Site Capacity Planning for EV Transition Projects

EV charging simplified Everyone talks about megawatts and mandates. Few talk about what actually works. Here’s the U.S. playbook that does. 1️⃣ Start with siting, not hardware. Use NREL’s EVI-Pro Lite or EVI-X along with the AFDC Station Locator to map real demand, dwell time, and grid impact. The best sites are workplaces, retail areas, fleet depots, and freight corridors, not empty parking lots waiting for traffic that never comes. 2️⃣ Build to open standards. Use OCPP 2.0.1 for charger control, OCPI 2.2.1 for roaming, and ISO 15118 for Plug & Charge. These keep you vendor-agnostic, prevent app chaos, and meet NEVI interoperability rules. 3️⃣ Cover every connector. NEVI still mandates CCS per port, but SAE J3400 (NACS) is gaining momentum. Dual-cable configurations future-proof sites as automakers switch to J3400 through 2025 and 2026. 4️⃣ Meet the reliability and payment bar. Each NEVI site must have at least four DC fast ports delivering 150 kW simultaneously with 97 percent uptime. Pricing must be displayed in $/kWh with tap-to-pay, SMS, or toll-free fallback and no memberships required. Publish live status and report via EV-CHART. If you cannot hit 97 percent, do not cut the ribbon. 5️⃣ Design for everyone. Follow the U.S. Access Board guidance now. Include clear routes, proper reach ranges, signage, and cable management. The proposed ADA/ABA rule will make these mandatory soon. 6️⃣ De-risk grid connections early. Start utility pre-applications before design. Expect transformer lead times of 12 to 30 months. Where capacity is limited, use staged power, on-site battery storage, and managed charging to control peaks. 7️⃣ Operate like a service, not a project. Write service-level agreements for uptime and repair time. Stock spares. Enable remote resets and secure firmware updates. Provide 24 / 7 multilingual driver support. NEVI funding assumes long-term operations, not quick builds. 8️⃣ Make smart charging the default. Vehicles are parked most of the day. Managed charging and storage reduce bills and help the grid. U.S. pilots such as Con Edison SmartCharge and BGE EV Smart Charge prove real savings and load shifting are achievable. Four-step rollout • Plan: Run EVI-Pro Lite, shortlist sites, and complete utility screening. • Procure: Require CCS and J3400, OCPP 2.0.1, ISO 15118, OCPI roaming, and clear uptime clauses. • Build: Follow NEC 625, design for accessibility, lighting, security, and transparent pricing signage. • Run: Show live pricing and status, maintain 97 percent uptime, report via EV-CHART, and iterate with driver feedback. Right siting, open standards, and clear SLAs mean fewer dead chargers, faster installs, and happier drivers. #EVCharging #EVInfrastructure #NEVI #OCPP #ISO15118 #SAEJ3400 #Accessibility #SmartCharging #EnergyStorage #Utilities #FleetElectrification #OpenStandards #GridIntegration #Sustainability

After deploying 1,700+ automated battery swapping stations across 22+ cities in India, here’s one thing I’ve learned that many people underestimate. Planning decides the speed of deployment. You have to plan things early, and plan them well. A location can look perfect on paper. But that is not enough. You also have to check: → Can we get the EB connection on time? → Is the required load available? → Are the property documents clear? → Will the site be easy to access for maintenance? → Is the internet stable enough for daily operations? And that’s just a small part of it. There are also approvals, documentation, acquisition challenges, maintenance access, and local execution realities. A lot of thought goes in before we plan an EV station. So while many people think deployment is all about asking: “Can we install here?” The right question we ask is: Can this site survive power, approvals, maintenance, access, and customer use? That is where good site planning actually starts. #EVDeployment #SitePlanning #EVInfrastructure #BatterySwapping

