Permits - What I really need to know today
over the weekend I did a lot of digging on what can derail the project if anything. See below, yes I used AI, but the content is sill important
NUAI & the Texas Grid Regulatory Maze — What's Actually Going On Before Tonight's Call
Most of the NUAI discussion online focuses on the money — the Macquarie facility, the Stream LOI, whether the hyperscaler lease gets signed. That stuff matters, so here's the quick version: NUAI closed a $290M senior secured credit facility with Macquarie in April, alongside a ~$115M equity raise. Only $20M of that Macquarie facility is actually committed right now — the rest draws down against project milestones. They also still carry a going concern flag from Q1, though the April capital raise materially improved that picture. The JV with Stream Data Centers and the hyperscaler lease are both still at LOI stage, not signed contracts.
On the hyperscaler specifically — there's a strong reason to think one is already quietly in the tent. The Macquarie loan documentation contains a defined term for a "Letter of Intent Party" that must be a U.S.-based investment-grade hyperscaler, and a closing condition on the loan required an executed copy of that LOI with a JV term sheet attached. In other words, Macquarie wouldn't have funded without it. NUAI hasn't named the counterparty publicly, but the structure of the financing essentially confirms something is signed. The open question isn't really whether there's a hyperscaler — it's whether that LOI converts to a definitive lease, and on what timeline.
That timeline is almost entirely a function of regulatory progress. Which is where the real story is.
First: Why Texas Rewrote the Rules
Texas has its own grid — ERCOT — that operates almost entirely within state lines, which means it sits outside federal (FERC) jurisdiction. Washington's rules don't apply here. Austin does.
For years ERCOT had a fairly simple process for connecting large power users to the grid. Then AI happened. Data centers, crypto miners and hyperscalers started flooding the queue with interconnection requests. By early 2026, ERCOT had roughly 380,000 MW of pending large-load requests — nearly quadrupling in a single year, with over 70% coming from data centers alone. To put that in perspective, the entire Texas grid's all-time peak demand record is about 85,000 MW. The queue is now 4x that. Obviously most of it is speculative and won't materialize, but ERCOT had no tools to separate the serious projects from the paper ones. Every request had to be studied individually, creating what ERCOT's own VP called a "study doom loop" — constant restudies as projects changed or dropped out, grinding the whole system to a halt.
Texas responded with Senate Bill 6, signed into law in June 2025. It's the most significant overhaul of large-load grid access in Texas history. The PUCT (Public Utility Commission of Texas) is now implementing it through multiple active rulemakings, with a final deadline of December 2026 to complete them all.
What SB6 Actually Does — The Rules That Apply to NUAI
Any new customer wanting to pull 75 MW or more from the ERCOT grid now faces a completely different process. Here's what it looks like:
$50,000 per megawatt upfront. Before ERCOT will even begin studying your interconnection request, you post financial security at $50K/MW. For NUAI's Phase 1 at ~200 MW, that's $10 million sitting with ERCOT before a single study result comes back. This was specifically designed to kill the speculative queue positions — underfunded developers simply can't afford to hold multiple slots anymore. The original draft rule had this at $100K/MW; it was reduced to $50K after intense lobbying from large-load customers.
You must actually control the land. You need a deed, a signed purchase option, or a signed lease with a minimum term of five years beyond your planned energization date. No more queue-camping on land you don't control.
No gaming multiple positions. You have to disclose if you're pursuing a substantially similar interconnection request elsewhere in Texas. If approving one would cause you to walk away from the other, you have to say so upfront. This killed the hyperscaler strategy of holding five positions and picking whichever came through first.
30 days to execute once ERCOT finishes your study. Miss the window, your request is cancelled automatically.
Withdraw after signing and you forfeit. If you pull out after executing an Interconnection Agreement, your financial security gets drawn down. Whatever's left splits 20% back to you, 80% applied to transmission costs. The further along you are, the more you lose.
These rules are being finalized under PUCT Project No. 58481, with comments having closed in April 2026. Final rule adoption is expected throughout the rest of 2026.
NUAI's Specific Situation: Two Different Regulatory Tracks
NUAI's TCDC campus in Ector County (outside Odessa, West Texas) has two phases with two very different regulatory paths.
Phase 1 (~200 MW, grid-connected): This goes through the standard SB6/§25.194 large-load interconnection process described above. ERCOT study, financial security posted, the works. It also enters the new Batch Zero process (more on that below). This is the more established path and the one most directly relevant to signing a hyperscaler lease — because a tenant needs power certainty before they'll commit.
Phase 2 (~450 MW, behind-the-meter): This is NUAI's differentiating bet. Rather than pulling power from the grid, they plan to generate power on-site — natural gas turbines co-located with the data center campus — and sell/supply it directly to the tenant without the electricity flowing through the grid in the traditional sense. This is called a "behind-the-meter" or co-location arrangement.
