be rewarded for using less electricity, or shifting use, when the system needs support.
This is where flexibility becomes socially important.
If designed well, it can reduce pressure on the grid, allow more low carbon technologies to connect, reduce the need for expensive reinforcement and create revenue opportunities for those who can adjust demand or provide storage. If designed poorly, it risks becoming another complex market in which only sophisticated operators benefit, while ordinary consumers are asked to adapt to systems they do not fully understand.
Paul Fitzgerald, Flexibility Manager at SSEN Distribution, said the new auction builds on progress already made in flexibility markets and that long term contracts can give providers greater certainty of revenue while helping manage constraints efficiently and support low carbon technologies. SSEN also linked flexibility to energy security, saying participation in the markets could help develop a home grown, secure energy system during a period of geopolitical uncertainty.
That argument has force. Since the energy price shocks that followed Russia’s invasion of Ukraine, governments, regulators and network companies have repeatedly linked domestic low carbon energy with security and affordability. The logic is that an electricity system drawing more from domestic renewables, storage and flexible demand should be less exposed to international fossil fuel markets.
Yet energy security is not achieved merely by adding more devices to the grid. A secure electricity system must be resilient, affordable and understandable. It must work in rural areas as well as cities, in winter as well as summer, and for households without the money to install batteries, heat pumps or electric vehicles.
Scotland’s rural and island geography makes that point sharper. In a dense urban grid, flexibility may involve thousands of assets responding across a compact area. In a Highland or island context, the same idea can be constrained by distance, communications, weather, income and local infrastructure. A battery, generator or flexible load may be valuable precisely because there are fewer alternatives nearby.
This is why the development of local flexibility markets needs public attention. Decisions about where flexibility is bought, who can provide it, how much they are paid, what happens when flexibility is unavailable, and whether reinforcement is deferred or merely delayed all have consequences for communities and consumers.
There is also a question of transparency. Network operators must increasingly publish data on constraints, procurement and flexibility requirements. SSEN’s own procurement page sets out upcoming bidding windows and identifies different flexibility products, including availability and utilisation arrangements.
The wider market is also being reshaped. Ofgem appointed Elexon in July 2024 as the market facilitator for local flexibility markets, with a mandate to develop and align local markets and reduce fragmentation. Ofgem’s later framework documents identify the need to coordinate local and national flexibility markets, while Elexon says the current system is fragmented and that flexibility must play a bigger role in reaching clean power targets.
That matters because complexity can become a barrier. Distribution operators, national system operators, aggregators, suppliers, asset owners and consumers can all be part of the same chain. Without clear rules, a valuable flexibility resource may be difficult to access, double counted, or trapped behind processes too complicated for smaller participants.
The auction opening on 26 May is therefore a small window into a larger restructuring of Britain’s electricity system. It is about 708MW of potential services, but it is also about a new way of operating the grid.
For decades, electricity networks were planned around predictability. The future will be less predictable. Wind output varies. Solar output rises and falls. Electric vehicles add new peaks. Heat pumps change winter demand. Data centres, industry and electrified transport may increase load in particular locations. Households and businesses may both consume and generate.
A rigid grid can respond to that world only by building more capacity everywhere. A flexible grid tries to respond by using time, location and digital coordination as part of its infrastructure.
The important question is whether flexibility is used alongside investment, or instead of it.
If flexibility complements grid investment, it can help Scotland connect more clean power, reduce waste and manage local demand more intelligently. If it becomes a substitute for necessary reinforcement, the country may find itself managing constraints rather than solving them.
For now, SSEN’s auction marks another step in the development of local flexibility markets. It offers providers an opportunity to bid into longer term contracts and gives the network operator another tool for managing pressure across 178 areas. For Scotland, it is also another sign that the energy transition is no longer only about turbines, pylons and policy targets.
It is about when electricity moves, where it moves, who is paid to adjust, and whether the public understands the system being built around them.
The grid of the future will not be built only in substations and offshore wind farms. It will also be built in markets, contracts, software platforms and the timed behaviour of millions of devices. That may be necessary. But it should not happen out of public view.
