A decade ago, DERs were hot. The hype was that things like batteries, smart devices, and other distributed energy technologies would offset the need for expanding traditional grid infrastructure.
But DERs never took off, at least not at the scale that many hoped for. They had high price tags and short track records compared to the existing substations, transmission lines, and generation options that utilities were familiar with. In short, the market didn’t need them yet.
Fast forward 10 years, and things have changed. Load growth is increasing while major grid bottlenecks — like in transmission, interconnection, and supply chains — may be opening up a new opportunity.
So is the time finally right for DERs?
In this episode, Shayle talks to his colleague Andy Lubershane, partner and head of research at Energy Impact Partners. Last week, Andy published a blog post making the case that DERs were a good idea that was just too early, but the market is ready now. Shayle and Andy cover topics like:
- What held DERs back a decade ago
- Why now is different, including falling system costs and growing grid bottlenecks
- The difference between demand response and virtual power plants
- The potential hurdles to scale, like supply chain bottlenecks, foreign entity of concern regulations, and fire codes
Resources
- Latitude Media: Can distributed energy answer AI’s power problem?
- Open Circuit: The grid flexibility solutions staring us in the face
- Catalyst: Making DERs work for load growth
Credits: Hosted by Shayle Kann. Produced and edited by Daniel Woldorff. Original music and engineering by Sean Marquand. Stephen Lacey is our executive editor.
Catalyst is brought to you by Anza, a solar and energy storage development and procurement platform helping clients make optimal decisions, saving significant time, money, and reducing risk. Subscribers instantly access pricing, product, and supplier data. Learn more at go.anzarenewables.com/latitude.
Catalyst is supported by EnergyHub. EnergyHub helps utilities build next-generation virtual power plants that unlock reliable flexibility at every level of the grid. See how EnergyHub helps unlock the power of flexibility at scale, and deliver more value through cross-DER dispatch with their leading Edge DERMS platform by visiting energyhub.com.
Catalyst is brought to you by Antenna Group, the public relations and strategic marketing agency of choice for climate and energy leaders. If you’re a startup, investor, or global corporation that’s looking to tell your climate story, demonstrate your impact, or accelerate your growth, Antenna Group’s team of industry insiders is ready to help. Learn more at antennagroup.com.
Transcript
Tag: Latitude Media: covering the new frontiers of the energy transition.
Shayle Kann: I’m Shayle Kann. And this is Catalyst.
Andy Lubershane: The power grid didn’t need DERs that much in 2015. Now it desperately does and every part of the system has major bottlenecks Now
Shayle Kann: Coming up this time might just be different for distributed energy resources, I’m Shayle Kann. I invest in early stage companies and energy impact partners. Welcome. Here’s a headline from The Guardian in July, 2014, will the Microgrid put Major Power Companies out of business? If you were around energy circles at that time, which I was, you’ll remember lots of these headlines as well as the general concept of the utility death spiral, which was a phrase that was thrown around a lot in those days. Long story short, surprise, surprise, it didn’t happen. And I don’t actually even think that is really worth talking about now because it’s definitely not happening these days. But the backdrop to that line of thinking was the concept that we were going to see this wave of distributed energy resources that would decentralize the grid. They’d provide flexibility and resilience, they’d give customers more autonomy over their own power supply.
Did that part happen? A little bit, but honestly at the macro level, not that much. So the industry has a lot of battle scars around this whole concept, but times change and there is good reason to revisit some priors here, which is exactly what I’ve been thinking about lately as I evaluate a whole host of new startups in the DER space. And as so often happens, while I’m thinking about a thing, my partner and head of research at EIP where I work, Andy Lubershane is writing about it. So he did. He published a great piece last week that’s called Finally the Time is Right for DERs. And let me just say he and I are both pretty bullish that the time is indeed right now for reasons we will discuss, but we do have plenty of learnings from watching this market largely failed to deliver its full promise over the last decade or so. If you are working on something truly novel and suited to the moment in this space, get in touch with us. But in the meantime, let’s get into it. Andy, welcome back as always,
Andy Lubershane: Excited to be back as always.
