Provincial Grid Matrix
Tariff structures, peak windows, interconnection timelines and incentives across ten provinces.
Canadian BESS Snapshot
Last verified: 2026-06-30- Provinces covered
- ON, AB, QC, BC, MB, NS, SK, NB, NL, PE
- Highest typical demand charge
- Quebec — CAD $16.14/kW-month (Rate M)
- Lowest typical demand charge
- Manitoba — CAD $10.40/kW-month
- Most volatile energy market
- Alberta — AESO energy-only pool
- Largest single value driver in Ontario
- IESO Global Adjustment, Class A coincident peaks
- Typical interconnection timeline
- 6 – 14 months nationally
ON
Ontario
$11.50/kW
StrongAB
Alberta
$13.20/kW
StrongQC
Quebec
$16.10/kW
StrongBC
British Columbia
$13.90/kW
ModerateMB
Manitoba
$10.40/kW
EmergingNS
Nova Scotia
$14.60/kW
StrongSK
Saskatchewan
$12.10/kW
ModerateNB
New Brunswick
$11.80/kW
ModerateNL
Newfoundland and Labrador
$12.90/kW
EmergingPE
Prince Edward Island
$13.40/kW
Emerging| Utilities | Tariff / rate class | Demand charge | Energy charge | Peak window | Interconnection | Source |
|---|---|---|---|---|---|---|
| Toronto HydroON | General Service 1,000–4,999 kW | $11.90 | 0.1010 | Weekdays 11:00–17:00 (summer), 07:00–11:00 & 17:00–19:00 (winter) | Typically 6–12 months (CIA + ESA + LDC approval) | 2026-06-30 |
| Hydro OttawaON | General Service 50–4,999 kW | $10.70 | 0.0960 | Weekdays 11:00–17:00 (summer), 07:00–11:00 & 17:00–19:00 (winter) | Typically 6–10 months | 2026-06-30 |
| Alectra UtilitiesON | General Service 50–4,999 kW | $11.20 | 0.0990 | Weekdays 11:00–17:00 (summer) | Typically 6–12 months | 2026-06-30 |
| Hydro OneON | General Service > 50 kW (demand billed) | $12.40 | 0.1040 | Weekdays 11:00–17:00 (summer) | Typically 8–14 months (rural feeders longer) | 2026-06-30 |
| ENMAX PowerAB | Rate D21 General Service (demand billed) | $13.60 | 0.0910 | Monthly billing demand — no fixed TOU window (pool price driven) | Typically 5–10 months (AESO + wires owner) | 2026-06-30 |
| EPCOR DistributionAB | General Service — Demand Billed | $12.80 | 0.0880 | Monthly billing demand; coincident transmission peak exposure | Typically 5–10 months | 2026-06-30 |
| Hydro-QuébecQC | Rate M (medium-power, 100 kW–5 MW) | $16.14 | 0.0577 | Winter peak events, December 1 – March 31, 06:00–09:00 & 16:00–20:00 | Typically 6–12 months (Hydro-Québec technical review) | 2026-06-30 |
| Hydro-QuébecQC | Rate L (large power, ≥ 5 MW) | $15.32 | 0.0378 | Winter peak events, December 1 – March 31 | Typically 9–18 months | 2026-06-30 |
| BC HydroBC | Large General Service (Rate 1500) | $13.90 | 0.0621 | Monthly billing demand with 12-month ratchet provisions | Typically 6–12 months | 2026-06-30 |
| Manitoba HydroMB | General Service Large (≥ 750 kVA) | $10.40 | 0.0548 | Monthly billing demand, seasonal differential | Typically 6–12 months | 2026-06-30 |
| Nova Scotia PowerNS | Medium General Rate (Demand billed) | $14.60 | 0.1419 | Winter peak, monthly billing demand | Typically 6–12 months | 2026-06-30 |
| SaskPowerSK | Commercial — Demand billed | $12.10 | 0.1112 | Monthly billing demand with ratchet | Typically 6–12 months | 2026-06-30 |
| NB PowerNB | General Service (Demand billed) | $11.80 | 0.1153 | Winter peak sensitivity, monthly billing demand | Typically 6–12 months | 2026-06-30 |
| Newfoundland PowerNL | General Service 110 kW and over | $12.90 | 0.1280 | Winter peak, monthly billing demand | Typically 8–14 months | 2026-06-30 |
| Maritime ElectricPE | General Service (Demand billed) | $13.40 | 0.1631 | Winter peak, monthly billing demand | Typically 6–12 months | 2026-06-30 |
Indicative rates compiled from published utility rate schedules. Verify the current schedule before any investment decision.