As distribution utilities prepare for a more dynamic, decentralized, and data-driven grid, advanced technologies often get the spotlight. But the conversations at CEATI’s recent Advanced Distribution Operations Program General Meeting pointed to a more practical reality: the future of distribution operations depends on getting the foundations right.

Hosted by BC Hydro in Vancouver, the meeting brought utility professionals together to share lessons, compare challenges, and discuss the capabilities needed to support grid modernization. Attendees also toured Powertech Labs’ facility and BC Hydro’s control center, offering a firsthand look at the systems and facilities supporting modern utility operations.

Across the discussions, one theme stood out: communications, data infrastructure, system integration, advanced metering infrastructure (AMI), and organizational readiness are becoming essential enablers of advanced distribution operations. 

1. Communications and integration are becoming core grid capabilities

Advanced distribution operations depend on reliable, scalable communications and systems that can work together effectively. As utilities add more field devices, sensors, automation schemes, distributed energy resources (DERs), and grid-edge technologies, communications networks must support more data, visibility, and operational coordination.

Advanced distribution management systems (ADMS) remain a major focus for utilities, but implementation is rarely straightforward. Members discussed challenges related to connecting ADMS with outage management systems, supervisory control and data acquisition (SCADA) systems, geographic information systems (GIS), AMI, and other enterprise platforms.

The takeaway: ADMS value depends not only on the system itself, but on how well it fits into the broader utility environment. Data quality, system architecture, business processes, and cross-functional coordination all affect whether utilities can realize the full value of modernization investments.

2. AMI is becoming an intelligence layer

Many utilities are planning the transition from first-generation AMI to next-generation systems. This shift is not only about replacing aging assets. It is also an opportunity to unlock new operational value from meter data.

Meeting discussions explored how AMI can support outage management, demand response, DER integration, customer programs, and better grid visibility. For many utilities, AMI is becoming part of a broader distribution intelligence ecosystem rather than a standalone metering function.

3. DERs require more coordinated operations

DERs, including solar, storage, and microgrids, are changing how utilities approach planning and operations. Members discussed growing interest in virtual power plants, distributed energy resource management systems (DERMS), hosting capacity tools, and strategies for improving visibility and control of behind-the-meter resources.

As DER adoption grows, utilities are looking for practical ways to move from passive interconnection management to more active coordination of distributed resources. That requires more than technology. It also depends on integrated systems, clear operational processes, customer participation, and organizational readiness.

4. Reliability and resiliency are becoming more data-driven

Reliability remains central to distribution operations, but resiliency is becoming an increasingly important part of the conversation. Extreme weather, wildfire risk, outage reduction, system hardening, and resiliency metrics are all shaping utility priorities.

Members discussed the use of smart devices, sensors, monitoring technologies, automation schemes, and programs such as public safety power shutoff ( a proactive measure to temporarily turn off electricity in specific areas to reduce the risk of wildfires) to better manage grid risk. These approaches all depend on timely data, strong communications, and systems that can support faster, more informed operational decisions.

5. Artificial intelligence adds both opportunity and pressure

Artificial intelligence (AI) came up in two ways: as a potential tool for utility operations and as a driver of increasing electricity demand through data centers and computational facilities.

For distribution teams, AI may support planning, automation, data analysis, and grid management. The near-term opportunity is to identify where AI can be applied practically, while ensuring appropriate governance, validation, and technical oversight.

What do these trends mean for distribution utilities?

The discussions in Vancouver reinforced a clear takeaway: advanced distribution operations depend on strong foundational capabilities. As utilities modernize AMI, integrate DERs, improve operational resiliency, explore AI, and deploy new grid technologies, success will depend on reliable communications, usable data, integrated systems, and alignment across teams.

These are not challenges any one utility is facing alone. By exchanging lessons learned, practical approaches, and emerging priorities, utilities can make more informed decisions as they move from grid modernization planning to execution. CEATI supports that process by bringing utilities together in a trusted, collaborative environment where members can compare approaches, learn from peer experience, and turn shared challenges into practical next steps.

CEATI thanks BC Hydro for hosting the meeting and supporting valuable knowledge exchange among members.

Learn more about CEATI’s Advanced Distribution Operations Program here. Interested in joining the next discussion? Contact us about membership or join us at our annual Transmission & Distribution Conference in Denver, November 17–18, 2026.