Shayle Kann: Okay, distributed energy resources. I don’t want to spend a ton of time just laying out all of the different types of distributed energy resources to start, but I thought you had kind of a useful categorization in this article that you put together. So start by categorizing, how do you separate out the different types of DERs?
Andy Lubershane: So in this article, I have a whole taxonomy, but we want to get into the details. I think there’s really two key categories of DERs and they’re the things, basically the things that are distributed, capacity resources, which I can define in a second. And then the things that are not, and maybe it’s easier to start with the things that are not, which is energy efficiency and solar are sort of the two primary categories of DER that don’t really provide you dispatchable capacity if you’re a grid operator. And I don’t want to throw shade on energy efficiency and distributed solar because I think those can both be extremely valuable resources including for grid planners, not as much for grid operators because they don’t give you enough real time control, which is the real challenge here. But for grid planners, they can be extremely valuable. We should be considering them as a part of integrated resource plans for the power system.
We should very much be counting on them, pushing the boundaries of them, et cetera. But the challenge is that what grid operators need increasingly today are resources where they give you a button, an on off button so that you can provide capacity to the grid when it’s needed and ideally for however long it’s needed. And the problem with energy efficiency in solar is that while you can take a typical profile that those resources give you on a planning basis, they don’t give you an on off button that operators can use in a real time basis, which is really increasingly valuable.
Shayle Kann: And then the other category, the things that are dispatchable capacity, which you should just run through a quick list of, they do give you the on off button, but they do not generally give you the on off button as long as you want it bit. Right. That is important to note.
Andy Lubershane: Of course. Yeah, I mean there’s mostly no such thing as a perfect energy resource here. And I mean the closest thing to a perfect resource from the perspective of a grid operator is a flexible distributed gen set of some sort that can turn on and off really quickly, can ramp up and ramp down very quickly. And ideally if it’s a natural gas gen set and tied into a gas distribution line or a gas transmission line, it really can operate just like any other power generation resource and give you an on off button and turn on for as long as needed, particularly if it’s a really efficient low emissions natural gas gen set. For example, one of our portfolio companies at EIP, Enchanted Rock, has been deploying that type of resource for a long time now. And so it’s not restricted by air permitting concerns. That’s the closest thing to a perfect resource from a grid operator standpoint because it’s just like a centralized generation asset.
It just happens to be spread out there at the edge of the grid. So that’s one category is distributed generation, but some of the newer categories that I think are interesting, that’s one category. There’s kind of three other, really two other primary categories of distributed capacity resource that do give you some degree of on off button. The first is flexible loads, basically some piece of equipment out there on a customer premise that is capable of being turned on or off and ramped up and down quickly in response to some kind of signal from a grid operator. And one sort of name for flexible loads, the name we have known them by for most of the history of DERs is demand response, which is just the setup in which a grid operator or utility comes to an agreement with a customer to operate those flexible loads in response to some kind of signal.
And these demand response programs have taken a variety of forms for many years, sometimes bidding into energy markets and the wholesale supply side of the market sometimes as utility resources. But in general, the idea is this is customer stuff that’s turning on and off. The challenge there is that typically customers don’t want you to be turning on and off their stuff all the time or for very long periods of time. So there are limits on what you can do with flexible loads as a grid operator. And then the third category is energy storage batteries in particular, which are sort of an in-between. They’re great from a customer standpoint because to a certain extent, if a customer has a battery on their property, they don’t necessarily care what that battery is doing most of the time, depending on whether the customer is trying to use that battery in some way to do self-consumption of solar, which they can sometimes earn a lot more or value their solar more highly by doing or if they’re trying to reserve some of the capacity in that battery for backup power. But even in that case, there’s still some portion of the energy stored in a battery system that a customer is probably fine with a grid operator using on a regular basis and they won’t even know the difference. And so storage is a duration limited resource. You can’t dispatch a battery forever. It has a limited amount of energy in it, but it can be used very frequently throughout the year.
