AGENDA
SPRING 2025 CONFERENCE

Workshop: Design a Fully Funded Electrification Program
Join us for a conversation about electrification and how its programs vary by building type and region across the country. We’ll share some short case studies then break into groups to collaborate on the construction of some fully funded building electrification programs where the sky’s the limit! Learn from colleagues across the country about the ways they are advancing electrification opportunities for residential, commercial, industrial, retail and LMI buildings.

Redefining C&I Load Flexibility to Address Customer Needs and the Grid
News Flash! Customers are demanding more from the grid than ever. Join us for an interactive session in which we’ll explore the unique flexibility challenges of small/medium commercial buildings, industrials, large commercial buildings, and the exploding data center segment. We’ll hit all of the sector’s hot topics and will invite the audience to determine priority issues in need of immediate attention.

Engaging C&I Customers on Innovative Rates
Innovative rates like Time of Use (TOU) and Critical Peak Pricing (CPP) constitute a key demand flexibility engagement lever for C&I customers. However, as our session panelists can attest, engaging C&I customers on this topic is no easy task. This interactive session offers an opportunity to hear lessons from the field about the best strategies for engaging C&I customers on innovative rates. It will also include recent research from ACEEE and NREL on how rates can be both a solution and a barrier to incorporating new technologies in the C&I setting. We’ll also delve into the real world challenges of engaging large customers on advanced rate plans.

Half-Baked: Valuing EV Load Management Programs
Ever wonder why EV load management programs have trouble passing cost effectiveness tests? In this session, a panel of evaluators who have analyzed utility programs will discuss what is necessary for robust, cost-effective EV load management programs, what value streams should be quantified further, and program designs that capture the most benefits.

What’s Old is New Again: Rethinking Switch-based HVAC Control
Switch-based control networks are the overlooked, unsexy stepchild of residential demand response. Quietly, unassumingly, they have been reliably delivering MWs and evolving under the radar alongside their smart, glamorous, more favored peers: thermostat-based programs. But smart thermostat programs are underperforming and costing utilities more than expected, in addition to the hassle they bring through OEM and aggregator middlemen which has caused load serving entities to rethink their approach to residential DR. New technologies like 2-way switches and updated AMI networks have led some utilities to rethink the value of switch-based HVAC networks. Is cheap, simple, and direct “enough” to compete with expensive, smart, mediated, and uncertain?

Scaling Down: Smaller Utility DR Programs Where Every Customer Counts
Every utility, regardless of size, has an important role to play in managing peak demand. Although many factors are involved in the success of a demand response program, all demand flexibility programs and VPPs thrive with one simple ingredient: customer enrollment and participation. This panel will dive into Northeastern REMC’s smart thermostat program’s success and enrollment strategies. We’ll also highlight the technology needed to ensure continued engagement and retention in these types of programs. Join us as we discuss how to connect and engage with customers to incentivize their enrollment and participation in demand response.

Overcoming Certification Hurdles to Build Stronger Vendor-Utility Partnerships
The certification and approval process is a significant hurdle for technology vendors looking to scale within utility operations. Lengthy, complex and costly procedures—such as testing protocols and vendor qualification—can extend project timelines and increase costs, straining vendor-utility relationships. Regulatory requirements add further complexity, with varying standards across regions and jurisdictions, delaying technology adoption. Speakers from TRC, Edge Zero and Dominion Energy Virginia will give consultant, technology vendor and utility-provider perspectives on the challenges vendors face and how delays hinder business and innovation. They will also explore how early transparency and collaboration can help navigate these hurdles. The utility perspective, represented by Dominion Energy Virginia, will address the role of certification in ensuring safety, compliance, and grid reliability. Speakers will discuss ways vendors and utilities can collaborate to streamline processes, improve communication, and create a more efficient path for technology adoption at scale.

Driving the Grid Forward: Transformer-Constrained EV Managed Charging
As electric vehicle (EV) adoption accelerates, managing grid impacts at the local level is crucial. This panel brings together Vermont Electric Cooperative (VEC), Duquesne Light Company (DLC), and Camus Energy to explore innovative solutions for transformer-constrained EV managed charging. VEC will share insights from their pilot program using managed EV charging to avoid transformer overloading. DLC will present findings from a grid-wide analysis on the value of transformer-constrained charging strategies. Camus will discuss their experience integrating data sources to enable planning and operational workflows for grid-constrained EV charge management. Attendees will learn practical strategies for balancing local grid reliability with electrification goals.

From Paging to Premium: Load Control Switches Ain’t What They Used to Be
Demand response programs originally deployed one-way load control switches but are finding new life on utility-owned AMI networks. Durable and cost-effective two-way communication is allowing for better asset retention, program performance, and broader DR options.

During this panel session we will discuss where several utilities are in their journey, how traditional DR fits into their DER portfolio, and hear their experiences and lessons learned coordinating with their AMI teams.

