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Texas Commercial Electricity Rates and the 2026 Supply Gap: What Buyers Should Do Now

| 7 min read

Texas commercial electricity buyers face a window most contract strategies have not priced in. ERCOT's preliminary Long-Term Load Forecast filed April 15, 2026 projects peak demand could grow from a 2023 record of 85.5 GW to roughly 367 GW by 2032 in its high-growth scenario, a 4x rise driven almost entirely by data centers, electrification, and industrial expansion. The Apricitas Economics analysis describes Texas as on track to grow commercial and industrial electricity use more in the next four years than it did in the prior two decades. Supply additions are coming, but on 12-36 month build timelines. The mismatch is the rate risk window, and contract timing matters more in 2026 than it has in years.

What Is the Texas Electricity Gap

The "gap" is the spread between how fast commercial demand is growing and how fast new firm supply can be permitted, built, and energized. Three datasets sharpen the picture for Texas in 2026.

First, demand. S&P Global Commodity Insights projects US data center power demand to roughly triple to 64 GW, with Texas leading the surge at a projected 35.9% increase to about 13.5 GW in 2026 alone. CenterPoint's Greater Houston territory has 12.2 GW of firmly committed industrial and data center load with a target of 8 GW energized by 2029. Oncor's territory has roughly 273 GW of large-load interconnection requests on the books.

Second, supply. Texas is doing the heavy lifting on national capacity additions. According to EIA-tracked data summarized by PV Magazine USA, Texas accounts for roughly 41% of new US utility-scale solar in 2026 (about 17.4 GW of the 43.4 GW national total) and 53% of new battery storage (about 12.9 GW of 24 GW nationally). Battery storage on the ERCOT grid reached 15.7 GW operational by early 2026, with average duration around 1.65 hours.

Third, the timing. Solar and battery projects move on 12-36 month interconnection and construction cycles. Commercial demand from data centers and industrial users is energizing now. Natural gas covers the majority of net new load growth on shorter horizons, and gas peakers set the marginal price during scarcity hours. That is the structural piece commercial contract strategies need to account for.

How the Gap Hits Commercial Electricity Rates

The gap shows up in commercial bills through three distinct mechanisms, and contract type determines which ones you feel and when.

Scarcity pricing on real-time and index exposure. ERCOT's energy-only market lets prices rise to a system-wide offer cap of $5,000/MWh during operating reserve emergencies. Index and pass-through contracts settle directly against those moves. ERCOT's 2026 Summer Reliability Assessment forecasts peak demand of 89-92 GW with a 1-in-10 year scenario at 92 GW. As the supply cushion narrows, scarcity hours per summer rise, and that drives index settlement higher.

Forward curves and renewal pricing. Fixed-rate buyers feel the gap at renewal. REPs hedge their exposure when they price your fixed product, so tighter expected supply lifts the curve REPs quote against. Contracts expiring between Q4 2026 and 2028 are renewing into a forward curve that already prices in expected data center buildout but does not fully price in delays or interconnection slips. If supply lags forecasts, that quote will move higher.

TDU delivery and 4CP transmission charges. Every commercial buyer in Texas pays TDU pass-through regardless of contract type. ERCOT's Four Coincident Peak (4CP) program allocates transmission cost recovery based on a customer's demand during the four highest 15-minute grid intervals across June, July, August, and September. As data center load lifts the grid peak, the dollars allocated per kW of 4CP demand rise, even if your facility's load profile does not change.

The practical implication: fixed contracts expiring before Q4 2026 are renewing into the most exposed window. Index contracts feel the gap monthly. Pass-through and block-and-index sit in between. None of the structures avoids 4CP transmission exposure.

The Texas Commercial Buyer's Rate Lock Timing Checklist

Run this five-point check before your next renewal cycle. Each step takes 30-60 minutes and produces a written artifact you can compare across REPs.

Step 1. Map every contract by expiry quarter

Build a one-page table of every commercial meter, contract type, expiry date, and annual usage. Anything expiring before Q4 2026 should start an RFP this month. Anything expiring in 2027 should have a quote in hand by Q4 2026.

