AP1000 Supply Chain: Grid Interconnection & Licensing Guide

An engineering and interconnection perspective on the federal supply-chain loan program for large light-water reactors, the bird-in-hand value of existing combined operating licenses, and what it takes to connect new nuclear units to the bulk power system.

Executive Summary

The federal government has signaled, for the first time in a generation, a willingness to underwrite the rebuilding of America’s large-reactor manufacturing base. A conditional commitment under a new supply-chain loan program would finance the long-lead equipment for ten large-scale light-water reactors organized as five projects of two units each with the explicit goal of shortening deployment timelines by up to three years. The reactor at the center of the program is the only large Generation III+ design currently licensed and operating in the United States.

For developers and utilities weighing participation, the financing is only half the equation. The other half is physical: where can two 1,100-megawatt units actually be built, licensed, and connected to the grid quickly enough to justify the equity? This paper argues that the answer is written largely in the existing license landscape and that the projects with the clearest path forward are those that can reuse a site, a switchyard, and a transmission corridor that the bulk power system was already studied to accommodate.

Key takeaways

Ten units at roughly 1.1 GW each represent on the order of 11 GW of new firm capacity seeking interconnection over the 2030s a scale that will reshape transmission planning in several regions.

Sites with an existing or recently held combined operating license (COL) for the chosen reactor type are a “bird in hand”: the licensing basis, point of interconnection, and transmission studies are partially or fully complete.

The interconnection scope switchyard, generator step-up transformers, line additions, dynamic and electromagnetic-transient modeling, protection coordination, and NERC compliance is a critical-path workstream that should begin in parallel with equipment procurement, not after it.

The Supply-Chain Loan Program: What Was Announced

The program issues a conditional loan commitment to finance the purchase of long-lead equipment needed to restart the domestic nuclear supply chain. As structured, it would back up to five projects, each pairing the reactor vendor with a utility or energy-company partner, and each delivering two large reactors at a single site. The combined facility size of the program is ten units. A separate, much smaller construction-loan facility sits alongside the equipment program.

The financing is a commitment, not a disbursement. Before funds flow, the parties must satisfy technical, legal, environmental, and financial conditions and execute definitive agreements. Each project also carries a substantial upfront equity requirement understood to be on the order of half a billion dollars from each of the two project owners before loan funds can be drawn which keeps real capital at risk and tests the seriousness of every prospective partner.

The vendor has reportedly signed letters of intent with several potential partners, each with an identified site, though none of the partners or sites have been named publicly. That secrecy is itself instructive: publicly traded utilities know they will face hard questions from boards and shareholders about whether a new large-reactor commitment meets the “prudent investor” standard, given the recent history of cost and schedule performance on this reactor class in the United States.

Why Long-Lead Equipment Is the Critical Path

Large reactors are gated by a handful of components that simply cannot be produced quickly. Reactor pressure vessels, steam-supply equipment, primary coolant pumps, and main turbine-generator sets each require specialized heavy-forging and fabrication capacity, and many of these items take three years or more to manufacture and deliver. A meaningful share of this capacity sits with heavy-industry firms in Japan and South Korea, because domestic capability atrophied during the long gap in new construction.

This is the strategic logic of financing equipment first. By aggregating bulk orders across multiple projects at a fixed price, the program aims to lower per-component cost, create supply-chain efficiencies, and critically compress schedule by getting forgings into the queue before sites are even finalized. For an engineering team, the implication is direct: the procurement clock and the interconnection clock should start together. A reactor vessel ordered today is of little value if the point of interconnection is still years from an executed agreement.

Putting the Numbers in Perspective

Recent international benchmarks for new large pressurized-water reactors point to an overnight cost in the range of $9,000 per kilowatt. Applied to a single large unit, that implies a capital cost approaching $10 billion; a two-unit project, with some economy of scale, lands in the high-teens of billions; and a full ten-unit build-out sits in the neighborhood of $90 billion in current dollars.

Against that backdrop, the headline incentive package on the order of $17 to $18 billion across the equipment and construction facilities represents roughly one-fifth of the total expected capital cost of building all ten units. That is a material de-risking of the long-lead procurement, but it is not a turnkey subsidy. The remaining four-fifths must still be financed by project owners who carry the construction, schedule, and market risk.

The figures at a glance



• Benchmark overnight cost: ~$9,000/kW for a large PWR.
• Single large unit: just under $10 billion.
• Two-unit project: roughly $18–19 billion.
• Ten-unit program: on the order of $90 billion in current dollars.
• Federal incentive package: ~20% of total expected capital cost.
• Per-project owner equity: substantial, committed upfront before loan draws.

The Lessons That Shape Every Boardroom Decision

No serious discussion of new large reactors in the United States happens without reference to the two most recent attempts. The completed two-unit project in Georgia delivered working reactors, but only after roughly fifteen years of construction and a final cost in the mid-$30-billion range well above original estimates. A parallel two-unit project in South Carolina fared worse: it was abandoned in 2017 amid management failures across the utility, the vendor, and the contractors, leaving ratepayers with billions in stranded debt, pushing the vendor into bankruptcy, and resulting in fraud convictions and prison terms for several executives.

