Illinois utilities have a lot on their plate at the moment – and they’re more than happy to share what they’ve been working on.
Representatives from ComEd, and its parent company Exelon, will speak on DER integration, the growth of electrified transportation, workforce challenges, private LTE, generative AI, and more at DTECH (formerly known as DISTRIBUTECH), convening from March 24-27, 2025 in Dallas, Texas.
Below is a breakdown of DTECH sessions featuring the two utilities. Register here to secure your spot, and we’ll see you in Dallas!
ComEd
March 25
5 IOUs on the integration of DERMS, ADMS, VPPs and microgrids for next generation distribution operations
10:00 AM-10:50 AM
DERs continue to integrate with the distribution system in a variety of ways, as behind-the-meter assets (either aggregated or stand-alone), front-of-the-meter DERs connected to the medium-voltage system, and in some cases operated as part of microgrids. Moreover, regional transmission organizations (RTOs) are at various stages of implementation of FERC Order 2222, which aims to remove barriers to the participation of DERs in wholesale electricity markets. Utilities responsible for the planning and operation of distribution systems need to strategically assess how these trends will impact their business and evaluate the most appropriate architectures to seamlessly integrate and operate these systems in the most effective manner possible.
This panel will provide views from several different investor-owned utilities, including PG&E, ComEd, Con Edison, and Georgia Power, to compare their perspectives and experiences of how they are planning for the coming changes, what specific initiatives are underway, and learn how they see the impacts and growth within the medium term. The moderator will then guide a discussion on specific topics around the different DER applications and how this should affect the operation of the distribution system of the future. Specific discussion points may include:
- How are DER aggregations expected to operate in different jurisdictions and what is being done to understand how to best coordinate their operation with distribution systems?
- With ADMS at various stages of deployment, how are DERMS, microgrids, and VPPs integrated into ADMS and how does it affect the advanced ADMS applications?
- What are some of the barriers or challenges that have been encountered with the deployment of these operating technologies, and what strategies have been devised to address these issues?
- Does the concept of hosting capacity or other DER planning need to be rethought in the context of DER aggregators for both PV and EV, and customer-owned storage?
- How do system operators gain situational awareness of DER aggregation, and can they influence the operation of these DERs in any way?
- Do aggregators have a role in power restoration after a storm or proactive de-energization to improve overall system resilience?
ComEd Project Planning with Jurisdictional Analysis and Risk Mitigation Systems
3:00 PM-3:50 PM
The electric grid is rapidly changing. Many of the technologies attaching to the grid are requiring the grid to be operated, maintained and planning in new, innovative ways. As these operational challenges continue to expand, so must the tools engineers use to prepare the grid to act as a foundation for clean energy technologies. With this added complexity, the grid will experience newer and more risks that must be mitigated in order to engineer cost-effective, secure and reliable solutions. These risks result in execution challenges which manifest as extended delays due to permitting and access.
In order to mitigate such delays, ComEd created a tool to analyze jurisdictional permitting needs and assess risk to prioritize work efficiently and provide its engineers and execution management with data driven planning and visualization capabilities. The tool uses geographic information systems which allows ComEd to incorporate project data and permitting/jurisdictional data with spatial references to deliver reporting outputs that range from interactive mapping solutions to risk reports. ComEd coined this tool as Jurisdictional Analysis Risk Mitigation System (JARMS).
The JARMS tool outputs geospatial data that allows design-phase pre-identification of risks that projects may encounter, including but not limited to railroad crossings, bridge crossings, and adjacency to wetlands, all of which pose unique challenges that impact execution schedules and costs. Mitigation of these risks can begin in the design phase by allowing ComEd’s design teams to employee the many engineering solutions at their disposal, including changing proposed routing, and to immediately understand estimated impacts to cost and schedule.
March 26
Electrifying transportation: Insights from utility leaders
9:00 AM-9:50 AM
Even as electric vehicle sales continue to rise – 20% year on year, per the latest projections – utilities are struggling to roll out the EV charging infrastructure needed to meet demand and enable their vision of a more sustainable, electrified future. Utility leaders must answer pressing questions about where to build charging stations, how to prioritize locations and rollout plans, and how to more effectively manage a power grid already at (or beyond) capacity. They also need to address CapEx and profitability considerations.
