Role of Distributed Energy Resources in Power Grids

We’ve entered the biggest era of electricity demand growth since World War II. With 150 GW of new load expected in the next five years, we can’t afford to treat virtual power plants (VPPs) and distributed energy resources (DERs) as experimental. We need to position them as core infrastructure, on par with gas, wind, solar, and transmission. In my latest byline for Utility Dive, I write about the shift underway: utilities are no longer gatekeepers: they’re buyers. Programs like Xcel Energy’s Distributed Capacity Procurement and Exelon’s utility-scale battery filings show that when DERs are treated as capacity, not just flexible demand, utilities respond. This moment calls for alignment, not tribalism. It’s not about who owns the asset. It’s about who delivers reliable, scalable capacity. The companies building and operating DERs are solving real utility challenges, and they deserve a seat at the planning table. Let’s focus on outcomes, unlock scale, and build with urgency.

For most of the last century, generators stabilised the grid as a by-product of producing energy. Today, we are building assets that stabilise the grid without producing energy at all. That shift identifies the binding constraint. Electricity system transition is no longer constrained by renewable resource availability. It is constrained by deliverability and operability. In inverter-dominated systems under rapid load growth, the binding constraints are: - transmission and major substation capacity - system strength, fault levels, frequency and voltage control - connection and commissioning throughput - secure operation under worst-day conditions - execution pace across networks and system services Generation capacity remains necessary. On its own, it no longer delivers firm supply or supports large new loads. Historically, synchronous generators supplied energy and stability together. Inertia, fault current, voltage support, and controllability were implicit. As synchronous plant retires, these services must be provided explicitly. Stability shifts from physics-led to control-led. System behaviour becomes more sensitive to modelling accuracy, protection coordination, control settings, and real-time visibility. Curtailment is not excess energy. It is a deliverability or security constraint. When transmission and substations lag generation, congestion and curtailment rise. Independent analysis shows that delay increases prices and emissions by extending reliance on higher-cost thermal generation. Distribution networks are no longer passive. They now host distributed generation, storage, EV charging, and large loads at the edge of transmission. Voltage control, protection coordination, hosting capacity, and connection throughput now constrain both decarbonisation and industrial growth. Firming is a hard requirement. Batteries provide fast frequency response and contingency arrest. They do not provide multi-day energy and do not replace networks or system strength in weak grids. Demand response reduces peaks. It cannot be relied upon for system-wide security under stress. Execution speed is critical. Slow delivery increases congestion duration, curtailment exposure, reserve requirements, and reliance on ageing plant. These effects flow directly into costs, emissions, and reliability. This is why electricity bills can rise even when average wholesale prices fall. Costs are driven by peak demand, contingencies, and security, not average energy. Large digital and industrial loads are transmission-scale, continuous, and failure-intolerant. They increase contingency size and correlation risk. At that scale, loads do not connect to the grid, they shape it. Supporting growth requires time-to-power, transmission and substation capacity in load corridors, explicit system strength and fault levels, operable firming under worst-day conditions, scalable connection and commissioning, and early procurement of long lead time HV equipment. #energy

Utility Death Spiral: How Grid Economics Are Being Flipped Upside Down Emerging markets like Pakistan and South Africa are providing a preview of what happens when distributed energy resources rapidly outcompete traditional utility models. As grid defection accelerates globally, U.S. utilities and regulators face critical decisions about how to manage this transition without financial collapse. Here's what energy professionals need to understand about this evolving dynamic: 1. The Economics Driving Change - Falling costs for distributed energy resources (DERs) have created compelling alternatives to grid power - As customers adopt these alternatives, utilities must spread fixed infrastructure costs across fewer kilowatt-hours - This triggers rate increases, making self-generation even more attractive - Commercial and industrial customers often lead this shift, removing significant revenue sources - The cycle accelerates as storage costs continue to fall, enabling more complete grid independence 2. The Broader Implications - Grid defection isn't limited to residential solar—commercial microgrids, industrial cogeneration, and campus-scale systems are growing rapidly - Essential public services (hospitals, data centers, military installations) are increasingly prioritizing energy independence - Utilities face stranded assets as large customers reduce grid dependence - Traditional cost-of-service regulation struggles to address these market dynamics - Developing countries may leapfrog centralized grid models entirely in some regions 3. Potential Adaptation Strategies - Forward-looking utilities are exploring platform business models that embrace distributed resources - Modernized regulatory frameworks can create value streams for grid services beyond commodity power - Investments in grid flexibility and intelligence can integrate rather than compete with distributed generation - Rate structures that separate capacity and energy costs more transparently may preserve economic sustainability - Public ownership or cooperative models might provide alternative paths for maintaining essential infrastructure The situation in Pakistan is particularly revealing—with approximately 17-18 GW of solar panels imported in 2024 alone. This adoption wasn't driven by environmental policy but by basic economics and reliability concerns, as solar-plus-storage became both cheaper and more dependable than grid power. For U.S. stakeholders, the key insight is that resistance to distributed energy may ultimately accelerate utility obsolescence. Creating sustainable business models that embrace rather than fight this transition is increasingly urgent for maintaining grid stability and ensuring equitable energy access. #EnergyTransition #UtilityBusinessModel #GridModernization #DistributedEnergy