Shayle Kann: Okay. So good categorization of all the different kinds of DERs. You and I were both around a decade ago, decade plus ago when there was a lot of hype around DERs at that point. I dunno, it was mostly it was about thermostats, it was maybe a little bit about batteries, kind of early days of batteries. It was about EV chargers, maybe managed charging, stuff like that. It was different technologies, but the hype was very exciting. People talked about decentralizing the electricity system and things like that. And long story short, that’s not what happened at this point. So how would you diagnose, why didn’t it take off?
Andy Lubershane: I think there were really two reasons why DER mania, DER enthusiasm, which I participated in. So again, I’m not trying to insult anyone out there. I think there is two primary reasons why it was too early in the early to mid 2010s, which is when all of that conversation about the utility death spiral and the New York reforming, the energy vision proceeding and all these other extremely optimistic DER forecasts and plans were coming out were too early. The first is primarily that the power system just didn’t need DERs very much. And I wrote about this in the article, but one experience for me stands out when I first started at Energy Impact Partners as an employee, this was back in 2017, we gathered together this group of folks from the utility sector, from our LPs, many of whom were utility engineers working on distribution system problems and people that were specifically tasked with considering distributed energy resources.
And I was super eager and excited to talk to this group at the time about all of the myriad ways that they were considering using distributed energy resources to reduce costs for customers and to solve problems on the grid. And I sort of set out by asking them, where are you all finding the non wires alternatives on your systems? Because if you were a DER fan at that point, non wires alternatives was this very exciting concept where utilities could use things like load flexibility or distributed batteries as an alternative to building out new substation capacity, upgrading, making significant distribution system upgrades that were otherwise very costly. So I asked the group, where are you finding all these non wires alternatives? And I got this extremely disappointing answer, which was basically we’re not finding them maybe one or two here and there, but they’re outliers. And for the most part we’re trying, we’re looking around for where we might be able to use these alternative resources instead of upgrading the grid in a business as usual capacity.
And we’re just not finding them. And I really came to believe that these people were operating very much in good faith, they were looking and they just were not finding them. And that’s in part just because as we know at a macro level, the past 15, 20 years in the power system, we just haven’t seen until very recently much load growth. So there just weren’t that many places on the grid where there was tremendous amount of pressure to upgrade things quickly. It wasn’t all that expensive to make the upgrades that were needed in most cases where they were needed. And so one reason we just didn’t see that much interest in DERs is because we didn’t need them for a long time. And by the way, that’s not just true at the level of the transmission and distribution system. That was true in the generation world as well, where for quite a long time generation capacity markets, supply side capacity markets had plenty of supply. There just wasn’t an incremental need for new capacity in most places. And so why build DERs when you don’t need ’em?
Shayle Kann: Yeah, I think it was like if it ain’t broke, don’t fix it kind of situation actually, which is like there was nothing broke. I think it was actually, maybe the other way to put it is there’s this trope in venture capital, you want to be selling painkillers, not vitamins, right? And I think the early days of distributed energy resources, they were a vitamin. It was like, Hey, isn’t this cool? You leverage a bunch of these distributed resources instead of building a new substation, but actually you could build a new substation, we could build it fast enough on the timeline that was needed. And so it was a vitamin, Hey, neat, maybe this would be a better way. It wasn’t a painkiller at that time.
Andy Lubershane: That’s a great, and actually to take that metaphor a little bit further, they were vitamins that were not fully FDA approved in the sense that they over the counter risks.