Bridging the Gap: Collaboration Between Cooperatives and IOUs in Flexible Load Management
Rural electric cooperatives (co-ops) face unique challenges in managing flexible loads, ensuring grid reliability and integrating distributed energy resources (DERs). Co-ops often have fewer resources and infrastructure than larger investor-owned utilities (IOUs), yet their ability to adapt to changing demand and decentralized generation is vital for grid stability. While challenges like limited access to advanced technologies and data exist, the co-op membership model encourages innovation and member-focused solutions. This panel, moderated by Edge Zero with representatives from three co-ops, will address these hurdles, including data access, communication barriers and funding challenges for grid technologies. Each utility will explore how these factors influence their approach to load management and grid operations, sharing insights and best practices beneficial for both co-ops and IOUs. The panel will also discuss strategies for enhanced collaboration between co-ops and IOUs, promoting a more resilient and reliable grid in the face of growing clean energy demand.

Re-Tuning the Trade Ally Network to Meet Large Demand Response Goals
For many utilities to meet their ambitious demand response targets in the coming years, it will take a village – or as we call it in the demand-side management program world, a strong Trade Ally (TA) Network. TA Networks have long been relied upon by energy efficiency program implementers to achieve and scale efficient market transformation. However, very few demand response programs presently leverage these networks. Previously dominated by lighting contractors, TA Networks have evolved to include more diverse providers of efficient building equipment and services, and now – demand response market partners. Our session offers an overview of the key market partners capable of moving the needle on demand response enrollment and performance, as well as the shared experience of Generac, GridBeyond, TRC, and our utility partners in developing new strategies to engage these market actors, including challenges encountered, lessons learned, and results achieved to date.

Improving on Success: Revisiting Consumers Energy’s PowerMIDrive Program
By focusing on outcomes and accessibility, Consumers Energy’s PowerMIDrive program has become one of the most successful EV load management programs in the US. PowerMIDrive uses AMI-based passive EV load management – more than 90% of all charging happens overnight and less than 2% of charging occurs during system peak hours. Since presenting at the 2023 EV Symposium, participation in the PowerMIDrive program has more than doubled, and importantly, 50% of grid impacting vehicles are enrolled. This presentation will highlight some of the innovative changes to the program, and the data that has informed them. One new feature addresses “timer peaks” by spreading EV load throughout overnight hours, and Consumers/Sagewell monitor distribution system stress for high value peak reduction target marketing. Even after the Michigan Public Service Commission (MPSC) added a 12-month cap on incentives, former participants continue to charge off-peak at nearly the same level.

Batteries Unleashed: Supercharging Benefits Through Smarter Storage Programs
Battery storage systems can offer myriad benefits ranging from resiliency, peak demand reduction, and energy arbitrage (to name a few). Programs incentivizing adoption of energy storage technologies are proliferating throughout the country – California provides upfront incentives for the installation of battery storage systems that serve a customer’s needs. In other states like Massachusetts, New York, and Vermont, different models are emerging ranging from utility ownership of batteries, utility/aggregator dispatch of batteries, and pay for performance programs. California currently finds itself at a crossroads regarding the future of battery storage. The State has provided incentives for tens of thousands of battery storage systems and produced tangible benefits to both participants and non-participants, providing resiliency during multi-day outages, generating greenhouse gas (GHG) emissions reductions, reducing system peak load, and delivering bill savings to customers. At the same time, research has shown that residential batteries are only discharging roughly 45% of their kWh capacity on average on a daily basis and 16% of their kW capacity during the system peak hour. As California looks to the future, should its battery program be considered a success given the benefits listed above, or are we only beginning to scratch the surface of potential benefits? Optimal dispatch modeling suggests that a battery optimized to provide grid benefits could provide 4x the societal benefits than systems are currently providing, and a system optimized for GHG emissions reductions could achieve 3x the reductions observed today. Exposing customers to marginal-cost based rates could dramatically improve grid benefits but significantly reduce bill savings.

Unlocking Growth: Empowering Commercial and SMB Customers in DR
In 2024, PGE’s Energy Partner Smart Thermostat (EPST) and Energy Partner On Demand (EPOD) programs achieved unprecedented growth, with the EPST program experiencing a remarkable 260% increase in participation. Despite the challenges of engaging commercial and industrial customers in demand response & programs—where C&I customers constitute less than 2% of DR participants but deliver over 50% of peak demand savings nationwide—PGE has made significant strides in scaling its programs. This session will explore the strategies that fueled these successes in 2024, from innovative customer engagement tactics and connected device integration to addressing barriers specific to the C&I sector. Attendees will gain actionable insights on scaling commercial load management programs, engaging underserved communities, and aligning DR efforts with decarbonization goals, while learning best practices for unlocking the immense potential of C&I customers in DR programs.

