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To determine whether a proposed data center or other large power project can connect in Texas, start with the site’s exact peak demand and electrical design, identify the transmission or distribution provider serving the site, and obtain the project’s current ERCOT process status from that provider. For loads of 75 MW or more at one site, ERCOT’s large-load process applies. Since July 11, 2026, qualifying requests have moved from the former individual-study route into the transitional Batch Zero framework. ERCOT later delayed planned data-center classifications while it verified projects, so a queue entry, study, or public announcement is not proof that a project can energize.
Only a location-specific provider and ERCOT record can establish how many megawatts are serviceable, which transmission facilities or operating limits apply, what commitments remain, and when energization could occur.
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What you must establish before asking for a connection
A Texas grid connection is not decided by a statewide queue number or by the fact that a nearby substation exists. The answer depends on the project’s electrical configuration, requested demand, ramp to full load, point of interconnection, local transmission constraints, other committed projects and the upgrades that can be built in time.
Prepare a single, consistent project description before contacting a provider. It should include:
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- Exact site boundary and address or parcel description.
- Aggregate peak demand in megawatts (MW), including all facilities behind common points of interconnection or service-delivery points.
- Expected ramp and commissioning increments, rather than only the ultimate nameplate load.
- Requested in-service or first-energization date and the date for reaching peak demand.
- Load type, such as a data center, industrial plant, hydrogen facility, manufacturing site or another large load.
- Proposed transmission or distribution point of interconnection.
- On-site generation, storage, backup generation, power-conversion equipment and controls.
- Any plan to curtail demand or operate with a reduced grid draw.
ERCOT’s process Q&A describes a preliminary Load Commissioning Plan that sets out increments and the timeline to peak demand. A provider cannot evaluate a schedule accurately if the project supplies only an eventual MW figure without its ramp profile.
Does the project meet ERCOT’s large-load threshold?
ERCOT generally defines a “Large Load” as one or more facilities at a single site with aggregate peak demand of at least 75 MW behind one or more common points of interconnection or service-delivery points. The threshold is about the site’s aggregate arrangement, not simply the rating of one building or one meter.
The December 2025 ERCOT Q&A says the Section 9 process applies to:
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- A new Large Load.
- Certain modifications to an existing load that increase facility demand by at least 75 MW.
- Certain changes or additions to the point of interconnection.
The exact result can change with the site’s electrical configuration. Ask the serving provider and check the current Planning Guide for the treatment of multiple facilities, staged additions, shared delivery points, on-site generation and changes to an existing service.
Projects below 75 MW
A project below the general Large Load threshold is not automatically free of grid review. It still needs the normal transmission or distribution interconnection and service process, and a provider may need to study local facilities, voltage, protection, power quality or planned upgrades. The 75 MW definition tells you when the ERCOT large-load framework is generally implicated; it is not a promise that smaller projects can connect without study or construction.
Islanded and partially self-supplied projects
A facility that is genuinely islanded and has no grid connection generally falls outside ERCOT’s interconnection process, although Public Utility Commission of Texas (PUCT) registration or other obligations may still apply. A project that remains connected while using on-site generation or storage is different: its import capability, controls and operating conditions must be evaluated. ERCOT’s Batch Zero materials contemplate possible pathways for credible on-site self-supply and for loads willing to curtail when local transmission constraints require it.
What changed in 2026: Section 9 to Batch Zero
The large-load route changed during 2026, so older articles and presentations can describe a process that is no longer the current intake path.
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| Date | Development | Practical meaning |
|---|---|---|
| June 18, 2026 | PUCT approved ERCOT’s Batch Zero framework. | Qualifying large projects of 75 MW and greater are evaluated together in a system-wide study intended to allocate available grid capacity and identify needed transmission upgrades. |
| July 10, 2026 | Last day for the former Large Load Interconnection Study process under Planning Guide Section 9. | Do not assume a new request can start the old individual-study route. |
| July 11, 2026 | Batch Zero took effect as a transitional system-wide study for large-load requests meeting its maturity and commitment criteria. | Requests are considered together rather than relying solely on the former sequence of individual studies. |
| August 3, 2026 | ERCOT announced that it had received gubernatorial direction to verify data-center large loads before advancing them. | ERCOT said it would not notify providers of each Batch Zero classification by the planned August 7 date and would consult PUCT on next steps. |
Batch Zero is intended to evaluate qualifying requests together, allocate available transmission capacity among studied and committed loads and, where feasible, produce an actionable transmission plan. It does not make every requested MW deliverable, and it does not itself authorize energization.
ERCOT President and CEO Pablo Vegas characterized the change this way: “This new process represents a fundamental shift in how ERCOT manages the significant growth of large load interconnection, providing a structured, transparent path forward that protects reliability for Texans while supporting the state’s continued economic growth.” That is ERCOT’s description of the framework, not a guarantee for an individual project.