Yeah, exactly. Like something I saw on an Instagram ad, I don’t have Instagram anymore by the way, but theoretically one might see it in an Instagram ad. And that gets back to this partial challenge for DERs even today for most classes of DER which we were just talking about, which is, although there are a number of these DERs which really can qualify as distributed capacity resources, they don’t offer exactly the same kind of capacity as utility planners from the generation system to transmission to distribution are used to. So if you need capacity on a particular feeder distribution feeder out at the edge of the grid and you see load growing quickly there and you’re a utility planner, you can upgrade the substation and the transformer and all the other equipment and maybe even the conductor going into that neighborhood. And that solves your problem because it gives you capacity, increased capacity all the time, and you’ve designed sort of perfectly for the capacity you need.
If you add a bunch of storage, you get a dispatchable resource with a limited amount of energy to work with. And so you have to be pretty darn sure. You have to really sharpen your pencil and know that I need capacity for four hours a day or six hours a day at a maximum during these days per year, and I’m never going to have to dispatch the battery and recharge and not have enough time to recharge the battery and then have to dispatch it again right immediately afterwards. So yeah, it’s a vitamin you don’t know very well and unless you really need that vitamin, unless you’re desperation, is one of the reasons people try new things. And I think the system was not desperate enough back then.
Shayle Kann: And then the second point that you make in the article is the other relevant one, which is not only was there not a ton of desperation in the market at the time, but actually a lot of those resources that you might use were also just expensive. I mean, this is particularly, I think that of the category of things that we’ve been talking about, batteries are the one where it’s most different today from 10 years ago, but it was also just an expensive resource.
Andy Lubershane: It was. And some of these resources still are expensive, and I think what the DER optimists or maximalist at the time got wrong was what we got was that the cost of a lot of the hardware to enable distributed energy resources would fall precipitously. Everyone I think listening to this podcast is probably familiar with that story for lithium ion battery cells and battery packs driven down by the EV industry. Everyone’s familiar with that story in the last decade with solar photovoltaics, solar panels. And it’s also true, by the way, of all kinds of other distributed energy resources that were enabled by the so-called internet of things like the cost of setting up a device, making it connected and capable of reaching via the internet became a lot lower and there was lots of experimentation with different types of smart home and smart building devices during that period.
So we got that right. What we didn’t get was that the soft costs of deploying DERs would not fall. And that’s largely the cost of customer acquisition. It’s like getting people, getting customers, whether they’re homeowners or businesses to sign up to put something on their property or to sign up for a load flexibility that was pretty stubborn. That still is pretty stubborn unfortunately. And then also the installation costs. And when you’re shrinking down a large scale battery system and putting it into a box that has to be interconnected into a homeowner’s, a homeowner’s circuit breaker, and you put all the safety switches in place and you get a skilled labor out on site to make that happen, it adds a lot of cost. And so even during this period as battery prices plummeted, we didn’t really see the same thing happen with the cost of a fully installed residential battery system. And in fact, there’s some evidence now just in the past few years that that’s finally starting to budge. But it really has been a past two to three years phenomenon where we’ve started to see, especially for batteries, the cost of systems start to really come down a bit.
Shayle Kann: Okay, so this is getting to the, I guess the crux of the thing we want to speculate a little bit about here, which is I think people are smart enough to, here are the two things that we said we’re holding the market back, which is that the market didn’t really need these resources and that the resources were expensive and they can extrapolate to today when the market definitely needs this and prices, at least for some things, batteries especially are significantly lower. And so the thesis of your piece I think is maybe the time is right now, and actually this was a real thing, but it was 10 years too early or whatever it was. Am I framing sort of how you think about it, right?
Andy Lubershane: Yeah, that’s exactly right. I’m pretty darn confident that the time is now of the two big blockers from 10 years ago. I think one of them is completely flipped on its head, which is the power grid didn’t need DERs that much in 2015. Now it desperately does. And you and I have talked about all of the reasons for that on this podcast before. There’s this electricity gauntlet metaphor that we’ve been using at EIP for the past few years to describe the state of the market. We don’t have to be labor here, but every part of the system has major bottlenecks now. So if I convened that same group of utility engineers from 2017, if I convened them again today and said, are you seeing places hotspots on your network where there’s load growth that’s going to be very difficult to meet and extremely expensive to build out and upgrade a distribution feeder?