Combining AI and digital twins offers some fast, effective paths forward. How are utility leaders addressing the EV infrastructure imperative? What types of tools are used to streamline processes, standardize practice, and simplify interactions? What steps are being taken to address citizens’ demands along with the needs of commercial freight carriers? Hear from innovators in both areas and learn some practical steps utilities can take on a day-to-day and strategic planning level.
Powering resilient communities: Enabling DER with innovative microgrid solutions
10:00 AM-10:50 AM
Join us for an insightful session on “Powering Resilient Communities: Enabling DER with Innovative Microgrid Solutions,” where we will dive into the groundbreaking Bronzeville Community Microgrid—one of the first utility-owned microgrids integrated into an urban neighborhood. Serving 1,000 customers, this microgrid combines solar PV, battery storage, and controlled generation to deliver reliable energy to the community, critical infrastructure, and surrounding areas.
In this session, ComEd will share the journey of transforming the Bronzeville Community Microgrid from a concept in a lab to a functional reality. Learn about the key technical challenges, community partnerships, permitting hurdles, and the collaborative efforts that enabled this microgrid to flourish.
You’ll also gain insights into how the Bronzeville Microgrid contributes to ComEd’s 2030 roadmap for a cleaner, more equitable energy transition. As part of the discussion, the presentation will reflect on lessons learned throughout the various phases of the project, offering valuable takeaways for anyone interested in deploying Distributed Energy Resources (DER) and microgrid solutions.
Attendees will walk away with a better understanding of how DER & innovative microgrid technology can enhance community resilience, and the strategies required to implement successful DER projects in urban settings.
Policy impacts on distribution planning at LUMA, ComEd, and Eversource
10:00 AM-10:50 AM
Panelists from major utilities — LUMA Energy, ComEd, and Eversource — will discuss distribution planning within the regulatory space. Their discussion will cover important subjects like:
- Policy directives, market structures, distribution analysis, and technological innovations
- The broad regulatory landscape that shapes renewable integration—from regulatory orders, tariffs, and net metering to capacity markets and carbon pricing
- The regulatory barriers that hinder efficient distribution planning including permitting processes, grid access rules, and interconnection standards
The session will foster dialogue among policymakers, regulators, and industry stakeholders to promote regulatory environments conducive to the seamless integration of renewables into the distribution system, thereby advancing the transition toward renewables and electrification.
Navigating EV growth in Maryland and Illinois
10:00 AM-10:50 AM
The penetration of electric vehicles (EVs) has grown rapidly in the U.S. Many states have set ambitious EV adoption goals. Additionally, the increased adoption of EVs will help reduce the transportation sector emissions in a utility’s service territory. Detailed analysis of the impacts of EVs on distribution feeders will help utilities make intelligent investment decisions to upgrade the distribution system equipment (e.g., transformers, distribution wires, and protection systems).
Over the past five years, Baltimore Gas and Electric‘s (BGE) EVsmart portfolio, comprised of residential, commercial, and BGE-operated programs, has pursued goals in alignment with the state’s policy directives. BGE’s pilot was designed to coordinate seamlessly with state policy initiatives, driving towards a future when internal combustion engine cars are no longer sold in the state.
To accommodate EV charging infrastructure, Pepco Holdings (PHI) developed a public, customer-facing map to visualize EV load capacity. The capacity on different feeders helps identify areas with reasonable capacity to host EV charging infrastructure and areas with constraints that would need equipment or system upgrades. PHI has worked with several partners to utilize multiple data sources to estimate the load impacts of EV adoption with different EV types and charging scenarios. These studies broadly include medium-heavy duty fleet charging at depot, commercial charging along highway corridors, and light-duty residential EV charging at home and public charging stations.
In this panel, experts from Exelon Corporation, Baltimore Gas and Electric (BGE), Pepco Holdings (PHI), and Commonwealth Edison (ComEd) will discuss EV growth and challenges in Maryland and Illinois. Panelists will approach the problem from the aspects of customer, planning, and long-term strategic points of view.
Public cellular vs. private LTE: Southern Company and Evergy share network strategy considerations
1:00 PM-1:50 PM
Utilties are actively modernizing their grid infrastructure to enhance reliability and control, with the overarching goal of creating a ‘smart grid.’ Achieving this vision necessitates deploying numerous access points to collect substantial real-time data on grid status. However, many utilities overlook the critical communication requirements for analyzing this data promptly.
