Ontario’s electricity grid is under pressure. As electrification accelerates — more EVs, more heat pumps, more industrial load — the demand placed on local distribution networks is growing faster than traditional infrastructure can keep up. The result is a growing class of problem that utilities across the province are increasingly turning to local demand response to solve.
Two of Ontario’s most significant local DR programs are live right now: GrandBridge Energy’s GridShare program in Cambridge and North Dumfries, and Toronto Hydro’s Local Demand Response program serving six transformer station zones across the city. Edgecom Energy is an approved aggregator in both — and for commercial and industrial businesses in these service areas, the opportunity to turn operational flexibility into recurring revenue has never been more accessible.
The Grid Problem Nobody Talks About
When most people think about grid reliability, they think about generation — do we have enough power plants running to meet demand? But in Ontario, some of the most pressing reliability challenges aren’t about generation at all. They’re about the pipes.
Local distribution networks — the transformer stations, feeder lines, and substations that deliver power to your neighbourhood or industrial park — have finite capacity. When demand in a specific area spikes, those local assets can become bottlenecks, regardless of how much generation is available provincewide.
This is the challenge playing out in communities across Ontario. In Cambridge and North Dumfries, transformer stations at Preston TS, Galt TS, and MTS#1 are approaching their capacity limits ahead of the new MTS#2 substation coming online in 2028. In Toronto, six transfer stations — Finch, Leslie, Manby, Horner, Strachan, and Dufferin — face similar peak demand pressures across some of the city’s most densely loaded service zones.
The traditional answer is to build infrastructure faster. But that’s expensive, slow, and often disproportionate to a constraint that may only materialize for a few hours on a handful of peak days each year.
What Is a Non-Wires Alternative?
A Non-Wires Alternative (NWA) is exactly what it sounds like: a way of solving a grid constraint without building new wires, transformers, or substations. Instead of spending tens of millions of dollars on infrastructure to handle peak loads that occur a fraction of the time, utilities can pay energy consumers to temporarily reduce their demand during those critical windows.
The economics are compelling. A facility that can shed 500 kW for a few hours on a hot summer afternoon provides the same grid relief as a transformer rated for that additional capacity — at a fraction of the cost and without a multi-year construction timeline.
NWAs have been used successfully across North America for years, but they’ve historically been deployed at the provincial or regional level. What makes programs like GridShare and Toronto Hydro’s LDR significant is that they’re tackling constraints at the hyperlocal level — targeting specific transformer stations in specific communities. This precision matters because local bottlenecks require local solutions.
Two Programs, One Growing Trend
The emergence of both GBE GridShare and Toronto Hydro’s Local Demand Response program in the same period is not a coincidence. It reflects a broader strategic shift among Ontario’s local distribution companies: rather than defaulting to capital-intensive infrastructure solutions, forward-thinking utilities are building the frameworks to harness the flexibility that already exists within their service territories.
GBE GridShare is a capacity auction program covering Cambridge and North Dumfries. Commercial and industrial customers agree to provide flexible load available during the summer months, specifically between June 1 and September 30th. They’ll receive a set monthly capacity payment to ensure availability, along with extra payments for any additional dispatches. This program aims to fill a crucial need until MTS#2 comes online in 2028. The contracted capacity will increase from 5 MW in 2026 to 20 MW by 2028.
Toronto Hydro’s Local Demand Response program operates across six targeted transfer station zones in Toronto — Finch TS, Leslie TS, Manby TS, Horner TS, Strachan TS, and Dufferin TS. Participants must offer at least 500 kW of load reduction, either from a single site or through aggregated resources across approved station pairings. Activations occur on business days between 12 p.m. and 9 p.m., with each event lasting four hours and a maximum of six activations per season. Participants receive at least two hours’ advance notice before each activation, and monthly settlement statements are issued with payment following within 15 business days of invoice.