Maximizing Flexible Load Potential with Machine Learning
Utilities often struggle to identify when customers are using major end-use devices like HVAC systems and EV chargers—essential data for flexible load management programs. Without this visibility, demand-side management and marketing teams cannot target customers, limiting program effectiveness. To solve this problem, Alabama Power Company partnered with E Source to apply machine learning to 15-minute interval kWh AMI data. Our approach detects HVAC and EV usage patterns, classifies equipment types, and scores customers based on HVAC usage intensity compared to peers. The results are helping demand-side management teams refine their program strategies, focusing on more efficient targeting and resource allocation. In this session, we’ll walk through the process behind this data-driven solution and share lessons learned, including: Using AMI data to detect major end uses Helping EV customers optimize charging based on time of day for maximum savings Refining ongoing strategies to improve marketing and grid management.

Load Flexibility For All: Dynamic Rates for Commercial Customers
Discover how today’s commercial buildings can be enabled to deploy artificial intelligence to “shift and shimmy” in response to dynamic pricing. This session will explain that with the help of innovative software, commercial customers can reduce costs and enhance resiliency by leveraging hourly electricity prices through SCE’s Dynamic Rate Pilot. We’re not just talking about managing HVAC systems, but all flexible loads behind the meter including EV charging and stationery batteries. This overview of a dynamic price response demonstration at multiple sites is a postcard from the future – real customers controlling real equipment in response to real-time prices. We’ll share promising results from multiple sites that participated in SCE’s Dynamic Rate Pilot, that deepen our understanding of the range and variability of load flexibility.

Understanding the Impact of DER Adoption on Load Shapes
Since 2021, EPRI, the National Renewable Energy Laboratory, Lawrence Berkeley National Laboratory, and seven electric utilities have been exploring the propensity of residential and commercial customers to adopt a range DER technologies (solar PV, energy storage, and/or electric vehicles and attendant charging infrastructure). Funded by the DOE, this effort has entailed collecting/analyzing a comprehensive survey data set to discern customer adoption preferences, assessing real-world customer interconnection and premise-level metering data to determine baseline customer load shapes from which to extrapolate the effects of DER adoption, and developing a forecasting tool for modeling national/regional adoption outlooks. This presentation will describe key takeaways from the stated and revealed customer survey results, and then focus in on the implications of DER adoption on customer energy use. It will discuss the time-differentiated and aggregate differences in consumption between DER non-adopters, singular adopters, and co-adopters to characterize prospective load shape management opportunities.

Beyond the Screen: Engaging Small-to-Medium Non-Residential Customers
Demand management programs are becoming increasingly critical for electric utilities, benefitting participants while supporting grid reliability and sustainability goals. However, securing enrollments from small-to-medium-sized commercial accounts requires more than a “one-size-fits-all” approach. These customers are traditionally non-managed accounts, and despite their interest in being part of the solution, they require flexible program options, reliable event strategies and a customized event day action plan to meet their specific needs. This presentation will showcase Xcel Energy’s Demand Management portfolio, which includes programs such as Peak Partner Rewards and Peak Flex Credit. Xcel Energy designed this portfolio specifically to serve the non-managed customer base. Michaels Energy, the implementation contractor, provided marketing and engineering support tailored to these often-overlooked customer groups. By combining technical expertise with personalized engagement, this presentation demonstrates how utilities can effectively connect with small-to-medium businesses, enable them to participate, and inspire their commitment to energy efficiency and carbon reduction goals.

Multifamily Line Voltage Thermostats: A Load Flexibility Story in Progress
NEEA and Puget Sound Energy partnered on a winter load flexibility study on Line Voltage Thermostats (LVTs) in multifamily buildings. We aimed to understand the current load shifting potential of LVTs for baseboard heating, learn about building owner and tenant recruitment, and test event strategies to limit customer impact. We identified opportunities to improve future results (such as technology enhancements and building envelope energy efficiency). We installed LVTs and Wi-Fi in two multifamily properties. We educated tenants about how to sign-up and receive participation incentives by responding to surveys throughout the study period. Several event calling protocols were tested (morning/evening, event duration, and event frequency). Utility meter and telemetry data were analyzed to assess impact. We will share findings, key learnings, and next steps to maximize potential for multifamily load flexibility. Additionally, we will highlight coordination between energy efficiency and load flexibility to achieve better customer experience and results.

Innovation and Interoperability via adoption of OpenADR 3.0
Using the PG&E’s Peak Day Pricing and Capacity Bidding Program as examples, this session highlights the real-world challenges that OpenADR 2.0 users have had in supporting the standard and the innovation that can be unlocked with the recent release of OpenADR 3.0. OpenADR 3.0 provides simplicity at a time when technology is becoming more complex, offers a modern web service design that is easier to use, provides added functionality which makes energy management easier and future-proofs energy systems. The speakers will share unique insights about the development of the OpenADR 3.0 standard, major technical departures from previous versions and how OpenADR 3.0 will accelerate interoperability of DERs into flexible load programs. The session will showcase various projects leveraging the new standard, standard adoption into ADR programs and where OpenADR fits in with other “hot” standards (CSA Matter 1.4, IEEE 2030.5).