To address this challenge, a comprehensive communications strategy is essential—one that seamlessly integrates both fiber and wireless networks. Efficiency and low latency are paramount. Broadband capacity and speeds achievable through LTE technology become indispensable. This leads to a pivotal decision point: Should utilities rely on public cellular networks or invest in building private LTE networks?
In this session, we will engage with utility leaders who have grappled with these issues. We’ll explore their journey toward PLTE (private LTE) deployment. Some decisions have been met with acceptance, while others faced resistance. Our discussions will delve into the decision-making process, the analytical considerations behind transitioning to LTE (Long-Term Evolution), and the successful realization of these networks.
Harnessing the power of DER for utilities
1:00 PM-1:50 PM
The rapid integration of distributed energy resources (DERs), both behind-the-meter (BTM) and in front of the meter (FTM), along with EVs, is transforming the electricity delivery sector. This evolution necessitates utilities to gain control and visibility over these assets, irrespective of their location on the grid. If these assets are not optimally managed, they may not contribute effectively to the premises or the grid, potentially compromising grid operations and preventing the grid and the premises from reaping maximum benefits.
The emergence of grid edge control and communication technologies has paved the way for optimal frameworks for the independent operation of assets and information exchange between the premises and the utility. This provides a deeper understanding of premises flexibility and potential operation for grid services.
ComEd will share strategies for merging large-scale renewable energy and microgrid technology, a significant step toward improving grid reliability and sustainability. Quanta Technology will discuss its role in supporting utility DER projects, focusing on hosting capacity, reliability enhancement, and grid modernization. Eaton Corporation’s Eaton Research Labs will provide valuable insights and lessons from a recently concluded project, executed in collaboration with partners including the Delaware Electric Cooperative (DEC). DEC will discuss its successful demand response program and emphasize the recent funding by the DOE’s Grid Deployment Office (GDO) Grid Resilience and Innovation Partnerships Program (GRIP), which aims to boost DEC’s hosting capacity by approximately 10 MW through flexible connections.
ComEd’s distribution automation falling conductor protection pilot
1:00 PM-1:50 PM
Downed electrical conductors are a safety and reliability concern for the ComEd distribution system due to short-circuit protection limitations in clearing high-impedance faults. ComEd’s distribution automation (DA) group is piloting the SEL and SDG&E patented falling conductor protection (FCP) solution to bridge the relay protection gap, prevent wire-down faults on utility infrastructure, and mitigate hazardous conditions for customers, first responders, and property.
Using IEEE C37.118 protocol, synchrophasor data is streamed over ComEd REACTS fiber from the 12kV substation feeder protection relays and DA reclosers to a phasor data concentrator (PDC) with a SEL-3555 RTAC located at the substation. The FCP RTAC analyzes synchrophasors from each of the phasor measurement unit (PMU) enabled relays using five open-phase detection methods, including voltage rate of change and both negative and zero sequence magnitudes and angles to determine a falling conductor event.
During a falling conductor event, the PDC RTAC will analyze the synchrophasor streams and transmit a direct transfer trip (DTT), via IEC 61850 GOOSE, to open the protection devices surrounding the affected segments. The energized conductor is isolated within 500ms of the break before the conductor makes ground contact. The FCP algorithm will block falling conductor DTTs if a short-circuit fault is detected at the start of an event, allowing the existing GOOSE advanced distribution protection (ADP) blocking scheme to clear the fault and avoid upstream momentary customer outages.
The FCP communications architecture presents a unique set of cybersecurity challenges for ComEd because the protection scheme requires IP-connected devices from the separate substation and distribution networks to route information to the FCP RTAC. To maintain isolation between the two networks, the distribution synchrophasor, GOOSE, and DNP3 network traffic is secured by a specially programmed SEL-2741 ethernet switch to prevent unauthorized network traffic back to the substation. Additionally, GOOSE communications to the SEL-351 feeder relay are performed by the SEL-2411 using mirrored bit serial communications.
Utility workforce development challenges and solutions
1:00 PM-1:50 PM
The rapidly evolving energy landscape presents significant challenges in cultivating a skilled and future-oriented workforce. This panel discussion brings together distinguished experts from academia, power utilities, including AES, and corporate engineering and consulting firms to share their unique insights, perspectives, and strategies for addressing workforce development and training obstacles.
