Improving Grid Visibility and DER Coordination in Ontario

Summary

How can utilities improve real-time DER visibility and coordination across distribution networks?

The absence of real-time data sharing between Ontario’s IESO, local distribution companies, and transmission operators has been one of the most persistent barriers to effective DER participation in the province. In this article, you’ll find a full account of how the FDMM project addressed that gap:

Live monitoring of performance data from solar, battery storage, and demand response assets across multiple LDC networks
Interoperability across utilities’ SCADA, DERMS, AMI, and OMS systems
Robust cybersecurity measures including Secure ICCP and Jump Boxes
Data standardization across LDCs, leading to improved forecasting accuracy and proactive management of grid conditions

The FDMM project showed that standardizing data formats across LDCs improves forecasting accuracy, that Secure ICCP and Jump Boxes provide robust protection for inter-utility data exchanges, and that real-time DER visibility is achievable today — offering a replicable model for utilities and system operators planning their next phase of grid modernization.

Distributed Energy Resources (DERs) are reshaping the electricity landscape, presenting both opportunities and challenges for utilities. While DERs enhance grid flexibility and support renewable integration, they also introduce complexities in forecasting, coordination, and system balancing. The Framework and Demonstration of a Multi-Market Model (FDMM) project, led by Ontario’s Independent Electricity System Operator (IESO) in collaboration with Survalent and multiple Local Distribution Companies (LDCs), is addressing these challenges head-on by enhancing grid visibility and interoperability.

The Challenge: Limited Data Visibility

One of the primary barriers to DER participation in Ontario’s energy market has been the lack of real-time data sharing between IESO, LDCs, and transmission operators. Without a unified view of DER operations, system planners and operators struggle to accurately forecast demand, balance supply, and optimize market participation.

A risk assessment conducted between 2019 and 2020 highlighted the urgent need for enhanced coordination to mitigate these issues. The FDMM project was developed as a proof-of-concept to demonstrate how an integrated Advanced Distribution Management System (ADMS) could bridge the data gap and improve system efficiency.

Ready to modernize your grid? Talk to our team about real-time data integration and DER coordination

The Solution: FDMM’s Data Integration Platform

The FDMM platform aggregates real-time operational data from multiple LDCs, providing a comprehensive and standardized approach to DER monitoring. By integrating with systems such as SCADA, DERMS, AMI, and OMS, the platform enables seamless data exchange between utilities, allowing for more efficient market participation and grid management.

Key features of the FDMM platform include:

Real-time monitoring of DER performance, including solar, battery storage, and demand response assets.
Interoperability between utility systems, ensuring that data flows securely across different operational environments.
Enhanced cybersecurity protocols to protect sensitive grid data and maintain regulatory compliance.
A sandbox environment for utilities to test new market participation models and optimize DER integration.

Discover how SurvalentONE ADMS supports real-time DER coordination and data sharing

The Results: Improved Coordination and Market Readiness

As part of the FDMM initiative, Survalent worked closely with participating Ontario utilities, including London Hydro, Oakville Hydro, and Elexicon Energy, to collect sample data from their networks. This collaboration provided critical insights into data governance, system scalability, and cybersecurity measures.

Among the project’s key findings:

Standardizing data formats across LDCs improves forecasting accuracy and operational efficiency.
Real-time data access enhances decision-making, enabling utilities to respond proactively to grid conditions.
Cybersecurity measures such as Secure ICCP and Jump Boxes provide robust protection for data exchanges.
The integration of AMI data remains a challenge, with improvements needed in data granularity and timeliness.

What’s Next?

The success of FDMM lays the groundwork for future grid modernization efforts. By demonstrating the feasibility of real-time DER integration, the project offers a scalable model for expanding market participation and enhancing system reliability.

As Ontario’s energy transition accelerates, continued collaboration between utilities, regulators, and technology providers will be essential to building a smarter, more resilient grid.

Read the press release about this project here and the infographic here.

Frequently Asked Questions (FAQs)

What is the major challenge facing utilities looking to integrate DERs and participate in energy markets?

One of the primary barriers to DER participation in Ontario’s energy market has been the lack of real-time data sharing between the IESO, LDCs, and transmission operators. Without a unified view of DER operations, system planners and operators struggle to accurately forecast demand, balance supply, and optimize market participation. The FDMM project, led by Ontario’s IESO in collaboration with Survalent and multiple LDCs including London Hydro, Oakville Hydro, and Elexicon Energy, was developed as a proof-of-concept to demonstrate how an integrated ADMS could bridge the data gap and improve system efficiency.

What does a real-time DER coordination platform look like in practice?

The FDMM platform aggregates real-time operational data from multiple LDCs, providing a standardized approach to DER monitoring. By integrating with systems such as SCADA, DERMS, AMI, and OMS, it enables seamless data exchange between utilities, supporting more efficient market participation and grid management. Key capabilities include real-time monitoring of solar, battery storage, and demand response assets, interoperability between utility systems, enhanced cybersecurity protocols, and a sandbox environment for utilities to test new market participation models.

What cybersecurity measures are needed to protect real-time DER data exchanges between utilities?

One of the key findings of the FDMM initiative is that cybersecurity measures such as Secure ICCP and Jump Boxes provide robust protection for data exchanges between utilities, helping to protect sensitive grid data and maintain regulatory compliance.

Are there any proven strategies utilities can adopt for DER integration?

The success of the FDMM project lays the groundwork for future grid modernization efforts. By demonstrating the feasibility of real-time DER integration, it offers a scalable model for expanding market participation and enhancing system reliability. As Ontario’s energy transition accelerates, continued collaboration between utilities, regulators, and technology providers will be essential to building a smarter, more resilient grid.