Mar 10, 2026 · 35m · catalyst
Frontier Forum: How VPPs earn grid-scale trust [partner content]
0:00 / 0:00
gold bands on the timeline = statements, start to end. Hover to read, click to jump. CC turns on captions
Host Stephen Lacey joins leaders from Duke Energy and Energy Hub to explore how virtual power plants are evolving from legacy demand response into scalable, trusted utility infrastructure integrated directly into grid operations and resource planning.
How this conversation actually went
Every chapter scored 0–10 on four independent dynamics. Hover any point for the reasoning behind the score. How this is scored →
Shayle as informed peer 5.0 Guest teaching 4.3 Guest disagreement 0.3 Shayle pushing back 0.9
speaking balance: gold is Shayle, purple is the guest (3 minute bins)
Sharpest disagreement ▶ 18:28 Stacey challenges the 'virtual' terminology
Stacey playfully but firmly rejects the 'virtual' label in favor of 'customer power plant', arguing that virtual diminishes the tangible, physical reality of customer contributions.
Hardest push from Shayle ▶ 27:05 Lacey presses on the realism of level four VPP deploymentLacey pushes past the theoretical framework to ask directly whether mass level four deployment is genuinely on the horizon or simply aspirational hype.
Biggest teaching moment ▶ 14:02 Stacey explains legacy AMI data science versus expensive DERMSStacey educates the room on how a scrappy utility can achieve 180 MW of reliable capacity with simple one-way switches paired with post-event AMI metering analytics rather than waiting for multimillion-dollar software suites.
Shayle holds their own ▶ 10:06 Lacey contextualizes VPPs against $100M data center load growthLacey shows domain command by citing Duke's capital expenditure plans for data centers and industrial manufacturing to test how software resources fit into heavy balance-sheet planning.
the scores for every segment, with the reasoning behind each
| Chapter | Topic | Shayle as informed peer | Guest teaching | Guest disagreement | Shayle pushing back | Why |
|---|---|---|---|---|---|---|
| Winter Grid Extremes and the Evolution of VPPs | 5 | 3 | 0 | 1 | Lacey sets the scene around severe winter storms driving record peaks for Duke Energy and asks how VPPs fit emerging capacity constraints. The guests collaboratively explain how smart devices have expanded flexible capacity from summer-only to dual-season peaking. | |
| Introduction to Frontier Forum and Modern VPP Capabilities | 4 | 4 | 0 | 1 | Lacey asks what technological and scale factors make VPPs reliably dispatchable today. Seth points to IoT reliability and statistical forecasting over huge device fleets, while Stacey emphasizes repeatable customer adoption and the reserve value of customer programs. | |
| Integrating VPPs into Utility Load Planning and Control Rooms | 6 | 5 | 0 | 1 | Lacey references Duke's hundred-million-dollar investment pipeline to accommodate data center growth and asks how VPPs integrate into IRPs. Stacey explains that Duke has run customer programs for 40 years across gigawatts of capacity, using customer flexibility to shrink the generation challenge. | |
| Comparing Legacy Demand Response with Modern VPPs | 5 | 4 | 0 | 1 | Lacey prompts Seth to draw the boundary between legacy demand response and modern VPPs. Stacey and Seth elaborate that utilities do not need massive upfront software outlays if they leverage existing AMI metering data effectively to prove performance. | |
| The Hewles Test and the Concept of Power Plant Parity | 6 | 4 | 2 | 1 | Lacey introduces Energy Hub's white paper on the Hewles Test. Seth defines the test as passing power plant parity in the control room, prompting playful pushback from Stacey, who advocates renaming the concept to Customer Power Plants and focusing on streamlined operator decisions. | |
| Minimizing Customer Friction and Reforming Value Frameworks | 5 | 5 | 1 | 1 | Lacey asks for utility reactions to the maturity framework. Stacey explains that in vertically integrated utilities, value is primarily driven by peak-hour avoided costs and minimizing customer friction rather than purely technological classification. | |
| Exploring the Five-Tier VPP Maturity Model | 5 | 5 | 0 | 1 | Lacey asks Seth to break down levels zero through four of the maturity framework and asks Stacey whether level four distribution integration is realistic. Seth and Stacey agree that level four multi-objective dispatch is a multi-year aspirational goal requiring extensive system modeling. | |
| Operational Integration and the Single Pane of Glass | 5 | 5 | 0 | 1 | Lacey asks about creating a single pane of glass for control room operations. Stacey describes building an internal, lightweight tool for Duke's energy control center that recently proved reliable during a surprise weekend event without manual coordination. | |
| The Future Vision of Foundational Grid-Scale VPPs | 4 | 4 | 0 | 0 | Lacey closes by asking what the market looks like once VPPs are truly foundational. Seth lays out a future where flexible resources are dispatched 24/7 across IRPs and control rooms to balance renewables, maintain affordability, and reinforce grid reliability. |
Statements from this episode (16)
Phillips: Duke Energy activated almost all winter programs during cold snaps
“And during those two weekends, we called almost all of our winter programs.”