This panel will explore how these sectors can collaborate, share best practices, and foster a synergistic approach to holistically tackle workforce challenges. Through interactive discussions, attendees will gain valuable perspectives on building a resilient, future-proof workforce capable of driving innovation and sustainable growth within the power industry.
Key Takeaways:
- Addressing skills shortages across the energy sector and exploring strategies for universities to collaborate with utilities and industry to revamp academic programs, producing graduates with relevant skill sets.
- Exploring approaches by utilities and companies to attract younger talent and promote workforce engagement and retention for the current workforce.
- Examining potential partnerships, knowledge-sharing, and collaborative platforms between academia, utilities, and industry stakeholders to facilitate comprehensive workforce development.
ComEd’s journey beyond the lab to test private LTE use cases
4:00 PM-4:50 PM
ComEd is preparing to deploy a private LTE network to provide additional flexibility to the current network design and deployment with fiber optics communication. Preliminary tests were conducted at ComEd’s lab with utility equipment such as reclosers, capacitor banks, voltage regulators, and substation relays which comprise many of the use cases that an advanced communication infrastructure enables.
Test cases consisted of peer-to-peer recloser communication using IEC 61850 GOOSE and IntelliTeam (S&C’s proprietary DNP3 protocol), SCADA DNP3 communication, Direct Transfer Trip (DTT), failover from a fiber primary path to a secondary PLTE path, and IP camera video streaming for equipment monitoring and security applications.
While lab testing can support initial validation of use-case functionality over the private LTE network, signal strength is generally going to be very good in an indoor lab environment. To test use cases in a more realistic environment, ComEd leveraged an outdoor testing site in Kent, IL. In its first iteration, ComEd established a fiber optics communication network to support the enablement of IEC61850 GOOSE in its extended applications.
As ComEd prepares to establish a private LTE network to add flexibility and cost savings in network design and deployment, additional testing is needed to validate IEC61850 GOOSE over private LTE.
March 27
Inside ComEd’s operational analysis with distribution automation
9:00 AM-9:50 AM
Distribution automation (DA), such as reclosers and sectionalizers, are important tools to maximize the reliability and resiliency of ComEd’s 34kV, 12kV, and 4kV lines. After a fault event occurs on the grid, ComEd’s distribution automation engineering department ensures there was proper operation of the DA devices, quantifies the number of customers protected by DA, and determines if any corrective actions are needed post-event.
For each fault that causes DA to reconfigure a ComEd circuit, an event record is automatically generated and stored in a central repository on an intranet site. The DA engineering team then analyzes each record and validates the proper operation of automated devices. Action can be taken immediately if the event analysis indicates a mis-operation of DA assets. The team also logs each device’s number of avoided customer interruptions (ACI). These ACI counts are crucial to tell the story of DA’s impact on system reliability and plan for the future installation of additional devices. For example, a recloser opening due to a downstream fault would protect and get ACI for upstream customers.
When there is a fault on one of ComEd’s sub-transmission 34kV distribution lines, the DA engineering team can perform a short circuit analysis to locate the fault regardless of whether a reconfiguration occurred. This location can be provided to maintenance crews to quickly find and repair the cause of the fault. The team uses several tools such as ADMS, CAPE, CYME, and CROSSBOW to retrieve the peak fault current, fault type, and circuit Thevenin resistance; these values are then used to calculate the approximate geographic location of the fault and generate a zone in which crews are instructed to patrol.
These processes have been continuously improved over the years and are essential to DA engineering. For the next evolution of Operational Analysis, the team is presently exploring enhancements through software coding that can automate monotonous steps of gathering data and running programs to unlock new opportunities.
Resilient communities via risk-driven infrastructure planning and automated restoration
10:00 AM-11:00 AM
Electric power grids face increasing vulnerability to extreme weather events, which disrupt power supply, jeopardize personal safety, and impact national security. To address this, speakers propose enhancing resilience in aging and stressed power distribution systems, particularly those serving underserved communities. Recent advancements, such as integrating distributed energy resources (DER) and distribution automation, offer opportunities for system resilience.