This week in Virginia, utilities announced 25 MW of distribution-connected batteries, five projects, 5 MW each, as a faster, cheaper alternative to transmission upgrades. The economics are sound. The speed advantage is real. But capacity is not just a quantity. It is also a behaviour. And that behaviour changes when you change what delivers it. On paper, the case is clear: • faster to deploy • lower upfront cost • effective for peak shaving • defers expensive transmission investment But this is not a like-for-like substitution. Because the moment capacity shifts from the network to converter-based resources, the system itself changes. Transmission network capacity has traditionally relied on synchronous-connected systems that provide: • inherent voltage support • fault current contribution • system strength At distribution level, that same capacity is delivered through current-limited, control-driven devices. That distinction doesn’t show up in normal operation. It shows up when the system is stressed. And in many planning frameworks, that difference is not always explicitly assessed under stressed conditions, particularly at the distribution connection level. The decision is often driven by cost and speed. The system behaviour can be assumed to be equivalent at the planning stage. Virginia is not an isolated case, it is an early example. We are starting to see this pattern across PJM, Europe, and other systems where load is growing faster than transmission can be built. And in every case, the planning question being asked is: “How much transmission did we defer?” The question that should also be asked is: 👉 What happens when the system is stressed and that deferred capacity no longer behaves like the network it replaced? At that point, you are not operating the same system anymore. You are operating a system that looks identical in normal conditions and behaves fundamentally differently under stress. The cost saving is real. But the system strength is not directly replaced in the same way. And that gap is not always visible in the business case. #PowerSystems #GridStability #EnergyStorage #SystemStrength #IBR #GridPlanning #Transmission #ReactivePower #PowerSystemOperation #PJM #BESS

Navigating the New Grid Reality: How DERs and Data Centers are Challenging T&D Infrastructure In today's rapidly evolving energy landscape, the widespread adoption of Distributed Energy Resources (DERs) and the explosive growth of power-hungry AI data centers are creating unprecedented challenges for our Transmission and Distribution (T&D) infrastructure. As someone who has spent years helping utilities adapt to these changes, I've seen firsthand how traditional grid equipment—designed for one-way power flow and predictable loads—is increasingly vulnerable to new failure modes. Transformers overheating from harmonic distortion, protection systems confused by bidirectional power flows, and capacitor banks damaged by resonance issues are just a few examples of what our industry now faces. I'm excited to share a comprehensive investigation framework that my team has developed specifically for identifying, analyzing, and addressing T&D equipment failures related to DER and data center integration. This approach combines rigorous data collection, advanced analytics, and targeted mitigation strategies to help utilities maintain reliability while supporting grid modernization. In the attached article, I explore how these modern grid constituents affect different types of equipment and outline practical steps for protecting your infrastructure investments. Whether you're a utility engineer, a grid operations manager, or an energy policy professional, you'll find actionable insights to help navigate this new grid reality. Looking forward to your thoughts and experiences with these challenges! #GridReliability #DERIntegration #DataCenters #EnergyTransition #UtilityInfrastructure

TL;DR: Virtual Power Plants (VPPs) are being tested at scale using home batteries in the open market Last week, California pulled off something extraordinary, thanks to the coordination of over 100,000 home batteries, the grid received a 535 MW injection during the evening peak, enough to power more than half the city of San Francisco. In this historic test held July 29 from 7 PM to 9 PM, Sunrun’s network was the standout performer—delivering 360 MW on average, contributing more than two‑thirds of the total energy supplied. What’s so remarkable? This was not a hypothetical model or simulation; it was a utility‑grade demonstration, coordinated by CAISO, the California Energy Commission, Sunrun, and even CASIO-linked tech infrastructure, proving that virtual power plants (VPPs) truly work in the real world. ✅ Here’s what this means for energy and business leaders: • Reliable peak‑period support: Output was stable throughout the two‑hour window, showing this resource is dependable and predictable when most needed. • Scaled without new plants: This VPP mimicked centralized power station capacity, avoiding land use, permitting delays, and capital costs of traditional generation. • Customer‑driven value: Participating households earn up to $150 per battery per season, creating monetary incentives aligned with grid reliability. • Proven repeatability: This was Sunrun’s second major dispatch this summer, after 325 MW on June 24, showing consistent operational capacity, not one‑off luck. Together with CASIO and other tech enablers, Sunrun has validated the real-world effectiveness of VPPs. Distributed energy resources, aggregated via smart tech and software orchestration, are no longer just promising—they’re mature enough to deliver utility‑scale reliability, economic value, and cleaner operations today. If you’re in energy policy, utility operations, tech strategy, or sustainability leadership, this is your wake‑up call. Virtual power plants aren’t tomorrow’s innovation, they’re today’s solution for resilient, flexible, and cost‑effective grid support. #VirtualPowerPlant #DistributedEnergy #GridReliability #EnergyStorage #SmartGrid

