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A data center can contract for electricity associated with a nuclear plant and receive power through the regional grid. A power purchase agreement (PPA) is a commercial arrangement, not a dedicated wire: the nuclear plant injects electricity into the grid, and the data center takes grid service at its own location. A direct connection or behind-the-meter setup is a separate physical and regulatory arrangement.
How can a data center use nuclear power through the grid?
The operator can sign a PPA with a nuclear generator or its owner, agreeing to buy electricity, capacity, or another defined product under the contract. The plant supplies electricity to the regional grid; the data center receives electricity through the grid connection serving its site. The contract links the buyer and generator commercially, while transmission and distribution networks deliver and balance electricity across the system.
That distinction matters because a PPA does not reserve a physical path for particular electrons to travel from one reactor to one data center. Nor does it require the plant to produce electricity at the exact moment the data center consumes it. The grid remains the physical network and balancing context, and the contract defines the parties’ commercial obligations. The specific delivery, settlement, and service terms depend on the contract and the applicable power-market and utility arrangements.
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1Clear out junk files and repair common Windows errors2Scan for outdated or missing drivers - takes under a minute3Repair Windows errors before they cause bigger problemsFor a large, continuously operating data center, a nuclear PPA can be a way to procure power associated with a generator that operates steadily. The U.S. Energy Information Administration (EIA) describes nuclear as a potential electricity source for data centers, while also noting uncertainty about how quickly data-center demand will grow and reach full load. A contract’s duration, amount, and ramp schedule therefore matter as much as the headline capacity figure.
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What is the difference between a nuclear PPA and a direct connection?
| Arrangement | Physical supply | What the contract or configuration does | Key questions |
|---|---|---|---|
| Grid-connected nuclear PPA | The plant injects electricity into the grid; the data center receives grid service at its site. | Sets commercial commitments between purchaser and generator. It does not create a direct wire. | What capacity or energy is committed, when does the commitment ramp, and what grid service and charges apply? |
| Co-located or behind-the-meter supply | A data center at or near a plant may receive some electricity directly from the generator rather than sending that portion through the wider transmission network. | Changes the physical delivery arrangement and may change transmission-service needs and allocation of grid costs. | How much load is served directly, what backup and grid services remain necessary, and what tariff and reliability rules apply? |
| Advanced nuclear supply | Depends on the eventual project design: possible models include grid delivery, private-wire supply, or a hybrid. | Would depend on a future reactor, its licensing and development, and the chosen connection model. | Is the reactor operating, or is the arrangement only an announced plan or agreement? What approvals and infrastructure are still required? |
In a grid-connected arrangement, the data center remains a grid customer at its location even if a contract names a nuclear plant. In a direct or behind-the-meter arrangement, some generation and load are physically connected in a different way. That may reduce the use of the wider transmission network for the directly served portion, but does not by itself settle how the facility obtains backup power, pays for services, or meets utility and regulatory requirements.
Co-location raises a system-wide cost question as well as a site-design question. EIA describes the argument that a large new load directly offsetting generation can be useful, alongside concerns that a co-located customer might avoid costs associated with maintaining the grid. The answer depends on the particular arrangement and applicable tariff; proximity to a plant does not automatically mean the data center can avoid grid obligations or charges.
What do the announced nuclear data-center agreements show?
EIA’s October 1, 2024 article described two different commercial examples. They illustrate how a nuclear supply agreement can be structured, but are dated reports rather than confirmation of current project delivery status.
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| Example as reported by EIA in 2024 | Reported terms | What the figures mean |
|---|---|---|
| Constellation Energy and Microsoft, involving Three Mile Island Unit 1 | Announced 20-year PPA to supply Microsoft data centers in the mid-Atlantic. | Twenty years was the announced contract duration, not a statement here about present delivery status. |
| AWS and Talen Energy’s Susquehanna plant | Agreement for 960 MW of capacity. EIA said AWS’s share would increase in 120 MW increments over multiple years and included an option to cap its commitment at 480 MW. | The 960 MW figure is the contracted capacity reported by EIA; it is not, by itself, a claim that AWS continuously consumed that amount of energy. The increments and cap describe the reported ramp and option. |
These details show why readers should distinguish capacity from actual energy consumed. Capacity describes a power level or commitment; energy is power delivered over time. A contracted capacity number does not explain when the buyer takes service, how quickly its data-center load grows, or how the contract treats any difference between the commitment and consumption. Those details have to be read in the agreement and alongside the grid-service arrangement.
Why are grid access and tariffs still important?
A commercial agreement with a generator does not replace the rules for serving a large load. Depending on the configuration, the data center may still need transmission service, interconnection capacity, utility arrangements, and backup supply. In a co-location case, regulators and grid operators also have to determine how the facility’s use of grid services and its share of grid costs are treated.