This panel will discuss industry-academic partnerships focused on improving grid resilience for underserved communities affected by high-speed wind hazards. The panel will quantify community resilience, explore metrics-driven distribution planning, and discuss operational strategies. The approach includes automated restoration using solar and storage technology, risk-centric infrastructure planning, and a scalable layered architecture to be deployed in a low-income area of Rockford, Illinois.
VRDT roll-out strategies and experiences from Pepco and ComEd
11:00 AM-11:50 AM
Within the energy transition, the strong adoption of distributed energy resources (DERs) combined with the continuing electrification of buildings and transportation, as well as the need to meet clean energy goals, pushes utilities to search for easy and effective technologies to enable them to keep up with these trends while providing safe, reliable and affordable power.
Learn how Pepco Holdings (PHI) and ComEd identified two different applications for which the voltage regulating distribution transformer (VRDT) was considered the best investment alternative and the experiences they gained throughout the process, from purchase and commissioning to first operation.
In the case of PHI, a single-phase 50 kVA overhead VRDT increases the hosting capacity of a neighborhood, allowing for more rooftop solar installations. Meanwhile, at ComEd, a three-phase 10 MVA padmount VRDT, equipped with a smart recloser and communications, optimizes the efficiency of their CVR/VVO program. Both technologies incorporate an on-load tap changer (LTC) into the distribution transformer.
The panel will delve into these use cases and discuss the strategic deployment of VRDTs, exploring where their implementation is most beneficial and when it may not be as effective.
Exelon
March 25
EPRI addresses cybersecurity challenges in ‘DER gateways’ with Exelon and Duquesne Light
1:00 PM-1:50 PM
With rising DER levels, utilities across the U.S. are beginning to design communication and control systems that will be used to manage and monitor inverter-based resources. The architectures to manage these resources include both direct (utility DERMS-to-DER) and aggregator pathways. As these designs are progressing, there has been broad recognition of the need for “DER gateways”. DER gateways are equipment deployed at each DER site, connecting the DER to the managing entity’s DER aggregator or distribution system operator system via the IEEE 1547 standard local interface. Although they reside at the DER site, these gateways are part of the monitoring and management system rather than the consumer’s DER.
DER gateways are being planned for a wide range of functionalities, as is a new IEEE recommended practice being developed in 1547.10. The chief driver for DER gateways, however, is cybersecurity. Nationwide, DER management systems, including secure DER gateways, will represent a substantial investment in infrastructure and serve as a foundation for the transition to a renewable, carbon-free power system, through reliable and efficient management of DERs.
This panel will discuss the various cybersecurity challenges for DER integration, the opportunities and needed DER gateway cybersecurity features being researched and developed by EPRI, government agencies, vendors, and utilities to address these challenges, and the current IEEE 1547 efforts to provide industry guidance on secure DER gateways.
How Southern Company and Evergy utilize all that private LTE data
1:00 PM-1:50 PM
In this session, we will delve into the transformative impact of owning and operating a private LTE network. Unlike carrier networks which offer limited visibility, a proprietary private LTE network empowers organizations with unparalleled access to critical data. This session will explore the data-gathering process and its utilization for predictive analysis and fault prevention.
The session will engage with two pioneering utilities — Southern Company and Evergy — that have meticulously built out their private LTE networks. These utilities leverage the vast amount of data delivered to them as network operators, gaining deeper insights into their infrastructure. Beyond being mere network users, they embrace the opportunities that arise from network ownership.
By harnessing data from their private networks, these utilities can proactively detect trends and conditions before failures occur. This foresight enables strategic decision-making and risk mitigation that was once considered unattainable. Join us as we uncover the untapped potential of private LTE networks and their pivotal role in revolutionizing utility operations.
AI for proactive storm response at Exelon and Oncor
1:00 PM-1:50 PM
The increasing frequency and intensity of storms pose significant challenges to electric utilities, emphasizing the need for technological solutions to optimize storm response. Accurate storm outage and damage prediction is crucial for mitigating the adverse impacts of power disruptions, enhancing grid resilience, and ensuring timely restoration of services. Emerging in-field and AI technology allows utilities to proactively allocate resources, optimize crew deployments, and communicate more effectively with customers and stakeholders. However, challenges remain, including data quality and availability, integration with existing systems, upstream process improvement, and change management.
