Some utility programs pay a commercial charging site for demand response without bidirectional hardware; the site needs chargers that can be told to slow down and a program that pays for it. Three published programs show the range. California's Emergency Load Reduction Program pays non-residential customers $2 per kWh reduced during grid emergencies, through 2027, and is open to customers through their utility, subject to size and eligibility criteria. Con Edison's SmartCharge Commercial pays $0.03 per kWh for off-peak charging and $10 per kW in June through September, or $2 per kW in October through May, for avoiding the network peak. Eversource in Connecticut pays $5 to $40 per charger plug per month, June through September, for light-duty fleet managed charging. National Grid in Massachusetts runs a commercial ConnectedSolutions program with published per-kW rates, but its page does not mention EV chargers. Published terms differ by utility, so confirm yours before putting any of it in a pro forma.
Updated Nov 20269 min read
Guest surveys on hotel EV charging range from 19 percent who say they need it to 91 percent of EV drivers who say they are more likely to book a property that has it, and the high numbers come from sponsored surveys. The only per-site revenue benchmark found averages about $3,300 a year for paid charging, so the electricity revenue is small and the decision rests on room nights. Start with a few ports, price for overnight dwell, and model the booking effect as an explicit assumption.
Updated Oct 20269 min read
A battery sitting between the grid and a DC fast charger can cut a site's required grid capacity, and with it the billed coincident peak, by roughly 50 to 80 percent, per NREL's 2024 materials prepared with the Joint Office of Energy and Transportation (the range is an approximation drawn from NREL's reference tables), and vendors like ADS-TEC Energy sell hardware built around exactly that. But the pitch that a battery belongs at every DCFC site skips the part that decides whether it pays back: a low-utilization site still faces a nearly full demand charge but has far less total revenue to amortize the same fixed battery cost against, and it often has a cheaper fix already available in load management software. Battery storage earns its keep at sites with real tariff exposure and enough session volume to carry the capital, often cited in the 3 to 5 year payback range at the high-tariff end, though this article could not independently verify a system cost precise enough to pin down an exact year for every site. It is not a default upgrade.
Updated Oct 202610 min read
EV-specific commercial rates soften the early penalty that demand charges impose on low-utilization charging sites, but the relief mechanism varies by utility and often does not last. Florida Power & Light's demand limiter tariffs move sites toward standard rates as load factor rises, and 34 of the 76 customers who enrolled since 2021, or 45%, had transitioned to regular rates by the end of 2024. Con Edison offers an EV Phase-In Rate that phases demand charges in as utilization increases. SDG&E's EV-HP discount steps down annually to zero in 2032, and its subscription level ratchets up if maximum demand exceeds it. ComEd and Georgia Power took structural routes with no stated sunset. A credible charging model needs the applicable tariff's transition rules, not just today's price sheet.
Updated Oct 202613 min read
Your electricity tariff is usually the single biggest variable in a commercial charging pro forma, and the line that decides it, the demand charge, is the one most operators read wrong. This guide walks the anatomy of a commercial EV tariff sheet (fixed charge, energy rate, time-of-use periods, demand charge, and the subscription alternative that several utilities now offer in place of demand) and shows where each line goes in the commercial ROI snapshot tool, with worked examples for SCE TOU-EV, SDG&E EV-HP, PG&E BEV, and a Georgia Power demand tariff whose seasonal structure has to be computed outside a single-input tool.
Updated Oct 202623 min read
DC fast charging ROI is not Level 2 ROI with bigger numbers. Demand charges add monthly costs that L2 sites do not face, install runs $90,000 to $200,000 per port (real NEVI awards median about $183,000), the federal reference case for public utilization is 8 percent (NREL 2025 Transportation ATB; Paren's tracked-time measure runs about 16 percent), and most viable corridor sites depend on NEVI funding for 80 percent of cost. Three site types pencil today: NEVI-funded highway travel-stops, high-traffic retail anchors with a co-funding partner, and fleet depots where fuel and maintenance savings carry the case.
Updated Oct 202625 min read
Commercial EV charging ROI has two components: direct financial returns (charging revenue, incentives, demand charge reduction) and indirect returns (tenant retention, property value, competitive positioning). Direct returns rarely justify the investment alone in low-utilization scenarios. The strongest case includes both, with incentives doing most of the heavy lifting in the first 3 years.
Updated Oct 202619 min read
EV charging can increase commercial property value three ways: NOI enhancement (charging revenue capitalized at market cap rates), reduced vacancy in markets where EV owners self-select, and repositioning aging assets. The strongest evidence is in multifamily housing in high-adoption markets. Valuation is still inconsistent: appraisers and buyers treat it differently depending on market and asset type.
Updated Oct 202610 min read
EV charging shapes tenant and customer behavior: multifamily residents who use on-site charging face a real switching cost when moving, though no public study quantifies a renewal-rate gap; retail customers who charge spend more time on-site and make more purchases; hotel guests who charge are more likely to return and give higher satisfaction scores. The effect is largest in high-adoption markets and grows as EV ownership increases.
Updated Oct 20267 min read