ERCOT Forecasts 367 GW Peak Demand by 2032 — 4.3 Times the Current Texas Record
ERCOT filed a preliminary long-term load forecast on April 15, 2026 projecting Texas electricity demand could reach 367,790 MW (367 GW) by 2032 — roughly 4.3 times the current all-time record of 85,508 MW set in August 2023. ERCOT says the forecast is built from several inputs, including information from transmission and distribution companies working with medium and large-load customers such as data centers, cryptocurrency mining, industrial, and oil and gas loads. ERCOT CEO Pablo Vegas cautioned that "we believe this forecast to be higher than expected future load growth" and ERCOT described the filing as a preliminary snapshot, not a prediction of what will be built.
Executive Impact — Texas Commercial Buyers
- →Infrastructure Investment Is Coming Regardless: Even if actual demand reaches only 25-30% of the 367 GW forecast, Texas will still need to add the equivalent of its entire current grid capacity over the next decade. This means billions in new transmission and generation investment funded through charges that flow to all commercial ratepayers.
- →The Queue/Forecast Alignment: Yesterday's 410 GW interconnection queue report and today's 367 GW demand forecast tell the same story from different angles. The queue shows what developers want to build; the forecast shows what ERCOT expects the grid to need. Both numbers will be filtered through reality — but the direction is unmistakable.
- →Procurement Strategy Implication: Texas's wholesale electricity prices remain competitive today due to abundant wind, solar, and battery storage. But structural transmission cost increases can compound over the 2027-2032 period. Commercial buyers negotiating multi-year contracts should model delivery/transmission escalation separately from energy price assumptions.
Understanding the 367 GW Number
The 367,790 MW figure is a preliminary, unadjusted long-term load forecast filed with the PUC as required by recent state legislation. It represents the sum of existing load plus all large-load requests reported by Texas's transmission and distribution providers (TDPs) — without applying any conversion factors for project viability, financing probability, or historical completion rates.
Think of it this way: every entity that has told a Texas utility "we want to connect X megawatts of load" is counted at face value. This includes:
- Hyperscaler data center campuses with firm financing and executed contracts
- Speculative AI compute projects still seeking venture capital
- Bitcoin mining operations that may relocate based on price signals
- Industrial facilities in early planning stages with no site control
ERCOT CEO Pablo Vegas acknowledged this directly: "We believe this forecast to be higher than expected future load growth." The organization is working with the PUCT to apply adjustment factors — potentially reducing the figure by 50-60% based on historical realization rates — before using it for official resource adequacy and transmission planning.
What a Realistic Scenario Looks Like
If high attrition applies to Texas large-load requests, an adjusted 2032 demand path could still be far below the headline 367 GW while materially above today's record. Even a conservative scenario would imply:
- 55+ GW of new generation capacity needed (equivalent to building Texas's entire existing battery storage fleet 4× over)
- Hundreds of miles of new 345-kV and 765-kV transmission lines connecting generation to load centers
- Major water infrastructure for thermal generation cooling in drought-prone regions
- Billions in new substation and distribution capacity in metro areas receiving data center clusters
The Generation Response Pipeline
Texas is already mobilizing to meet projected demand growth. Key developments include:
- $16 Billion Anderson County Megaproject: A proposed 5.2 GW gas-fired power complex — the largest single power investment in U.S. history — backed by a U.S.-Japan partnership. Would add approximately 6% to ERCOT capacity.
- $350 Million Nuclear Energy Fund: Texas has launched a state fund to accelerate small modular reactor (SMR) development, targeting first deployments in the 2030-2032 timeframe.
- 14 GW Battery Storage Fleet: Already operational, with an additional 30+ GW in the interconnection queue. Battery storage provides essential peak-shaving capacity but cannot serve baseload data center demand.
- Co-Location Projects: Concord New Energy secured ERCOT approval for 1 GW of co-located solar + battery + data center capacity — a model that may become standard for hyperscaler campuses seeking grid access in Texas.
Commercial Buyer Action Items
- Factor Transmission Escalation Into Contracts: If you're negotiating a 3-5 year fixed-price electricity contract in ERCOT, ensure the delivery/transmission component includes a realistic escalation clause. Flat transmission pricing over 2027-2032 is increasingly unrealistic given the infrastructure investment trajectory.
- Evaluate Behind-the-Meter Options: With TUOS charges likely to rise structurally, the economics of on-site solar + battery systems are improving for commercial facilities with daytime load profiles. A behind-the-meter system reduces your grid demand and thus your transmission cost exposure.
- Monitor PUC Methodology Revisions: The adjusted forecast — expected later in 2026 — will be the number that drives actual infrastructure planning and cost allocation. Watch for the PUC's methodology announcement to understand which adjustment factors are applied and how they affect your TDU's service territory.
Connected Analysis
This forecast directly builds on yesterday's ERCOT 410 GW Interconnection Queue analysis and the Batch Zero Interconnection Framework. Follow the broader ERCOT large-load topic or the data-center load topic before moving to the $16B Anderson County 5.2 GW Gas Plant.