Exelon has teamed up with the University of Connecticut (UConn) to develop an outage prediction model for its area. As part of the partnership, UConn is developing four machine learning-based models for rain/windstorms, tropical storms, snow/ice storms, and thunderstorms. Panelists from Exelon, Oncor, and UConn will discuss their use of AI to enhance the tools and procedures for managing storms within their utilities. They will also address the existing challenges in securing stakeholder acceptance and trust and implementing these solutions in an operational environment.
Engineering best practices for quantifying cyber risks
3:00 PM-3:50 PM
Cyber risks, weaknesses, and vulnerabilities are everywhere, but what do we need to fix first? This is a common refrain from asset owners and operators trying to prioritize limited mitigation resources. In the last few years, there has been a significant growth in vulnerability discovery.
Despite these growth areas, cyber threat intelligence has failed to keep pace with adversary advancement and capabilities. Defensive efforts continually fall behind adversary activities designed to attack and hold critical infrastructure at risk. Infrastructure susceptibility analysis (ISA) is a repeatable, proactive methodology designed to leverage threat actor information commonly overlooked by normal threat cyber intelligence practices. ISA expands on existing engineering best practices to enable asset and system owners to understand not only the most damaging outcomes of a cyberattack but also the most likely ones.
This session is designed to provide the audience with a background in relevant engineering practices for understanding cyber risk, as well as the limitations of these approaches. It will introduce the audience to the ISA process and highlight key differentiators from past approaches. This session will also expose the audience to term and trend cyber threat intelligence practices and provide recommendations for how to track adversary capability growth against their own systems and infrastructure.
March 26
Generative AI is transforming Exelon’s organization
1:00 PM-1:50 PM
In this session, Exelon will explore how its award-winning analytics team is pioneering the use of generative AI technology to materialize novel capabilities across various organizational functions within the utility’s operating companies. Generative AI, with its capability to synthesize information, execute agentic commands, and easily process natural-language input, is providing unprecedented capabilities that enhance decision-making, operational efficiency, and customer satisfaction to utilities that are willing to experiment.
The discussion will cover:
- Generative AI Use Cases:
- GasGPT: An interactive LLM-powered chatbot that helps Baltimore Gas & Electric engineers research gas engineering queries and surface relevant information
- VICTOR: A training program that uses an LLM to simulate customer conversations for customer service representatives (CSRs) to practice their skills and knowledge
- Electrical distribution standards engineering assistant: Using large multi-modal models such as GPT-4V and GPT-4o to process questions related to standard drawings
- Agentic AIs: Embuing generative AI systems with the capability to execute actions on behalf of users with only natural language queries as input.
- Generative AI stack choices and lessons learned evaluating/developing potential use cases
- Suggested frameworks for building generative AI capabilities within utilities
By attending this session, participants will gain a comprehensive understanding of the practical applications of Generative AI in the utility sector and learn how to implement similar strategies within their own organizations.
Transforming power & utilities with AI – a thought leadership conversation
2:00 PM-2:50 PM
In an era where the energy landscape is rapidly evolving, the integration of Artificial Intelligence (AI) and strategic partnerships are pivotal in transforming utility operations. This panel discussion brings together leaders from the power and utility sector and Microsoft to explore how AI-driven solutions are revolutionizing the way utilities operate.
Enhancing worker and driver safety with AI at Exelon
2:00 PM-2:25 PM
This session will explore innovative approaches to safety analytics within the electric utility industry, focusing on two key areas: actionable driving insights (ADI) and energy-based analytics (EBA).
ADI:
The ADI program at Exelon leverages telematics data to notify first-line supervisors about unsafe driving behaviors exhibited by their drivers. This data-driven initiative includes tailored recommendations for coaching conversations, training, etc based on the type and history of these behaviors, promoting driver accountability and safety. The program’s benefits include deeper integration with operational safety initiatives, enhanced tracking of driving audits and training attendance, and a robust mechanism for measuring the effectiveness of these initiatives. By providing managers and senior managers with visibility into driving metrics and recommended actions, ADI serves as a comprehensive tool for managing and improving driving behaviors across the organization.