The South Carolina site has since attracted a new owner the private-equity firm that now controls the reactor vendor with a plan to complete the two partially built units. A final investment decision is not expected before 2028, and because the original licenses were terminated, the project would require new licensing. Industry-wide, that completion effort is the bellwether: its cost and schedule outcome will heavily influence whether any utility commits to entirely new units, with or without federal incentives.

“Bird in Hand”: Why the Existing License Landscape Decides the Short List

The single most useful question a developer can ask is not “where would we like to build?” but “where is the licensing and interconnection groundwork already done?” A site that already holds or recently held a combined operating license for the chosen reactor type carries an enormous head start. The environmental review, the safety basis, the site characterization, and the point of interconnection have all been examined once already. A site licensed for a different reactor type, by contrast, would have to repeat much of that effort and expense to accommodate a new design.

The table below organizes the U.S. sites whose licensing history makes them logical candidates for new large light-water units. Sites already associated with the program’s reactor type are the strongest matches; sites licensed for other designs are listed because the underlying site, switchyard, and transmission position retain value even when the reactor type would change.

Reading the Short List Site by Site

Duke the deepest bench

One utility carries six large-reactor licenses across three sites that were never built, including two units acquired through a corporate combination and two more that came off the active list when demand growth slowed and low natural-gas prices undercut the economics. None were pursued to construction which is precisely what makes them attractive now: the licensing and interconnection work exists, but the steel does not, leaving full flexibility on timing.

Turkey Point licensed but stalled on cost recovery

Two licensed units in Florida were suspended indefinitely after a state regulatory decision declined to let the utility recover construction costs during the build and found that the applicant had not demonstrated a realistic and practical intent to break ground in the near term. The license remains a real asset; the obstacle has been regulatory cost-recovery rather than engineering feasibility.

V.C. Summer a partially built site with terminated licenses

The two abandoned units retain enormous latent value as physical infrastructure, but because the licenses were terminated, completion would require fresh licensing. This is the project the rest of the industry is watching.

South Texas Project, Fermi 3, and North Anna 3 right sites, different reactors

These carry licenses for boiling-water or other designs rather than the program’s reactor type. The terminated boiling-water units in Texas faced strong ratepayer opposition from municipal participants two decades ago and are unlikely to revive in their original form; the other two were shelved chiefly over local demand. In each case the site and grid position remain valuable, but a reactor-type change would reopen licensing.

Sites With Withdrawn Applications

A second group of sites once pursued licenses but withdrew their applications, typically for other reactor designs. These represent thinner head starts the regulatory record is incomplete but the underlying sites, several with prior environmental and siting work, can still shorten a greenfield timeline.

The Interconnection Reality: 11 GW Looking for a Home

Ten units at roughly 1.1 GW apiece is on the order of 11 gigawatts of new firm, dispatchable capacity enough to power millions of households entering the interconnection process over the 2030s. Whether a project succeeds or stalls often comes down to how cleanly that capacity can be absorbed by the surrounding transmission network. This is where the existing-license advantage becomes an engineering advantage, not merely a regulatory one.

A brownfield nuclear site typically comes with a high-voltage switchyard, established transmission corridors, and a transmission system that was once studied (and in many cases physically built) to export large blocks of generation. Reusing that interconnection position can save years of study time and hundreds of millions of dollars in network upgrades relative to a greenfield site that must be added to an interconnection cluster from scratch. The same logic increasingly applies to retiring coal sites and other large generators, where surplus interconnection service and generator-replacement provisions can let new capacity inherit an existing point of interconnection.

Why a brownfield interconnection position is worth so much

• An existing point of interconnection and switchyard footprint reduces new right-of-way and permitting risk.

• Prior system-impact and facilities studies narrow the unknowns in network-upgrade scope and cost.

• Transmission that already moved large generation lowers the odds of deep, schedule-killing network upgrades.

• Generator-replacement and surplus-interconnection pathways can preserve queue position and in-service dates.

Substation, Switchyard, and Transmission Scope

Connecting a two-unit station of this size is a major substation and transmission undertaking in its own right. Each unit needs generator step-up transformers sized for its full output, a high-voltage switchyard arranged for reliability (commonly a breaker-and-a-half or ring-bus configuration), and station-service and backup power that meet the stringent reliability requirements of a nuclear facility. Delivering two gigawatts-plus from a single site frequently requires new or reconductored extra-high-voltage lines, expanded terminal stations, and reactive-power resources to hold voltage within limits across a range of system conditions.

These are not afterthoughts to the reactor island; they are long-lead, permit-heavy scopes that belong on the critical path next to the reactor procurement. An owner’s engineer who can carry interconnection, substation, and transmission design alongside the nuclear scope keeps the grid connection from becoming the constraint that idles a finished plant.

