V2G is not a charger feature. It is an operating model.

V2G is not a charger feature. It is an operating model.

Vehicle-to-grid will not scale simply because vehicles can export power. It will scale where boards, investors and operators can see a controlled, repeatable and bankable value model.

·    7 minute read

Vehicle-to-grid is too often discussed as a technical feature. A vehicle can discharge. A charger can run bidirectionally. A software platform can respond to grid signals. All true, and none of it sufficient.

The commercial questions are different, and they are questions of control. Who controls the vehicle, the charger and the site connection? Who holds the right to dispatch the battery, and who owns the revenue when it does? Who carries the degradation, availability and customer-risk consequences? And can any of it be repeated across a portfolio rather than a single favourable site?

That is where V2G or as it is also known V2X becomes interesting: not as one vehicle sending power back to the grid, but as part of a wider energy infrastructure platform. The revolution is not bidirectional charging on its own. It is treating mobility, grid capacity, storage, site energy flows and customer demand as one investable system.

Complex infrastructure fails at the joins, and V2G is mostly joins: the seams between the vehicle, the charger, the connection, the customer relationship and the market. The value lives in controlling those seams, not in any single asset that meets at them.

The scale is material, but only if it can be controlled

The theoretical scale is significant. In a fully electrified UK car fleet scenario of around 35 million vehicles, gross battery stock could reach roughly 2.0 to 2.8 TWh. Very little of that would ever reach the grid. Vehicles need to move, customers need confidence, and batteries carry warranty, degradation and operating constraints. A fully electrified UK commercial vehicle fleet (vans, buses/ coaches and HGV would have a plausable range of 500-900GWh depending, principally, on the HGV battery mix. Availability is not the same as capacity.

Even so, for the UK car fleet, as the example, after practical haircuts for state of charge, participation, plug-in behaviour, mobility needs and export availability, a realistic accessible flexible capacity could still sit between 50 and 400 GWh. With a central planning assumption of perhaps 150 to 200 GWh.

To put 200 GWh in human terms, it is 200 million kWh: equivalent to the annual domestic electricity use of roughly 74,000 UK homes. More than twice the household electricity demand of a town the size of Crewe in England or Paisley in Scotland. From a European perspective that’s towns the size of Gouda in the Netherlands, Bayreuth in Germany or Benidorm in Spain.

The power figure tells the same story. On our prior scenario modelling, a full-fleet electrification case implied V2G power potential of around 86 GW, even though only a minority of vehicles would ever be connected, available and exporting at any moment.

These are not forecasts. They are scale markers, and they cut both ways: they show why V2G matters, and why the operating model matters more. A large theoretical battery stock is not usable flexibility. The investable question is how much of it can be accessed, dispatched, settled and monetised without compromising the primary purpose of the vehicle.

EV charging becomes energy infrastructure at scale

At scale, EV charging is not a property amenity, a customer service or an equipment rollout. It is an energy infrastructure business.

The assets that matter are not only the chargers. They are the grid connection and the capacity contracted against it, the site load profile and the private network behind it, the customer demand and the dwell time, as well as the energy procurement strategy, the data layer that prices it; and increasingly, the ability to flex demand or export value back into the system.

That distinction changes the investment case. A passive model installs chargers and buys electricity. An active model owns or controls the energy architecture and optimises across charging, storage, solar, grid import, flexibility, capacity and customer demand. The value is not in the charger. It is in the controlled energy position around it.

The same logic holds at a hub level. A major EV car charging hub can carry a peak demand of 10 to 15 MW or more. Add 5 to 10 MWh of stationary storage, onsite generation, a constrained connection, dynamic tariffs and high utilisation, and the site stops behaving like a retail location and starts behaving like an energy asset.

The investable value is then not only electricity sold to drivers. It can include avoided reinforcement, managing peak-import management, arbitrage, grid services, uptime and private-network optimisation.

This is why V2G should not be underwritten as speculative trading upside. Flexibility revenues, wholesale optimisation and grid services are real, but they are variable, market-dependent and hard to finance in isolation. The base case has to hold without assuming perfect availability, stable market revenues or frictionless customer participation.

The more credible model is revenue stacking, but only where control exists. Demand management, peak import reduction, deferred reinforcement, fleet charging optimisation, access to flexibility markets, wholesale price optimisation and a customer or landlord revenue share all contribute. None of them is investable unless the operating model can prove when the asset is available, who can dispatch it, how the revenue is captured and how the risk is allocated.