Frader-Thompson: EnergyHub deployed ~120MW combining thermostats and batteries
“We just deployed about a 120 megawatts from kind of a traditional thermostat program layering in batteries. So we're sort of stacking up these resources to both firm the resource while growing it.”
Frader-Thompson: VPPs have transitioned to summer and winter peaking resources
“It used to be that VPPs were really kind of like a summer peaking resource, and now they're a summer and winter peaking resource, and that kind of points in the direction that we're all moving.”
Phillips: Duke Energy built a 45 MW battery VPP in 18 months
“Brought together the partnerships with aggregators like Energy Hub, as well as our local trade allies and other stakeholders who were interested in that. And 18 months later, we've got 45 megawatts of it, and it's a great program.”
Frader-Thompson: VPPs will be dispatched hundreds of times per year
“Now it's a resource because of that repeatability that you can use operationally, and you can be confident that if you need to use it, you know, today I think maybe dozens of times per year, but moving toward hundreds of times per year, that repeatability just…”
Phillips: Duke Energy manages one million customers and 2.5GW in summer capacity
“We have a million customers who participate in our programs with us. We've got two gigawatts across all the utilities in the winter and two and a half in the summer.”
Frader-Thompson: VPPs need roughly 50 MW to interest utility control rooms
“I think scale is the other thing, right? I mean, I think Stacy talks about there being a threshold like somewhere around 50 megawatts where, you know, you are actually at the scale of a, an individual beaker plant, and that's kind of the that's kind of the hur…”
Phillips: Duke Energy has one million field switches, mostly one-way
“People make fun of me because we have a million switches in the field. And the vast majority of them are one way.”
Frader-Thompson: Spending $20M on software before launching a VPP is backwards
“That is in contrast to some other plans that I've seen where we're saying like, let's build out twenty million dollars worth of software infrastructure before we even stand up a program, and that's backwards.”
Phillips: Grid operators only need reliable parameter forecasting from VPPs
“As long as it's repeatable and reliable forecasting of how long, how much notice do I have to give it, because everything has notice, how long can I run it, And then, what do I need to know about it afterwards, and when can I run it again? That's what they nee…”
Phillips: Running load switches for one hour prevents customer churn
“If I look at my level zero switches, and I don't mind calling them level zero a couple years ago, we would run them for three or four hours at a time, and customers would get very hot. Now we run them one hour at a time, and customers don't leave the program f…”
Frader-Thompson: Regulators rely on one-size-fits-all M&V for flexible resources
“What we don't have in the industry right now is sort of regulatory recognition of those different things. We tend to have kind of a one-size-fits-all M&V approach.”
Duke Energy's VPP capabilities are at Level 2 maturity
“Well, I only know my utilities very well. And I'd say we are like a strong level two. And as you heard before, obviously we've got a lot of devices in zero and one.”
EnergyHub CEO: Level 2 thermostat VPPs provide peaker plant value
“Like, the smart thermostat programs are at a strong level two in general. And at level two, like I said before, they are clearly already providing the value that a peaker plant would provide.”
EnergyHub CEO: Level 4 VPP deployment is a 5-year goal
“So I think level four is, I don't think it's a 10 year goal. I think it's a five year goal.”
Phillips: VPPs require energy management system integration for power plant parity
“I've talked to our energy control center director around, like, what would it take for us to be integrated into the energy management system? Where, you know, is that what this looks like when you actually have parity with power plants? And the answer is yes. …”