FERC technical conference spotlights software, operations and data as keys to scaling grid‑enhancing technologies

Eric Ciccaretti, an advisor in FERC’s Office of Technical Reporting and Economics, opened a two‑day technical conference focused on how software can improve grid and market efficiency and warned participants the session would avoid discussion of pending Commission proceedings. The first day centered on grid‑enhancing technologies (GETs) such as dynamic line ratings (DLR), topology optimization and power‑flow controllers, and on the software, data and operational changes needed to deploy them.

Panelists from utilities, RTOs and vendors said the chief barriers are institutional and integrative rather than purely technical: production of frequent ratings or telemetry is feasible, but threading those data into energy management systems (EMS), day‑ahead markets and interconnection processes requires long coordination. “It adds a lot of variability to their ability to plan,” said Emily Tolis of LineVision about shifting from seasonal ratings to hourly or real‑time ratings, and she urged EMS integration rather than manual ‘swivel‑chair’ workflows.

Speakers gave concrete deployment examples. David Quire of PPL Electric Utilities described work with PJM to carry DLRs from sensors into day‑ahead market processes, including weekly IT‑to‑IT coordination and development of application programming interfaces; he said one project deferred “an over $50,000,000 rebuild” after a several‑hundred‑thousand‑dollar DLR pilot. Michael Craig of Great River Energy said small utilities must weigh member value and facility limits (substations or breakers can remain the constraint even if conductor ratings rise).

Several panelists urged better software models and shared data approaches. Dr. Alexander of the Linux Foundation Energy said open‑source, modular platforms and shared governance can make integration easier and described the value of a common tooling ecosystem. He also pointed to an operational example from France: a zonal automaton that monitors pockets of lines in real time and automatically applies the least‑cost remedial action — including DLR or reconfiguration — to reduce renewable curtailment.

Panelists highlighted two crosscutting needs: cybersecurity/data governance for CEII and a single operational ‘source of truth’ in the control room. Vendors and utilities discussed cloud vs. on‑prem choices: pilots often tolerate cloud models, while EMS integration and CEII restrictions increasingly push on‑prem or hybrid architectures and require clear data‑ownership arrangements. Several presenters said vendors had been willing to support on‑prem deployments and data access to satisfy utility compliance needs.

The conference underscored that GETs are tools in a broader toolbox: software, real‑time analytics and digital twins can identify and help optimize combinations of GETs with traditional transmission upgrades, but utilities must still demonstrate clear benefit‑to‑cost cases and manage risk. The panels reconvened in the afternoon to discuss load forecasting and will continue the program the next day.