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AI data centers can attract substantial demand and capital yet still fail to become operating assets on schedule. Investors need to assess more than customer demand and power capacity: permits, grid access, water, local acceptance, cost allocation and insurance can all affect whether a project is built, energized and economically viable. The backlash is a site-specific execution and policy risk—not evidence that every planned facility will be cancelled or that the whole sector faces the same outcome.
Why are communities pushing back?
For host communities, the debate is often about practical local impacts rather than AI in the abstract. Data centers can require large amounts of electricity and cooling water, and their effects may intersect with grid reliability, utility bills, land use, noise and neighborhood conditions. Residents may also question whether they were consulted early enough or whether a project’s infrastructure costs will be borne by its developers or by other ratepayers.
MSCI reported that local opposition topics shifted toward water use, zoning and energy affordability between the first half of 2025 and the first half of 2026. Arizona’s Attorney General’s Office has likewise cited grid pressure, electricity bills, water demand, nearby temperature impacts and insufficient community consultation. Associated Press reporting describes concerns across political affiliations; some labor representatives and local supporters also point to construction work and operating jobs. That mix makes it misleading to treat opposition as either uniformly partisan or simply anti-AI.
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These figures describe different locations, dates and measures. They indicate exposure and reported disruption, not a common estimate of sector-wide losses or the odds that any particular project will fail.
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| Measure | Reported figure | Scope and interpretation |
|---|---|---|
| Share of global data-center capacity under construction located in the U.S. | 70% | MSCI Research, 2026. A share of capacity under construction, not a measure of completed capacity or investment losses. |
| Wait for new power projects | 64 months on average | MSCI Research, 2026, for regions where data centers are being developed. A regional average, not a guaranteed wait for every project. |
| Median capacity of newly built data centers | 11 MW in 2016; 130 MW by June 2026 | MSCI Research. The change in median facility capacity indicates that newer projects can have larger power requirements; it does not establish the load of any named project. |
| Delayed or cancelled U.S. projects | At least 75 in Q1 2026 | MSCI Research’s tracked-project count, equal to its stated total for all of 2025. It is not a universal census, a count of cancellations alone or a dollar-loss estimate. |
| Projects exposed to legislation | Around 80% | MSCI Research reported that this share of U.S. data centers under construction or planned were in jurisdictions with active or pending data-center-related legislation. |
| Projects in counties with prior withdrawals or data-center-specific rules | 52% | MSCI Research’s project-location measure. It does not mean that this share of projects will be withdrawn or restricted. |
| Electricity rates in Oregon | 29% increase for data-center corporations, with decreases for other Portland General Electric ratepayers | The Oregon Governor’s Office said this followed the POWER Act, signed in 2025. The figure concerns that utility service area and should not be generalized nationally. |
| Potential Phoenix-area data-center water demand | More than 450% increase if all planned projects are built | Arizona’s Attorney General’s Office attributed this projection to a 2025 analysis. It is a conditional forecast, not an observed increase. |
How does backlash turn into investment risk?
Schedule and energization
A completed building cannot generate expected operating revenue until it has the power and approvals it needs. Grid queues, permitting disputes or local opposition can therefore extend the period before a project is usable. On-site generation may bypass some grid-connection constraints, but MSCI notes that equipment limits and first-of-a-kind technologies introduce their own delivery and execution risks.
Capital costs and who pays
Transmission, generation and interconnection expenses can change project economics, especially when the rules for assigning those costs are unsettled. A proposal that assumes other ratepayers or the wider grid will absorb part of the bill may face regulatory or political resistance. Conversely, a clear cost-allocation framework can reduce uncertainty while still leaving developers with significant infrastructure obligations.
Permits and policy changes
Local zoning decisions, proposed moratoria and state directives can affect approvals, but their legal status matters. A proposal is not an enacted restriction, and a directive to gather information or pause certain approvals is not automatically a permanent ban. Investors should track which government has authority, what types of applications are covered, when a measure takes effect and whether it is still being implemented.
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Cooling design and water supply need to be assessed against local conditions, not just a project’s stated efficiency. MSCI also identifies water scarcity and river-flow exposure as diligence concerns. Physical hazards and insurance availability can affect resilience and operating costs as well. MSCI identifies insurance gaps as a risk category, but the available figures do not quantify losses from backlash attributable to insurance shortfalls.
Community acceptance and viability
Organized opposition can combine with changing government expectations to alter a project’s path, even after preliminary planning has begun. That creates a risk of delay, redesign or withdrawal; these outcomes should not be treated as interchangeable. One project’s experience is a warning to investigate local conditions, not a basis for assuming that projects in the same state—or elsewhere—face equal risk.