In earlier site-level modelling, a large EV hub with meaningful peak demand, onsite storage and active energy management could support flexibility value in the order of £1 million a year, depending on connection arrangements, utilisation, market access and dispatch strategy. That is not a universal number. It is a reminder that flexibility becomes material when energy infrastructure, customer demand and operational control are designed together.

Where is V2G most likely to scale first?

Early scale is more likely to come from fleets and depots than from fragmented domestic aggregation.

Passenger EVs hold large theoretical potential, the asset is dispersed and regulatory framework immature. The driver controls behaviour, plug-in time is uncertain, dwell time varies, and warranty and degradation concerns sit close to the user. Domestic V2G will come, but later and likely under a different adoption model.

Depots are different. Vehicles return to known locations, duty cycles are more predictable, and the operator controls the charging window. The economic rationale is clearer too: reduce energy cost, manage peak demand, use spare battery capacity while vehicles are parked, and potentially earn revenue from it.

Commercial fleets, buses, vans, local authority vehicles and depot-based logistics are the more practical starting point because they offer concentrated demand, repeatable behaviour and clearer operational control.

Motorway and public hubs matter, but they pose a different problem. Vehicles are there to charge quickly and leave; the customer need is availability, speed and reliability. In that setting, the near-term value sits more naturally in stationary batteries, private networks, renewable generation, demand optimisation and grid-capacity management than in treating transient customer vehicles as export assets.

That is not a weakness in the thesis. It is a reminder that the use case decides the model.

None of this is a verdict against domestic V2G. It will come. The household fleet holds the largest single pool of flexibility, and that potential does not disappear because it is harder to reach today. Domestic scale is a question of timing, investment and clearing the current frictions in interoperability, policy and regulation, not of whether the value is real. The direction is clear. The sequencing matters.

What unlocks that market is the demand side, and it is where the operating model earns its name again. Mass adoption will not come from asking drivers to think about dispatch windows, price spreads or state of charge. They will not, and they should not have to.

The complexity has to be absorbed by the platform and kept away from the user. The user should see only a simple proposition: plug in, and be better off.

The same discipline that makes flexibility bankable for investors, controlling the joins between vehicle, charger, connection and market, is what makes the product effortless for the customer. Insulating the end user from the system is not a nicety. It is the precondition for adoption at scale.

What investors, boards and CEOs should test

In our work with platform developers, the question that decides bankability is rarely around the technology. It is whether the value around it can be controlled.

For investors, the question is not whether V2G has theoretical value, because it does. It is whether that value can be controlled, evidenced, contracted and repeated.

For boards, the issue is risk allocation. A business acting as charge point operator, fleet operator, landlord, energy trader, aggregator, infrastructure owner or flexibility provider takes on a different risk profile in each role, and each demands different capabilities and decision rights.

For CEOs, the operating model is the constraint. V2G requires coordination across mobility, energy, customer service, technology, finance, asset management and regulation. Many businesses are still built in silos that make the full value hard to capture, even where the technology works.

Six tests help to separate an investable infrastructure thesis from a technology story.

Control. Who owns or controls the battery, charger, meter, connection, data and customer relationship? If control is fragmented, the case is fragile.

Availability. When is the asset genuinely free for export or optimisation, once duty cycles and customer requirements are protected?

Route to market. How is the energy metered, aggregated, dispatched, settled and monetised? A technical export capability is not a bankable revenue channel.

Downside protection. Does the base case work without heroic upside from flexibility markets, perfect customer behaviour or full availability?

Repeatability. Can the model travel across a portfolio, or does it depend on one site, one customer, one tariff, one OEM or one favourable local condition?

Materiality. Is the flexibility value large enough to move the investment case, or is it a useful secondary benefit? There is a real difference between a feature, a revenue line and an underwriting assumption.

Closing Thought.

V2G will not become mainstream because vehicles can technically export power. It will become mainstream when boards, investors, OEMs, fleet operators, regulators and energy companies can see a controlled, reliable and repeatable value model.

The scale of future battery capacity is not the constraint; the numbers are already large enough to matter. The constraint is whether that capacity can be accessed, dispatched, settled and monetised without undermining the primary mobility use case.

That means treating EVs not as isolated transport assets and chargers not as standalone infrastructure, but as part of one energy system.

The winners will be organisations that combine infrastructure ownership, grid strategy, customer behaviour, data, flexibility and operational control into a single coherent case, and that hide all of it behind a proposition as simple as plugging in.

V2G becomes investable when it stops being a charger feature and becomes an operating model.