Ancillary Service Charges Would Stay on Texas Business Bills Under the PUCT Staff Plan Headed to Lawmakers December 1

On October 29, 2026, Public Utility Commission of Texas (PUCT) staff recommended keeping the rule that puts 100 percent of ERCOT's ancillary and reliability service costs on load, the cost a Texas business pays as an ancillary service charge or inside its energy rate. Load-serving entities paid $385.8 million for those services in 2025, about $0.78 per MWh, and the PUCT's study of whether generators should share the cost is due to the Texas Legislature by December 1, 2026. For commercial electricity buyers, staff's finding means the charge stays where it is, so the contract wording that decides who carries it through 2027 matters more than the policy debate.

Key takeaways:

PUCT staff recommend keeping 100 percent of ERCOT ancillary and reliability service costs on load, and found no net consumer savings in any of the three alternatives ERCOT modeled.
The 2025 cost works out to about $0.78 per MWh, or roughly $468 a year for a business using 600 MWh.
Before signing a 2027 rate, check whether the offer bundles these costs or passes them through, and whether a change-in-law clause could reopen the price.

What Happened

PUCT staff filed a memorandum in Project No. 58555 on October 29, 2026 concluding that ERCOT's current cost allocation methodology should stay in place, because none of the three alternatives ERCOT modeled is expected to save consumers money. In the memo's words: "The current cost allocation methodology should be preserved. None of the alternative allocation methodologies examined are expected to yield any net consumer savings."

The study exists because the Legislature asked for it. Texas Utilities Code (PURA) §39.1593, added by House Bill 1500 in 2023, directs the PUCT to evaluate whether allocating ancillary and reliability service costs among generators and load-serving entities, in proportion to their contribution to unreliability during the highest-risk hours, would save consumers money compared with charging all of it to load. Subsection (d) sets the report deadline at December 1, 2026.

The staff memo was set as Item 37, for discussion and possible action, on the commission's November 5, 2026 open meeting agenda. As of November 6, 2026, the project's filing list shows no order or filing after the October 29 memo, so we report the recommendation as staff's, not as a commission decision.

Today ERCOT charges these costs to the qualified scheduling entities (QSEs) that represent load, by load ratio share, settled in 15-minute or hourly intervals depending on the service. No ancillary or reliability service cost is allocated to generation. Retail electric providers then recover their share from customers. The study covers two groups of services:

Ancillary services: Regulation Up, Regulation Down, Responsive Reserve Service (RRS), Non-Spinning Reserve Service (Non-Spin) and ERCOT Contingency Reserve Service (ECRS).
Reliability services: Black Start, Emergency Response Service (ERS), Firm Fuel Supply Service (FFSS), Reliability Must-Run (RMR), Reliability Unit Commitment (RUC) and Voltage Support Service (VSS).

The memo leaves the Dispatchable Reliability Reserve Service (DRRS) out of scope because it is still being implemented, and points it to the 2028 ancillary service methodology. Read the staff memo and ERCOT's final study report, the November 5 open meeting agenda, and ERCOT's 2025 financial summary for annual load.

Who Would Pay Under the Three Alternatives ERCOT Modeled?

The two alternatives that charge generators would move close to 60 percent of the cost off load, while the third would leave 96 percent where it is today. ERCOT's final study report, attached to the staff memo, measured each one against a two-year (2024 and 2025) model base of $1,015.6 million: $698.2 million in ancillary services and $317.4 million in reliability services.

Method	Who it charges	Cost moved off load ratio share (2024 and 2025 model base)
Current method	All load, by load ratio share	None (100% stays on load)
Alternative A	Load, dispatchable generation and non-dispatchable generation, semiannually, by contribution to unreliability in high-risk hours	$617.2 million (60.8%) to generation
Alternative B	The same operational-risk approach across all hours, settled daily	$593.2 million (58.4%) to generation
Alternative C	Load QSEs short scheduled generation relative to their load, hourly, with the rest by load ratio share	After QSE-to-QSE capacity trading, $975.3 million (96%) still lands on load ratio share

Source: PUCT Project No. 58555, Commission Staff memo with ERCOT final study report, filed October 29, 2026.

The filing's annual cost tables sit on a different basis from that model base, so we quote them separately: load-serving entities paid $608.7 million for ancillary plus reliability services in 2024 and $385.8 million in 2025, a 36.6 percent drop.

Staff's reason for rejecting all three is about where the money ends up. Reallocating a cost does not change how much reserve ERCOT buys or what it pays for it. Staff expects generators to treat an allocated charge mostly as a fixed cost, so their short-term offers would not change, and over time they would recover it through higher energy and reserve offers, including through earlier retirements or delayed new plants. The cost would leave the load column and come back through the price of power.

Impact on Commercial Electricity Buyers in Texas

Staff's recommendation keeps the cost on load, so a Texas business keeps paying its share through its retail provider, and we see three channels where that reaches a commercial bill in 2027.

