In May 2025, a substation fault in New Orleans left more than 100,000 customers without power, disrupting traffic systems, businesses, and critical services across the city.
While events at that scale are uncommon, the underlying failure pattern is not.
Most distribution outages begin as localized, developing conditions—deteriorating connectors, insulator contamination, vegetation interaction, or conductor stress. These issues often produce measurable electrical disturbances long before they result in sustained faults.
The challenge is not understanding the physics. Distribution engineers know these signals exist. The challenge is having enough visibility across the feeder to detect and localize them early enough to act.
The Visibility Gap in Distribution Systems
Most utilities maintain strong visibility at substations and increasingly collect large volumes of data from advanced metering infrastructure. But between those two layers—across miles of distribution feeders—operational awareness can still be limited.
When outages occur, operators may know which circuit is affected but have limited information about where along that circuit the problem originated.
This gap becomes more significant as systems face new pressures, including: aging distribution infrastructure, increasing load variability from electrification and distributed energy resources, and higher reliability expectations from communities and regulators.
Municipal utilities operate in a particularly challenging position. They often serve dense populations and critical community infrastructure while operating with smaller engineering teams and constrained budgets. At the same time, they need to maintain reliability standards comparable to much larger utilities.
Because of these realities, public power utilities typically need practical operational solutions rather than large enterprise-scale modernization programs.
Starting Where Monitoring Matters Most
The most effective monitoring strategies for municipal systems rarely begin with systemwide deployment. Instead, utilities often start with targeted monitoring on circuits where visibility can have the greatest operational impact.
Examples include:
- Feeders that experience recurring momentary faults
- Circuits serving hospitals, water treatment plants, or critical municipal services
- Areas with older conductors or hardware
- Portions of the system where outages are difficult to locate
By focusing on these locations first, utilities can gain meaningful insight into circuit behavior without requiring large-scale infrastructure investments.
This targeted approach allows operators to observe patterns that are otherwise difficult to detect, such as recurring disturbances in a specific section of line or gradual changes in electrical conditions along a feeder.
A Field Example: Finding a Problem Before It Becomes an Outage
One municipal utility in the Midwest experienced a series of brief disturbances along a feeder serving a mixed residential and commercial area. The events were short enough that customers rarely noticed them and protection systems did not register sustained faults.
However, the disturbances appeared at similar times during periods of high load.
By reviewing feeder-level monitoring data, engineers were able to narrow the source to a short span of line. When crews inspected the area, they discovered a deteriorating connector that had begun intermittently arcing under load conditions.
Replacing the hardware eliminated the disturbances and prevented what could have eventually become a sustained outage.
Situations like this illustrate an important point: distribution systems often provide early electrical indicators of developing problems, but those signals are only useful if utilities can observe them.
Supporting Small Operations Teams
Another advantage of targeted monitoring is its ability to support smaller engineering and operations teams.
Municipal utilities rarely have large analytics departments dedicated to interpreting grid data. Any monitoring solution must therefore provide information that is immediately useful to operators, rather than requiring extensive analysis.
In practical terms, this means helping utilities:
- Narrow the likely location of faults more quickly
- Recognize patterns in recurring disturbances
- Improve coordination between system operators and field crews
- Reduce time spent investigating unexplained circuit events
For organizations operating with limited personnel, improved visibility can significantly reduce the time required to diagnose problems during both normal operations and outage events.
A Practical Path Forward
Grid monitoring does not need to be implemented everywhere to deliver value. For many municipal utilities, the most effective approach is incremental—deploying monitoring where it improves visibility and operational decision-making first.
Over time, the information gained from these deployments helps utilities better understand how their distribution systems behave under different operating conditions. This knowledge supports improved reliability, more efficient operations, and more informed planning.
For public power utilities, the objective is straightforward: gain the right level of visibility in the right locations, so operators can respond more effectively and prevent problems before they escalate.
Stay informed on how utilities are improving reliability through better visibility.