ERCOT & Grid Operations
Updated April 25, 2026
8 min read
Texas Deregulated Electricity Market Explained for Businesses
Texas runs the largest competitive electricity market in the United States. Here is how commercial rates, contracts, and TDU territories actually work for businesses.
Texas runs the largest competitive electricity market in the United States, and most of its commercial customers can choose who supplies their power. That choice rarely shows up cleanly in the search results. Type "texas electricity rates" into Google and the top pages return residential aggregator listings written for homeowners on 1,000 kWh-per-month profiles. Commercial buyers face a different rate stack, different contracts, and different risks.
This article covers how the deregulated market works for businesses, what actually drives a commercial rate, the contract types available, and what to ask before signing. For weekly tracking of how those rates move, see current ERCOT market news.
Texas Electricity Deregulation Explained
The framework that lets Texas businesses shop for power is built on a 1999 statute. Senate Bill 7, signed by Governor George W. Bush on June 18, 1999, restructured the state's electric utility industry and authorized retail competition starting January 1, 2002. The full legislative text is on file with the Texas Legislature, and a market overview is maintained at Wikipedia: Deregulation of the Texas electricity market. Pat Wood, director of the PUCT during the SB 7 implementation period, oversaw the 2002 retail launch.
About 85% of Texas load now sits inside the deregulated market. Three distinct roles split the work that a single vertically-integrated utility used to perform:
- **Generators** sell electricity into the wholesale market run by [ERCOT](https://www.ercot.com), which manages the grid and clears prices on a 15-minute interval.
- **Transmission and Distribution Utilities (TDUs)** own the poles, wires, and meters. They are still regulated monopolies. Buyers do not choose them; they are assigned by territory.
- **Retail Electric Providers (REPs)** buy from the wholesale market and resell to end customers. The [Public Utility Commission of Texas (PUCT)](https://www.puc.texas.gov) certifies more than 100 REPs.
Outside the deregulated zone, customers stay with their incumbent utility. That includes municipal utilities (Austin Energy, San Antonio CPS, Garland Power and Light, Bryan Texas Utilities) and most rural electric cooperatives. A handful of cooperatives have opted into competition, but the default for muni and co-op territory is no choice.
How Texas Electricity Rates Work for Businesses
The headline number a REP quotes is rarely the all-in cost. The current Texas commercial average sits around 8.60 to 9.12 cents per kWh per the U.S. Energy Information Administration (April 2026 data), which runs 35% to 37% below the national commercial average of 13.6 to 14.1 cents. That advantage is real, but the path to capturing it depends on understanding what each line item contributes to the total.
The energy supply piece, which is what most quotes show, averages about 6.80 cents per kWh on competitive 12-month commercial contracts. TDU delivery typically adds 1.5 to 3.5 cents per kWh on top, set by territory and rate class. ERCOT-driven ancillary services add another 0.5 to 1.5 cents per kWh.
Demand-metered commercial accounts face a separate cost driver that does not appear on residential bills: capacity and demand charges. The average runs around $40 per kW per month based on the customer's peak demand, and demand can account for 30% to 70% of the total commercial bill. For a 500 kW facility, a single bad summer afternoon can lock in nearly a quarter-million dollars of annual demand charges.
The Five Components of a Texas Commercial Rate
Every commercial bill in the deregulated market breaks into five components. If a quote does not separate all five, the buyer is comparing partial pictures. Use the Five Components framework as the analyst lens for every rate quote a REP or broker hands over.
1. **Energy Supply.** The REP's component, market-driven, usually quoted in cents per kWh. Term length, load size, and credit profile all move it. Range in early 2026: roughly 5.50 to 9.50 cents.
2. **TDU Delivery.** Regulated by PUCT and set by the territory's filed tariff. Non-bypassable. Range: 1.5 to 3.5 cents per kWh, with Houston (CenterPoint) typically running about half a cent higher than Dallas-Fort Worth (Oncor).
3. **Ancillary Services.** Set by ERCOT to keep the grid balanced (frequency regulation, spinning and non-spinning reserves, ECRS contingency reserve). Range: 0.5 to 1.5 cents per kWh, and rising as reserve margins tighten.
4. **Capacity and Demand Charges.** Apply to demand-metered accounts. The driver is [ERCOT's 4 Coincident Peak (4CP) program](https://www.ercot.com/mktinfo/data_agg/4cp), which identifies the single highest 15-minute grid-wide demand interval in each of June, July, August, and September. A facility's load during those four windows sets its transmission demand charge for the entire next year.
5. **Regulatory Fees.** PUCT-mandated charges, including the Retail Renewable Portfolio Payment, nuclear decommissioning rider, and similar pass-throughs. Small in dollars (roughly 0.02 to 0.04 cents per kWh) but always present.
A practical takeaway: a quote at 6.50 cents per kWh in Oncor territory becomes about 9.0 to 9.5 cents all-in once delivery, ancillary, demand, and regulatory components are added.
