There are 410 gigawatts of large-load interconnection requests sitting in ERCOT's queue right now. To put that in perspective, the all-time peak demand ever recorded on the Texas grid was 85.5 gigawatts. The queue is now nearly five times that figure, and it grew by 198 gigawatts in a single quarter.

Numbers like these signal demand. What they do not signal, and what they are increasingly being mistaken for, is supply. The queue is not a list of projects that will get built. It is a list of projects that submitted load requests. For buyers trying to place AI, cloud, or HPC capacity in Texas, the relevant question is no longer how many megawatts are announced. It is how many are real, and by what measure.

The gap between paper megawatts and deliverable power

Announced capacity and deliverable capacity are two different things, and the distance between them is growing. Industry observers have noted that a significant share of projects in interconnection queues will never materialize, as developers face challenges such as transmission infrastructure that does not yet exist, regulatory delays or financing hurdles. This is not a reflection on any developer's intentions. It is a function of how the grid actually sequences, and how physical timelines do not bend to capital commitments alone.

Voltage level is not a technical detail. It is a timeline

One of the most underappreciated variables in evaluating a project's deliverability is the voltage level at which it connects to the grid, and what that implies about the infrastructure required.

High-voltage transmission projects and substantial grid enhancements frequently necessitate extensive processes for environmental review, right-of-way acquisition, permitting, and construction that routinely run seven to ten years from initiation to energization.

A project that requires new transmission to be built in order to be served is, in practical terms, tethered to that timeline regardless of how quickly the building itself can be constructed.

Projects that connect into existing, committed transmission capacity move dramatically faster. The infrastructure is already there. The question is whether the project has a genuine, documented path into it.

The 765kV dependency chain

Texas is building its first extra-high-voltage backbone, a 765kV system endorsed by ERCOT's Board in December 2025 and approved by PUCT. It is a major forward-looking investment. It is also a project with an in-service window of 2030 to 2032.

A meaningful portion of the transmission capacity that appears available in the 345kV and 138kV layers of the Texas grid today is contingent on that 765kV backbone coming online on schedule. The system is designed to relieve congestion and unlock transfer capacity in the lower voltage layers beneath it. If it is delayed or resized, projects that depend on the capacity it unlocks are affected alongside it.

This is how cascading transmission planning works. A project that shows available transmission headroom today but whose energization path runs through congestion relief requiring a 2030 infrastructure project has a 2030 dependency embedded in it.

The question for buyers is simple: does this project connect into transmission infrastructure that exists and is committed today, or does it rely on infrastructure that is planned but not yet operational? And what happens if challenges such as land rights for transmission partners take far longer than initially envisioned, as has occurred in many similar projects across the US?

Batch zero changes the filter

On March 4, 2026, ERCOT filed PGRR145, introducing the Batch Zero framework for large-load interconnection. Under it, projects must submit technical models, commissioning plans, and non-refundable fees of $100,000 per megawatt of contracted peak demand. Capacity allocations cover the 2028 to 2032 window, meaning even projects that clear the process face a meaningful queue before energization is authorized.

Projects with utility paths committed before Batch Zero are not waiting on those results. They are not competing for capacity allocations in a multi-year study window. That distinction matters when a buyer's timeline does not have the luxury of waiting until the end of the decade. For developers with projects across the size spectrum, including larger-scale projects that will go through Batch Zero alongside everyone else, understanding both paths from the inside changes how you structure commitments to customers.

Equipment is the hidden variable

Even projects with committed grid paths face a second constraint that is often underweighted: equipment.

Transformer lead times have stretched beyond 160 weeks and high-power units can run to five years. Medium voltage switchgear runs 40 to 60 weeks or longer. A building can be structurally complete and ready. Without the electrical and mechanical equipment onsite, it cannot be energized. Procurement is not a downstream task. It is a parallel-path activity that must begin early and stay coordinated with the energization schedule.

What ‘real’ looks like

For buyers evaluating Texas options, the questions worth asking are straightforward. Is the utility path committed and documented? Does the interconnection agreement require new transmission to be built? Is the project dependent on infrastructure with a 2030 or later in-service date and what occurs if that project sees delays? Is equipment procurement underway and sequenced to the energization schedule?

Projects where all of those answers point in the right direction are fewer than the queue suggests.

At Blueprint, select capacity remains available for pre-lease across our Taylor and Georgetown campuses, with committed utility paths, defined energization schedules, and procurement already in motion. If you are working through power diligence on Texas options or simply want a framework for evaluating how any site stacks up, we are happy to have that conversation.