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Fix the driver behind crashes, sound loss and screen glitchesFind Drivers →Repair Windows errors before they cause bigger problemsFix Now →Scan for outdated or missing drivers - takes under a minuteDriver Scan →Nuclear plants generate electricity at a steady rate for long stretches, and data centers draw power around the clock. That match explains most of the interest. A nuclear deal, however, does not automatically mean a data center sits beside a reactor, uses the same electrons at the moment they are generated, or runs without interruption. Operators reach nuclear output through a contract, through the regional grid, through a direct connection to a nearby generator, or through a combination of these. Each route changes how the power is metered, who pays for transmission, and what a reliability promise actually covers.
In short, nuclear supply can anchor a data center’s electricity, but reliability at a specific facility still depends on the grid, plant maintenance, the building’s electrical design, and its backup systems.
Why nuclear matches a data center’s load
The U.S. Energy Information Administration (EIA), in an October 1, 2024 article, reported that data centers typically need a steady electricity supply at all hours. Nuclear plants run continuously, which suits that profile. The fit has a limit: nuclear plants have difficulty ramping output up and down to follow variable demand, and they do have outages. The U.S. Department of Energy’s Office of Nuclear Energy put the core idea more briefly in an April 8, 2025 article: “Data centers never sleep and neither do nuclear power plants.”
Nuclear also plays a large role in the wider power system. The International Energy Agency (IEA), in its 2025 report The Path to a New Era for Nuclear Energy, put nuclear’s share of global electricity at 9% in 2023. That figure describes the whole electricity system, not the data-center sector, so it should not be read as the share of data-center power that comes from nuclear.
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Nuclear’s direct operating emissions are low. The “carbon-free” language used by companies and agencies refers to emissions at the point of generation. It does not mean zero lifecycle emissions, and it does not resolve questions about uranium enrichment or spent fuel.
Reading capacity, energy and contract numbers
Much of the confusion in coverage of these deals comes from mixing units and contract terms. The table below defines the terms used in the rest of this article.
| Term | What it measures | How to read it in a deal |
|---|---|---|
| Megawatt (MW) | A rate of power at a given moment (capacity) | Talen’s Amazon contract is stated as up to 1,920 MW; that is a maximum rate, not a total of energy delivered |
| Megawatt-hour (MWh) | Energy delivered over a period of time | Not stated for the Talen contract in the sources reviewed; do not convert the MW maximum into an annual energy total |
| Power purchase agreement (PPA) | A contract to buy electricity, which may be tied to a particular plant | Describes who buys and on what terms, not the physical path of each electron |
| Contract maximum and ramp schedule | The most the buyer may receive and the timeline for reaching it | Full volume may be scheduled for a future date rather than delivered today |
| Planned SMR capacity (GW) | The total of announced reactor plans | Plans at different stages of maturity, not installed capacity |
How nuclear power reaches a data center
Two physical models sit beneath most of these deals: grid-delivered supply and direct connection. A contract such as a PPA can be layered on top of either one, so it is worth separating the paperwork from the wires.
The contract layer: power purchase agreements
A PPA is a commercial agreement to buy electricity, and it may be tied to output from a specific plant. It does not make the buyer and the generator neighbors, and it does not require the data center to consume the plant’s output at the same moment the plant produces it. Physical delivery runs through the regional grid under the transmission and retail arrangements that apply in that region. The contract tells you who is buying and on what terms; the grid determines how the electricity travels.
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Grid-delivered supply
In a grid-delivered arrangement, the plant’s output enters the regional grid and reaches the customer through utilities and transmission providers. Talen’s June 2025 description of its Amazon arrangement shows how this works in practice: Susquehanna would supply power to the PJM grid, Talen would act as retail electric generation supplier to Amazon, and PPL Electric Utilities would handle transmission and delivery. Because the power moves across the wider network, the transmission and delivery rules of that region govern the charges.
Direct connection and co-location
A directly connected data center takes power from a nearby generator without sending all of that power through the larger transmission system. This can change which transmission services the facility uses and who pays for them. Utilities and regulators have raised concerns that some such arrangements can avoid charges that support the grid, or shift costs onto other customers. “Behind the meter” and “co-located” describe the physical setup. They do not by themselves settle metering, tariff, or cost treatment, and they should not be read as an automatic exemption from grid costs.
Checking a deal: questions that separate the models
Use these questions to see which model a project actually uses and what it implies for cost and reliability.
| Question | Grid-delivered supply | Direct connection |
|---|---|---|
| Who delivers the power to the facility? | Utilities and transmission providers under regional rules (in Talen’s Amazon case, PPL Electric Utilities) | A nearby generator; the role of any utility is not stated in general terms in the sources reviewed |
| Who pays for transmission? | Set by regional transmission and retail rules | Depends on tariff design, which is a central concern for regulators |
| What reliability does the facility inherit? | Grid delivery reliability plus the plant’s own availability | Depends on the connection design, the generator’s outages, and the facility’s backup systems; no general rule is established |
| What should a filing disclose? | Delivery schedule, retail supplier role, and transmission changes | Interconnection terms, tariff treatment, and whether the arrangement is co-located |
Real projects and what their status allows you to say
Announcements, contracts, and operating plants are different milestones. The three examples below are described as of their source dates, and each should be checked against current filings before a later operational claim is made.
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Susquehanna and Amazon Web Services
Talen’s June 2025 agreement expanded an earlier relationship with Amazon Web Services (AWS). Talen’s 2025 annual report on Form 10-K, filed with the SEC in 2026, describes up to 1,920 MW of nuclear power annually through 2042, with options to extend. The delivery schedule ramps toward the full contracted volume no later than 2032, and potentially sooner. The revised contract includes minimum commitments.