I have zero doubt that the answer would be very different today. So that’s changed a lot. I think it’s still more of an open question whether and how much we can really move the cost of deploying various classes of DERs down. That’s the piece that, like I said, we’re starting to see budge in some ways, but it has been more stubborn over the years. And so the hope at this point is that there is a positive cycle of reinforcement in that the need for DERs will drive more programmatic deployment of DERs by various types of grid operators, which will start to reach economies of scale and drive down the cost. And I am encouraged that we’re starting to see some significant use of DERs as capacity resources start to scale, which gets us to this other three letter acronym of Virtual Power Plant or VPP where there are real VPPs now hundreds of megawatts in scale that are being dispatched to actually make a difference on the grid in some places. And so I, I hope that we see economies of scale starting to create a positive feedback loop for DER deployment.
Shayle Kann: Just to play devil’s advocate for a minute, well first lemme say where I’m not going to play devil’s advocate, which is actually I think I don’t care about the cost as much because whether or not the costs come down significantly from here, it’s all about comparative cost and the cost of the comparison is going up. So if you’re just thinking about this as capacity, well, the cost of capacity has clearly gone up, procuring any other type of capacity is more expensive than it was before. We’ve talked before on this podcast about the cost of natural gas turbines, which has been rising, but the cost of retail electricity, which is what a lot of these resources get compared against from a customer perspective is going up. So I actually don’t worry that much about the cost. It matters of course, but that to me is not the bigger question here.
The bigger question for me actually is your first thing about, well, it’s proven that the market needs it and so it’s going to happen. And where so many different technologies and categories have hit a brick wall in electricity historically is where people assume that just because the thing is better or even needed it will happen. But instead everything moves too slowly and is driven by these esoteric state level regulations and utility programs that take forever to be introduced and they’re introduced but that they’re too small or they have rules that are hard to meet or whatever. So I mean, you just said the thing that is the counterpoint in my mind, which is we have actual VPPs being dispatched now in the hundreds of megawatts, hundreds of megawatts. That’s great. I’m very excited about that. It is so little compared to the scale of the problem that we’re talking about here. And so the question is, are we betting that those hundreds of megawatts we’ve hit an inflection point and that now the curve is going to bend upward and hundreds of megawatts turns into gigawatts and tens of gigawatts in the next few years, two, three years? Is that a thing that can happen given the market construct?
Andy Lubershane: To your point, one of my weaknesses is that I have an economics training, and I do tend to think like an economist, which means I tend to assume people make rational decisions and systems, economic systems make rational decisions. And so it’s a good point that there’s a lot of friction in between where we are today and having really meaningful gigawatts of DER distributed capacity resources deployed out there. And to a certain extent, my optimism today is more of a bet that the need is so great that the economic fundamentals will in this case finally win out and be able to overcome those frictions. And we’re starting to see again more, this is sort of another data point of the need, but I think it also speaks to the increasing comfort of system operators using these resources. So one of the things that actually prompted me to write this article was seeing a post from Dana Guernsey, and apologies Dana if I’m not pronouncing your last name correctly, but she’s the CEO of Volti, which is a big demand response aggregator.
And she posted this chart on LinkedIn, which really caught my attention. We passed it around a bunch of us at EIP and it’s basically showing how many times per year volt’s demand response resources are actually dispatched by grid operators. So not the resources they have signed up to turn down when someone calls on them, but the number of times they actually do. And that in the last two years has been kind of escalating off the charts. I mean, it seems to be going exponential in 2025. And again, you could take that as just a signal, oh crap, grid operators really truly need these resources now, and it is a signal of that. And so if you’re finally actually using these resources, you’re probably going to want to go find more of them. But I also think it speaks to the comfort that grid operators are having with DERs as an actual solution to their problems because it’s not theoretical anymore.
