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1Clear out junk files and repair common Windows errors2Scan for outdated or missing drivers - takes under a minute3Repair Windows errors before they cause bigger problemsA data center can buy electricity associated with a nuclear plant through a power purchase agreement (PPA) and receive electricity through the regional grid. The contract does not create a dedicated wire from the reactor, and the data center does not have to sit beside the plant. A direct or behind-the-meter connection is a different physical arrangement, with its own grid-service and cost-allocation questions.
How can a data center buy nuclear power through the grid?
The simplest route is a grid-connected PPA: a data-center operator agrees to buy electricity, capacity, or both from a nuclear generator under a commercial contract. The plant injects electricity into the grid; the data center draws electricity at its own grid connection and receives the network services available there. The contract links the buyer and generator commercially, while the grid remains the physical delivery and balancing system.
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This distinction matters because electricity on a shared grid is not delivered along a traceable path from one named generator to one named customer. A PPA does not mean that particular electrons from a reactor travel to a particular server campus. It also does not require the plant to generate at the exact moment the data center consumes power. The customer still depends on grid service, and the generator’s output is balanced with supply and demand across the system.
A contract can support a plant’s operations or a buyer’s electricity-procurement goals without changing the physical network. The parties must define what the buyer is purchasing—such as energy, capacity, or a combination—as well as duration, delivery and settlement terms, ramp schedules, and any options. Those terms are not interchangeable: a stated capacity commitment is not the same as a promise that the customer will consume that quantity of electricity at every hour.
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What is the difference between a nuclear PPA and a behind-the-meter connection?
A grid-connected PPA changes the commercial relationship between a generator and buyer. Co-location or behind-the-meter supply changes the physical arrangement: the data center is at or near a generator and may receive some electricity directly, potentially avoiding use of part of the wider transmission network for that portion of its load. A site can also combine direct supply with grid service; the labels alone do not establish how much of its load is served by each route.
| Arrangement | Physical supply | What the contract or configuration changes | Questions to resolve |
|---|---|---|---|
| Grid-connected nuclear PPA | The plant supplies the grid; the data center takes grid service at its own location. | Commercial purchase terms, which may support generator operations or investment. | Energy and capacity commitments, timing, grid service, transmission charges, and the buyer’s actual load profile. |
| Co-location or behind-the-meter supply | A nearby plant may directly supply some of the data center’s load; grid service may still matter. | The physical supply path and potentially the amount of transmission service used. | Tariff treatment, cost allocation, reliability obligations, backup supply, and responsibility for grid-related costs. |
| Advanced or small modular reactor project | Future supply could be grid-connected, private-wire, or hybrid, depending on the project and jurisdiction. | A proposed supply model; an announcement or agreement does not mean a reactor is operating. | Licensing, construction and deployment timing, financing, fuel, spent-fuel storage, and applicable grid rules. |
Co-location can let new demand directly use generation that might otherwise be sent to the grid. But a direct connection does not make reliability, backup, or grid-cost questions disappear. If a facility uses fewer transmission services for some electricity, regulators and utilities still have to determine which grid costs it should pay and what services it may rely on in other circumstances. EIA described both the potential for new demand to offset generation and concerns that co-located arrangements could avoid costs associated with maintaining the grid.
What do the announced nuclear data-center agreements show?
Examples reported by the U.S. Energy Information Administration (EIA) on October 1, 2024 illustrate the scale and variety of commercial commitments. They should be read as arrangements reported at that date, not as confirmation of current delivery status.
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- Constellation Energy and Microsoft: EIA reported an announced 20-year PPA to supply Microsoft data centers in the mid-Atlantic from Three Mile Island Unit 1. The duration describes the announced agreement; it does not, by itself, establish when or whether power is currently being delivered.
- AWS and Talen Energy: EIA reported an agreement for 960 MW of capacity from Talen’s Susquehanna plant. The arrangement described a phased increase in 120 MW increments over multiple years and included an option to cap the commitment at 480 MW. These figures describe the reported contract structure; they should not be read as the data center’s hourly electricity consumption or as proof that all 960 MW is already being supplied.
The examples show why contract details matter more than a headline capacity figure. A staged ramp can align a procurement commitment with a campus that is being built or loaded over time. An option to cap a commitment changes the buyer’s exposure. Neither feature changes the basic grid-connected PPA principle: the generator and customer can be far apart, and the grid remains the physical network between supply and demand.
Why are nuclear power and data-center demand being discussed together?
Data centers often need electricity continuously, and nuclear plants are designed to generate steadily. That overlap makes nuclear an appealing source to consider for a large, ongoing load. Nuclear generation also has no direct operational carbon dioxide emissions, although the emissions and reliability implications of a particular arrangement depend on the full system, including other generation, grid services, and backup arrangements.
