Evaluate your grid constraints before you install a single charger

Your grid capacity is defined by the weakest point in your electrical supply chain — typically your utility service entrance rating, your main transformer capacity, or your main distribution panel breaker. The starting point is your utility interconnection agreement, which specifies your contracted supply capacity in kW or kVA. From there we look at your transformer nameplate rating and your existing peak demand data from interval meter readings. If you do not have easy access to these documents, we can help you identify what to request from your utility and facilities team. In most cases we can complete a preliminary capacity assessment with just a few documents.

This is the most common situation we encounter and there are several ways to address it. The first option is a phased deployment — installing as many chargers as your current grid supports and adding more as the fleet grows and grid upgrades complete. The second option is battery storage, which can provide additional peak power beyond your grid connection limit by charging during off-peak periods and discharging during high-demand charging windows. The third option is a utility grid upgrade, which takes longer and costs more but removes the constraint permanently. Most operators use a combination of all three, phased over time.

This varies significantly by market and upgrade type. A simple transformer upsizing on the customer side of the meter can often be completed in 3 to 6 months. A utility-side interconnection upgrade — where the utility needs to upgrade its distribution infrastructure to provide additional capacity — typically takes 12 to 36 months in most European and North American markets, and can take longer in congested urban areas or regions where the grid is under high demand pressure from industrial electrification. This lead time is one of the most important reasons to assess your grid constraints early, well before your fleet delivery schedule requires chargers to be operational.

In some cases, yes — but it depends on the size of the gap between your current grid capacity and your charging requirement. Battery storage works best as a grid deferral tool when the additional peak power needed is relatively modest and the charging windows are long enough for the battery to recharge between sessions. For sites where the charging load significantly exceeds the grid connection — for example a 500 kW grid serving a fleet that needs 2 MW of peak charging power — battery storage alone is unlikely to be sufficient and a grid upgrade will eventually be necessary. Our assessment models both scenarios so you can make an informed decision about timing and cost.

Smart load management is software that controls the power output of each charger in real time, distributing the available site capacity dynamically across all active charging sessions. Instead of each charger drawing its full rated power simultaneously — which would trip the site breaker — the system allocates power based on vehicle priority, state of charge, and departure time. The result is that you can charge significantly more vehicles than a static calculation would suggest. For example, a site with a 600 kW grid connection and 10 chargers each rated at 150 kW can charge all 10 vehicles overnight under smart load management, cycling power intelligently so that every vehicle reaches its required state of charge before its scheduled departure.

Yes. For operators with multiple depots or industrial sites, we conduct the grid assessment across all locations and produce a site readiness ranking that shows which sites have the most available grid capacity, which require upgrades, and which are good candidates for battery storage or solar. This ranking is one of the most useful outputs of the full electrification assessment because it allows you to sequence your rollout by site readiness rather than geography or fleet size alone — deploying first where the infrastructure is already in place and the return on capital is highest.