Short answer: For new U.S. generators modeled to enter service in 2030, natural-gas combined-cycle power has the lower average levelized cost, while nuclear offers firm, continuous generation without direct operational carbon-dioxide emissions. That does not make gas the universal winner. A data center’s delivered cost and uptime depend on the site, transmission connection, fuel arrangements, contract structure, backup system, permitting schedule and the way emissions are counted.
The practical comparison is therefore between complete electricity-supply arrangements—not two fuel names on a spreadsheet. A new reactor, an existing nuclear plant under a power-purchase agreement (PPA), a utility gas contract and an on-site gas plant have different timelines, risks and prices.
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What data-center operators are actually comparing
Data centers typically need a consistent and steady supply of electricity at all hours. As the U.S. Department of Energy (DOE) puts it, “Data centers can impact regional grids given the steep increases in load size, may be geographically constrained due to latency requirements, and often require firm power sources to operate continuously.” (DOE Office of Electricity)
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- New construction versus an existing plant: a newly built reactor has a different schedule and capital burden from buying output from an operating nuclear station.
- Generation cost versus delivered electricity cost: a plant’s levelized cost does not include every transmission, capacity, interconnection, balancing or backup charge a data center may pay.
- Firm energy versus flexibility: nuclear is designed for sustained output; gas units can generally dispatch and ramp more readily.
- Direct emissions versus lifecycle and purchased-electricity accounting: the boundary chosen for carbon reporting changes the result.
The right question is not simply “Which fuel is cheaper?” It is “Which supply portfolio can deliver the required megawatts, reliability, schedule and emissions performance at this location and under this contract?”
Modeled cost for new U.S. generation entering service in 2030
The U.S. Energy Information Administration’s (EIA) Levelized Costs of New Generation Resources in the Annual Energy Outlook 2025 models resources entering service in 2030. Its figures are in 2024 dollars per megawatt-hour (MWh), include levelized tax-credit components for eligible technologies and represent the cost to build and operate a plant—not a data-center tariff or retail bill. (EIA AEO2025 LCOE report)
| Resource modeled by EIA | Simple-average LCOE | Capacity-weighted average | What the number means |
|---|---|---|---|
| Advanced nuclear | $81.45/MWh | Not stated; the modeled technology had no 2030 additions for this calculation | Average modeled cost for advanced-nuclear resources entering service in 2030 |
| Natural-gas combined cycle | $64.55/MWh | $67.09/MWh | Average modeled cost for combined-cycle gas resources entering service in 2030 |
On this defined comparison, gas is lower by $16.90/MWh on a simple-average basis. The result is an average across modeled U.S. resources, not a quote for a particular site. EIA cautions that levelized cost does not capture a plant’s full value to the grid. It also does not resolve a data center’s delivered energy price, hourly shaping, capacity payments, transmission upgrades, interconnection queue position, firm fuel arrangements, financing terms or backup obligations.
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Why a new-build comparison is not an operating-cost comparison
EIA reports that nuclear plants have historically been expensive to construct but generally have relatively low operating costs. DOE identifies nuclear’s largest cost components as upfront capital and labor; uranium is a smaller share of total cost. Gas projects usually require less initial capital and can be built more quickly, but their operating economics are exposed to fuel prices and how often the plant runs. Comparing the operating cost of an existing reactor with the levelized cost of a new gas or nuclear project answers a different question.
How the figures can mislead a procurement team
A data center may pay a utility tariff, sign a PPA, purchase energy and capacity separately, or use a behind-the-meter arrangement. Each structure allocates construction cost, fuel risk, transmission cost, curtailment risk and outage responsibility differently. A $64.55/MWh or $81.45/MWh LCOE cannot be inserted directly into a campus operating budget without those additions.
Reliability: continuous nuclear output versus dispatchable gas
Nuclear’s operating profile
Nuclear units are built to run continuously, which matches a data center’s relatively flat demand. EIA notes that “Data center electricity demand doesn’t fluctuate during the day in the same way as demand from residences or many other businesses.” (EIA, October 1, 2024) The same source describes nuclear’s consistent generation as providing around-the-clock access to a large source of power without direct operational CO₂ emissions.
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Continuous output is not the same as unlimited availability. DOE says current nuclear units commonly operate for 18–24 months between refueling outages; a refueling outage typically lasts a few weeks and is planned in advance. A data center using a nuclear supply must arrange replacement power, storage or other firming for those outages, as well as for unexpected trips and transmission interruptions.
Nuclear plants also have difficulty ramping rapidly up and down to follow changing load. That is less problematic for a steady hyperscale load than for a highly variable system, but a campus that adds large halls in stages still needs a plan for the difference between contracted baseload and actual hourly demand.