🏝️ Puerto Rico Shows How Community Resilience Can Power Grid Innovation⚡ From devastating darkness to distributed energy leadership - Puerto Rico's transformation offers powerful lessons for grid planners everywhere. After Hurricane Maria left the island without power for months, Puerto Rico reimagined its entire energy system. Today, the island operates the nation's largest behind-the-meter virtual power plant, with over 81,000 customers enrolled and 70,000 home batteries working together as a coordinated grid resource. The results speak to what's possible when utilities embrace distributed energy. During summer peak demand, this network delivered 48MW back to the grid with an impressive 82% participation rate. What makes this remarkable is the equity focus. LUMA Energy's program includes households without their own batteries through financing partnerships, ensuring clean energy benefits reach all communities while participants earn up to $600 per battery. As grid planners face rising demand from electrification and data centers, distributed energy programs like this offer a proven path forward. One that puts communities at the center while delivering measurable grid benefits. How do you see virtual power plants fitting into your utility's integrated resource planning? https://lnkd.in/g8chKap8 #VirtualPowerPlants #GridResilience #DistributedEnergy #CommunityEnergy #CleanEnergyForAll

As I wrote in Fast Company last week, America’s grid is under more stress than ever before. Increased demand combined with a lack of new supply is pushing our infrastructure and our electricity bills to the breaking point. Part of the solution is already scaling fast, and it’s sitting on and in American homes across the country. Residential solar and battery storage systems networked together as distributed power plants can respond to grid stress in minutes. My article details the policy unlocks happening across the country as states work to take advantage of distributed storage as a resource for the grid. I applaud the work of decision makers who are working to make sure that the costs of new demand from data centers aren't pushed onto American families. Sunrun is proving that distributed power plants are critical pieces of energy infrastructure. Customer participation in our programs grew fivefold last year to more than 106,000 Sunrun customers, resulting in nearly 18 gigawatt-hours of energy dispatched to the grid—enough electricity to power 15 million homes for one hour. Meeting our energy demands requires rethinking our energy system, and there is no time to waste. The answer isn’t only more poles and wires. It’s millions of homes generating, storing, and sharing energy.

The grid is moving away from a 100-year old paradigm where controllable centralised supply is adjusted to meet uncontrollable demand, to one where controllable demand is adjusted to meet increasingly uncontrollable and decentralised supply. Data centres have huge UPS and backup generators. The issue is whether they can avail of these for interruptible load/demand response, bearing in mind their very stringent operational requirements. The grid is the backbone of decarbonisation. There is no transition without transmission. "Singapore's demand for electricity is also expected to grow with the increase in businesses and facilities that rely on large and steady supplies of electricity, such as data centres and EVs. "Grid management will become more complex with these new load profiles", he added. To address this, EMA will explore a demand-side flexibility roadmap aimed at allowing the grid to tap "underutilised" distributed energy resources such as battery energy storage systems and backup generators. This means that such resources, which keep energy on standby when they are not being used, could be relied on for Singapore's power needs on a "near-continuous basis". The authority said in a statement: "These resources are typically maintained on standby, placing them in a state of readiness that enables activation with short notice. "Their capability to sustain load curtailment over extended periods suggests they could be well-positioned to provide ancillary services alongside their primary operational role." Together, distributed energy resources and electricity users or facilities that require a continuous and high load of power can be a "potentially dependable and scalable means of contributing to system reserves", EMA said. EMA will be publishing a tender to explore the feasibility and design of a programme that can incentivise relevant parties to contribute to power grid reliability continuously, it said. As part of this roadmap, EMA will also enhance its interruptible load programme, which is targeted at business consumers. The scheme allows eligible participants to be compensated for being on standby and to reduce their electricity demand when the grid faces tight supply constraints. The authority plans to provide greater certainty to these participants during contingencies by reducing interruptible load activation period to 30 minutes. Implementation details have yet to be finalised." EMA said the current pool of interruptible load resources was "opportunistic", as participants only reduce their load when schedules allow. These participants, who are mainly factories or production lines, cannot offer capacity consistently or for prolonged periods as they need to keep their own core operations running." https://lnkd.in/gh9U7Sp5