Step-by-step: check a proposed project’s Texas connection status
1. Freeze the project assumptions
Write down the project’s peak MW, ramp, commissioning stages, load type, controls, proposed point of interconnection and requested dates. Include the maximum simultaneous demand for all facilities at the site. If the design has alternatives, label them separately instead of presenting a range that the provider cannot study.
Identify whether a generator, battery or other resource will reduce the project’s normal grid import. State whether that equipment is intended to operate in parallel with the grid, to support curtailment, or to create a genuinely islanded operating mode. The provider must know the operating arrangement, not just the equipment nameplate.
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Determine which transmission service provider (TSP) or distribution service provider (DSP) serves the parcel and the proposed delivery point. The first practical contact is that provider, not a generic ERCOT mailbox and not a real-estate broker’s claim about nearby capacity.
Ask the provider for its current large-load intake route, application requirements and the ERCOT forms that apply to the project. ERCOT’s older process description had customers submit through the appropriate TSP, which requested project details and informed ERCOT. The newer Batch Zero notice says current applicant and provider forms, guides and attestations are posted on ERCOT’s Large Load Integration page. Because the individual-study process was superseded, confirm each step rather than copying an old checklist.
3. Confirm whether the request is in ERCOT’s process
Ask the provider to identify:
- Whether the project has been submitted into the current ERCOT large-load process.
- Which Batch Zero eligibility and maturity criteria apply.
- The project’s application or Large Load Integration identifier.
- The current status, including any missing commitment, study or verification material.
- Whether ERCOT or the provider has requested additional information about the load type, ownership, schedule, controls or data-center classification.
ERCOT’s August 3 notice confirms that verification delayed planned classifications. It does not establish the status of an unnamed project. A provider should be able to tell you what record it is relying on; a marketing announcement or an unverified queue reference cannot substitute for that record.
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4. Request a location-specific serviceability answer
Ask for the study assumptions and results that apply to the actual site. At minimum, request the provider’s and ERCOT’s view of:
- Serviceable MW and the date or commissioning stage for each amount.
- Transmission constraints, thermal limits, voltage issues, stability concerns and operating limits.
- Required substations, lines, transformers, protection, controls, communications and other facilities.
- Whether other committed or must-study loads in the area affect the result.
- Expected in-service dates for each required upgrade.
- Any curtailment, import limitation or special operating condition.
- How on-site generation or storage changes the project’s grid draw and study assumptions.
Under the former Section 9 process, the TSP coordinated reliability studies with ERCOT review and input. The commissioning plan could be revised if upgrades were needed. Batch Zero evaluates qualifying requests together, so a result can depend on the group of projects studied and committed in the same framework.
5. Separate a study result from permission to energize
A completed study or favorable classification is not an energization authorization. Before a project can operate, confirm the current requirements in the Planning Guide and with the provider. The earlier Section 9 Q&A identified later-stage items such as:
- Required agreements.
- Construction notice and financial security.
- Inclusion in the network operations model.
- Operational telemetry.
- A current commissioning plan.
- Applicable stability conditions.
- Applicable net-metering or parallel-operation conditions.
The exact list can change under the current process and project configuration. Ask for a written milestone list that distinguishes study completion, construction authorization, testing, first energization, staged load increments and full-peak operation.
6. Recheck every material design change
ERCOT’s Q&A says a change in load type, schedule, point of interconnection or controls may require a full or partial restudy. Treat those changes as reportable. A redesigned cooling system, faster data-center ramp, different generator controls or a move to another substation can invalidate assumptions behind a prior result.
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Before approving a design change, ask the provider whether it affects Batch Zero eligibility, the project identifier, the study model, required facilities, curtailment terms or the energization sequence.
How long can connection take?
There is no single ERCOT-wide answer for an unnamed project. Timing depends on the provider, study stage, load ramp, local system conditions, required facilities, permitting and construction schedules, as well as the current Batch Zero and PUCT direction.
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Build a schedule around explicit milestones rather than a promised number of months:
- Provider intake and confirmation that the project description is complete.
- ERCOT process entry and confirmation of the applicable Batch Zero criteria.
- Study assumptions accepted and any verification responses completed.
- Serviceable MW and operating limits identified.
- Transmission facilities designed, approved, financed and scheduled.
- Agreements, security, construction notice, model updates and telemetry completed.
- Testing and staged commissioning approved.
- Each load increment energized, followed by the next increment only when its conditions are met.
A date tied only to a queue position is not a reliable energization date. Ask which milestone the date represents and what dependencies could move it.
