Lowering Energy Costs with Peak Demand Management Software

Lowering Energy Costs with Peak Demand Management Software

Blog Post
May 23, 2025
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A Regional Guide for IESO, AESO, U.S. Mid-Atlantic & ERCOT

In today’s volatile energy markets, energy-intensive businesses across North America are pressured to control costs while staying competitive. One of the most powerful—but often underutilized—tools available is peak demand management software.

In energy markets across Canada and the United States, peak demand management software helps large energy users optimize their operations around grid events and pricing signals. This allows them to avoid expensive charges and participate in demand-side programs for revenue generation. How peak demand management works—and the value it delivers— varies significantly across regions.

Here’s how Ontario, Alberta, U.S. Mid-Atlantic, and ERCOT companies can lower energy costs using this smart software.

What is Peak Demand Management Software?

Peak demand management software uses real-time data, predictive analytics, and automation to help facilities:

  • Anticipate and respond to grid Coincident Peaks (CPs)
  • Shift or shed load to avoid high charges
  • Automate curtailment strategies
  • Maximize participation in coincident peak programs

Think of it as an AI-powered co-pilot for your energy strategy—reducing costs without compromising operations.

IESO (Ontario): Avoiding Global Adjustment Costs with Precision

In Ontario, large electricity consumers in Class A are charged Global Adjustment (GA) based on their percentage contribution to the top 5 system peaks. Missing just one peak can cost hundreds of thousands—or more.

Peak prediction software in Ontario helps by:

  • Accurately predict when the ICI peaks will occur with advanced algorithms
  • Enable automated alerts by phone, text, and email for curtailment notices
  • Reduces the number of curtailments required to hit the peaks

The Current Savings Potential for Large Class A users is approximately $350,000 per MW per year.

AESO (Alberta): Navigating the Regulated and Competitive Markets

In Alberta’s electricity market, Demand Transmission (DTS) charges are the rates industrial and commercial customers pay to utilize the transmission system, depending on their peak demand. They are an important component of electricity costs and are calculated from the peak 15-minute average during monthly or coincident peak periods. DTS charges are approximately $134,000 per MW per year, as of 2025, so efficient demand management is necessary in reducing costs.

Peak Prediction Software in Alberta can help by:

  • Forecasting peak transmission, for example, estimating one-minute DTS demand levels, to help facilities manage loads during periods of peak-cost times
  • Integrating with Distributed Energy Resources (DERs) to reduce peak demand and lower DTS charges

Pro Tip: Platforms, like Edgecom’s pTrack Alberta, allow facilities to set custom thresholds and receive alerts based on real-time pricing and peak forecasts.

U.S. Mid-Atlantic & Northeast: Maximize Capacity & Peak Shaving Revenue

U.S. Mid-Atlantic transmission pricing depends on a customer’s peak demand in the system’s five annual Coincidental Peaks (5CP)–the system’s most extreme one-hour peak demand periods. Large loads will save a lot of money by scheduling during these peaks.

Smart predictive software makes this technique easy to implement by:

  • Determining likely 5CP time windows with high-resolution forecasting models
  • Triggering timely, automatic curtailment alerts to multiple communication channels
  • Maximizing load reduction measures to minimize operational disruption

Through effective 5CP management, as much as $98,000 per MW can be saved yearly.

ERCOT (Texas): Real-Time Optimization in a Volatile Market

In the ERCOT market, large electricity users can significantly cut their transmission costs by reducing demand during the Four Coincident Peaks (4CP)—the highest 15-minute system load intervals in June, July, August, and September. These peaks set a facility’s transmission charges for the entire following year.

Our pTrack product helps facilities stay ahead of 4CP events by:

  • Analyzing real-time and historical grid data to forecast likely peak days and intervals
  • Sending timely curtailment alerts via email, text, and phone to enable fast response
  • Optimizing load reduction strategies to minimize disruption while maximizing savings

Avoiding just 1 MW during 4CP periods can save up to $67,000 annually, making precise peak management a key opportunity for large energy users.

Weather Watch: Software platforms that incorporate weather, ERCOT alerts, and pricing signals offer a significant edge in managing these unpredictable peaks.

Benefits Beyond Peak Avoidance

Across all regions, peak demand software offers more than just curtailment support. Facilities gain:

  • Real-time visibility of energy usage
  • KPI dashboards and GHG reporting
  • Better alignment with sustainability goals
  • Long-term planning insights

Ready to Take Control of Your Energy Spend?

Whether you’re in Ontario managing Global Adjustment, in Alberta tackling TCC, or participating in the U.S. Mid-Atlantic or ERCOT demand response markets, peak demand management software is your strategic advantage.

Solutions like Edgecom Energy’s pTrack® and NeuraCharge empower your team to make smarter, data-backed energy decisions—every day and at every peak.

Want to see how much you could save?

Request a free peak savings assessment meeting and discover the ROI of proactive energy management in your region.

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