The primary focus of the meeting was the meter change-out program, an initiative to replace approximately 20,000 first-generation meters installed around 2012. These meters, while not failed, have reached the end of their useful life. The proactive replacement aims to prevent failures before they occur and maintain a reliable electric system. The Advanced Metering Infrastructure (AMI) system, which captures energy usage data every 15 minutes, plays a role in this project. It facilitates monthly billing and helps troubleshoot high bills or usage anomalies. The integration of the AMI system with the outage management system enables automatic notifications during power outages, allowing for faster utility responses.

A significant topic of discussion was the transition from GE to Itron for the metering platform, expected to yield significant cost savings. The current annual cost associated with GE is about $1.7 million, while the transition to Itron is projected to reduce this cost to around $400,000. The transition’s final stages are anticipated to be completed in the next couple of months. The budget impact of this transition includes an allocation of approximately $800,000 within the capital budget to initiate the replacement program, with a goal of replacing 3,500 meters in the first phase.

The board also addressed the communication strategy for the meter replacement process, emphasizing the use of neighborhood signs with QR codes directing customers to a dedicated website for more information. The actual meter change-out process is expected to be quick and efficient, typically taking only a minute, conducted by city employees to ensure recognition in neighborhoods. Text messaging alerts about the replacements were mentioned as a potential communication tool, although their effectiveness would need to be assessed based on customer responses.

Concerns were raised about potential vandalism and break-ins during the meter replacement process. The meter supervisor shared experiences and conveyed that safety considerations were integral to the project’s planning. Established procedures ensure that customers are aware of the work, with city employees knocking on doors to inform residents when necessary.

In addition to the meter replacement project, the board discussed ongoing infrastructure projects aimed at improving the reliability and resiliency of the electric distribution system. The L62 and L59 feeder reconductor projects, along with the Ravenwood subdivision project, were highlighted. These projects involve upgrading existing infrastructure to enhance redundancy and reliability, with significant portions funded through grants. The board also noted the need for a transformer replacement at the North Substation due to operational issues.

Financial discussions during the meeting included the Department of Energy’s Electric Grid Resiliency Grant Program. The program aims to modernize the electric grid and mitigate extreme weather impacts. Projects like the system hardening on County Road 25A received grant funding, reducing the city’s financial burden. The board underscored the importance of budgeting for projects without relying solely on grant approvals, emphasizing preparation to cover full project costs if necessary.

The meeting also addressed potential electric rate increases due to fluctuating natural gas prices. The Bulk Power Cost Adjustment (BPCA) was discussed, with proposed increases from $20 to $22.50 in January and further to $25 in April. These adjustments could lead to average customer cost increases of approximately $325 and $650, respectively. The board considered the psychological impact of rate increases on consumers, debating the merits of one significant increase versus multiple smaller adjustments. Communication strategies to ease public perception of rate hikes were also discussed, highlighting the need for clear messaging about the reasons behind the increases.