Together, these programs signal that local DR is no longer a niche concept — it is becoming a core tool in how Ontario’s distribution utilities manage their networks.
Why Local DR Programs Matter for Ontario
This shift has implications that extend well beyond the businesses that participate directly.
It unlocks a massive untapped resource. Ontario has an enormous amount of flexible commercial and industrial load that currently plays no role in grid management. Refrigeration systems, HVAC, process loads, EV charging, and behind-the-meter storage all represent flexibility that could be mobilized — if the right programs exist to capture it. Local programs are building those pathways.
It reduces costs for all ratepayers. Every megawatt of peak demand deferred through demand response is a megawatt that doesn’t require new infrastructure investment. Those savings ultimately flow through to electricity rates across the board.
It builds community grid resilience. Local DR programs create a more distributed, resilient grid where communities can manage their own peak constraints rather than depending entirely on provincewide solutions. As extreme weather events become more frequent and peak demand grows with electrification, that local resilience becomes increasingly valuable.
It accelerates the clean energy transition. Demand flexibility is an important component of a high-renewables grid. Wind and solar generation are variable by nature — the ability to shift load in response to generation availability makes the overall system more efficient and reduces reliance on dispatchable fossil generation during peak periods.
The Role of Aggregators
For most commercial and industrial businesses, the prospect of participating in an energy market — even a local one — is daunting. Metering requirements, bid preparation, dispatch protocols, settlement processes: the operational complexity can quickly outweigh the revenue opportunity, particularly for businesses without dedicated energy management staff.
Aggregators like Edgecom Energy solve this by acting as the expert intermediary between facility operators and the program. We assess your load profile, identify the flexibility you actually have, prepare and submit your bid, manage dispatch notifications, and handle all settlement reporting. From your perspective, participation means responding to an alert from our platform when an activation is called — everything else is handled.
Aggregation also enables facilities whose individual load may not meet program thresholds to participate collectively. Under Toronto Hydro’s LDR program, for example, aggregation is permitted within the same station area or across approved station pairs — meaning smaller facilities can pool their flexibility and participate in ways that wouldn’t be possible on their own.
Edgecom has been operating as a demand response aggregator in Ontario for years. Our experience across both the GBE GridShare and Toronto Hydro LDR programs means we understand the nuances of each — how to build the strongest possible bid, how to design a curtailment strategy that minimizes operational impact, and how to maximize the revenue your flexibility can generate.
Is Your Facility a Candidate?
If your facility is located in Cambridge, North Dumfries, or within one of Toronto Hydro’s six targeted transfer station zones, you likely have flexibility worth monetizing. Businesses that tend to be strong candidates include those with:
- HVAC or refrigeration systems that can temporarily adjust setpoints
- Industrial process loads that can be shifted or curtailed for short periods
- On-site generation, battery storage, or behind-the-meter assets
- EV charging infrastructure with flexible timing
- Pumping, compressed air, or other interruptible mechanical loads
You don’t need to have participated in any energy market before, and you don’t need sophisticated energy management infrastructure in place. Edgecom will assess your facility, model your revenue potential, and design a participation strategy tailored to your operations.
For GBE GridShare, registration closes April 10, 2026, with the bid window running April 13–24. The obligation period runs June 1 through September 30.
For Toronto Hydro’s LDR program, reach out to Edgecom to understand the current program cycle and whether your facility qualifies.
The Bottom Line
Ontario’s grid is evolving, and the most forward-thinking businesses aren’t just adapting to that change — they’re finding ways to benefit from it. The emergence of local demand response programs from utilities like GrandBridge Energy and Toronto Hydro is a signal that this evolution is accelerating. Utilities are actively seeking the flexibility that exists within their communities, and they’re willing to pay well for it.
Edgecom Energy is here to make participation as simple as possible — assessing your facility, handling the complexity, and ensuring you capture the full revenue potential of the flexibility you already have. Contact us today to determine eligibility.