One operator found £50k of unexpected costs under their hardstanding. The diesel tank nobody remembered, plus the contaminated soil that came with it. Site constraints kill more depot projects than technology ever will. Rarely because the chargers don’t work, more often because power, land rights, or ground conditions were misunderstood. The early adopters learned that the hard way and now they survey first, plan second. Here's some of the things that can catch you out: 𝗟𝗲𝗮𝘀𝗲 𝘁𝗲𝗿𝗺𝘀 𝗮𝗻𝗱 𝗹𝗮𝗻𝗱𝗹𝗼𝗿𝗱 𝘀𝗶𝗴𝗻-𝗼𝗳𝗳 Who actually owns the site? Leasehold constraints often dictate what infrastructure is viable. One operator got halfway through design before discovering their landlord wouldn't approve ground works. Six months lost. - Approval often covers chargers but not substations, trenching routes, or long-life electrical assets that outlast the lease 𝗨𝗻𝗱𝗲𝗿𝗴𝗿𝗼𝘂𝗻𝗱 𝘀𝘂𝗿𝗽𝗿𝗶𝘀𝗲𝘀 Fuel tanks, drainage, unmarked cables. A proper underground services survey costs a few thousand. Skipping it can cost ten times that. - Ground conditions, earthing arrangements and legacy infrastructure can be just as costly as anything you find buried 𝗘𝘅𝗶𝘀𝘁𝗶𝗻𝗴 𝗲𝗹𝗲𝗰𝘁𝗿𝗶𝗰𝗮𝗹 𝗶𝗻𝗳𝗿𝗮𝘀𝘁𝗿𝘂𝗰𝘁𝘂𝗿𝗲 Where's the transformer? What's the current agreed capacity? How far do cables need to run? Every metre of trenching adds cost. - Headline capacity rarely reflects what’s actually usable once peak demand, protection limits and diversity are understood. 𝗗𝗲𝗽𝗼𝘁 𝗹𝗮𝘆𝗼𝘂𝘁 𝗮𝗻𝗱 𝗼𝗽𝗲𝗿𝗮𝘁𝗶𝗼𝗻𝗮𝗹 𝗳𝗹𝗼𝘄 Fixed vs flexible parking. Maintaining throughput during installation. The chargers need to go where the vehicles actually park – not where it's convenient to put them. - Phasing and temporary works are important too, some depots fail to plan how operations continue during construction. The operators who got it right treated the site survey as the foundation, not a box-ticking exercise. Two weeks of proper assessment saves months of rework. At Neertec, depot readiness assessments are where every project starts. It's not glamorous, but it's where the problems get found (or missed). And when legacy fuel infrastructure needs decommissioning alongside EV installation, we handle both. One contractor, one programme, no gaps.

Fleet peak load looks scary on paper, but in most cases, you don’t need a bigger utility feed. You might just need better math. #Loadmanagement is an electrical design strategy. In a #fleet application, the question is not how many 150 kW or 350 kW chargers you install. The question is what your coincident peak actually is once you factor in duty cycles, arrival windows, and required kWh per vehicle. Most fleets return in waves. Most vehicles dwell for 8 to 12 hours or more. That means your design target is total energy delivered over time, not simultaneous nameplate demand. That distinction changes everything. Technically, load management allows you to cap site demand at the main breaker or switchgear rating. The system dynamically allocates available amperage across chargers so you never exceed service capacity. Instead of 10 chargers at 150 kW each demanding 1.5 MW, you might cap the site at 800 kW and sequence output based on state of charge and departure time. Same fleet readiness. Half the peak demand. When engineered correctly, that impacts: • Switchgear amp rating • Transformer sizing • Breaker selection • Conductor size and parallel runs • Voltage drop calculations • Demand charge exposure Oversize the peak, and you oversize everything downstream. Load management lets you design around controlled peak load instead of theoretical maximum load. But it only works if upstream to downstream coordination is correct and protection is sized properly. Fleets are predictable. The grid is constrained. If you are still multiplying charger nameplate ratings to size service, you are probably leaving serious capital on the table. #EVInfrastructure #EVCharging #CleanEnergy #Electrification

A lot of people still think building EV charging infrastructure is pretty simple: pick some spots, install chargers, and let the returns roll in. I get it. I used to think that too. But the real difference-maker is using real, local data, not industry averages. We help companies model utilization site by site, using inputs like local EV ownership, traffic flow, and nearby amenities. With better forecasting and scenario tools, we’ve seen teams avoid low-performing sites and boost ROI by 15–20%, just by getting more precise about where and how they build. Scenario planning has become just as important. With things like EV adoption curves and energy pricing still in flux, investors don’t just want a single forecast. They want to see how breakeven changes under different conditions: policy changes, market shifts, utility costs. IRR and NPV outputs need to reflect that variability now. Then there’s financing. Grants, tax credits, and incentives are a big part of the equation. When you can layer in IRA benefits — like the 30% tax credit per charger in the right locations — it can meaningfully shift the economics. We also think about long-term risks. What happens if charging hardware becomes outdated faster than expected? How does downtime impact cash flow? Smart investors are building those questions into depreciation schedules and financial models upfront. Post-2022, the playbook has changed. It's not about generic buildouts — it's about site-level granularity, real scenario planning, and smart capital stacking. If you're trying to get more out of your EV infrastructure strategy, happy to walk through how we approach it.