And so I’m not going to say I’m confident that we’re getting to, every utility has a gigawatt DER program, but could every utility, every major utility in the country within five years have a several hundred megawatt DER program instead of it just being a few that have a several hundred megawatt DER program. And in a few places where you have a little bit more maturity in the market and more need, you could scale the gigawatt plus that seems reasonable to me. So I don’t think this is going to replace all the gas power plants that we are building right now. This doesn’t stave off the need for all the other types of resources that we’re considering for addressing the gauntlet, but I think it makes a dent and it makes a meaningful dent hopefully for the next five years
Shayle Kann: For what it’s worth. I actually do agree with you, but I think it’s important for us always to look the challenges of rapid evolution of the electricity market in the face because it does happen, but it’s pretty rare that it happens rapidly because again, something needs to happen again in regulated markets, right? It’s different things in ercot are just going to happen, but in regulated markets, something needs to happen and then proliferate pretty quickly through lots of other territories and jurisdictions and so on. So that is a challenge, but as it starts to be, there is some tipping point that one can imagine we hit.
Andy Lubershane: I think that’s right. Yeah. And it’s going to happen at different paces for different types of resources. So while we’ve talked a bunch about batteries and I am, my long-term view on batteries is about as bullish as it gets in homes and businesses and vehicles, in all kinds of other things in the near term, in a three to five year timeframe, I’m probably more optimistic about really expanding demand response. So demand response across the country has kind of been flat to even declining slightly over the past decade, which is sad and it really shouldn’t be that way. There’s definitely more latent demand response potential out there. It’s around 2025 gigawatts. Now, could we double that? That seems completely doable from commercial.
Shayle Kann: Can you draw the distinction between, I’m not sure people always understand, what is the distinction between just expanding demand response versus this concept of a virtual power plant?
Andy Lubershane: Yeah, I mean it’s partially because many people, myself included, just casually use demand response as a stand-in for commercial larger scale facility facilities offering up flexible load. And in practice you can have a virtual power plant, which is just an aggregation of resources that provides push button control of some kind to the grid operator commercial and industrial facilities that have agreed to a demand response program can be a part of a virtual power plant. Usually though the connotation, this is all connotations because there’s no strict definitions here, but the connotation of VPPI find tends to be smaller aggregations of more smaller resources and oftentimes including newer stuff like batteries basically, but a big demand response program kind of, it is a virtual power plant of sorts. And I think partly the reason the demand response had a connotation as being sort of separate is because historically those resources have really not been called on very much.
I mean, if you’re a grid operator and you have a button that says demand response, but when you use this, you’re probably going to frustrate some customers. And yes, they signed up but they signed up to be called on only 10 times a year for up to eight hours at a time or something along those lines. You’re going to be pretty hesitant about pushing that button. And I think what really makes the demand response market grow is enrolling customers with more automation, a little bit more sophistication around how resources are dispatched so that they can with less impact on customers, actually be dispatched more often. So in one of our portfolio companies at EIP is a company called Grid Beyond that’s really mastered doing that kind of next level of demand response with industrial consumers where they really look at a facility holistically and think, how can we ring the most megawatts out of that facility with the least impact on operations? And I think there’s definitely more of that to be done. VPP call it demand response, but there’s more of that resource out there.
Shayle Kann: Okay, so I’m going to wrap up by asking you to describe two scenarios for me. Five years from now, first scenario it goes right, and this DERs finally take off and start to reach the promise land and they solve a meaningful portion of the gauntlet problem. What does that look like? How do we get there?
