Welcome back to The Pexapark Podcast! In this episode, before we go deep into the dynamics of the Texas energy market, we start with an edit of key developments in European renewables. Topics include early takeaways from the Spanish blackout, the latest from Italy’s MACSE auction and possible strategy decisions by players, and Germany’s proposes bidding zone split. We also dive into the increasingly notable trend of rising balancing costs, the price divergence in the Nordics and more.
In the second part of the episode, Ian Niebor – Head of Energy Transition Research at Enverus, offers a deep dive into what makes ERCOT one of the most vibrant and complex energy ecosystems globally, citing its diversity of resources, policy landscape, and rapid infrastructure development. On the supply side, the discussion highlights continued growth in solar, storage, and selective gas capacity additions, tempered by policy fragmentation and limited coordination mechanisms.
Listen now:
Episode breakdown:
- 00:00 – Intro
- 01:06 – Regulation
- 05:47 – Deals & Prices
- 12:30 – Interview with Seb Kenedy
Key Takeaways
- ERCOT Load Forecasts Are Likely Overstated
Enverus projects a more conservative load outlook (~100 GW by 2030), significantly below ISO forecasts inflated by speculative data center and hydrogen projects. - Battery Storage Is Now Inseparable from Solar Growth
The days of standalone solar are ending — storage is increasingly deployed in lockstep, driven by both economics and grid reliability needs. - Policy and Market Signals Remain Misaligned
Despite legislative activity like the 1:1 gas backup rule, actual gas buildout is limited. Lack of clear coordination mechanisms could slow the energy transition. - Tariffs Raise Costs but Support U.S. Manufacturing
While tariffs increase renewable project costs, they also strengthen the case for domestic supply chains when combined with IRA incentives.
Interview Transcript
Host: Luca Pedretti (LP)
Guest: Ian Niebuhr (IN), Head of Energy Transition Research, Enverus
LP:
Now welcome to the second part of the Pexapark Podcast, where we always have a guest, and today I’m very happy to have Ian Niebuhr with us from Enverus. We’re going to talk about the Texas energy market, which is a phenomenon with global interest — not just from Texas clients, but something is happening here that’s showing where things could go. Ian, welcome to the show.
IN:
Thank you for having me. Excited to be here.
LP:
Maybe first to start with — who are you? What are you doing at Enverus, and who is Enverus?
IN:
Oh, geez, that’s a great question. So, I’ll start with myself. My name is Ian Niebuhr. I’ve been part of the Enverus family for just about 13 years. Today, I head up our Energy Transition Research team.
That team looks at everything from power and renewables all the way through clean energy, clean molecules, carbon capture and storage, etc. I’ve spent the last three or four years building that business up. Before that, I covered energy markets across oil and gas, global macro, etc.
Enverus, at its core, is a software and intelligence business. We provide the core analytics that allow decision-makers across the energy space to make better decisions. That could be software solutions, raw analytics, or more of an advisory or consultant-type relationship with teams like mine.
LP:
Yeah, and you’re a huge company. Just remind me — how many clients do you have? It’s a huge shop.
IN:
I think today we’re more than 8,000 logos across the globe. So it’s a pretty incredible, complete footprint across the energy space.
LP:
Yeah, and the news is out — very recent: Pexapark data will be accessible to Enverus clients as of now. So we’re very happy about that.
And now, without further ado, let’s talk Texas energy. I’m fascinated by Texas energy because it’s the biggest, most vibrant PPA market in the U.S. — maybe in the world (gonna be challenged on that). What is it for you, Ian?
IN:
I would just extend that definition to one of the most interesting, complete, vibrant energy markets in the world. Whether it’s looking at the molecule side, the electron side, or the diversity of technologies being applied — so many of the really interesting, innovative, leading examples of what’s going on in the world and where we might be going are happening in Texas.
Of course, there are analogies elsewhere. But for me, it’s one of my favorite petri dishes to look at — and obviously an important market.
