One provider for the whole site: generation, storage, controls and charging behind the meter. PolarLit 1 on the public and fleet bays, NorthernLit 1 at home and at work, Community Power Hub where one panel has to serve a whole lot.
Most vendors sell a box and leave the joining-up to you. We take the site as the unit, and stay responsible for all six layers of it.
Twelve months of interval data, the peak demand line, and the connection date you were quoted.
Modular blocks on your side of the meter, sized to the load rather than to a catalogue.
A battery buffer that absorbs step loads, so generation runs near its efficient point.
Switchgear and load management that cap grid draw and decide when to generate, charge or shed.
PolarLit 1 for public and fleet bays, NorthernLit 1 for homes and workplaces, Community Power Hub for shared lots.
Monitoring, fuel, scheduled maintenance, and a monthly report of the peak that did not happen.
Not the price of power. It is how long it takes to be allowed to draw more of it — in most of Canada, years.
Data-centre connection requests reported by the IESO — up about 70% in two months. Hydro Ottawa separately reported 34 large projects in its queue, together worth roughly 86% of the utility’s average load.
More than 20,600 MW of data-center load has been requested from the AESO, against a provincial peak of roughly 13,000 MW. The interim allocation for new large load through 2028 is about 1,200 MW — and it is fully spoken for.
Alberta’s Data Centre Regulation (AR 117/2026) now codifies a “bring your own generation” approach, giving projects that tether their own supply priority over those that do not. The policy is telling large loads to supply themselves.
Application, capacity study, connection agreement, construction, transformer. The queue decides the date — and one peak month resets your charges every month.
Sized to your load profile and delivered as modules. Manufacturing and permits set the schedule, not a queue. The grid stays backup.
Generators are a commodity. What decides whether a site saves money is the layer that knows when to run them.
01 — Generation
Containerised or trailer-mounted, sized to the load. Natural gas primary, CNG/LNG/RNG where the fuel path allows, black-start capable.
02 — Storage
A battery buffer absorbs step loads, so generation runs near its efficient point.
03 — Controls
Measures demand in real time, caps grid draw, decides when to generate, charge or shed. Without it, a generator is an expensive backup.
04 — Charging
Vehicles? The chargers join the same controller — PolarLit 1 on the public and fleet bays, NorthernLit 1 at home and at work. NorthernLit 1 speaks OCPP 1.6J, so charging follows the site peak.
Public and fleet bays take PolarLit 1. Homes, workplaces and shared lots take NorthernLit 1. Both sit on the same controller as the rest of the site.
Commercial & public
Pillar charger for sites where the driver does not own the meter: public bays, fleet yards, workplaces and main streets. Pedestal form factor, silver-white body with a vertical yellow panel down the right side.
PolarLit 1 numbers go here once the data sheet is verified. Ask us for the current revision before you specify a site.
Home & workplace
Level 2 charging for driveways, workplaces and shared lots. 12 kW hardwired or 9.6 kW on a NEMA 14-50, J1772 or NACS, 7.6 m cable, three-year warranty and OCPP 1.6J. UL Listed.
Not every building needs a substation. A Community Power Hub puts several points on one shared service and bills each session to the driver.
A Community Power Hub is a group of chargers on a shared service, so the site pays once for the electrical work instead of once per resident. Drivers tap in, take what they need, and pay for the energy they used. The building gets a single monthly statement.
It is the middle option between “everyone buys their own” and “we wait for the grid”. No new service drop, no panel upgrade race, no queue.
NorthernLit 1 — the same unit we put in driveways. J1772 or NACS, 7.6 m cable, three-year warranty.
Two to six points on one circuit, added or removed as occupancy changes.
Energy measured per session and invoiced to the driver. The site sees one line, not a stack of accounts.
OCPP 1.6J, so the network is replaceable. We are not the only door.
Two dozen units, one parking lane, nobody wants a $40,000 panel replacement.
Three storefronts chasing the same handful of spots.
Crews arrive at 7 and leave at 6. Plug-and-charge beats a reserved pole.
Early access. The Community Power Hub is offered site by site across the Greater Toronto Area. Availability, panel capacity and pricing depend on the building — we will tell you plainly if your site is not ready for shared charging yet.