Gas’s operating profile
Natural-gas generation is dispatchable: operators can start or adjust output when the system needs it. Gas turbines can generally ramp faster than nuclear units, making them useful for incremental load, reserves and short-duration changes. The exact performance depends on the unit design, ambient conditions, maintenance state, pipeline capacity and fuel availability.
Gas is not automatically reliable merely because it can ramp. A winter pipeline constraint, compressor outage, extreme weather event, plant failure or transmission bottleneck can remove both the primary generator and its supposed flexibility. A gas-dependent campus may need dual-fuel capability, firm pipeline transportation, stored fuel, multiple generating units or a separate grid connection.
Reliability belongs to the whole supply system
Neither a reactor nor a gas turbine guarantees a data center’s service level by itself. Evaluate the complete chain:
- generation availability and planned-outage calendar;
- number and independence of transmission feeds;
- substation and interconnection capacity;
- fuel delivery, storage and pipeline resilience;
- reserve capacity and replacement power during outages;
- uninterruptible power supplies, batteries and on-site generators;
- controls, protection systems and black-start arrangements; and
- physical and cyber security of the facilities.
DOE’s July 2024 recommendations say backup technologies should be assessed across cost, performance, reliability, availability, emissions, space and supply-chain requirements. (DOE, Powering AI and Data Center Infrastructure: Recommendations) A generator’s capacity factor is not a data center uptime guarantee.
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Deployment schedule and permitting
Schedule can outweigh a modest difference in modeled LCOE. DOE expects licensing, demonstration and deployment of new advanced nuclear designs to take years, with widespread commercial advanced reactors more likely in the 2030s. The same DOE material identifies gas among the sources that can help meet near-term demand. (DOE Office of Nuclear Energy, April 8, 2025)
A new nuclear project must complete site selection, environmental review, design certification or licensing, financing, construction and fuel loading. Supply-chain capacity and the availability of qualified labor can affect the critical path. A gas plant still needs air permits, water and interconnection approvals, equipment procurement and pipeline or other fuel infrastructure, but its construction sequence is often shorter.
Existing nuclear is a separate option
An operating reactor can be relicensed, uprated or potentially restarted, and its output can be sold through a PPA. That route may fit a nearer-term load better than waiting for a new reactor. It should not be described as proof that a new advanced reactor can meet the same deadline: the licensing, construction and financing risks are different.
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Direct plant emissions
EIA states that nuclear electricity generation does not directly emit carbon dioxide. Combusting natural gas in a power plant does produce direct CO₂ emissions. “Zero direct emissions” refers to the plant’s operation; it does not mean that every stage of the fuel cycle is emission-free.
Lifecycle emissions
A lifecycle comparison can include uranium mining, conversion, enrichment and fuel fabrication; gas production and processing; methane leakage; pipeline transport; plant construction; decommissioning; and the time horizon used to value methane and carbon dioxide. Studies can produce different results when they use different boundaries, leakage assumptions and accounting periods.
No single directly comparable nuclear-versus-gas lifecycle figure is established here. A procurement team should require both vendors to disclose the same boundary, geography, time horizon and verification method rather than place a “zero” beside nuclear and a single combustion number beside gas.
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Purchased-electricity accounting
The emissions assigned to a data center depend on whether it reports location-based grid emissions, market-based contract instruments, direct ownership of generation or another accounting method. The U.S. Environmental Protection Agency’s eGRID database provides U.S. generation, emissions, emissions rates, heat input and resource-mix data; its page identifies 2023 as the latest data update at the time of publication. (EPA eGRID) Use the same eGRID region or contractual boundary for both options, and do not assume that a grid average is identical to the output of a specific PPA.
Procurement structures and real-world examples
Commercial terms can change the economics more than the fuel label. Compare the following structures explicitly:
| Structure | What the buyer receives | Questions to ask |
|---|---|---|
| Utility supply | Energy and possibly capacity under a regulated or market tariff | What are demand charges, transmission upgrades, interruptibility rules and capacity obligations? |
| Power-purchase agreement | Contracted energy, capacity or environmental attributes for a defined term | Who bears plant outages, congestion, imbalance, curtailment and fuel-price risk? |
| Co-location or behind-the-meter generation | Power delivered near the load, potentially avoiding some grid charges | Who owns the interconnection, backup, fuel supply, controls and regulatory obligations? |
| Portfolio supply | A mix of grid power, firm generation, storage and standby units | How are hourly shortfalls, seasonal peaks and long-duration outages covered? |
EIA cites a 20-year agreement announced in 2024 between Constellation and Microsoft for power from Three Mile Island Unit 1, and an AWS agreement for up to 960 megawatts from Talen’s Susquehanna plant, with phased increases described by EIA. (EIA’s data-center nuclear examples) These are examples of contract structures and project scale, not standard prices or evidence that every data center can obtain identical terms.
