ERCOT 410 GW Large-Load Queue: What Is Real, What SB 6 Filters
ERCOT's April 2026 materials show approximately 410 GW of large-load requests seeking interconnection, with about 87% tied to data centers. That number is a planning and queue signal, not a forecast that all load will energize. ERCOT's separate preliminary 2026-2032 load forecast projects 367,790 MW of regional demand by 2032 and explicitly describes the forecast as a snapshot for planning rather than a prediction of what will be built. For Texas commercial buyers, the practical question is which requests survive SB 6, financial-security, study, water, generation, and transmission constraints, then how surviving load affects TUOS, 4CP, and 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 410 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.
410 GW: Potential vs. Reality
ERCOT's 410 GW figure is best read as queue pressure, not a load forecast. The April 9 House State Affairs presentation says ERCOT is tracking approximately 410 GW of large loads seeking interconnection, while the April 15 forecast release says the 2026-2032 forecast is a preliminary planning snapshot and not 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. Projects are grouped and studied collectively, allowing ERCOT engineers to model cumulative grid impacts rather than evaluating each request in isolation.
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 410 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 ERCOT data-center topic path for the full cluster. For the original Batch Zero framework analysis, see ERCOT Batch Zero: Texas Interconnection Scramble (March 2026). 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.