Bill share. $385.8 million spread over the roughly 494.6 TWh of load in ERCOT's December 2025 financial summary works out to about $0.78 per MWh, or 0.078 cents per kWh. Median commercial plan rates in the plans we track, the data behind our weekly TxCP Commercial Rate Index (TCRI), sat between 6.29 and 6.50 cents per kWh across all five TDU territories as of November 6, 2026, so the charge is about 1.2 percent of a typical rate. A business using 50,000 kWh a month, or 600 MWh a year, carries about $468 a year. That is twice the $0.39 per MWh in our September 30 explainer on how much reserve ERCOT buys, and the two figures do not conflict: the Independent Market Monitor's number covers the five ancillary services alone, while the $385.8 million also includes reliability services such as RUC, ERS and FFSS.

Pass-through versus bundled wording. A commercial contract can bill ERCOT costs as a separate ancillary or ERCOT-charges line, or fold them into a fixed energy price for the term. Staff's analysis shows why the label matters less than it looks: if the cost ever moved to generators, a separate line could shrink while the energy price rose to cover generators' recovery. Our guide to the commercial Electricity Facts Label shows where pass-through lines appear. The same contract read applies to the Winter Storm Uri securitization charge and to ERS, one of the reliability services in this study, which some commercial loads are paid to provide (our ERS winter bidding piece).

2027 session timing. The 90th Texas Legislature convenes on January 12, 2027, six weeks after the report deadline. PURA §39.1593 requires a report and nothing more, so the allocation does not change unless lawmakers pass a new bill or the PUCT acts on its own, and the staff memo recommends no change. If something does change, a change-in-law clause in a 2027 contract is what lets a provider reopen a fixed price.

The Who-Pays Test: Three Checks Before a 2027 Rate

The Who-Pays Test asks who carries the ancillary service charge in a 2027 offer, because the dollars are small but the allocation question will sit in front of lawmakers during the term of any contract signed this winter.

1. Who carries the cost today, you or your provider?

If the offer bundles ancillary and reliability service costs into a fixed price for the full term, the provider carries the swing, and that cost fell from $608.7 million in 2024 to $385.8 million in 2025. If the cost is a pass-through line, you carry it.

2. If the cost moved, which line would it come back on?

Staff found that charges moved to generators would return through energy and reserve offers. Compare offers on the all-in price per kWh, not on whether one has a smaller ERCOT line.

3. Does the contract treat a new state law as a reason to reprice?

Look for change-in-law language that names legislative or PUCT action. A contract signed before January 12, 2027 runs through a session that will receive this report.

What You Should Do

This report changes nothing on your bill today, so the useful work is a short contract read before you sign or renew for 2027.

Search your current bill, contract and Electricity Facts Label for "ancillary," "ERCOT charges," "pass-through" and "change in law."
Estimate your exposure by multiplying your annual MWh by $0.78, the 2025 level. At 600 MWh a year, that is about $468.
When you compare 2027 offers, ask each provider to confirm in writing whether ancillary and reliability service costs are included for the full term.
Judge offers on the all-in price, term length and TDU delivery charges. The ancillary service charge is a wholesale cost that providers pass through, not a delivery charge.
Do not delay a good offer to wait for the Legislature. The statute asks for a report, and staff recommended no change.

Questions to Ask Your REP or Broker

These four questions show how a provider handles ERCOT's reserve and reliability costs, which rarely appear on a rate comparison but decide who pays if the allocation ever changes.

Are ERCOT ancillary and reliability service costs included in the fixed price for the whole term, or billed as a separate line?
If they are billed separately, how is the charge calculated for this account, and what did it come to on comparable accounts in 2025?
Can the price change during the term if the Texas Legislature or the PUCT changes how these costs are allocated?
If a separate ERCOT line fell because generators took on part of the cost, would the energy price stay fixed?

We will follow Project 58555 through the December 1 report. Subscribe to Weekly Market Insights, free. We publish a data-driven rate report every Monday.

To compare offers for your meter, browse Texas commercial rates by TDU or see every commercial plan we track in our data download.

Frequently Asked Questions

What are ancillary service charges on a Texas business electricity bill?

Ancillary service charges are a business's share of what ERCOT pays for reserve and reliability services, recovered by its retail provider either as a separate line or inside the energy price. Load-serving entities paid $385.8 million for ancillary plus reliability services in 2025, about 0.078 cents per kWh. It is a wholesale cost, not a TDU delivery charge.

Who pays ERCOT ancillary and reliability service costs today?

Load pays 100 percent of them. ERCOT allocates the costs to the QSEs that represent load, by load ratio share, and allocates none to generation. PUCT staff recommended keeping that method on October 29, 2026.

Would moving the costs to generators lower business electricity bills?

Not according to PUCT staff. Their October 29, 2026 memo found that none of the three alternatives is expected to yield net consumer savings, including the two that would shift about 60 percent of the cost to generators, because generators would recover the charge through higher energy and reserve offers.

When is the PUCT report due to the Legislature?

The report is due no later than December 1, 2026, under PURA §39.1593. The 90th Texas Legislature convenes on January 12, 2027. The statute requires only a report and does not change how the costs are allocated.