Andy Lubershane: To your point, I think we need to start soon because these things take time and they don’t take time because of DER deployment. By the way, that can happen very quickly. That’s one of the advantages of many classes of distributed energy resources, whether it’s a natural gas gen set or whether it’s a residential battery. You can go out there and put a bunch of them out there very rapidly and that can scale up to hundreds of megawatts very quickly, particularly compared to the bottlenecks in large scale resources we’re seeing today. But it’s the programmatic side of things like whatever entity is running the procurement or the program, let’s start with the utilities who sit in the middle of all of this. They need to start ramping up their programs today if we want to have meaningful the kind of meaningful resources deployed within five years that you’re talking about.
So I think what we would need to see is lots of utilities saying, look, we need capacity today. It really truly is an all of the above strategy today, and we are going to set up a crack team to go figure out how we get distributed energy resource capacity most efficiently, and we’re going to set a goal and it’s going to be a reasonable goal, but we’re going to include that in our plan, in our integrated resource plan. So this is not some little program sitting aside that a regulator has told us we have to do. This is something we’re actually counting on to provide capacity when and where we need it. And I think I in my world, am starting to see signs of movement towards that. Although these things do take time, but if you start doing that today, I can imagine a world where within two to three years there’s a bunch of those programs standing up and like I said, once you have the signal, the DERs can be deployed very quickly. That’s the bull case.
Shayle Kann: Okay. So now on the flip side, right, that’s the bull case. On the flip side then describe to me the bear case, what happens to lead this to just be another kind of floundering effort to really scale up. And I guess that would be something other than
Andy Lubershane: Just the opposite of what I just said.
Shayle Kann: It’s the opposite of that. Yeah.
Shayle Kann: Like what goes wrong here?
Andy Lubershane: Yeah, I mean in addition to that, there’s a bunch of pretty glaring risks. If we’re talking about batteries, then supply chain is a pretty big risk. And FEOC restrictions on applying for the ITC.
Shayle Kann: Fire code, one could add.
Andy Lubershane: What’s that? Fire code potentially fire.
Shayle Kann: Fire code.
Andy Lubershane: So far that’s not been a problem for residential batteries. It has been in larger commercial buildings and dense cities. In some cases I’m less worried about that. But batteries are just not falling in price. Batteries continuing to be really expensive is the real challenge. Batteries do need to get cheaper, not the cells. Those have gotten really cheap, but the full systems need to get cheaper. If they’re going to be really cost effective resources, that probably means some portion of the battery, like the cells — at least for a while longer — is coming from China. I guess the other one is, this is somewhat related to programmatic approaches to deploy them not moving fast enough but continued hesitancy on using resources that do have some limitations because utility planners, they are inherently always going to prefer a 100% solution.
That’s how we’ve built the grid in the past and nobody gets fired for putting in place a 100% solution that is going to work every day for all of the hours of the day all the time. If you’re going to put in a solution that’s not 100%, that has some capacity utilization limitations like a battery or most load flexibility and even some gen sets, because for the most part, you’re not going to run a natural gas gen set indefinitely truly for the entire year. You need to really plan for it much more carefully because you need to make sure that if you have a four hour battery or six hour battery, you really have enough juice to get through the peaks when you need them. So in addition, utilities really need to plan for these resources very carefully and accept that they– they’re going to get a hundred percent solution for their actual problem, not for all problems that could potentially arise. That’s tough. That’s legitimately, I understand fully why that’s not their go-to and why that requires a mental shift and they historically have not been incentivized to do it.
Shayle Kann: Alright, Andy, fun as always. Sure. We’ll do it again as soon as you intuit what is already on my mind and write another article. It’ll happen two weeks from now or something.
Andy Lubershane: Always a great time. And it’s fun to be plotting with another longtime DER believer,
Shayle Kann: Andy Lubershane is a partner at EIP with me and our head of research. This show is a production of Latitude Media. You can head over to latitude media.com for links to today’s topics. Latitude is supported by Prelude Ventures. This episode was produced by Daniel Woldorff. Mixing and theme song by Sean Marquand. Stephen Lacey is our executive editor. I’m Shayle Kann and this is Catalyst.