What do recent disputes and rules reveal?
The examples below show how policy and project decisions can affect development. They differ in scope and status, so investors should not treat them as a single nationwide rule.
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Texas: information requirements and a withdrawn proposal
On September 21, 2026, Texas Governor Greg Abbott directed state agencies not to advance regulatory approvals related to data-center development until required grid and water information is acquired. The directive says projects should pay electrical-infrastructure costs, report electricity and water use, and protect community resources. It set October 19, 2026, as a date for a Texas Commission on Environmental Quality update; as of October 7, that date had not arrived.
Separately, on July 23, 2026, the Governor’s Office announced that Diode Ventures would not pursue its proposed Henderson County project near Cedar Creek Lake. The office said the proposal did not meet state directives or community expectations. Diode said it would proceed only with sites aligned with infrastructure availability, community priorities and long-term viability. The office described standards including payment for electrical infrastructure, added capacity, water-efficient technology such as closed-loop cooling, setbacks and noise reduction. The Texas Tribune separately reported on local opposition and the company’s explanation that it would not advance the site beyond preliminary planning. This was a project withdrawal, not proof that all Texas proposals face the same result.
Federal grid rules: clearer processes, changing obligations
On June 18, 2026, the Federal Energy Regulatory Commission directed all six regional grid operators to justify or reform tariffs for data centers and other large energy users. Its stated reform areas include transmission application and study processes, cost transparency, co-location and behind-the-meter generation, flexible large loads, and study of generation serving large loads. The action could make access and cost allocation clearer; it can also change project obligations and economics as operators respond. FERC Chairman Laura V. Swett said the Commission could integrate large energy users while protecting consumers: “We can facilitate both, which is exactly what we did today.”
Oregon: rate allocation under a state law
The Oregon Governor’s Office said the 2025 POWER Act led to higher electricity rates for data-center corporations and lower rates for other Portland General Electric ratepayers. This is an account of the act’s effect in that utility’s service area, not a prediction of how every utility will allocate costs.
Dane County: a proposed moratorium
A May 2026 Dane County notice described an introduced resolution for an 18-month moratorium on applications and zoning permits in towns subject to county zoning while the county continued its research. At the time of the notice, it was a proposal. The release excluded cities, villages and towns with their own zoning codes, so the proposal’s stated reach was limited.
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Arizona: a call for a pause
Arizona’s Attorney General called for a statewide pause and cited electricity bills, water use, cooling and public consultation. The office’s projection about Phoenix-area water demand is conditional on all planned projects being built; it should not be read as evidence that demand has already risen by that amount or that a pause was enacted.
Independent reader supportYour contribution helps us test, update, and keep practical guides available for everyone.How should investors compare individual projects?
Project-level diligence is more useful than applying one sector-wide backlash discount. Compare projects on the same evidence and development stage, and distinguish confirmed arrangements from estimates, proposals or management assumptions.
- Verify power access. Check the grid-connection status, expected energization date and queue assumptions. Ask whether the date depends on transmission or generation upgrades, and how delays affect the operating schedule.
- Trace the cost allocation. Identify who pays for interconnection, transmission and generation, and whether those terms are approved, proposed or assumed. Review how applicable tariffs and large-load rules could change the arrangement.
- Assess the power plan. Establish the source of electricity and, where on-site generation is planned, its equipment availability, readiness, permitting and delivery dependencies.
- Test water assumptions. Document the water source, cooling design and expected demand, then compare them with local scarcity and any applicable reporting or use requirements.
- Map approvals and political exposure. Confirm current permits and zoning, identify pending moratoria or legislation, and note relevant rulemaking and election timelines. Separate adopted requirements from introduced proposals.
- Review community engagement. Look for documented consultation, opposition history and unresolved concerns about affordability, land use, noise, setbacks or local resources.
- Evaluate physical and insurance exposure. Consider site hazards, resilience requirements, coverage availability and exclusions alongside the project’s operating assumptions.
- Connect each risk to project value. Determine which risks could cause delay, redesign, higher capital or operating costs, or withdrawal, and whether those outcomes are reflected in the project’s schedule and financial assumptions.
This framework is a way to compare candidates, not a rating of any particular company. A project with documented grid arrangements, credible water plans and a workable local approval path may have a different risk profile from a proposal whose critical inputs remain uncertain, even if both are described as AI infrastructure.
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