EBA:
High-energy control assessments (HECA) are a modern strategy designed to enhance worker safety on construction and utility job sites by ensuring all high-energy hazards have corresponding controls to mitigate risks. Exelon is using an app to facilitate HECA, capturing over 4,000 energy-based observations monthly. Exelon’s in-house analytics team is turning these observations into actionable insights. By applying artificial intelligence to this vast dataset, Exelon aims to uncover valuable insights to further enhance safety performance and mitigate future risks.
Join us as we delve into these cutting-edge safety analytics programs and discuss how they are transforming safety protocols within the electric utility industry.
Mitigating cybersecurity risk in utility supply chains
2:00 PM-2:50 PM
One of the most overlooked areas when considering the cybersecurity posture of grid entities is the impact of their supply chains. In today’s smart grid environment, myriad third-party solutions are required, most of which either have a digital interface or are connected to highways of remote access in the form of IP packet networks. Many grid partners, meanwhile, utilize their own project applications and tools, and some either connect remotely to an entity’s infrastructure or require the accumulation of sensitive customer information that is then analyzed and processed outside of the entity’s control.
Finally, lacking specificity and non-uniform approaches for the identification and assessment of supply chain security risks can lead to incomplete or inaccurate risk evaluations by either the supply chain partner or the entity itself. This variation suggests that supply chain risk analysis may not reflect the actual risk posed to the entity.
These concerns have been addressed with the release of NERC CIP 013-2 standard which pertains to supply chain risk management. However, today there is no single uniform recommended process for ensuring that supply chain partners are taking appropriate actions to protect entity infrastructure data.
Using real-world practical examples, speakers will identify weaknesses inherent in current non-standardized grid supply chain compliance activities and offer updates on efforts to improve compliance capabilities and reduce risk.
How Exelon uses end-to-end asset lifecycle modeling and objective decision making to deliver better strategic outcomes
3:00 PM-3:50 PM
Learn how BGE is leveraging IFS Copperleaf AIP (asset Investment Planning) and IFS ALM (asset Lifecycle Management) to ensure optimal decisions in substation project planning, from the boardroom to behind the meter. Learn about how they minimize downtime, mitigate system risk, and create long-term (10+ year) asset sustainment strategies, all while seamlessly unifying asset lifecycle management to align operations with strategic goals.
How a utility can use AI to identify operator-to-field-operator miscommunications
3:25 PM-3:50 PM
Thousands of operator-to-field-to-operator calls are completed each year in transmission and distribution operations centers for a given utility. Clear, concise communication between parties is required to avoid miscommunications/mistakes. A simple mistaken word, switch number, etc. can lead to devastating and even life-threatening circumstances. EPRI, Datch, and a large utility have been testing the use of AI as a listening and alerting agent to ensure communications are as sound as possible. Datch’s voice assistant and AI technology has been adapted to listen to switching orders and alert the operator and field worker of mismatching words or phrases. To do this, an AI model was leveraged to identify switching calls and then transcribed batches of audio and diarised transcripts from the two speakers in real-time. The model then uses named entity recognition and LLMs to identify miscommunications. Recorded switching calls were utilized to test out the concept. The demonstration has been successful to date. Additional work is occurring this summer to reduce the sensitivity of alarms and to introduce severity and improved alarm categorization.
March 27
Making the most of AMI: Data drives organizational decisions at Exelon and Duke
9:00 AM-9:50 AM
The utility industry has been facing new challenges in dealing with Big Data, in order to utilize them to improve decision-making and deploy smarter grid infrastructure. In the past decade, how to leverage AMI data for customer analytics, demand response, load research, and rate design, has become a top priority for the utility industry. The criticality of modernizing the load research process from a sample design to using 99% of data could lead to more intelligent rate design and better load forecasting both short-term and long-term at both the distribution and bulk system level.
In this panel, experts from Exelon, Baltimore Gas and Electric (an Exelon company), and Duke Energy will discuss how they leverage data from customer analytics to decarbonization planning. The panelists will discuss the successful experience of investing time and resources into unlocking AMI interval data and customer data to help with internal decision-making, customer programs and experiences, and grid readiness.
Key Takeaways:
- The new development of optimal products and services across demand response, energy efficiency, dynamic rates, and electric vehicles
- How the latest analytics can help a utility better understand each customer’s load shape
- Understand what is going on behind the meter
- Insights into large customers and better forecasting
- Electrification and the future of gas system planning
- How integrating electric and gas systems could offer a cost-effective and realistic approach to decarbonization
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