Demand projections should not be mistaken for settled outcomes. A U.S. Department of Energy (DOE) page attributes to the Electric Power Research Institute an 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. The estimate is a forecast attributed by DOE to EPRI, not an EIA statistic or a guaranteed level of future consumption. Data-center construction schedules, the pace at which new facilities ramp to full demand, and efficiency improvements all make future load uncertain.
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That uncertainty affects procurement decisions. A plant’s available output and a campus’s eventual demand may not rise on the same schedule. Buyers and generators therefore need to consider ramp timing, forecast error, contract flexibility, and the treatment of electricity that is contracted but not needed at a given time. A long-term commitment can be meaningful even when it is not a one-to-one physical match for the buyer’s hourly consumption.
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What do grid rules and FERC’s PJM actions mean?
Access to the grid, transmission service, and tariff terms remain central even when a data center is located near a power plant. In the United States, the details depend on the applicable utility, grid operator, and jurisdiction; there is no single co-location rule that can be inferred from one regional proceeding.
On February 20, 2025, the Federal Energy Regulatory Commission (FERC) announced that it had opened a proceeding concerning PJM tariff rules for co-located generation and large loads. FERC was examining whether the rules were clear, reasonable, and consistent with grid reliability and consumer-cost protections. Then-chairman Mark Christie said, “Co-location arrangements are a fairly new phenomenon that entail huge ramifications for grid reliability and consumer costs.” That statement described the regulator’s concerns; it was not a finding that a particular project had caused reliability problems or raised costs.
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FERC’s December 18, 2025 fact sheet reported a later action: the Commission found PJM’s tariff unjust and unreasonable because it lacked clarity and consistency on rates, terms, and conditions for serving co-located load. It directed PJM to revise the tariff and identified transmission-service options, including network integration service and proposed firm or non-firm contract-demand service. The order also addressed transition arrangements and required reliability reporting.
Those actions are specific to PJM and the proceeding described by FERC. They should not be treated as rules for every U.S. grid, nor as proof that PJM has completed all implementation steps. A project evaluating co-location needs to establish which tariff and service options apply to its site and what the relevant regulatory process currently requires.
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No arrangement is automatically cheapest or best. The available evidence does not establish comparable project costs across grid-connected PPAs, co-location, and advanced-reactor proposals. A decision should instead test the physical, commercial, reliability, and regulatory assumptions that apply to the specific site.
- Map the supply path. Identify whether electricity will come through ordinary grid service, directly from a co-located generator for some of the load, or through a hybrid arrangement. Do not treat a PPA as evidence of a private wire.
- Separate capacity from energy. Confirm whether a commitment is expressed in MW of capacity, MWh of energy, or both. Establish the contract duration, any staged ramp, options or caps, and how the terms relate to the facility’s forecast consumption.
- Establish grid services and charges. Determine the applicable transmission service, tariff, connection requirements, potential upgrades, and how grid-maintenance costs are allocated. For co-location, clarify which services the customer still uses and which reliability obligations apply.
- Plan for reliability and backup. Identify how the facility will be served if the generator is unavailable, if its output does not match the load, or if the site needs grid support. A direct supply path does not by itself establish uninterrupted service.
- Check project readiness and timing. Distinguish an operating plant from a project that needs approvals or a restart, and distinguish both from an advanced reactor that is still being licensed or developed. Match the expected supply date to the campus construction and load-ramp schedule.
- Verify jurisdiction and current status. Confirm the local utility and grid-operator rules. FERC’s PJM action is regional; UK planning and private-wire arrangements operate in a separate national framework.
These checks help avoid a common planning error: comparing only the nuclear plant’s announced capacity with the data center’s planned demand. The relevant question is whether the contract, physical connection, grid services, timing, and reliability plan work together for the particular campus.
Can advanced nuclear reactors supply future data centers?
Small modular reactors and other advanced nuclear designs may eventually provide electricity to data centers through a grid connection, a private wire, or a hybrid model. But a proposed project, a signed agreement, and an operating reactor are different stages. DOE identifies licensing, demonstration and deployment timelines, first-of-a-kind cost, fuel supply, and spent-fuel storage as challenges relevant to nuclear-powered data centers. Those factors make advanced nuclear a longer-term possibility rather than an assumed near-term supply source.
The UK Department for Energy Security and Net Zero’s advanced nuclear framework illustrates possible models: selling electricity to the grid, using private-wire supply to data centers, or combining the two. Its planning, grid-connection, regulatory, and financing details are specific to the UK context. They should not be applied as U.S. rules.
For a buyer, the practical test is whether the proposed project has a credible route through licensing, construction, fuel arrangements, financing, and connection or private-wire approvals on a schedule compatible with the facility’s needs. Until a reactor is operating and its supply arrangement is in place, an advanced-nuclear announcement is not equivalent to delivered electricity.
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