Modeling, Studies, and NERC Compliance

Large synchronous reactors bring real strengths to the grid inertia, fault current, and voltage support but they must still earn their interconnection through rigorous study. That work spans steady-state power-flow and short-circuit analysis, dynamic stability simulation in tools such as PSS/E, and electromagnetic-transient studies in tools such as PSCAD for fast phenomena, weak-grid behavior, and transient recovery voltage on switchyard breakers. Protection coordination, relaying, and ride-through performance round out the package.

Layered on top is a thick stack of mandatory reliability obligations. Modeling and data standards, facility-rating and interconnection requirements, protection-system standards, and transmission-planning standards all apply, and each generator interconnection agreement carries its own testing and validation commitments. Getting the studies right the first time is one of the most effective schedule-protection measures available to a new-build project, because re-study and dispute are among the most common causes of interconnection delay.

Global Context: A Broader New-Build Wave

The domestic supply-chain push is one front in a wider movement. Several developments underscore how much momentum is building behind both large reactors and small modular reactors, and why supply-chain capacity is now a strategic concern worldwide:

• A federal program is separately exploring whether nearly twenty metric tons of surplus plutonium could be converted into advanced reactor fuel, with several developers in active negotiation a potential bridge between waste liability and domestic fuel supply.

• A U.S.-based supplier and a European state utility have jointly proposed up to four small modular reactors at a former coal site in the United Kingdom, building on a completed national design-assessment milestone, while the supplier’s first-of-a-kind twin units advance under regulatory review in the United States.

• A major engineering firm has filed a notice of intent with the U.S. regulator to begin licensing a long-established heavy-water reactor platform, aiming at large industrial and data-center demand.

• Canada has issued its first national nuclear strategy, targeting up to ten new large reactors domestically, expanded uranium output, and export of its reactor technology.

• In Poland, a developer has agreed terms with a host city for a small modular reactor station, part of a multi-site program referencing a Canadian build already under construction.

• In India, a large private conglomerate has announced plans to enter nuclear generation with an ambition of up to ten gigawatts of capacity by the mid-2030s, following the opening of the sector to private firms.

The common thread is demand data centers, artificial-intelligence compute, advanced manufacturing, and broad electrification colliding with a global shortage of heavy-reactor manufacturing capacity. Whoever can secure long-lead equipment and clean interconnection positions first will set the pace.

What This Means for Developers and Owners

1. Treat the license landscape as a procurement input. The strongest candidate sites are those whose licensing, point of interconnection, and transmission studies are partially or fully complete. Screen the portfolio against this filter before committing equity.
   
   
2. Start interconnection in parallel with equipment orders. Reactor forgings and the generator interconnection agreement are both multi-year items. Sequencing them in series wastes the schedule advantage the financing is designed to create.
   
   
3. Quantify the network-upgrade exposure early. A feasibility-level interconnection screen — power flow, short-circuit, and a first cut at stability — can reveal whether a site is a clean connection or a deep-upgrade problem long before a formal study queue position is taken.
   
   
4. Plan the studies to NERC standards from day one. Modeling, facility ratings, protection, and transmission-planning compliance are not paperwork at the end; they shape the design and the in-service date.
   
   
5. Consider brownfield and generator-replacement pathways. Retiring thermal sites and previously licensed nuclear sites can offer an inherited interconnection position that materially de-risks schedule and cost.
   

How Keentel Engineering Supports New Nuclear Interconnection

Keentel Engineering is a power-systems and grid-interconnection consultancy built around exactly the workstreams that determine whether a large new generator reaches commercial operation on schedule. For nuclear and other large interconnecting projects, Keentel supports owners and developers across the full interconnection lifecycle:

• Point-of-interconnection engineering and interconnection studies — feasibility, system-impact, and facilities-level analysis.

• Substation and switchyard design, including generator step-up arrangements and high-voltage bus configurations.

• Transmission-line design and network-upgrade scoping.

• Dynamic and electromagnetic-transient modeling using PSS/E and PSCAD, including stability, short-circuit, and protection studies.

• Owner’s engineer services that integrate the interconnection scope with the balance of plant.
• NERC operations-and-planning compliance support across the applicable reliability standards.

Talk to Keentel

If your team is evaluating a site against the new-build financing program or weighing a brownfield interconnection position Keentel can run an early-stage interconnection screen and frame the substation and transmission scope before you commit capital.

Sources & References

This paper is grounded in publicly available program announcements and licensing records, interpreted through Keentel Engineering’s own engineering analysis. Primary references include:

• U.S. Department of Energy program announcements describing the supply-chain and construction loan facilities and their structure.

• U.S. Nuclear Regulatory Commission licensing records for combined operating licenses, including issued, terminated, and withdrawn applications (basis for Tables 1 and 2).

• Publicly reported international cost benchmarks for large pressurized-water reactors.

• Public statements and announcements regarding international new-build and small-modular-reactor programs referenced in the global-context section.

All interconnection, substation, transmission, modeling, and NERC-compliance analysis and recommendations represent the independent professional perspective of Keentel Engineering.

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