The upcoming workshop on End-of-Life Strategies: Replacement of Aging Overhead Transmission Lines Assets has been scheduled for April 3rd at 1-2:30pm ET. As transmission infrastructure ages, utilities must navigate the complex challenge of replacing overhead transmission line assets in a cost-effective, strategic, and data-driven manner. Understanding how the industry approaches this challenge is key to optimizing investment decisions and ensuring long-term grid reliability.This workshop aims to facilitate industry benchmarking by bringing together the Overhead Transmission Equipment and Asset Management in T&D groups to share their replacement strategies, methodologies, and decision-making frameworks. Participants will engage in discussions that provide valuable data for strategic planning and asset management.Key topics of discussion will include:Industry Benchmarking: Comparing strategies, timelines, and methodologies across utilitiesData-Driven Decision Making: Leveraging condition assessments, failure rates, and predictive analyticsRisk-Based vs. Age-Based Replacement: Evaluating different asset replacement modelsLessons Learned: Real-world case studies from utilities with established replacement strategiesPresenters: Chelsey Knibbs, SaskPower, Dmitriy Misyura, PSEG, Justin Nettesheim, ATC

Subject: CMMS WG Discussion – Risk Integration Part IIIDate & Time: April 9, 2024 | 3:00 PM to 4:30 PM ETLocation: Webex (register on this portal page - a calendar invite will then be automatically sent via your inbox)Description:Join us for Part III of the CMMS Working Group discussion on Risk Integration in Asset Management. This session will focus on:How utilities are using CMMS to forecast potential failuresIntegrating risk into CMMS workflowsBuilding on insights from Part II, this roundtable will explore best practices in leveraging CMMS for risk-based maintenance prioritization, asset criticality scoring, and decision-making.Who Should Attend?Asset managers, maintenance planners, reliability engineers, and CMMS administrators looking to enhance their risk-based maintenance strategies.Background from Part II:Our previous session featured contributions from organizations like Yukon Energy, Manitoba Hydro, BC Hydro, PG&E, and the U.S. Bureau of Reclamation, discussing:Risk-Based Maintenance PrioritizationCriticality Scoring & Decision ModelsMonetizing Risk & Work PrioritizationCMMS Integration Challenges & SolutionsTools & Technologies supporting CMMS-based risk assessmentNext Steps:Be part of this important discussion and share your utility’s approach to risk integration in CMMS. Your insights will help shape best practices and drive industry-wide improvements.Mark your calendar and join us for this collaborative session.

Please save the date for the upcoming Training Series on Inverter-Based Resources – MOD & PRC Standard Compliance. Please note that this training is designed as a series; the completed sessions are prerequisites to attend the next sessions (i.e. if you are planning on attending session 3, and have not completed sessions 1 & 2, it is strongly recommended to watch the recordings).Series Schedule:Session 1 - Fundamentals: Thursday, March 13, 12:00 - 2:30 PM ETSession 2 - Control & Testing: Thursday, April 10, 12:00 - 2:30 PM ETSession 3 - PRC & Grid Forming IBR: Thursday, May 8, 12:00 - 2:30 PM ETSession 4 - Modeling: Thursday, June 12, 12:00 - 2:30 PM ET

We are pleased to announce that we have re-scheduled our FERC session that was originally planned as part of our DS Sprig 2025 General Meeting. The FERC session with Dave Capka will be held on Thursday, April 10th at 11amET.Questions for FERC:What does FERC do with the information when utilities report public safety incidents as well as rescues?Would FERC be able to contribute to a database* of incidents that are reported by utilities?*the database would not be created or maintained by FERC; FERC would only contribute to it with data that they receive from utilities  How has (or will moving forward) the new Administration’s offer of early retirement, hiring freeze, and back-to-office mandate impacted FERC staffing? Will the time required for FERC to respond to submittals be impacted?If a reduced workforce occurs, what will FERC’s priorities be?We continue to work through Site Specific PMP analyses under the requirement of BOCs.  After so many years (20+) standardizing the process, and so many approved projects, why are we still being required to assemble boards to direct this work?  It adds cost, but also adds significant time, and the benefit is not apparent.After receipt and review of the early CAs, is FERC coming to any opinions on preferred methodologies for the consequence analyses?  We’ve now used both RCEM and LifeSim with mixed feedback from FERC during the L2RA process.  In composite, does FERC have any direction to assist owners in project planning?  Understanding what FERC is seeing in total would be helpful