ERCOT 438 GW Large-Load Queue: What Batch Zero Filters
ERCOT's June 2026 materials say more than 438,000 MW of proposed large-load demand had entered the connection queue, with nearly 90% tied to data centers. Batch Zero starts July 11, but the queue remains potential demand, not confirmed energized load. Texas commercial buyers should watch which projects clear study, financial-security, water, generation, and transmission constraints before pricing TUOS, 4CP, or congestion exposure.
Executive Impact — Texas Commercial Buyers
- →Transmission Cost Allocation: If a meaningful share of large-load requests becomes substantiated and energizes, related transmission upgrades can show up through ERCOT Transmission Use of System (TUOS) charges and TDU delivery tariffs. Buyers should track tariff filings and contract treatment rather than assuming the full 438 GW queue converts to load.
- →4CP Timing Risk: ERCOT's 4CP cost allocation mechanism rewards loads that curtail during the four peak 15-minute intervals each summer. New large-load patterns can alter peak timing, so existing commercial facilities should review 4CP playbooks against current interval data instead of relying on last year's curtailment windows.
- →Congestion Monitoring: Data-center and industrial-load concentration can increase localized congestion before transmission upgrades catch up. Commercial loads near North, West, or Permian-area growth corridors should monitor nodal and hub-basis movement, then evaluate demand response or operational flexibility where it fits the site.
438 GW: Potential vs. Reality
ERCOT's large-load figure is best read as queue pressure, not a load forecast. The April 9 House State Affairs presentation showed approximately 410 GW of large loads seeking interconnection. ERCOT's June 18 Batch Zero explainer moved the public queue context to more than 438,000 MW of proposed demand, nearly 90% from data centers, while the April 15 forecast release still frames the 2026-2032 forecast as a preliminary planning snapshot rather than a prediction of what will be built.
That distinction matters for readers arriving from search. A large queue can still affect planning, transmission studies, generation siting, and commercial procurement, but it should not be described as confirmed demand. The cleaner buyer question is: which requests become substantiated load, which are filtered by SB 6 and financial-security rules, and which remain speculative.
Senate Bill 6: The Filter
Texas's primary regulatory response is Senate Bill 6 (SB 6), passed during the 2025 legislative session. SB 6 establishes a framework for regulating large-load customers with peak demand of 75 MW or more, a threshold aimed at very large campuses rather than most ordinary commercial accounts:
- Financial Security: The PUCT has proposed $50,000 per MW in financial security in 16 TAC 25.194. For a 500 MW site, that would equal $25 million before any other project-specific costs.
- Project Substantiation: ERCOT and transmission providers are moving toward stronger evidence that a requested load has financing, site control, timeline, and interconnection readiness.
- Planning Standards: Large-load treatment can affect reliability studies, transmission planning, energization timing, and potential cost-allocation debates.
Large-Load Due-Diligence Map
ERCOT's public materials describe load type, timing, and interconnection pressure, but they do not publish a definitive top-10 data-center ranking for commercial buyers. Rather than imply project-level certainty, this page uses a due-diligence map: zones and questions that procurement teams can verify against current ERCOT, PUCT, TDU, and supplier materials.
| Buyer Question | Why It Matters | Where to Verify |
|---|---|---|
| Is the load substantiated? | Substantiated load is more relevant to procurement than a raw queue request. | ERCOT load forecast updates, TDSP filings, PUCT projects |
| Which zone is exposed? | North, West, South, and Houston exposure can differ by congestion, TDU delivery charges, and generation additions. | ERCOT hub/nodal prices, TDU tariff updates, congestion reports |
| Does SB 6 apply? | 75 MW+ load treatment can change interconnection timing, financial security, and study requirements. | PUCT rulemaking, Texas Register, supplier contract exhibits |
| Can the site flex load? | Flexible load can reduce 4CP, scarcity, and congestion exposure if operations can respond reliably. | Interval data, REP/QSE demand response options, facility controls |
This table intentionally avoids naming unverified project rankings. ERCOT's official materials support the system-level queue and forecast context; project-specific claims should be verified against current interconnection, TDU, and public-company disclosures before being used in customer advice.
Texas Legislature Takes Notice
The Texas House Committee on State Affairs held April 2026 hearings that touched three buyer-relevant dimensions of large-load growth:
- Grid Reliability: Whether ERCOT's current reserve margins can accommodate the scale of new load without compromising reliability for existing residential and commercial customers.
- Long-Term Infrastructure Planning: The need for new generation capacity, including the state's $350 million fund for nuclear energy development and proposals for 765-kV transmission lines to serve the Permian Basin and other industrial corridors.
- Water Resources: Data center cooling systems consume significant water, particularly in operations that don't use closed-loop or adiabatic cooling. In drought-prone West Texas, water availability may become the binding constraint before electricity.
Those hearings do not create a direct rate outcome by themselves, but they show why large-load policy, water constraints, and cost allocation are becoming part of Texas energy procurement due diligence.
ERCOT's Batch Study Process
To manage the volume of requests, ERCOT is transitioning from case-by-case interconnection studies to a batch study process. ERCOT's June 23 market notice says Batch Zero becomes effective July 11, 2026, after the current Large Load Interconnection Study process remains in effect through the end of July 10.
The Large Load Integration page gives the near-term workflow: interconnecting large-load entities must send several forms to their DSP or TSP by July 10, while interconnecting TSPs must submit the Batch Zero Load Information Form and related dynamic-stability materials to ERCOT by July 24. Those milestones are process filters, not proof that any given data-center campus will energize.
For commercial buyers, the batch process matters because it can separate near-term substantiated load from earlier-stage requests. That makes future ERCOT updates more useful than the raw 438 GW number when evaluating delivery charges, congestion exposure, and supplier contract terms.
Commercial Buyer Action Items
- Monitor TUOS and TDU Tariffs: Transmission Use of System charges and delivery tariffs are where many infrastructure costs become visible to commercial accounts.
- Refresh 4CP Strategy: Use current interval data, not last year's assumptions, to decide whether the facility can reliably curtail during likely coincident peaks.
- Evaluate Demand Response Fit: Flexible facilities should ask REPs or QSEs which programs match their operational constraints before assuming revenue potential.
- Track PUCT Rulemaking: SB 6 implementation and 16 TAC 25.194 can shape which large-load requests become real planning inputs.
Connected Analysis
Follow the data-center load hub and the ERCOT data-center topic path for the full cluster. For the updated Batch Zero framework analysis, see ERCOT Batch Zero: 438 GW Queue and July 2026 Deadlines. For summer pricing impacts, see ERCOT Summer 2026 Pricing Outlook. On the generation side, compare large-load growth with the $16B Anderson County 5.2 GW gas plant coverage.