How to compare candidate Texas sites
Use the same questions and assumptions for every parcel. A site with a lower land price or a nearby high-voltage line may still be less viable if its deliverable MW arrives later or requires a long transmission build.
| Comparison axis | What to obtain from the provider or ERCOT record |
|---|---|
| Process path | Current provider route, Batch Zero eligibility and application identifier. |
| Demand profile | Requested MW, ramp rate, commissioning increments and date to peak. |
| Electrical arrangement | Point of interconnection, delivery points, voltage, parallel operation and controls. |
| Local competition | Other committed or must-study loads that affect the local study. |
| Deliverable capacity | MW available at each commissioning stage and in each target year. |
| Required construction | Transmission lines, substations, transformers, protection, communications and controls. |
| Upgrade schedule | Expected in-service date for each facility and dependencies outside the project’s control. |
| Operating conditions | Curtailment rights, import limits, stability requirements and telemetry obligations. |
| Self-supply effect | Credible on-site generation or storage and the resulting grid-import requirement. |
Require the same load model and commissioning assumptions for each candidate. Otherwise, one site may appear better simply because it was evaluated against a smaller or slower load.
What ERCOT’s statewide queue statistics do—and do not—tell you
ERCOT reported that its Large Load Interconnection queue contained approximately 400 individual requests totaling 239,000 MW in February 2026. In a June 2026 release, ERCOT reported more than 438,000 MW of large-load requests, nearly 89 percent of them from data centers.
Those figures come from different report dates and use different totals. They should not be combined into one snapshot, and neither figure predicts whether a particular project will connect. Queue demand is not the same as deliverable capacity, and it does not reveal a site’s required upgrades, operating limits or energization date.
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- What is the site’s serving TSP or DSP and the applicable delivery point?
- Does the aggregate configuration meet ERCOT’s 75 MW Large Load definition?
- Which current ERCOT and provider forms are required?
- What is the project or Large Load Integration identifier?
- Which Batch Zero maturity, commitment and verification criteria apply?
- Has ERCOT issued or deferred a classification for this request?
- How many MW can be served at each commissioning stage and on what dates?
- What transmission facilities, operating limits and curtailment conditions apply?
- Which upgrades are required, who is responsible for them and when are they expected in service?
- What agreements, security, telemetry, model updates, testing and commissioning approvals are still outstanding?
- Which proposed changes would trigger a full or partial restudy?
Keep the provider’s response with the project record and date every revision. The process is changing, and an answer that was accurate before July 11, 2026 may describe the retired individual-study route.
Official records to monitor
For current requirements, use ERCOT’s Large Load Integration page for Batch Zero forms, guides and attestations. Check the ERCOT Planning Guide, especially Section 9 for large-load interconnection and Section 6.6 for Network Operations Model issues, while recognizing that ERCOT’s process Q&A is informational and the Protocols and Planning Guide control if there is a conflict.
Follow the ERCOT Large Load Working Group for stakeholder materials and meetings. Monitor ERCOT Market Notices and PUCT open-meeting materials for changes to classifications, verification and implementation. The August 3, 2026 notice established a delay to the planned classification schedule; it did not publish the final disposition of every request.
Common mistakes that produce a false “yes”
Confusing a queue entry with capacity
A listed request shows that a project is being considered, not that its requested MW is deliverable. Obtain the provider-confirmed serviceable MW and upgrade plan.
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The former individual Large Load Interconnection Study process ended on July 10, 2026. Confirm the current Batch Zero route and forms.
Ignoring the ramp
A project that reaches peak demand quickly can create different system requirements from one that commissions in small increments. Submit a realistic Load Commissioning Plan.
Counting planned generation as guaranteed supply
On-site generation or storage affects the grid study only under credible, enforceable operating assumptions. State how equipment operates in parallel, how controls are verified and what happens during an outage.
Treating a study as permission to energize
Agreements, construction, security, model inclusion, telemetry, testing and commissioning conditions may remain after the study. Obtain the provider’s milestone list.
Assuming a public delay answers a private status question
ERCOT’s verification-related delay applies to the classification schedule generally. It does not prove that any unnamed project was accepted, rejected or classified.
What a defensible connection determination looks like
For a proposed Texas data center or power project, the defensible answer is a dated, location-specific record from the serving provider and ERCOT that identifies the project, its study path, assumptions, serviceable MW, operating limits, required facilities, upgrade dates and remaining energization conditions.
If any of those elements is missing, describe the project as under evaluation rather than “approved,” “guaranteed” or “connected.” ERCOT’s statewide request totals demonstrate the scale of demand, not the probability of success for one site. The practical test is whether the provider can map the project’s exact load and commissioning plan to a current ERCOT process record and a buildable transmission or distribution plan.
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