In February 2025, the Federal Energy Regulatory Commission (FERC) opened a proceeding concerning whether PJM’s tariff rules for co-located generation and large loads were clear, reasonable, and consistent with reliability and consumer-cost protections. FERC Chairman Mark Christie said in the announcement: “Co-location arrangements are a fairly new phenomenon that entail huge ramifications for grid reliability and consumer costs.” That was the regulator’s stated concern; it was not a finding that a particular project had caused reliability problems or raised consumer costs.
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In a December 18, 2025 fact sheet, FERC reported that it had found PJM’s tariff unjust and unreasonable because the tariff lacked clarity and consistency about rates, terms, and conditions for serving co-located load. FERC directed PJM to revise its tariff. The fact sheet listed transmission-service options, including network integration service and proposed firm or non-firm contract-demand service, and said the order addressed reliability reporting and transition arrangements.
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This action concerns PJM, the regional grid operator involved in that proceeding. It should not be read as a national rule for every U.S. utility or grid region, and the December 2025 fact sheet is a dated account of the Commission’s order, not proof that all directed tariff changes have since been implemented. A project’s location and current tariff matter.
What should a data-center buyer compare?
No one arrangement is automatically best. A buyer evaluating a nuclear-linked supply plan should compare the commercial promise with the physical path and the site’s actual load profile. Useful questions include:
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- Delivery path: Will the facility take ordinary grid service under a PPA, receive some power through a direct co-located connection, or use a hybrid? A PPA alone is not evidence of a dedicated connection.
- Contract product and schedule: Does the agreement specify energy, capacity, or both? What is the duration, ramp schedule, and any cap or option? How does the scheduled commitment relate to the data center’s expected demand at each stage?
- Grid service and charges: What transmission or network service is needed, what charges and upgrades may apply, and who pays for the services the project uses? In co-location arrangements, confirm the applicable tariff rather than assuming a direct connection removes costs.
- Reliability and backup: What supplies the facility when the associated plant is unavailable, the data center’s load exceeds the contracted amount, or the physical configuration cannot serve the load? The PPA and the site’s reliability plan answer different questions.
- Project readiness: Is the generator already operating, is a restart or other approval needed, or is the proposal a future advanced reactor? A signed agreement or announcement is not the same as an operating plant delivering power.
- Jurisdiction: Which grid operator, utility, and regulator govern the site and arrangement? FERC’s cited co-location action is PJM-specific; rules in other U.S. regions or countries may differ.
- Cost evidence: Compare costs using the project’s actual contract, connection, transmission, and reliability assumptions. The cited official material does not establish a universally cheaper model or directly comparable project costs.
Load forecasting deserves particular care. EIA notes uncertainty in data-center buildout, the time needed for facilities to ramp to full demand, and the effect of efficiency improvements. If demand arrives more slowly than expected, a long-term commitment may not match the facility’s actual usage profile; if it grows quickly, the contract and available grid service must still align with the required supply. The point is not that any one mismatch is inevitable, but that an announced megawatt figure alone cannot show whether a procurement plan fits the site.
Independent reader supportYour contribution helps us test, update, and keep practical guides available for everyone.Can future small modular or advanced reactors supply data centers?
They may, but future supply must be distinguished from operating supply. The U.S. Department of Energy (DOE) identifies licensing, demonstration and deployment timelines, first-of-a-kind costs, fuel supply, and spent-fuel storage as challenges for nuclear-powered data centers. A proposed reactor, project announcement, or commercial agreement does not establish that a reactor is licensed, built, operating, or delivering electricity.
Possible configurations are not limited to one model. The UK Department for Energy Security and Net Zero’s advanced nuclear framework discusses supplying electricity to the grid, private-wire supply to data centers, and hybrid models. Its planning, grid-connection, regulatory, and financing details belong to the UK context; they should not be treated as U.S. rules. In either country, the choice between grid supply and a private connection is a separate question from whether a proposed reactor can be developed and brought into service on the required schedule.
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How large could data-center electricity demand become?
DOE’s Office of Electricity page cites an Electric Power Research Institute estimate that data centers could account for up to 9% of U.S. electricity generation by 2030, compared with 4% of total load in 2023. This is a forecast attributed by DOE to EPRI, not an EIA statistic or a settled outcome. The two figures also use the wording reported by DOE—generation for the 2030 estimate and total load for the 2023 comparison—so they should not be presented as a like-for-like measured trend without further qualification.
The estimate helps explain why large-load procurement and grid rules are receiving attention, but it does not determine which projects will be built or how much nuclear generation they will use. A data center’s own demand, location, timeline, and available grid service remain central to evaluating a particular agreement.
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