The building. Clink sells and installs the hardware; whoever owns the service panel owns the chargers. We stay on as the service contact for the life of the install.
That is the normal case, and the reason we plan the load first. Points share the circuit sensibly and each driver still gets a full session. Sites that charge all day need a bigger panel, and we will quote it honestly rather than oversell.
Only if they want one. Billing can sit with the site as a flat monthly fee, with each driver paying through the plug. You choose the model at sign-off.
Yes, if the panel has room left. We plan the conduit with spares so the second phase is a breaker and a box, not a second project.
We do not sell this to everyone. It earns its place when the grid is slow, expensive to expand, or not there.
Fleet depots & logistics
Vehicles return evening, leave morning. That concentration sets a demand peak the utility may not serve for years.
Manufacturing
On a demand-billed account, the month’s worst fifteen minutes can dominate the bill. Trimming that peak beats cutting consumption.
Charging hubs
A fast-charging site needs a connection a queue may never deliver. On-site supply decouples the two.
Remote & resource
Communities, mines and camps on diesel. Delivered LNG or CNG displaces the fuel that costs most to move.
Construction & events
Power that arrives before permanent service, then leaves. Rent capacity for the job instead of building a connection you abandon.
Data & critical loads
Energise on your own supply while the connection builds, then keep it as backup — what Alberta’s new rules reward.
Agriculture
Greenhouses and grain drying want heat as much as power. CHP turns one fuel bill into both.
On a demand-billed account the line that hurts is kilowatts, not kilowatt-hours. Put your own numbers in — the rates are editable.
Defaults come from Hydro One’s published 2026 General Service demand example, where the distribution volumetric demand rate is $22.5201 per kW and the retail transmission network and connection rates add $3.1662 and $2.4073 per kW in the same worked example. Your rates are on your bill — overwrite them. This is arithmetic, not a quote, and it excludes commodity, Global Adjustment and everything else that is not a demand charge.
One hundred kilowatts of peak at those rates is about $2,800 a month of demand charges. Cutting forty is worth roughly $13,700 a year — before a single kWh is generated.
Alectra’s Ultra-Low Overnight prices on-peak at 39.1¢/kWh and overnight at 3.9¢/kWh — roughly ten to one. That window is where the rest of the value sits.
A saving we have not modelled against your interval data. On-site generation has a real cost per kWh — if the grid is cheaper for your profile, we will say so.
We keep no catalogue of generators. We start from what your site does, write the spec, and hold manufacturers to it.
Twelve months of interval data, the peak demand line, the connection date you were quoted.
Required kW and kWh, run hours, noise limits, emissions envelope, mobility, winter.
We take that spec to manufacturers and hold them to it. The value is knowing what to demand, not buying boxes.
NRTL certification, interconnection, permits, plus the noise and air approvals that decide if the site can run.
Remote monitoring, fuel, scheduled maintenance, and a monthly report of the peak that did not happen.
You own it; we engineer, deliver, commission, then maintain under contract.
Capacity for a defined term, off your balance sheet.
Temporary supply while the permanent connection builds.
Energy, not equipment. We carry the capex and the risk.
Where the load is public charging, we take our return from utilization.
A young line of business. Here is the boundary, honestly stated.
Certifiable in Canada before it is worth discussing. The list is not optional:
We would rather lose a month than win a signature on a promise we cannot keep:
No. We operate behind your meter. Whether surplus can be exported depends on your utility and province — we will not assume it in a business case.
For gas generation, yes — a pipeline service or a delivered CNG/LNG supply chain. Where neither exists, we will tell you early rather than sell you around it. All-electric configurations with storage-only peak shaving are a separate conversation.
It has to. Cold-weather packages, enclosure ratings and black-start capability are part of the specification we write, not optional extras — and the commissioning plan includes a cold start, not just a warm one.
Slower than a brochure and faster than a connection queue. Once a site is surveyed and permitted, the schedule is driven by manufacturing and delivery, not by an interconnection study. We will give you a real date after step 01, not before it.
Twelve months of electricity bills — or just the peak demand line. The load you want to add. The date you need it by. That is enough for us to tell you whether this is worth pursuing, and we will tell you when it is not.
Prefer to talk it through first? Book a call — we will ask about your bill before we say anything about our equipment.
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