TDU Territories and Contract Types
The TDU determines the delivery side of the equation. There are six commercial territories serving deregulated customers:
TDURegionApprox. Commercial Delivery (¢/kWh)
OncorDallas-Fort Worth, North Texas, parts of West Texas2.8 to 4.8
CenterPoint EnergyGreater Houston metro3.2 to 5.0
AEP Texas NorthAbilene, Wichita Falls area4.2 to 5.0
AEP Texas CentralCorpus Christi, Rio Grande Valley4.2 to 5.2
Texas-New Mexico Power (TNMP)Scattered: Gulf Coast, North-Central, West Texas4.5 to 5.5
Sharyland UtilitiesParts of West, South, and Central Texasvaries
The supply side has more flexibility. Five contract structures dominate the commercial market:
- **Fixed-rate contracts** run 12, 24, or 36 months. Predictable, with early-termination fees. Best for steady-load operations.
- **Variable or month-to-month plans** track wholesale and serve as the default after a fixed plan expires. Useful only as a bridge.
- **Indexed plans** (heat-rate or block-and-index) pass wholesale through with a markup. Common for larger industrials willing to take basis risk for a chance at lower average cost.
- **Time-of-use plans** split rates by peak and off-peak periods. Worth modeling for businesses that can shift load to nights or weekends.
- **Swing tolerance and take-or-pay structures** apply to large customers with custom load profiles, defining usage bands or minimum take volumes.
For a snapshot of current commercial offers across these structures, the current commercial plan data tracks active rates by territory and term. For the mechanics of running an apples-to-apples comparison across REPs, see how electricity rate comparison works in the Texas ERCOT market.
What Businesses Should Do
Procurement is where most of the value is captured or lost. Seven steps cover the practical work:
1. Pull a recent bill and identify all five rate components: energy, TDU delivery, ancillary, demand, regulatory.
2. Build an accurate 12-month load profile, including monthly kWh and peak kW, before requesting any quote. REPs and brokers price against the load they see.
3. Open the procurement window 90 to 180 days before contract expiration. Longer windows give access to forward-curve dips that month-of buyers miss.
4. Compare quotes apples-to-apples by adding TDU delivery to every energy-only number. Brokers often quote the energy-only figure to look competitive.
5. For demand-metered accounts, build a 4CP load-management plan covering June through September. Even a 5% cut in a single peak interval shows up on the next year's bill.
6. Verify the REP's PUCT certification and POLR exposure before signing. The PUCT REP directory lists every active provider.
7. Read the Term Sheet (mid and large commercial) or the Electricity Facts Label (small commercial). The marketing one-pager is not the contract.
Procurement teams that need a sounding board can contact the TxCP team for an independent read on a specific quote stack.
Questions to Ask Your REP or Broker
A short list before signing:
- What is the exact pricing formula, and which components pass through (energy, TDU, ancillary, capacity, regulatory)?
- What are all fees: early termination, late payment, imbalance, swing penalties, and what is the credit or collateral requirement?
- How does the contract handle usage variance, peak demand changes, or ERCOT scarcity events?
- What is the renewal mechanism, and is there an evergreen clause that renews automatically?
- For brokers: how is your compensation structured, and will you share every offer received?
- What is your performance history, financial stability, and PUCT REP certification number?
Frequently Asked Questions
What is the average commercial electricity rate in Texas?
The all-in commercial average is 8.60 to 9.12 cents per kWh per EIA April 2026 data. That is roughly 35% to 37% below the national commercial average of 13.6 to 14.1 cents. Energy-only quotes from REPs typically sit around 6.80 cents, with TDU delivery, ancillary, and demand charges layered on top.
How is a commercial electricity bill different from a residential bill in Texas?
Commercial bills add demand charges (priced per peak kW, not per kWh), kVAR penalties for poor power factor, and ratchet clauses that can lock minimum demand for up to 11 months after a single peak. Residential bills are mostly a flat kWh energy charge plus TDU pass-through, with no demand or ratchet exposure.
What is ERCOT 4CP and why does it matter?
ERCOT identifies the single highest 15-minute grid-wide demand interval in each of June, July, August, and September. A commercial facility's load during those four intervals sets its transmission demand charge for the entire next year. The 2024 program identified Sunday, June 30, 2024 as a peak, which broke the historical pattern of weekday peaks and made prediction harder.
What happens if a Texas REP goes out of business?
PUCT designates a Provider of Last Resort (POLR) every two years. If a REP exits the market, service continues without interruption, but at POLR rates, which are typically higher than competitive plans. Customers should re-shop the market immediately rather than ride POLR pricing.
Hero photo by Max Fray on Unsplash. Substation photo by American Public Power Association on Unsplash. Warehouse photo by Sierra Bell on Unsplash.
Originally published at texascommercialplans.com
Top comments (0)