Two points keep this example accurate. First, 1,920 MW is the full contract quantity, not an amount already delivered in full. Second, the filing describes a planned transition away from the original co-located arrangement toward front-of-the-meter delivery after transmission reconfiguration, with full transition expected in spring 2027. That is a reported expectation; treat it as a milestone to verify rather than a completed change.
Three Mile Island Unit 1 and the Crane Clean Energy Center
EIA’s October 2024 account described a 20-year PPA between Constellation and Microsoft tied to restarting Unit 1, which the project also refers to as the Crane Clean Energy Center. At that time, the target was to reopen the unit in 2028, subject to approval from the Nuclear Regulatory Commission (NRC) and state and local authorities. Neither that account nor DOE’s April 2025 overview shows the unit delivering electricity to Microsoft’s data centers today.
Reader caution: the 1979 Three Mile Island accident involved the adjacent Unit 2, not Unit 1, according to EIA. Restart coverage should keep the two units distinct.
Small modular reactors and microreactors
The IEA’s 2025 report identifies up to 25 GW of planned small modular reactor (SMR) capacity, much of it aimed at meeting data-center electricity demand. The IEA notes that these plans are at different stages of maturity. That figure measures plans, not installed capacity.
DOE’s September 24, 2024 announcement of GAIN vouchers funded laboratory work for early technical studies and site identification related to microreactors and data centers. That is evidence of research and development, not commercial deployment. DOE’s April 2025 overview says licensing, demonstration, and deployment of new designs take years, and that widespread commercial advanced reactors were likely to arrive in the 2030s.
Reliability: what nuclear supply does and does not guarantee
Nuclear output is firm, which makes it a good match for constant load. It does not make a data center’s power uninterruptible. DOE’s April 2025 article cites a “99.999%+” reliability need for data centers. That is a service target a facility may require, not a measured result for any nuclear-backed site. Five nines allows roughly five minutes of interruption a year, so the figure is demanding and should be read as a requirement rather than an outcome.
Facility reliability depends on several layers:
- Transmission and distribution: the wires that carry power to the site, including any grid event that interrupts delivery.
- Plant availability: planned refueling and maintenance, plus forced outages that occur without notice.
- Electrical architecture: how the building is fed, switched, and redundant internally.
- Backup generation or storage: the systems that carry load during an interruption, and how they are tested.
- Operating procedures: load management, maintenance scheduling, and response to faults.
For restart or new-build proposals, construction schedule and regulatory approval also determine whether supply arrives when expected. For advanced designs, fuel availability and spent-fuel management are part of the deployment picture.
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Who pays: grid rules under review
On June 18, 2026, the Federal Energy Regulatory Commission (FERC) announced tailored show-cause orders to all six regional grid operators. Each operator must defend its existing tariffs or propose changes for data centers and other large electricity users. The areas listed in the action include:
- efficient transmission studies;
- prevention of cost shifting and transparency about transmission costs;
- co-location and behind-the-meter generation;
- flexible large-load service; and
- study of generating facilities that serve electrically proximate or co-located loads.
FERC Chairman Laura V. Swett said: “We are setting the stage for a resilient, reliable, and forward-thinking grid that empowers communities and safeguards consumers by transforming the way large energy users access the grid.” That is the Chairman’s description of the Commission’s aim, not an independent finding about nuclear reliability. The orders start a process; they do not settle every regional tariff question, so outcomes will differ by grid region.
Independent reader supportYour contribution helps us test, update, and keep practical guides available for everyone.What it means for household bills and investors
This section is education, not a recommendation to buy or sell any security or to change any energy contract.
Household bills
Nuclear supply does not automatically raise or lower a household’s electricity bill. The question is how the costs of serving large loads are allocated. If a data center’s arrangement adds transmission or grid-upgrade costs, and tariffs do not assign those costs to the data center, other customers may pay part of them. Utilities and regulators have raised exactly this concern, but the sources reviewed do not measure its effect on any particular bill. The practical check is your own utility’s tariff or rate filings, and whether they address charges for large loads.
Generator revenue and contract risk
For plant owners, a long-term PPA converts part of the output into contracted revenue. Talen’s president and CEO, Mac McFarland, described the Amazon agreement in June 2025 as designed to provide “a long-term, steady source of revenue and greater balance sheet flexibility through contracted revenues.” That is a company’s account of its commercial rationale, not an independent assessment of costs or system effects.
For investors, the key distinction is between a contract ceiling and delivered revenue. Ramp schedules, minimum commitments, and transition timing decide when money actually flows. A 1,920 MW maximum is the ceiling of the contract, not a forecast of earnings.
Timing and construction risk for new reactors
Restarts and new reactors face approvals, construction, financing, fuel supply, and spent-fuel management. A deal signed today can therefore carry a delivery date several years away, and the public-interest questions around cost allocation, financing risk, and waste remain open policy issues.
Signals to watch
- Talen’s SEC filings for progress on the AWS delivery ramp and the planned transition to front-of-the-meter delivery.
- FERC proceedings that follow the June 18, 2026 orders, and tariff filings from each regional grid operator.
- NRC project status for the Three Mile Island Unit 1 restart, which determines whether the announced timeline holds.
- IEA and DOE updates on SMR plans, to separate announced capacity from installed capacity.
The Bottom Line
Judge any nuclear-data center announcement by three tests: whether the claim describes delivered power or a contract, which party pays for the wires and any grid upgrades, and what date the milestone is tied to. A steady generation profile is a real advantage, but it does not replace those checks.
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