Fault prevention is at the heart of Advanced Grid Reliability—shifting utilities from reactive response to predictive maintenance. This session explores how high‑resolution half‑cycle voltage and current waveforms captured by 32 kHz and 4 kHz sensors enable early detection of fault precursors across overhead, underground and low‑voltage assets. Attendees will learn what’s new compared to traditional practices, the role of power quality in corrective maintenance and the operational path to preventative maintenance. The session also highlights wildfire POC results, showcasing how predictive fault detection reduces unplanned outages, improves SAIDI/SAIFI, rebalances TOTEX and helps utilities avoid outages before they occur.

Tampa Electric is using the expanded data available through AMI 2.0 to turn meter data collected in IEE MDM into a powerful source of operational insight. By managing millions of interval reads, meter events, and alarms within a centralized, analytics‑ready meter data management environment, the utility has gained deeper visibility into system performance and day‑to‑day operations.

In this session, Tampa Electric shares how historical AMI 2.0 data—analyzed through an MDM‑centric, cloud‑based approach—is supporting key operational use cases such as revenue assurance, outage analysis, and system operations. By combining 15‑minute interval readings with device‑level event data, teams are able to identify discrepancies, validate system conditions, and uncover issues that were previously difficult to detect.

Attendees will learn how utilities can move beyond basic reporting to apply scalable analytics on trusted meter data, improve operational decision‑making, and lay the foundation for broader enterprise analytics and future cloud‑enabled use cases—while maximizing the value of their AMI 2.0 investments.

AMI 2.0 has matured into a deployable platform, enabling utilities to move beyond pilots and incremental upgrades. As utilities enter new investment cycles, a key question is when replacing an existing meter fleet delivers sufficient customer, operational, and grid value to justify the cost.

This session presents a practical benefit‑cost framework for evaluating the timing and phasing of an AMI 2.0 transition, incorporating asset life, benefit realization, operational constraints, regulatory alignment, and grid modernization goals. It demonstrates how enhanced data, visibility, and platform extensibility translate into measurable utility value and support defensible investment decisions.