pTrack®

What is pTrack®?

pTrack® is Edgecom Energy’s advanced market intelligence and forecasting platform that helps energy managers and organizations anticipate electricity demand, market prices, and potential peak events. Through its APIs, pTrack® provides both historical and forecasted data from major energy markets such as IESO (Ontario), AESO (Alberta), and PJM, combining official market data with Edgecom’s proprietary analytics and modeling. It delivers insights such as system demand forecasts, electricity price trends, Coincident Peak probability, predicted peak time windows, and historical peak events, enabling customers to better plan operations, manage energy costs, and proactively respond to high-demand periods. By turning complex market signals and data into actionable insights, pTrack® helps organizations reduce risk, optimize energy strategies, and make smarter decisions in dynamic electricity markets.

What is a Coincident Peak?

A Coincident Peak (CP) refers to the periods when electricity demand across an entire power grid reaches its highest levels. Different electricity markets use peak demand periods to allocate major portions of transmission or capacity-related costs to large electricity consumers.

In IESO (Ontario), costs are determined by the top 5 system demand hours of the year, which drive a customer’s Global Adjustment (GA) charges.

In AESO (Alberta), transmission costs are influenced by a customer’s demand during the peak periods and are reflected through Demand Transmission Service (DTS) charges.

In PJM (United States), customers are assigned Capacity and Transmission charges based on their demand during the grid’s Coincident Peak hours.

These peak hours usually occur during periods of extreme system demand—such as hot summer afternoons or cold winter evenings—when electricity usage across the grid is highest.

Your facility’s electricity demand during these peak system hours is used to determine your share of grid costs for the following year. Because of this, reducing load during these periods can significantly lower long-term electricity expenses.

Why It Matters

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**For large Commercial and Industrial Customers:

peak-based chargessuch as Global Adjustment (Ontario), transmission charges (Alberta), and capacity or transmission charges (PJM) can represent a significant portion of total electricity costs.

The key insight: the grid operator determines which 5 hours were peaks after the fact. By the time you know for certain, it's too late to act. You need to predict them in advance.

How pTrack® Helps

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Rule of thumb: A probability score above 0.70 (70%) typically

warrants activating your load curtailment or demand response strategy.

What to Do on a High-Risk Day

1. Check the probability score in the morning Call the peak probability endpoint for today's date. If the score is above 0.70, prepare your team to curtail.

2. Get the predicted curtailment window Call the peak window endpoint to get the specific 2-hour and 4-hour windows. This tells you exactly when to reduce load.

3. Curtail during the window Reduce your facility's electricity demand during the predicted window. Even partial reductions significantly lower your GA exposure.

4. Monitor and repeat Peak season in Ontario runs June–September (summer peaks) and December–February (winter peaks). Monitor daily during these periods.

Supported Markets

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Coming soon: AESO (Alberta) and PJM (Eastern US) coverage is in

development. Contact your account manager for early access.