Evidence update · October 27, 2026. This article was first published July 22, 2026. Some queue figures below have since been superseded or used too broadly. Berkeley Lab's 2026 queue report, published in June and covering year-end 2025, counted over 2,060 GW of generation and storage capacity actively seeking transmission interconnection (1,312 GW generation and about 749 GW storage). That total does not include large-load requests and is not a forecast of projects that will be built. ERCOT's June 1 board report counted about 438 GW of large-load requests in the process then in effect, which ended July 10. On August 3, the Texas Governor's audit directive cited about 474 GW of requests, approximately 90% associated with data centers. These are differently dated snapshots under changing processes; requests are not approved, energized, or guaranteed to proceed. On September 21, the Governor directed TCEQ to pause permits for infrastructure directly supporting data centers pending ERCOT's audit. The order set an October 19 reporting deadline. The latest public account found says TCEQ paused those air and water permits and ERCOT expected to complete its audit in December; no completion result was found through October 27. Berkeley Lab · ERCOT, June 1 · Texas Governor, August 3 · Texas Governor, September 21 · Houston Public Media, September 21
There is a delay that doesn't show up on some pro formas. The building is finished, the equipment is on the pad, the capital is spent — and nothing turns on. A project can wait for a grid connection, permanent generation, approvals, or commissioning. The length and cost depend on the project; no single duration or loss figure describes every site. This is the gap year.
It can affect data centers, oil and gas, construction, mining and other electricity-dependent operations. The scale, cause and commercial effect vary by project. The reports in this series examine examples from individual sectors; this article considers the general scheduling problem.
The Anatomy Of The Gap
The gap can arise from several project-specific constraints. Interconnection requests, equipment lead times, permits, construction and commissioning describe different steps; a queue position is not a service date. The evidence update above distinguishes national generation-and-storage queue capacity from Texas large-load requests. Neither count establishes how long an individual project will wait or whether it will be built.
Equipment availability is another possible constraint. The following source reports describe specific equipment scopes and observation periods; they are not directly comparable or a forecast for a new order.
| Equipment | Reported observation |
|---|---|
| Power transformers | 128-week U.S. average for Q2 2025, reported by Wood Mackenzie (published October 15, 2025) |
| Generator step-up transformers | More than 160 weeks, reported for Q1 2026 by Reuters (published July 9, 2026) |
| Gas turbines | Five-to-seven-year timelines in some cases discussed at an Oak Ridge National Laboratory workshop (March 31–April 1, 2026; report published April 17, 2026) |
These are separate source-reported observations with different periods and equipment scopes. They should not be added into a forecast for a particular project's energization date. Teams need current supplier quotes, utility milestones and permit conditions for their own site.
Where The Issue Appears
Electricity-dependent projects can encounter timing risk in different forms:
- Data centers may finish construction before utility service or generation is available. Construction duration, power delivery and revenue depend on each project and contract.
- Fixed field infrastructure — compression, saltwater disposal and midstream electrification — can be delayed if grid service or permanent generation is unavailable when the load is ready.
- Construction faces schedule and contractual exposure when permanent power dates move. Actual liability depends on the project documents.
- Mining and remote industrial operations may rely on grid extensions, on-site generation, or both; queue and equipment figures do not set a universal energization date.
- Commercial and industrial expansions need site-specific confirmation of utility capacity, equipment availability and permits before setting an operating date.
The cause and schedule are specific to each site and its power plan.
The Price Of A Year Spent Waiting
The financial effect depends on each project's actual operating plan, contracts, costs and alternatives. A generic revenue-per-megawatt figure cannot establish the loss for a specific delayed facility. A project team should calculate the exposure from its own load, achievable utilization, customer commitments, bridge-power costs and financing terms.
A finished asset that cannot yet run may still carry costs before it earns revenue. The financial effect depends on the project's contracts, operating plan and eventual service date.
For some projects, the expected energization date can materially affect financing and customer commitments. Teams should assess that alongside energy cost using their own project assumptions.
Temporary Power Can Bridge Some Delays
Temporary power may help a site operate while planned permanent power is pending. It does not itself resolve a queue position, equipment delay or permit requirement.
One possible approach is bridge-to-BTM: temporary generation supporting a site until its planned permanent equipment is ready. Another is bridge-to-grid: on-site generation used while grid service is pending. Neither fits every project; fuel, permits, emissions limits, availability, operating costs and the eventual handoff must be assessed for the site.
Any staged design must match the site's measured load and electrical design. Modular increments, redundancy and transformer configuration are engineering choices, not a universal recipe; they require project-specific load studies and qualified design review.
Evaluating Bridge-Power Options
No single generation source fits every project. A bridge-power plan requires a site-specific review of duty cycle, ambient temperature and altitude, fuel supply, emissions permits, equipment availability, redundancy, installation, and commissioning. Nameplate ratings should be adjusted using documented performance data for the intended site and operating conditions.
Fuel logistics and permitting can affect both feasibility and schedule. Project teams should confirm the applicable operating limits, fuel-delivery plan, emissions performance, and required approvals before relying on temporary generation. Equipment delivery and commissioning timelines also need to be verified for the specific project.
Plan For The Site's Actual Constraints
Power delays can have several causes, and temporary generation may help in some circumstances. It does not make an interconnection wait optional or guarantee an operating date: fuel, permits, equipment, installation and commissioning remain part of the schedule.
If your project is stranded between ready and energized — a utility date that keeps moving, permanent gear that keeps slipping — the gap year is the problem worth solving first. Treat temporary generation as a schedule-risk decision, with explicit procurement milestones and a defined handoff to permanent power.