Step 2. Pull fixed AND index quotes from at least three REPs

Require both structures from each REP for the same load profile and term. Without the index quote, you cannot price the optionality you are giving up by going fixed. Without the fixed quote, you cannot bound your downside on index.

Step 3. Stress-test at a 15-20% scenario

Model your annual electricity cost if rates move 15-20% higher across your renewal cycle. If a fixed lock today eliminates that exposure for less than the stress-test cost, the lock is the lower-variance choice. If not, hedge through block-and-index instead.

Step 4. Prioritize your highest-consumption sites for fixed locks

Multi-site portfolios should not lock everything. Prioritize the top 20% of sites by kWh consumption for the longest fixed terms, and accept more index exposure on smaller sites where dollar swings are limited.

Step 5. Enroll qualifying load in ERCOT demand response

Businesses with curtailable load above roughly 100 kW (HVAC pre-cool, process cooling, EV charging, refrigeration) can monetize flexibility through Emergency Response Service (ERS) and 4CP avoidance. Both payment structures grow as reserve margins tighten.

Six Questions to Ask Your REP or Broker This Quarter

  1. At what percentage of new load growth is natural gas your fallback assumption, and what does that mean for my rate over the next 12-24 months? If gas covers most of net new load, your rate is exposed to gas curve volatility, not solar economics.
  2. Does your fixed-rate pricing assume battery storage filling peak gaps, or natural gas peakers setting the marginal price? The answer materially changes how summer afternoon hours roll into your quote.
  3. Can you show me how my fixed offer today compares to your index forecast for Q4 2026 and full-year 2027? Insist on a side-by-side, not a verbal comparison.
  4. What is my historical 4CP exposure as a percentage of total bill, and how does the renewal quote handle TDU pass-through? If transmission is more than 25% of the bill, you have meaningful 4CP exposure.
  5. What ancillary service or RTC pass-through clauses are in the proposed contract, and what would they have cost over the past 12 months? Get historical line items, not a verbal "minor" assurance.
  6. What demand response credits or curtailment payments could my load qualify for, and what is the qualification process? ERS and 4CP avoidance are the two practical levers.

FAQs

What is the Texas electricity gap and how does it affect commercial rates?

The gap is the timing spread between commercial demand growth (energizing now) and new firm supply (12-36 month build cycles). It raises scarcity pricing risk, lifts forward-curve renewal quotes, and increases 4CP transmission cost allocation. The effect on any individual commercial buyer depends on contract type and renewal timing, but every commercial meter in Texas feels at least the TDU and 4CP component.

Should Texas commercial buyers lock in fixed rates now or wait?

The answer turns on contract expiry timing and risk tolerance. Anything expiring before Q4 2026 should be quoted now, because that window renews into the tightest part of the supply gap. For meters expiring 2027 or later, run the five-point checklist above and pull both fixed and index quotes. Fixed eliminates upside surprises; index keeps optionality. Block-and-index splits the difference for portfolios with mixed risk tolerance.

How fast is Texas commercial and industrial electricity demand growing?

ERCOT's preliminary Long-Term Load Forecast filed April 15, 2026, projects high-growth peak demand of roughly 112 GW in 2026, 278 GW in 2029, and 367 GW in 2032. Even after applying conservative build-out assumptions, ERCOT's 2026 Summer Reliability Assessment forecasts 89-92 GW. Independent analysts including Apricitas Economics describe the four-year demand growth as exceeding the prior two decades combined.

Will new battery and solar capacity in Texas lower commercial rates?

The honest answer is partially and on a delay. Texas is bringing on roughly 12.9 GW of new battery storage and 17.4 GW of new utility solar in 2026 alone, more than half of all new US battery capacity. That capacity helps shave summer peaks and reduces some scarcity events. But on 12-36 month build timelines, with average battery duration near 1.65 hours, storage cannot fully cover multi-hour peaks during heat waves or low-wind nights. Natural gas remains the marginal price-setter during the highest-priced afternoons, so commercial fixed-rate quotes will continue to track gas curves more than solar economics until duration and capacity scale further.

If you want to compare commercial plans by contract type, REP, and term length, start with our Texas commercial electricity rates overview.