Who pays for the grid Texas builds for data centers?

What the survey respondents requested

ERCOT’s November 2026 community-impact review covered 429 loads requesting 177.4 GW. That included 243 large loads requesting 166.1 GW and 186 medium loads requesting 11.3 GW. The counts and requested megawatts describe the surveyed population. Actual demand depends on which projects secure sites and financing, get through interconnection, and switch on equipment. ERCOT has likewise cautioned that its preliminary 2026 long-term load forecast incorporated submissions above its own expectation of future growth. ERCOT November community-impact update. ERCOT’s preliminary load forecast release.

Even for connected sites, individual peaks can occur on different days or hours. Adding those peaks measures the sum of the sites’ individual highs. A transmission planner needs to know what they demand together at the hours the network is most constrained.

How transmission costs reach the bill

Texas Senate Bill 6 and the implementing rule formalize customer commitments and direct cost responsibility. Financial security and a permanent construction contribution have different effects. Security gives the utility a way to collect under stated conditions. A permanent contribution can reduce the utility-financed capital on which customers pay a return. Recurring maintenance and taxes on utility-owned facilities can still enter rates. Texas SB 6 enrolled text. PUCT adopted interconnection rule.

What a billion-dollar project costs in a year

Dividing the construction price by the number of households overstates what the project costs in a single year and ignores the other customers who pay. A simplified first-year model starts with depreciation, adds a return on the average financed asset value, and adds operating expenses and taxes.

At $1 billion in service, a 40-year straight-line life gives $25 million in annual book depreciation. Assume a 7% financing return on $987.5 million of average net plant in the first year, $10 million of operating costs and $5 million of other taxes. These components total about $109.1 million for the year, before income-tax and deferred-tax adjustments. A different asset life, financing structure, in-service date or customer contribution changes the result. This calculation illustrates the mechanism and does not assert what the commission would allow for any project.

To turn an approved cost into a bill effect, start with the annual amount eligible for recovery, isolate the share attributable to the utility and the residential class, and divide by the appropriate billing units. Then apply the resulting delivery-rate change to a household’s billed usage. Statewide queue capacity does not determine any of those steps.

Who carries cancellation risk?

Before construction, a customer’s agreement and financial security determine which study and equipment costs the utility can recover if the customer cancels. Once a shared project is in service, regulators decide whether the utility can recover the remaining investment under the applicable rate rules. The answer depends on the project and its regulatory record. The public planning estimate is a starting point for that inquiry. PUCT large-load rule. PUCT transmission cost rule.

Method and limits

The figures describe reviewed survey responses. The worked example is illustrative. A household forecast would require approved project costs, in-service dates, the participating utilities’ tariffs and a defensible share assigned to the new data centers.