NORTH CAROLINA'S
SUPPLY PREMISE IS
CONDITIONAL.
Duke Energy asked North Carolina regulators in October 2025 to run three coal stations longer than planned, citing federal actions that eased restrictions on coal generation. The filing does not contain one answer. It contains two. Duke modeled a moderate demand future and a higher demand future, and published a different coal retirement schedule for each. Belews Creek moves to 2040 in both. Marshall and Cliffside move two years later in one and not at all in the other. The regulator has not ruled. Nobody can tell a North Carolina homeowner what will be in their concrete in 2032, because the utility itself filed two different answers and is waiting to see which one arrives.
Two futures, filed together. The fleet is indexed to which one arrives.
Three structural problems sit on top of each other in North Carolina. The first is the same coal extension pattern that runs through Georgia and Tennessee. The second is that Duke did not commit to one schedule, it filed two and indexed the difference to how fast demand grows. The third is that the eventual replacement generation Duke is evaluating for the Belews Creek site does not yet exist commercially anywhere in the United States. Whether any of those timelines hold is unknown at this time, and Duke says as much in its own note under the table.
Belews Creek. Cliffside. Marshall.
Those are the three stations Duke named, and it named them for a reason it stated plainly: they have dual fuel capability. Duke's own words on filing day were "following federal actions that eased restrictions on coal generation, targeted potential two- to four-year extensions of units that have dual-fuel capability." In the prior planning cycle the Commission had confirmed retirement dates for these units. Duke is now asking to move them. Nothing has been granted.
Read Table F-2 carefully and the picture is sharper than a simple delay. Duke published two columns, a moderate development scenario and an advancing development scenario, and the coal fleet retires on different dates in each. Duke also attached its own caution under the table: "Coal retirement dates are for planning purposes. Coal retirements in execution are dependent on commensurate replacement capacity and ensuring reliability of the system prior to retirement."
Belews Creek
Steam Station
Units 1 and 2, 1,110 MW each. Retirement effective January 1, 2040 under both demand scenarios, up from 2036 in the prior plan. This is the only unchanged-by-scenario move in the table, and the largest.
Marshall
Steam Station
Units 3 and 4, 658 and 660 MW. Retirement effective January 1, 2032 under the moderate demand scenario. January 1, 2034 under the higher one. Two years of coal, decided by a forecast.
Cliffside
Unit 5
546 MW at the Rogers Energy Complex. Retirement effective January 1, 2031 under the moderate demand scenario. January 1, 2033 under the higher one. Same conditional structure as Marshall.
The replacement plan rests on technology that does not yet exist commercially.
Duke is evaluating new nuclear generation as the eventual replacement, and it is evaluating two options, not one: small modular reactors at Belews Creek in North Carolina, or a large light water reactor at its W.S. Lee site in Cherokee County, South Carolina. Duke's target is a 2037 in service date. The plan evaluates both. It commits to neither. Separately, the NRC accepted an early site permit application from Duke Energy Carolinas for Belews Creek on February 9, 2026. An early site permit addresses whether a site is suitable. It does not authorize construction, it does not authorize operation, and it is not tied to any specific reactor design. As of today that application is still under review.
The small modular reactor half of that plan rests on technology that is not yet operating commercially anywhere in the country. Whether the timeline holds is uncertain. The North Carolina supply premise sits underneath that uncertainty.
Nuclear before retirement. Proposed, not law.
North Carolina Senate Bill 730, the Ratepayer Protection Act, would bar the Utilities Commission from authorizing retirement of baseload or dispatchable generating facilities above 100 MW until a certificate of public convenience and necessity has been issued for a nuclear facility of at least 1,000 MW. If enacted, it would tie the coal fleet's exit directly to nuclear progress, which is precisely the dependency described in section II.
It is not law. The Senate passed it on May 7, 2025 and the House passed it on June 3, 2026, but the Senate has not concurred in the House committee substitute and the bill has sat in Senate Rules since June 8, 2026. It remains eligible for a concurrence vote at reconvened sessions until the General Assembly adjourns sine die on December 18, 2026. This page states its status as proposed legislation and will say so until the General Assembly record shows otherwise.
Freeze-thaw in the Piedmont. Salt-air on the Outer Banks.
North Carolina concrete sees two distinct climate-driven exposure profiles in the same regional ready-mix supply territory. The Piedmont and the western mountains operate under freeze-thaw cycling. The Outer Banks and the coastal counties operate under salt-air and sustained Atlantic humidity. Both profiles affect mix-design durability planning. Both can sit inside the same residential project budget when a regional ready-mix supplier serves both climate zones.
Freeze-thaw cycling
ACI 318 exposure class typically requires air-entrained mix designs and durability planning for the freeze-thaw vector.
Salt-air corrosion
Sustained relative humidity from Atlantic coast climate, chloride-driven corrosion exposure profile, ASR-relevant moisture conditions.
Both climate vectors are real. Both can affect the same residential project budget when the same ready-mix supplier serves multiple climate zones. Neither vector is uniformly more severe than the other. Each is conditioned by location, exposure class, and the chemistry of the ready-mix that serves it.
Conditional supply. Dual climate. Documented pour.
PSIP-certified contractors specify the exposure class before the mix is ordered, document the SCM tier used, and retain the climate-day record. The protocol is structurally independent of every material supplier.