LP:
And why Texas? What are the drivers behind this energy boom we’ve seen over the last decade?
IN:
You can point to a couple things: endowments, incredible resources — wind, solar, people, subsurface pore space, access to tidewater, diversity of industry and talent, and depth of that talent. It really does have this incredible ecosystem — infrastructure, capital, tools — it’s got it all.
LP:
It goes so fast. I was just looking at the battery build-out. When you look at pre-Uri and now, it’s a factor of 10, even more, in deployment — gigawatts per year.
IN:
Yeah, I think that speed is a great feature too. The ability to adopt stuff at scale when there’s a tipping point — batteries are a great example. You look at what’s happened in shale for oil and gas — that’s incredible. There’s example after example where Texas is one of those great ecosystems to scale and accelerate development, which makes it fun for us to look at.
LP:
Indeed. Now, one of the bigger questions we’re all encountering here: how big is the load forecast going to be?
IN:
That keeps us really busy. There’s been a recent update — and again, an update — and the figures are quite staggering. I mean, we had 208 GW in the last forecast. Now that’s been adjusted to 129 GW. That’s always speaking of 2030, and today we’re at around 80 GW. That’s a huge question for everyone exposed to the market.
LP:
How do you see the recent load forecast in ERCOT?
IN:
We do a lot of our own bottom-up load forecasting that contrasts with what we see from the ISO. I’d say we’re at the lower end — even below what the most recent update is, with some vagaries.
What’s really interesting is this “fog of war” — what’s real, what’s not — and the series of incentives that exist to put lots of ideas into those queues. I feel for folks trying to distill what’s real. For our clients, that’s a big conversation — how to position for growth, but at what scale, from what sources, and at what locations.
LP:
So what’s your best pick for load forecast in ERCOT in five years?
IN:
I’ll pick on the data center one, because I think that’s the piece that catches most eyes. There’s almost 120 GW of data centers put in the queue by 2030. Our numbers? Less than 10 GW realized in that time frame — massive divergence.
You get some confusion in areas like hydrogen too — real project proponents, but the realities of capital deployment are different. If those upper-end forecasts play out, what does that mean for prices, and for the viability of other sources like hydrogen?
So long story short — we’re pretty far down that curve. But the envelope of uncertainty is very wide, especially with the data center wedge.
LP:
What would be your lower-end number?
IN:
We’re in the low 100s — quite a bit below the ISO’s risk-adjusted forecast.
LP:
I just had a call with traders — they would also be saying 100–110 GW, which is 20 GW off the recently adjusted forecast.
IN:
That’s much more in line with what we’re thinking. But obviously, there are a variety of views in market.
LP:
Some peculiarities too — for example, 7 GW of crypto. Is this really peak load? I mean, they can turn off…
IN:
That’s a great call. We interpret it as flexible load — not likely to show up at peak pricing. Some of those sites are transitioning to “data center”-type loads. So while they’re coded as crypto, they might eventually behave like data centers. But true crypto? More likely to raise the troughs than the peaks.
LP:
Interesting. And hydrogen? Also 7–8 GW on paper, but…
IN:
We’re very bearish. Not zero, but low single digits. Green hydrogen gets punished in a high-cost energy environment. Hydrogen derivative markets are nascent and require policy support from places like Japan or Europe.
So, we’re leery of hydrogen realizing at scale in that time frame.
LP:
So it boils down to: how many data centers do we actually get?
IN:
Exactly. It’s fun to track. These are 200–400 MW projects — highly visible. We track them closely — inventory, land ownership. For instance, hyperscalers have likely secured land for 115–120 GW of capacity.
But that’s a decade of development, even if it all materializes. You still need permits, water, power…
LP:
Rounding up the load forecast: what I haven’t really seen is demand flexibility. I see potential here in Texas — especially in the household sector. What’s happening there?
