Someone will offer to put a battery on your depot.

Someone will offer to put a battery on your depot.

It might be Zenobé. It might be VEV, Allye or Connected Energy. The offer will sound good, because it solves a problem that's about to get worse. The trucks are ready. The duty cycles work. What's stopping you electrifying is the grid connection, the capex stack, and the fact that nobody in your business knows how to run an energy asset on the side of a logistics operation. The offer makes all three problems go away. You sign. The trucks charge. Your operations director sleeps better.

What the offer doesn't tell you is what's on the other side of it.

A mid-sized depot. Thirty trucks. Roughly 6,000 square metres of roof. A 750 kVA connection that won't carry a full electric fleet. Built and operated properly, that site can generate, store and trade electrons. The solar saves around £20,000 a year in bills. Peak shaving drops network charges by another £30,000. Flex trading sits somewhere between £10,000 and £40,000 depending on how aggressive your aggregator is and whether you sit in a constrained zone. Over a ten-year contract that's somewhere between £600,000 and £900,000 of value the depot generates above and beyond the chargers doing their job.

In the deal you'll be offered, almost all of that stays on the other side of the table.

This is not a scam. It's an asset-finance structure that works for everyone who isn't paying full attention. The capital comes in. The risk transfers. The infrastructure gets built. Your fleet electrifies on a timeline that matches your customers' demand. Real benefits, real money to provide. But the deal is being struck in a market where the operator doesn't know what they're giving up and the financier does. The asymmetry is the deal.

This paper is the briefing you don't get before you sign.

The reason the deal is on the table is that the grid can't carry your electric fleet on its own.

The transmission demand queue grew 460% in the six months to June 2025, from 17 GW to 96 GW. The total demand queue across transmission and distribution now sits at around 125 GW, against a national peak of about 45 GW. Most of that queue is data centres, but the queue doesn't separate. A logistics operator wanting an 11 kV upgrade joins the same line. Typical wait for a new HV connection is 18 to 36 months in a functioning market. SMMT has documented operator wait times of up to 15 years.

The reform programme is real but it isn't reaching distribution-connected projects yet. Phase 1 covers transmission only and is calibrated to clear the data-centre queue. EV charging hubs were named alongside data centres as strategically important in March 2026, but Phase 2 — the part that would extend the new tools to depots — does not yet have a timetable.

The fleet is ready. The customer wants the contract. The connection is years away. Into that gap walks the deal: a financier who solves the immediate problem in exchange for a contract that captures the option value of your depot for the next decade.

A pure merchant battery in the GB market averaged £70,000 per MW per year in 2025. That's the number the trade press quotes. It is not the number your depot battery will earn.

A battery sized to back fleet charging duty captures somewhere between 15% and 60% of that benchmark. The trading desk competes directly with the charging schedule. For most operators the realistic range is £15,000 to £45,000 per MW per year. The trade press number is real for an asset dispatched purely for the market. Your asset is dispatched to make sure the 06:30 deliveries leave on time.

That's the line everyone leads with. It is not the biggest line on the stack.

Every kW of peak demand the battery shaves is a kW you can drop from your Available Supply Capacity. TNUoS fixed-band charges rose 64% in April 2026. DUoS red-band exposure at 4pm to 7pm is unforgiving. Realistic value per kW of ASC reduction sits between £50 and £200 a year — lasting and certain. On a thirty-truck depot with a 1 MW battery, the network cost avoidance line is typically two to three times the flex trading line. It rarely appears in an aggregator's pitch deck because the aggregator can't bill for it.

The smaller lines: bill savings from solar self-consumption, export at around 6p per kWh, Capacity Market revenue at £5 per kW per year — down 75% from the year before after the March 2026 T-1 auction. V2G, where no UK haulier has yet published a transacted revenue figure. Project Sciurus modelled £725 per vehicle and delivered £360. Build your case on the realised numbers. They're the ones that arrive.

Stacked correctly, the value lines close the project economics. The question is who keeps the value — and that is a question about the deal, not the asset.

Four structures are being offered to operators right now. Each transfers a different package of capex, risk, and revenue upside to a different party.

Asset wrap. The financier owns the battery, the chargers, sometimes the on-vehicle batteries. The operator pays a pence-per-mile rate or fixed monthly fee. The financier retains the grid services revenue and the residual asset value. Zenobé is the dominant UK example. The structure solves capex and skills in one move. It transfers everything else. The disclosure gap is real: Zenobé's per-depot grid services economics are opaque from outside, and Bus2Grid ran for three years without publishing a closeout.

Energy-as-a-service. The operator owns the physical assets but outsources the optimisation. VEV is doing this for Stagecoach and Maritime. Flexitricity's FlexGo, launched in autumn 2025, targets exactly this market. Revenue share splits typically sit between 50/50 and 70/30 in the operator's favour, but the definition of revenue matters more than the percentage. Gross or net of imbalance costs. Gross or net of warranty hits. Ask.

Connection wrap. An Independent DNO owns the connection and recovers value through a long-term capacity charge. The operator runs everything inside the meter. Aurora Utilities has connected a long list of Stagecoach depots on this model. The structure often solves the connection timeline. The disclosure gap is the long-term capacity charge: over thirty years, an IDNO arrangement is not always cheaper than a DNO connection. Model the full term.

Full-stack ownership. The operator owns and runs everything. Maximum upside, maximum complexity. No UK haulier has done this at scale and published the economics. Maritime Transport gets closest, with over 22 MW of installed charging across thirteen depots, but has not disclosed flex participation. The right structure for operators with the balance sheet and appetite to build the capability. Thin evidence base for what "well" looks like.

Four actions before the next conversation with a financier.

Get the ASC and TNUoS exposure for the depot modelled. Know the kW of network capacity you're paying for, the banding threshold you sit closest to, and what dropping a band saves in cash terms. Most operators do not have this number to hand.

Get written estimates from three aggregators against a stated duty cycle. The difference between their numbers tells you almost as much as the numbers themselves. Variance over £30,000 per MW per year means at least one of them is being optimistic.

Do not sign a wrap deal without seeing the flex revenue assumption modelled explicitly. Ask for the £/MW/year benchmark, the depot capture factor, and the revenue share on either side. If the financier will not show you those three numbers, the deal is not ready.

Talk to a peer operator who has already signed the same structure. Ask what they would do differently. Listen for what they will not say.

Five reforms would shift the position in operators' favour.

Mandatory disclosure of depot flex revenue from ZEHID and equivalent programmes. Public funding should produce public evidence. Distribution-connected EV charging hubs brought into Phase 1 of the grid reform programme, or a published Phase 2 timetable within twelve months. Capacity Market eligibility rules redesigned for sub-1MW behind-the-meter assets combined with fleet charging. DUoS red-band timing reform that recognises HGV depot return cycles. A standardised stacked flex product across DNO and NESO services, so operators do not need an in-house trading desk to participate.

The depot is the new substation. Operators who treat it that way will pay less for electrons, earn from flexibility, and electrify on their own terms. Operators who sign without doing the sums will hand the upside to whoever finances the asset. Both futures are happening right now, across the UK depot estate. This paper is the briefing that tells you which one you're in.