The trucks are the easy part of fleet electrification to finance — they are assets with resale markets, warranty coverage and established lending products. The charging infrastructure is where capital plans wobble: transformers, switchgear, DC chargers, civil works, grid connection fees and software land in one lump of CAPEX before a single electric truck has moved a pallet, and the numbers intimidate CFOs who have not yet seen the operating savings those assets unlock. A 20-truck depot is a USD 350,000–900,000 infrastructure programme depending on power class and site condition — comparable to 3–6 of the trucks it serves. This article lays out what the CAPEX actually consists of, the four financing structures available for depot build-outs in our export markets, and how to structure the investment case so the infrastructure — not just the trucks — pencils as an asset.
Every EV truck depot build shares the same cost anatomy, and understanding it is what lets you compare financing offers sensibly:
| Cost block | Typical range (20-truck depot) | Notes |
|---|---|---|
| Grid connection & transformer | USD 80k–250k | Most site-variable line; utility timelines run 6–18 months — apply early |
| DC fast chargers (120–240 kW) | USD 40k–70k each × 6–10 units | Dual-gun units improve utilisation |
| Civil works, cabling, canopy | USD 60k–150k | Rises sharply on brownfield sites |
| Load management & software | USD 20k–60k | OCPP-compliant; the ROI lever for tariff arbitrage |
| Battery buffer (optional) | USD 90k–200k | Enables smaller grid connection + peak shaving |
| Solar carport (optional) | USD 150k–350k | High-irradiation markets only; 20–35% energy cost reduction |
| Core programme (ex-options) | USD 350k–900k | 1.5–2.5 MW service typical at this fleet size |
Two design levers move the total more than any procurement negotiation: load management (which lets six chargers serve twenty trucks through staggered scheduling, cutting charger count by a third) and the buffer battery (which can downsize the whole grid connection — often the difference between a USD 250k utility project and a USD 120k one). Finance the design engineering properly; it repays itself several times in the CAPEX lines.
The default: fund the depot from cash or an existing facility, own everything, operate everything. The advantage is total control of charging cost — at USD 0.08–0.12/kWh blended tariff, the depot is a profit centre relative to diesel from day one, and every efficiency gain accrues to you. The disadvantages are the obvious ones: lump-sum capital, technology obsolescence risk, and operating responsibility (maintenance contracts for chargers run USD 3,000–8,000 per charger-year). Straight CAPEX suits operators with strong balance sheets, long site tenure (10+ year leases or owned yards), and fleets large enough to justify in-house energy management — as a rule of thumb, 15+ trucks.
Charger OEMs and their finance arms increasingly offer operating leases on the equipment layer: the chargers, software and sometimes the buffer battery lease for a monthly payment over 5–8 years, while the site works and grid connection remain the fleet's. Typical economics: a USD 500k equipment layer leases at USD 9,000–13,000 per month — converting 70% of the programme into opex while preserving the tariff upside. The structure suits fleets that want the trucks and infrastructure on comparable payment profiles, and it shifts obsolescence risk to the lessor, which matters in a market where charger power classes are still climbing (360 kW and MCS-class hardware are arriving). Watch the end-of-lease terms: chargers are heavy infrastructure, and removal/restoration clauses can bite on brownfield sites.
The full opex conversion: an infrastructure partner — an energy company, utility SPV, or specialist CaaS operator — builds, owns and operates the depot charging, and sells the fleet energy at a per-kWh rate or a monthly capacity subscription. The fleet signs a 7–10 year energy supply commitment, typically at USD 0.02–0.05/kWh above the raw tariff to cover the partner's capital and operating cost. The virtues: zero or near-zero upfront capital, professional uptime management, and a single predictable energy invoice that makes the fleet's TCO model bankable from day one — which is precisely why CaaS structures travel well into emerging markets, where the partner's infrastructure balance sheet de-risks the fleet's electrification case for lenders. The trade-offs: you surrender tariff arbitrage and solar upside to the partner, and the long commitment needs a break/step-down structure if your fleet size changes. CaaS suits first-mover fleets, concession-bound operators (ports, mines, municipal contractors) and anyone whose capital is better deployed in trucks than in transformers.
The layer most export-market fleets under-use. The pipeline of climate finance now touches commercial road transport in most of our markets: development-bank credit lines routed through local banks (IFC, ADB, AfDB and EBRD facilities in Africa, Central and Southeast Asia), national green credit windows with concessional margins for electrified transport, export-credit agency (ECA) cover on the Chinese equipment leg, and lease structures backed by climate funds that shave 150–300 basis points off standard commercial pricing. The application burden is documentation: an emissions-baseline calculation (the diesel fleet's fuel burn), a credible measurement plan (the telemetry platform), and a transition plan with milestones. We supply the technical file for the truck side of these applications as part of fleet programmes — the truck telemetry, warranty and TCO documentation doubles as the green-finance evidence pack. Fleets that assemble this paperwork can fund trucks and depot together at concessional rates; fleets that do not pay commercial rates and assume the market offers nothing.
Whichever structure you choose, the depot investment case should be argued as an asset with its own return, not overhead attached to the trucks. The argument has four legs:
Condensed to a page, the financing decision follows fleet reality. Strong balance sheet, owned yard, 15+ trucks, energy management appetite: build and own — straight CAPEX captures the full energy margin and the growth option value. Capital constrained, site tenure certain, trucks on payment plans: lease the equipment layer to match asset lives and shift obsolescence risk. First-mover in a market, concession-driven revenue, or capital better deployed in operations: CaaS converts the whole infrastructure to a predictable energy invoice and de-risks the fleet case for lenders. And in every configuration, check the green-finance layer first — the concessional windows available in most emerging markets today price the same infrastructure 150–300 basis points inside commercial terms, and the only barrier is documentation discipline. Whichever structure fits, the sequencing rule is universal: the utility application, the design engineering and the financing term sheet move in parallel, months before the first truck ships. The depot is the long-lead item in every successful EV truck programme we have delivered — and the best-financed fleets are simply the ones that started it first.
Ready to electrify your fleet? Contact Shaanxi Fenghan Trading — authorized Dongfeng EV truck exporter. WhatsApp: +86 153 1943 1311 | Email: sales@fenghan-trade.com | dongfengevtrucks.com And whichever financing structure carries the depot, the underlying asset case keeps strengthening: charger hardware costs per kW continue to fall, buffer batteries inherit the second-life supply stream the trucks themselves create, and every tariff reform in our markets has moved toward rewarding the controllable, schedulable load that a managed EV truck depot is.
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