IN:
Good question. There’s definitely opportunity. But behavior is hard to change — it’s always freezing in Texas conference rooms.
We’ve seen studies — Duke’s, and our own — that show just shaving a bit of peak demand (especially in large loads like data centers) would significantly increase grid capacity. Innovation and incentives are coming, but behavior change is tough.
LP:
Let’s switch to the supply side. There’s so much going on. I was surprised by the legislative action on the state level — a lot of bills and incentives. There’s this famous 1-to-1 rule requiring all new renewables to have gas backup. What’s your take?
IN:
Two sides: policy and actual market behavior. There are many emerging challenges and ideas to solve them — it’s a race to see what gains traction.
In terms of what’s in the queue: solar, batteries, a bit of wind. With the Texas Energy Fund (TEF), there’s effort to get more gas, but uptake hasn’t been as aggressive as hoped.
So short term: more of the same — solar, batteries. Market signals will need to draw in other assets, but today, we don’t see a ton.
LP:
If we need 40 GW but TEF gives us 8–10 GW over 5 years, how does the rest add up?
IN:
Depends on how load evolves. With more renewables and batteries, and gas as last-resort capacity (peak only), you might make it work.
You wouldn’t burn more gas, just have more capacity available. But if the high-load forecasts come true, you’ll need a lot more supply, and we don’t yet know where that will come from.
LP:
So you’d expect renewables to continue despite the legislative onslaught?
IN:
Yes, in the short run — partly because there’s no alternative. You can’t easily build new gas. Coal is tough. Nuclear, even more. Population growth alone will push Texas load up. If we get that boom, choices will be limited.
LP:
Even bringing old coal back online gives us only 5–7 GW — not enough.
IN:
Exactly. It’s a self-fulfilling pressure. Higher load leads to higher prices, which tempers demand. Markets may creatively solve this — via demand response, industrials adding self-supply, rooftop solar…
LP:
Yes, it’s messy. But large projects move slowly, and prices react quickly.
I’m curious about storage. Whatever happens on solar/gas/coal — storage seems primed for growth. Do you see anything that could check that growth?
IN:
Not really. Storage goes hand-in-hand with solar. The days of solar without storage are largely behind us. Whether co-located or not, it’s growing in lockstep.
With some gas in the mix, the grid can work — but you need both.
LP:
Yes, wind, solar, storage, and gas (not combined cycle, but flexible gas). But some form of coordination is needed.
IN:
Exactly — and that’s a hot topic. Capacity markets are very controversial in ERCOT. But eventually, some mechanism (market or bilateral) will emerge to compensate those resources.
Retail consumers, though, aren’t active market participants — which adds to the policy debate.
LP:
Speaking of price signals — we need to talk tariffs. Even after the May 9 announcement (we’re recording today), tariffs on China remain impactful. How do you see this playing out for renewables?
IN:
One way or another, we see cost structures rising. But combining IRA domestic adders and tariffs actually reinforces domestic manufacturing.
That means higher costs, yes — but possibly more domestic panels. The balance of economics still favors domestic in the short run. But this all leads to a step-change in costs for solar and storage.
LP:
Higher costs, but not a massive change in the technology mix?
IN:
Correct.
LP:
To sum up: demand side — forecasts in the low 100s GW. Supply side — continued deployments of solar, wind, storage, a bit of gas. But it’s messy — no clear policy consensus. Fair summary?
IN:
Yes. And maybe that’s a feature, not a bug — an open market design creates real signals. It may be painful, but also effective.
LP:
Yes, price signals are great — but there’s a limit, especially from a consumer policy standpoint.
IN:
Right — there’s real pressure, and real value. Hopefully that leads to creative compensation. The question is what that pathway looks like — especially for retail customers who don’t shape the market directly.
LP:
That was a fascinating walk through ERCOT — from demand to supply and beyond. We’ll be watching closely. Thanks a lot for coming on the show.
IN:
Thank you so much for having me.