Episode Summary
Executive Summary: The episode argues that distributed energy resources (DERs) are finally entering a moment where grid need and economics align. After a decade of hype that outpaced real demand and affordable deployment, rising load growth, grid bottlenecks, and maturing virtual power plants are making DERs—especially batteries, demand response, and flexible distributed generation—more relevant than ever, though regulatory friction and program design remain major obstacles.
Main Topics: Why DERs failed to scale in the 2010s (Priority: 5/5): The hosts revisit the earlier wave of DER enthusiasm and explain that it underdelivered because the grid didn’t urgently need these resources and many DER solutions were still too expensive or operationally immature. What counts as a DER and which types matter most (Priority: 5/5): Andy Lubershane distinguishes between non-dispatchable DERs like energy efficiency and solar, and dispatchable capacity resources such as distributed generation, flexible loads/demand response, and batteries. The grid’s current bottlenecks are changing the equation (Priority: 5/5): The discussion emphasizes that the electricity system now faces significant load growth and capacity constraints, making flexible resources far more valuable than a decade ago. Cost trends: hardware is cheaper, soft costs remain stubborn (Priority: 4/5): Hardware prices for batteries, solar, and connected devices have fallen, but customer acquisition, installation, and interconnection costs have remained a barrier to widespread DER adoption. Virtual power plants and demand response are scaling (Priority: 4/5): The episode highlights that real VPPs are now operating at hundreds of megawatts, and demand response dispatch frequency is increasing rapidly, suggesting growing operator comfort and real-world utility. Bull case vs. bear case for the next five years (Priority: 4/5): The bull case depends on utilities making DERs part of formal capacity plans now; the bear case centers on continued regulatory inertia, battery cost issues, and planner preference for 100% solutions.
Key Arguments: DERs were not widely adopted in the 2010s because the grid largely did not need them; utilities could still build conventional capacity fast enough and at reasonable cost. Many earlier DER resources were more like 'vitamins' than 'painkillers'—interesting, but not essential enough to drive procurement. Dispatchable capacity resources are the most valuable DERs for operators because they can be turned on and off in real time, unlike energy efficiency or solar. Battery cell prices have fallen, but installed-system costs still depend heavily on soft costs such as customer acquisition, labor, and interconnection. The current market is different because load growth and bottlenecks across generation, transmission, and distribution are creating real desperation for flexible capacity. Virtual power plants are no longer theoretical; they are being dispatched in meaningful volumes and can form a positive feedback loop for DER deployment. Demand response may be the fastest near-term growth area because it can expand from its current base without waiting on entirely new technology breakthroughs. Utilities must include DERs in integrated resource planning and begin programs now if they want meaningful scale within two to five years. The main risks are regulatory friction, battery supply chain and fire-code constraints, and utility planners’ preference for fully reliable 100% solutions over partial but flexible ones.
Data Points: DER dispatchable capacity in VPPs: 3.4 gigawatts - Energy Hub says 2.5 million customer devices are turned into 3.4 GW of dispatchable capacity. Customer devices aggregated: 2.5 million - Energy Hub’s VPP platform aggregates thermostats, batteries, and EVs across homes. Peak-period device participation: millions of thermostats, batteries, and EVs - Referenced as shifting energy during peak periods in May and June. Utilities using VPP partner: more than 170 utilities - Energy Hub says utilities are turning everyday devices into a grid asset at scale. Dispatch frequency trend: escalating off the charts in 2025 - Dana Guernsey’s Voltis chart showed demand response resources being dispatched far more often in the last two years. Current demand response potential: around 20–25 gigawatts - Andy estimates latent DR potential is currently in this range. Non-wires alternatives finding rate: very few; one or two outliers - A 2017 discussion with utility engineers found that utilities were not finding many non-wires alternatives. Timeframe for utility program ramp-up: 2–3 years - Andy says utilities starting now could stand up meaningful DER programs within this window. Five-year outlook: several hundred megawatt programs at most major utilities - The optimistic scenario foresees broad adoption of sizable DER programs within five years. Battery system cost trend: past 2–3 years - The episode notes that installed battery system prices have only recently started to move down meaningfully.
Pivotal Quotes: "The power grid didn't need DERs that much in 2015. Now it desperately does." — Andy Lubershane: Core thesis explaining why the DER market may finally be at an inflection point. "The early days of distributed energy resources were a vitamin." — Shail Khan: Analogy used to describe early DER offerings as nice-to-have rather than essential. "We have actual VPPs being dispatched now in the hundreds of megawatts." — Andy Lubershane: Evidence that DERs are moving from theory to operational grid assets.
Implications: DERs may finally become a mainstream grid resource, especially demand response and batteries, if utilities move quickly to build programs now. But scaling will still depend on regulation, program design, and willingness to accept flexible—not perfect—solutions.