The BTM path has an additional regulatory layer that Phase 1 doesn't. Under SB6:
- ERCOT must conduct a system impact study (120 days from when you file notice)
- The PUCT Commission itself — not just ERCOT staff — must formally approve the BTM arrangement
The rules governing exactly how this approval works are still being written. They won't be finalized until late 2026. And there's only one real-world test case underway right now — a Crusoe-Google campus in Texas is the first BTM arrangement to go through this process. How PUCT rules on that will set the precedent for every subsequent BTM project, including NUAI's.
So Phase 2 is genuinely gated on regulatory process that doesn't fully exist yet.
The Batch Zero Vote — What's Happening This Week
On top of the SB6 rulemaking, ERCOT is simultaneously redesigning its entire interconnection study process. The new framework is called Batch Zero, formalized through Planning Guide Revision Request 145 (PGRR145) filed March 4, 2026.
The old system studied each large-load request individually, one at a time. That process broke completely under the weight of 380,000 MW of requests. Batch Zero groups qualifying projects into a single system-wide study, allocating available transmission capacity across the whole cohort at once. It's more efficient, but it also means your project competes for capacity against every other project in the batch simultaneously.
The governance timeline for approving Batch Zero is:
- May 6 — Protocols Revision Subcommittee vote ✓
- May 7 — Reliability and Operations Subcommittee vote ✓
- May 19-20 — Technical Advisory Committee vote (this week)
- June 1 — ERCOT Board vote
- July 10 — Target effective date
- July 15 — Hard deadline to qualify for Batch Zero treatment
That July 15 deadline is crucial. Projects that want to be included in the first Batch Zero study need to have met certain eligibility milestones by then — including having filed their interconnection request and posted financial security. Projects that miss July 15 go into a later batch, adding months or more to their timeline.
There's also a "safe harbor" for legacy projects: anything that completed prior ERCOT study milestones before March 4, 2026 gets some protection and won't automatically have to restart under the new rules. Projects filing after March 4 are fully subject to Batch Zero.
One more wrinkle specifically relevant to NUAI's location: ERCOT issued a notice earlier this year flagging that Far West Texas (which includes Ector County) has specific transmission constraints. Any interconnection study in that region must now include a "no-solar" scenario, and some previously approved studies had to be redone. West Texas has a lot of solar and wind generation, but transmission capacity out of the region to major load centers is limited. ERCOT is essentially signaling that connecting large new loads in that area requires extra scrutiny.
The Question Nobody Has Clearly Answered
Here's where it gets uncomfortable. Back in October 2025, NUAI's own press releases listed "submitting a large-load interconnection application" as a near-term milestone — meaning it hadn't been filed yet at that point. The securities class action lawsuit filed against the company in early 2026 is specifically built around allegations that NUAI overstated permitting and regulatory progress — a research firm claimed to find no permit applications in any Texas, New Mexico, or federal database as of December 2025.
Since then, NUAI has raised real capital, secured real partnerships, and bought real land. The company looks materially more credible than it did six months ago. But the specific question of whether a formal ERCOT interconnection application has actually been filed — with the financial security posted — has not been clearly answered in any public filing or press release.
This matters enormously because:
- Without it, there is no regulatory clock running
- Without it, no Batch Zero eligibility by July 15
- Without it, a hyperscaler can't get real power delivery certainty
- And with the lawsuit in the background, it's exactly the kind of thing management needs to address head-on
What to Listen For on Tonight's Call
If you're following this situation, here are the specific questions that will tell you whether the regulatory story is real or still aspirational:
1. Has a formal ERCOT large-load interconnection application been filed for Phase 1? And if so, when — before or after March 4, 2026? That date determines whether they get legacy protection or go through Batch Zero fresh.
2. Has the financial security deposit been posted? For 200 MW that's $10 million minimum sitting with ERCOT. A yes here signals genuine commitment, not just planning.
3. Has the BTM co-location notice been filed with ERCOT for Phase 2? That filing starts the 120-day study clock. If it hasn't been filed, Phase 2 power is years away at minimum.
4. Any update on the Crusoe-Google BTM precedent? That case is winding through PUCT right now. Its outcome shapes how NUAI's own BTM approval will be evaluated.
5. What's the Industrial District designation status? NUAI has mentioned this as a near-term milestone. An Industrial District designation in Texas can affect how local taxes and utility obligations apply to a large campus — it's a real permitting step, not just a press release item.
If management gives clear, specific answers to the first three questions tonight, the regulatory story gets considerably cleaner. Vague references to "advancing workstreams" and "progressing permitting" without specifics would be a continuation of exactly what the lawsuit is about.
