The market for microgrids

Start with the definition, because it does real work later. Hade’s is one line: a distributed energy resource that can island. The part that matters is the second half of the Department of Energy version he cites, which requires the asset to provide services to the grid during normal operation and then island when the grid fails. That is what separates a microgrid from backup power. The diesel generators behind almost every data center can island, but they sit idle all year waiting for an outage, so on his definition they are not microgrids. Swap them for gas engines that can run when the grid needs capacity and the same site becomes one in some parts of the country and not others, depending on what the local rules allow. Four components make up most microgrids built today: solar, storage, switchgear, and a dispatchable generator. Only switchgear is bought specifically in order to island.

That framing sets up Hade’s reframe of the market question. The conventional question is which customers value resilience enough to buy a microgrid, and he answers it: grocery stores, mid-size warehouses and distribution centers where e-commerce delivery promises depend on staying up, fleet operators electrifying vehicles, and data centers, which he calls probably the biggest driver right now and mostly a dispatchable-gas play. But he thinks that is the wrong question. Hundreds of gigawatts of distributed energy resources are going to be built regardless, so the real question is why they are not being made islandable when the increment is small. The increment only became small because of storage. California’s change to its net metering rules made solar-only projects uneconomic, pushing that market to solar plus storage, and Hade expects every state regulatory environment to face something similar over the next few decades, hopefully less abruptly. Once a battery is in the system for its own economic reasons, the extra cost of islanding is mostly switchgear and panel work. He puts that at a 25 to 30% premium at one point and at 10 to 15% earlier in the same conversation, and Kann restates it as 20 to 30% with Hade agreeing, so it is best carried as a range rather than a figure. Kann pushes on the premise rather than the arithmetic: if distributed growth is mostly rooftop solar and smart thermostats, almost none of it becomes a microgrid. Hade rejects that premise directly, saying that if it were the future of distributed energy he would not hold his thesis.

What stops the incremental purchase, in his account, is mainly that resilience has no price. Traditional energy economics treats it as a private value, so it does not enter resource planning the way reliability, affordability and sustainability do, and there is no commonly accepted methodology for calculating it even for a single customer. Hade’s case against that treatment is not an economic model but a threat assessment, which is how he says he was trained in the military. He reads the grid as fragile, treats a regional outage lasting weeks or months as a when rather than an if, and argues electrification raises the stakes because a long outage stops being an economic disaster and becomes a humanitarian one. He is clear this is an argument he is making rather than a measured result. Kann agrees resilience deserves a more important place in planning while holding that its value genuinely differs between a hospital and a nail salon, and that nobody is putting a microgrid on every building.

Two practical constraints sit underneath the philosophical one. Switchgear, the least-discussed of the four components and the piece that actually allows a system to store, dispatch and island, is the industry’s worst supply chain problem: lead times of roughly 60 to 70 weeks against a pre-COVID norm near 20, at a point when solar, battery and generator supply chains had already recovered. Nobody agrees when it clears, and Hade reports expert estimates ranging from the middle of next year to three to five years, depending on whether the Chinese supply chain recovers on its own or new Western capacity has to be stood up first. The second constraint is financial plumbing. The 30% investment tax credit is nominally the same percentage for everyone, but the transaction cost of monetizing tax equity lands on a far smaller base for a small project. That is why, on his numbers, roughly 95% of commercial and industrial load sits below two megawatts while almost all microgrids get built above it. He is emphatic that the reason is soft cost rather than technology cost, and that the net effect tilts the field toward utility-scale assets, which he reads as an unintended consequence of the legislation rather than the intent of Congress.