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Is nuclear power cheaper than natural gas?
It depends first on whether you mean building new plants or operating plants that already exist. For a new-build comparison, the U.S. Energy Information Administration (EIA) models costs for resources entering service in 2031. Its AEO 2026 Counterfactual Baseline estimates are scenario outputs, not project bids or operating costs for existing plants. The report’s chart gives approximate regional ranges in 2025 dollars per megawatt-hour (MWh):
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| New technology in the EIA comparison | Approximate regional range | Simple-average marker | Capacity-weighted marker |
|---|---|---|---|
| Advanced nuclear | $80–$100/MWh | About $88/MWh | About $110/MWh |
| Natural-gas combined cycle | $68–$95/MWh | About $95/MWh | About $78/MWh |
These are approximate readings from the EIA’s AEO 2026 levelized-cost report, for its named case and 2031 service date. The two average markers summarize the displayed regional estimates in different ways; neither is a guaranteed price for a particular project. The ranges overlap, and the marker ordering differs, so the chart does not support a simple claim that gas is always cheaper.
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Clear out junk files and repair common Windows errorsFree Scan →Fix the driver behind crashes, sound loss and screen glitchesFind Drivers →Levelized cost is useful for comparing modeled new generation under consistent assumptions. It is not the same as the cost of continuing to run a plant whose construction costs have already been incurred, nor does it alone establish the value of a resource to a grid. Financing terms, construction execution, utilization, fuel prices, tax and policy treatment, and location can all affect the project comparison. The EIA describes its Annual Energy Outlook as analysis of alternative futures, not a set of predictions; natural-gas resource and price assumptions influence which technologies appear competitive. See the AEO 2026 narrative for that scenario framing.
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What to compare for a real project
- New construction versus continued operation of an existing plant.
- Advanced nuclear versus the specific gas design: combined-cycle units and simple-cycle combustion turbines have different roles and operating characteristics.
- Capital cost, financing, construction schedule and execution risk.
- Expected utilization, fuel costs and exposure to fuel-supply interruptions.
- The grid service required, such as steady generation, intermediate energy or fast dispatch.
- Location-specific transmission, water, regulation and policy conditions.
How much CO2 does natural gas produce compared with nuclear power?
For a lifecycle comparison—not just emissions at a plant’s smokestack—the Intergovernmental Panel on Climate Change (IPCC) reported 2014 median estimates of 12 grams of CO2-equivalent per kilowatt-hour (gCO2e/kWh) for nuclear and 490 gCO2e/kWh for natural-gas combined-cycle electricity. The ranges in the same IPCC table were 3.7–110 gCO2e/kWh for nuclear and 410–650 gCO2e/kWh for combined-cycle gas. These are assessed literature estimates, not measurements from one plant or a guarantee for every facility. The values and ranges appear in the IPCC’s Climate Change 2014, Working Group III, Chapter 7.
CO2-equivalent includes greenhouse gases beyond carbon dioxide, weighted under an assessment method; it should not be read as a carbon-dioxide-only stack figure. The IPCC identifies fugitive methane from the fossil-fuel supply chain as a major indirect contribution for fossil technologies. As a result, gas lifecycle emissions depend on upstream leakage and its treatment, as well as plant efficiency and operation. The cited figures establish a large difference in the assessed lifecycle medians, not the exact emissions of a particular project.
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Which is more reliable, nuclear or natural gas?
That depends on what “reliable” means. Annual energy production, the ability to dispatch on demand, availability during a particular peak hour, and contribution to grid reliability are related but distinct measures.
Nuclear: high annual output, with outages to plan around
The EIA reports a 91% average capacity factor for the U.S. nuclear fleet in 2025. Capacity factor compares actual generation over a period with the maximum generation possible if a plant ran at full output continuously; it is an annual operating statistic, not the probability a plant will be available at a particular moment. The EIA says reactors generally operate near generating capacity and typically reduce output for refueling every 18 to 24 months, usually scheduling those outages in lower-demand seasons. Planned refueling and unplanned outages still matter when assessing availability. See the EIA’s U.S. nuclear industry explainer and its capacity-factor FAQ.
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Natural gas: dispatchable, but not one uniform technology
Gas generation includes distinct technologies and operating patterns. The EIA distinguishes combined-cycle units from combustion turbines: combined-cycle plants can serve base and intermediate load, while efficiency and dispatchability vary by technology and region. One gas capacity factor or operating profile therefore cannot represent every gas plant. EIA’s analysis of U.S. gas-fired generation by technology and region explains these differences.
Dispatchability means a plant can be called on to change its output within its operating limits; it does not guarantee that fuel will be available during a system emergency. Fuel arrangements, delivery infrastructure, transmission, plant outages, reserves and demand all affect whether generation is there when needed.
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Can natural-gas plants back up nuclear power?
They can provide dispatchable generation when nuclear output is unavailable or when demand exceeds other available supply. But “backup” is a grid-planning role, not a guarantee that every gas plant can instantly replace a reactor. The amount, timing and dependability of that support depend on the gas unit’s technology and condition, fuel availability, transmission, reserve capacity and the rest of the generation mix.
What are the trade-offs between nuclear and natural gas?
| Question | Nuclear | Natural gas |
|---|---|---|
| Emissions | Very low lifecycle emissions in the IPCC’s cited median estimate; the assessment includes a range. | Higher lifecycle emissions in the IPCC’s cited combined-cycle estimate; methane leakage in the supply chain is an important variable. |
| Operating role | High average annual capacity factor in the U.S. fleet; refueling and other outages affect availability. | Dispatchable generation across technologies that differ in efficiency, operating role and regional use. |
| Cost exposure | New-build estimates are sensitive to financing, construction execution, location and modeled assumptions. | New-build comparisons depend on technology, fuel-price assumptions, utilization and location. |
| Reliability question | Assess outage schedules, unplanned outages, transmission and how steady output fits demand. | Assess dispatch needs alongside fuel supply, unit capabilities, transmission and reserves. |
The table summarizes the trade-offs, not a universal ranking. For a local decision, compare projects on the same date, in the same region, with the same financing and policy assumptions, and identify whether the goal is firm energy, flexible output or another grid service. National-level cost and fleet statistics cannot by themselves determine the cheapest or most reliable choice for a specific utility or region.
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