US efforts to curb speculative datacenter development and interconnection-queue buildup gain legislative ground.

Community opposition has emerged as a major barrier to data center development, alongside construction labor shortages, extended lead times for critical electrical equipment, limited power availability in key markets, and uncertainty around consumer demand for artificial intelligence tools.

More than $170 billion in AI data center capacity has been "blocked, withdrawn, or stalled" by community opposition since January 2024, according to the energy advisory company Relae, formerly Carbon Direct. This represents a sizable portion of the roughly $581 billion that Goldman Sachs expects major tech hyperscalers to spend in the U.S. on AI infrastructure, including data center construction, this year.

Despite these headwinds, market analysts see no sign that the AI-driven construction boom will disappear. Goldman Sachs forecasts that U.S. data center power demand will more than double from 2025 levels to reach 66 GW in 2027, with only about half of capacity scheduled for the next one to two years expected to come online on time amid delays and cancellations. The Electric Power Research Institute estimates that data centers will represent 9% to 17% of U.S. electricity demand in 2030 and up to 20% by 2035.

Public backlash against data centers, fueled partly by their enormous energy demands, is driving state-led efforts to impose stricter rules on development, up to and including moratoriums on new facilities. This growing uncertainty around the scale, timing, and location of new data center load presents challenges not only for utility planners and regulators ensuring the electric grid is neither over- nor under-built, but also for millions of other customers who could bear the consequences of a disorderly buildout.

Many utilities and their regulators have turned to large-load tariffs to weed out speculative requests by requiring minimum contract durations, minimum billing demand, collateral requirements, upfront payments for impact studies, exit fees, and specific ramp schedules. Some states have introduced incentives for developers that bring their own capacity, agree to be flexible in energy use, or commit to state clean energy or economic development goals.

Texas presents a particularly urgent challenge. The state has paused new data center interconnections pending an audit of its 474-GW queue—more than five times the Texas grid's recent all-time peak demand record of just over 90 GW set during summer 2026. Few experts expect all that load to materialize. Pablo Vegas, president and CEO of the Electric Reliability Council of Texas, called the forecast "higher than expected future load growth," citing uncertainty around protocols for identifying, verifying, and incorporating large load demand into long-range planning.

Thomas Gleeson, chairman of the Public Utilities Commission of Texas, was more direct: "The projections are extremely high, and what we know is that a lot of that load will not actually come here. A lot of it is speculative."

The sheer number of large-load interconnection requests compounds Texas's challenge. Load growth from large computing and industrial loads, along with routine residential and commercial demand, is creating congestion in load pockets that previously had spare capacity. This creates unwelcome uncertainty for large-load customers ready to commit to construction.

"When a customer has an interconnection agreement and they are ready to move forward, they need to know that the capacity will be there to serve them so they can make proper business decisions," Gleeson said.

Texas developed "gating" conditions to discourage speculative interconnection requests, balance load and capacity, and "make sure that no one is harmed by these large loads." Last summer, Governor Greg Abbott signed Senate Bill 6, requiring prospective large-load customers to demonstrate site control, substantially cover necessary grid upgrades, disclose duplicative interconnection requests elsewhere in Texas, and accept curtailment during firm load shed events, among other provisions.

On June 18, the PUCT adopted a cluster study framework for prospective loads larger than 75 MW designed to streamline the "lengthy and repetitive" sequential study process as ERCOT stakeholders develop a comprehensive transmission planning framework. ERCOT expected to publish a final transmission plan for the first study cluster, "Batch Zero," in late 2027.

Gleeson said the cluster study and transmission planning frameworks would mitigate uncertainty for large loads, grid operators, and generation owners. Together, they assure loads that "once they interconnect, they will get the electricity they need to fully energize," and assure other stakeholders that "all the loads coming here are real and will stay."

However, in August, Abbott effectively directed the grid operator to freeze new interconnection approvals until completing an audit of all data centers in the queue. ERCOT responded by delaying the Batch Zero process. The grid operator aims to complete the audit by December. Bloomberg NEF estimated that the interconnection pause could delay 20% of the total U.S. data center pipeline, and possibly more if extended into next year.

Large-load uncertainty affects regulated utility markets as well, where vertically integrated utilities face increasing scrutiny from state policymakers and regulators to distinguish speculative requests from those more likely to materialize. Brad Viator, president of Power for Tomorrow, a trade association for vertically integrated utilities, said many are raising load interconnection study fees as request volume increases. They are also structuring electric service agreements to prevent large loads from ramping power demand in ways that would strand costs or compromise reliability for other customers, such as by requiring upfront payment for substation upgrades and infrastructure.

"The structure is designed to ensure that by the time a customer reaches a contract—and certainly before any new generation is committed—the utility has high confidence they're dealing with a real project, not a tire-kicker," Viator said.

For legitimate large-load customers, vertically integrated utilities' ownership of generation, transmission, and distribution ensures adequate capacity and maintains reliability as they interconnect. This translates into comparatively short interconnection queues in regulated utilities—one to five years compared with eight or more in deregulated portions like PJM Interconnection, where new generation procurement faces additional complexity.