Location, transmission and the value of firm power
Large loads are often geographically constrained by network latency, land, water and fiber availability. A low-cost generator in a distant region may require years of transmission construction or may not deliver the capacity value the data center needs. Conversely, a nearby plant may face a congested substation, limited pipeline capacity or local air-quality restrictions.
Ask the utility and grid operator for a load-service study that covers the full ramp schedule, not just the ultimate megawatt figure. The study should identify transmission reinforcements, interconnection milestones, deliverability during regional peaks, curtailment rules and the cost of standby service. For a nuclear PPA, verify the physical path and replacement-power terms; a contract for attributes alone does not guarantee electrons at the campus.
A decision process for a specific data-center project
- Define the load: document initial and ultimate megawatts, hourly shape, power-quality limits, growth dates, acceptable interruption duration and seasonal peaks.
- Separate the supply question: decide whether the project needs new generation, an existing plant PPA, utility service, or a portfolio. Do not compare an existing reactor’s operating cost with a new-build LCOE.
- Request delivered-cost models: require energy, capacity, transmission, interconnection, fuel, balancing, taxes, credits, financing and backup costs to be shown separately and on the same real-dollar basis.
- Stress fuel and outage assumptions: model gas-price scenarios, pipeline constraints, nuclear refueling, forced outages, replacement power and multi-day regional emergencies.
- Confirm the schedule: map permitting, equipment lead times, interconnection studies, construction, commissioning and the date each tranche of load comes online.
- Set the emissions boundary: specify direct, lifecycle and purchased-electricity reporting rules, including methane assumptions and the eGRID region or contractual instrument used.
- Design redundancy: determine how grid feeds, batteries, UPS systems, standby generators, storage duration and black-start capability work together.
- Run sensitivity cases: test earlier or later load growth, lower utilization, delayed transmission, fuel disruption, carbon-policy changes and a failed primary generator.
- Compare contractual risk: review outage credits, availability guarantees, force-majeure language, congestion allocation, environmental-attribute ownership and termination rights.
When each option is most plausible
New gas is often the near-term choice
Gas can be attractive when the campus must add firm capacity quickly, has access to pipeline and transmission infrastructure, and can manage fuel-price and combustion-emissions exposure. Multiple units can be staged as halls are commissioned, and flexible operation can support changing demand. The project still needs a credible plan for fuel security, air permits, carbon costs and long-duration outages.
Existing nuclear can fit a large, steady load
An operating nuclear station or an uprated unit can match a flat 24-hour load and avoid the construction schedule of a new reactor. The buyer must verify available capacity, refueling coverage, transmission deliverability, licensing status, outage history and the contract’s treatment of replacement power and environmental attributes.
New nuclear is a long-horizon strategy
New advanced nuclear may become compelling for a campus that values firm generation, limited direct operational CO₂ emissions and reduced exposure to gas-price volatility, and that can wait for a 2030s-era deployment. The decision must carry substantial capital, licensing, construction and supply-chain risk, with contingency power available until the reactor is operating.
Why U.S. demand forecasts matter to the comparison
DOE reports an estimate from the Electric Power Research Institute that data centers could consume up to 9% of U.S. electricity generation annually by 2030, compared with 4% of total load in 2023. (DOE Office of Electricity) “Up to” marks a projection, not a measured future outcome. If growth approaches that level, utilities and developers may face tighter capacity, transmission and equipment markets, which can change project schedules and delivered prices for both gas and nuclear.
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Bottom line for an investment decision
Use EIA’s 2030 modeled averages as a starting benchmark: $64.55/MWh simple-average LCOE for combined-cycle gas versus $81.45/MWh for advanced nuclear, both in 2024 dollars and both for modeled new resources. Then replace the benchmark with a site-specific model that includes the value of firm supply, ramping, transmission, capacity, backup, fuel security, permitting time and the selected emissions boundary.
Gas is usually easier to deploy on a near-term schedule and offers operational flexibility, but it carries combustion emissions and fuel-supply exposure. Nuclear can provide sustained output with no direct operational CO₂ emissions, yet new construction takes longer and requires more upfront capital. The defensible choice is the supply arrangement that meets the data center’s required energization date and service level after all of those costs and risks are made explicit.
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