Canada’s electricity system is under growing strain. While it performs adequately in normal conditions, tight reserves and limited flexibility leave it vulnerable during prolonged cold snaps or compounding events. Last winter, Alberta issued 13 grid alerts, and Ontario triggered its first‑ever energy emergency alert in early 2024 — early warning signs of a system under pressure and of the rising importance of flexibility and demand‑side resources.
Yet public narrative often defaults to a single solution: build more generation. In reality, Canada’s challenge extends well beyond capacity. According to the Canadian Energy Regulator and industry analyses from Electricity Canada and Dunsky, electricity demand is projected to rise between 62% and 112% by 2050, driven by electrification, population growth, and industrial expansion. Meeting this demand will require nearly doubling electricity supply over the next 25 to 30 years, while expanding, upgrading, and modernizing the grid at the same time.
This pressure is already visible across North America. Last winter alone, peak electricity demand increased by 20.2 GW year‑over‑year, while new resource additions covered less than half that growth — the equivalent of adding the demand of multiple major cities without reinforcing the grid to support them.
As climate volatility intensifies, demand spikes grow sharper and aging infrastructure faces conditions it was never designed for. In this context, resilience increasingly depends on grid intelligence — real‑time visibility, automation, and flexibility that allow systems to anticipate stress, rebalance load, and absorb shocks rather than break under them.
The real bottleneck: smarter grid
Success will not be determined by ambition alone. Canada’s ability to deploy critical grid technologies at scale will define how quickly and cost‑effectively the electricity system can grow. Digital infrastructure, automation, advanced protection, and coordination of distributed energy are no longer optional — they are foundational to a reliable future grid.
Much of Canada’s grid was designed decades ago for north–south power flows and export‑driven markets. While cross‑border trade remains important, today’s electricity demand is more localized, dynamic, and weather‑dependent, requiring stronger coordination within regions and across provinces.
These shifts are placing new pressure on the system. Winter‑sensitive demand, growing variability, and the need for flexibility now shape grid performance. At the same time, the most acute stressors — including distributed energy resources (DERs), electric vehicle (EV) charging, and load volatility — are emerging at the distribution level, where visibility and control have historically been limited. Modernizing the grid from the bottom up is therefore essential to maintaining reliability and resilience.
Furthermore, the grid is more decentralized than ever before. Energy mixes consist of large-scale utilities, traditional power plants (e.g., coal or gas), renewables like wind turbines or hydroelectric and small-scale, grid-connected technologies, such as solar panels and battery storage that generate or store electricity close to where it is used.
“Canada doesn’t have a generation problem. It has a coordination problem — and intelligence is the fastest way to unlock the capacity we already have,” says Dina Morcos, VP, Marketing and Sales, Electrification Distribution Solutions at ABB Canada. “Today, we have a powerful engine with outdated steering and brakes. The power is there, but the controls are not.”
In practical terms, a smarter electricity grid starts with better real‑time visibility. When utilities can clearly see how power is flowing across the system, they can respond more effectively during winter peaks, extreme weather, and rising demand. Smart grid technologies help balance supply and demand, integrate electric vehicles and local energy sources, and reduce outages — allowing Canada to get more from existing infrastructure without relying solely on new construction.
NERC’s winter assessment reinforces this shift, recognizing demand response and flexibility as critical sources of winter reliability, now on par with traditional supply.
The upgrade myth: it doesn’t take a decade to modernize the grid
For years, the dominant narrative in the utilities sector has been that grid modernization is a long-term, capital heavy undertaking. But as Morcos puts it, “We don’t need to wait ten years to make the grid smarter. The fastest resilience gains come from intelligence, not steel.” The technology needed to harness these insights exists today.
Large transmission projects will always require lengthy permitting, consultation, and construction cycles. Digital upgrades do not. Because Canada’s bulk power system standards are already aligned with NERC, utilities can roll out advanced automation, monitoring, and protection technologies quickly and consistently, often in months,notyears. Additionally, thanks to the advanced grid technologies such as sensors or Centralized Protection & Control, not all these grid modernization initiatives are intrusive. There are plenty of options to map out a roadmap and gradually adopt these technologies without any disruptions to the operations or major upgrade of the existing installations.
The economics are hard to ignore. A digital substation upgrade typically costs USD 2–5 million, while a new transmission line can exceed USD 500 million. Meanwhile, Volt/VAR optimization can reduce peak demand by 2–4%, effectively unlocking gigawatts of usable capacity without adding new generation. This means that both CAPEX and OPEX for such initiatives will be very well justified.
Modernization is a strategic sequence of high impact interventions:
An advanced, secure, and real-time data collection infrastructure across all layers of the grid is essential to support the changes underway in the electricity system. Technologies at the grid edge are enabling more sophisticated distribution management and behind-the-meter applications, while early digitization efforts can start with a single high‑impact substation and be scaled across the network to maximize value. By moving from basic sensing to actionable insight, utilities can implement condition‑based monitoring that improves operations and supports proactive maintenance. At the same time, greater visibility into distributed energy resources is critical to prepare for the rapid growth of EV fleets and behind‑the‑meter generation, ensuring the grid remains reliable as demands evolve.
“These are not multi‑year transformation programs,” says Morcos. “They are targeted upgrades that deliver measurable resilience gains within 12 months. The technology exists. The use cases are proven. The only question is how quickly we choose to deploy them.”
Flexibility as a reliability superpower
Winter weather can drive real electricity demand as much as 25 % above forecast, underscoring why flexibility is emerging as one of the grid’s most powerful reliability tools. Evidence is already accumulating: BC Hydro’s managed electric-vehicle charging pilot reduced peak demand by 18% across participating fleets. Flexible resources, argues Morcos, are “the single fastest way to stabilize a stressed grid,” and Canada has no shortage of options it can scale immediately—from managed EV fleet charging and industrial load flexibility to microgrids for hospitals, data centres and other critical sites, more sophisticated orchestration of distributed energy resources, and adaptive protection systems that shorten fault-clearing times. Beyond resilience, Morcos adds, these measures carry a broader appeal: they help keep electricity affordable, a metric closely watched by regulators across the country.
Practical solutions to strengthen reliability today
Canada’s long‑term grid expansion will require significant capital and years of construction. But improving reliability doesn’t mean waiting for the next major transmission project to come online. There are practical steps that can be taken today — and large commercial and industrial electricity users are well positioned to lead.
By working directly with utilities on managed load programs, major employers can help reduce peak demand during periods of grid stress without disrupting core operations. Investing in on‑site flexibility — whether through battery storage, microgrids, or smart controls — can also provide continuity during outages while easing pressure on the broader system. These measures increasingly allow businesses to protect themselves from disruptions while contributing to overall system stability.
Participating in demand‑response markets takes this a step further, turning operational flexibility into a new revenue stream while improving reliability for everyone. Finally, industry has a strong stake in advocating for grid modernization funding. Reliable and affordable electricity underpins competitiveness, and targeted investment in digital and flexible grid solutions benefits not just utilities, but every sector that depends on power to operate.
Canada is well positioned to lead the next era of electrification, with a clean power mix and clear choices ahead on how we manage and modernize the grid. Reliability is no longer just a technical concern — it is a competitiveness issue. Intelligence is the lever that will keep Canada ahead. As Dina Morcos notes, “The technology is proven. The business case is clear. What’s needed now is coordinated action.” A smarter, more resilient grid is not a future ambition. It is a decision Canada can make now.
