A U.S. nuclear plant can raise its maximum operating power only after its owner supports the proposed higher limit with engineering and safety analyses and receives approval from the Nuclear Regulatory Commission (NRC). The work may involve better instrumentation, fuel and operating-limit changes, or major upgrades to equipment that moves steam and water; the exact scope depends on the plant and the size of the increase.
What a power uprate changes
The NRC regulates the maximum power level at which a commercial nuclear power plant may operate. A power uprate changes that licensed ceiling, recorded in the plant’s license and technical specifications. It is not simply a turbine upgrade or an operator choosing to run the reactor harder: the licensee must obtain NRC approval before operating at the higher licensed limit. See the NRC overview of power uprates.
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Uprate figures describe reactor thermal power, measured in megawatts thermal (MWt), unless stated otherwise. Electric output, measured in megawatts electric (MWe), is the electricity generated after heat is converted through the plant’s steam and turbine-generator systems. The two figures are related but not interchangeable: the amount of electricity produced depends on the plant’s conversion systems and conditions.
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The NRC groups uprates into three categories. These are general descriptions, not a guarantee that a specific plant can achieve a particular increase; its design, analyses, and available margins determine what is feasible. The agency’s Types of Power Uprates page describes the categories as follows:
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| Category | Typical scale | Typical focus |
|---|---|---|
| Measurement uncertainty recapture (MUR) | Less than 2% | More precise measurement of feedwater flow and revised power calculations reduce measurement uncertainty. |
| Stretch | Typically up to 7%; the plant’s design margins set the actual limit. | Often involves instrumentation setpoint changes and generally does not require major plant modifications. |
| Extended power uprate (EPU) | Above the stretch range; the NRC reports approvals as high as 20%. | Usually requires substantial changes to major balance-of-plant equipment. |
Measurement uncertainty recapture
A MUR project improves the accuracy of measurements used to calculate reactor power, commonly by improving feedwater-flow measurement. With less uncertainty in the power calculation, the analyses can account for a smaller measurement margin. This category is below 2%, not a general-purpose way to add a large amount of capacity.
Stretch uprates
A stretch uprate raises the licensed ceiling within the design margins of the existing plant. Instrumentation setpoints commonly change, while major equipment work is generally not required. “Up to 7%” is a typical category description, not a promise for every reactor.
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Extended power uprates
An EPU goes beyond the stretch range and typically calls for a broader engineering and equipment program. The NRC’s report that some approved increases have reached 20% describes the upper end of approvals, not what is generally available or suitable for any particular plant.
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More reactor thermal power produces more heat and, in turn, more steam for the turbine-generator. That can mean greater steam and water flows through systems that convert heat into electricity. The licensee must demonstrate that affected equipment, operating limits, and safety analyses remain adequate for the proposed conditions.
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Depending on the plant and uprate scope, work may include:
- Measurement and instrumentation: MUR projects use improved feedwater-flow measurement and revised power calculations; stretch uprates commonly involve instrumentation setpoint changes.
- Fuel strategy: Some projects use slightly more enriched uranium fuel or a higher proportion of new fuel. These are common approaches described by the NRC, not requirements for every uprate.
- Steam and water systems: Higher flows may require modifications to or replacement of condensate pumps and motors, pipes, valves, or heat exchangers.
- Turbine-generator equipment: Depending on the original equipment and proposed output, changes may involve the high-pressure turbine, main generator, or transformers. A major turbine replacement is one possible scope, not a default requirement.
The NRC’s background on power uprates explains the power-conversion systems and cost drivers. A list of possible modifications should not be read as a checklist of equipment every plant must replace; the engineering case is specific to the proposed operating conditions and the plant’s existing design.
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How the NRC licensing and safety review works
The licensee submits a license amendment request (LAR) to change the authorized maximum power level and relevant technical specifications. The NRC identifies 10 CFR 50.90, 50.91, and 50.92 as part of the governing amendment process. The request includes supporting analyses and information for the proposed plant configuration. NRC technical and legal staff review whether the plant can operate safely at the higher licensed power.
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- The NRC provides public notice. The agency’s regulatory-process description says the NRC allows 30 days for public comments and 60 days to request a hearing. A hearing request does not mean a hearing will automatically take place.
- The NRC reviews the application and public input. The review assesses the proposed changes and supporting safety case.
- The NRC issues a safety evaluation and notice of decision. It can approve or deny the request; operation at the proposed higher licensed limit depends on approval.
The NRC’s regulations and guidance page identifies LIC-112 Revision 2 as generic process guidance and lists review guidance for MUR, stretch, and extended uprates, including Review Standard RS-001 for extended uprates.
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Review targets are not full project schedules
The NRC’s Power Uprate Review Readiness page reports review targets of 12 months for an EPU, 9 months for a stretch uprate, and 6 months for a MUR uprate. The agency says these targets appeared in a May 7, 2024 letter to the Nuclear Energy Institute. They cover NRC review targets—not the full project, construction work, or a guaranteed decision date. Actual schedules depend on the application and project.
The same NRC page is the source for the review-target information.
What an uprate costs
There is no general dollar figure established by the NRC’s background material. It describes some modifications as major and costly, while noting that scope depends on the desired power increase and the plant’s original equipment design. A MUR project, a stretch uprate, and an EPU can entail substantially different work, so a single generic price would be misleading.
A defensible cost figure needs to be tied to a named project and attributable financial evidence, such as a licensee filing or project disclosure. Without that project-specific basis, the sound answer to “How much does an uprate cost?” is that the cost varies and no universal price is established here.
What the NRC’s projected application figures mean
The NRC’s Expected Applications for Power Uprates table, reviewed in 2026, lists 31 expected applications for 2026–2032, totaling 7,336 MWt and approximately 2,421 MWe. These are forward-looking expected applications and projected capacity—not completed uprates, approvals, or capacity already added to the grid.
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