Why do two turbines with the same nameplate sell for such different prices?
The nameplate says what the machine was; the maintenance clock says what it will cost to run. What moves price is not total hours but hours and starts since the last hot gas path inspection and the last major. A unit just past a major carries tens of thousands of hours of paid-for life. A unit approaching one carries the bill.
GE's own maintenance guidance for the 7E.03 (the 7EA) puts the hot gas path inspection at 24,000 factored hours or 1,200 factored starts, whichever comes first, and the major at 48,000 hours or 2,400 starts. A combustion inspection falls roughly every 8,000 hours before that.
Picture two 7EAs, both showing 90,000 hours. One had its major at 88,000 hours and has 46,000 hours of interval ahead of it. The other is 45,000 hours past its last major and a few months of baseload running from a full teardown. Same nameplate, same total hours, and the difference in price is the cost of that major plus the outage to do it.
There is a second, slower clock behind the first one. GE's rotor life limit is 200,000 factored hours or 5,000 factored starts. A machine that has been through three majors but is still well inside its rotor life is a different asset from one that is approaching the limit, because a rotor life extension is a study, a decision and a cost, not a routine inspection.
What do "factored" hours mean, and why does a buyer recompute them?
Factored hours are actual hours adjusted for how hard the machine was run. Peak firing, liquid fuel, trips and fast starts all consume interval faster than baseload running on gas. A buyer never takes the hour meter at face value. It rebuilds the figure from the logs, and that is usually where an owner's expectation and a buyer's offer part company.
The multipliers are published and they are not small. Running on distillate carries a hot gas path maintenance factor of 1.5. A trip from base load counts as eight normal shutdowns against the starts-based interval. Peak firing is an exponential penalty that rises with firing temperature. For hot gas path parts under sustained peak operation the factor reaches 6.
The practical effect is that a peaking unit with 12,000 actual hours and 900 hard starts can be closer to its next inspection than a baseload unit with 20,000 hours and 60 starts. If the unit was a peaker, expect the buyer's factored number to be well above what is on the counter, and expect the price to follow the factored number.
Which frames are worth the most right now?
The frames that can drop into a project that cannot wait for a new machine: the 7EA and 7F in 60 Hz markets, the 9E in 50 Hz, and the LM6000 and LM2500 aeroderivatives wherever fast start or a smaller block is needed. A frame with a live parts and repair base is worth more than a rarer one with better hours.
The reason is the new-build queue. Wood Mackenzie reports gas turbine prices have risen 195 percent since 2019 and expects them to reach roughly US$600 per kW by the end of 2027, with lead times of about six years. GE Vernova's gas equipment backlog stood at 116 GW in July 2026, with customer conversations already reaching 2032. Against that, a serviceable installed unit that can be at site in months is not being valued against its scrap weight. It is being valued against what a project would otherwise wait six years for.
| Frame | Class | Grid | Where the demand is | What buyers look for first |
|---|---|---|---|---|
| GE 7EA | E, heavy frame | 60 Hz | Data center and IPP baseload, utility bridge capacity | Hours since major, DLN fitted, controls generation |
| GE 7F (7FA.03/.04) | F, heavy frame | 60 Hz | Combined-cycle rebuilds, large baseload | Hot section pedigree, upgrade history, HRSG condition if sold with it |
| GE 9E | E, heavy frame | 50 Hz | Africa, Middle East, South and Southeast Asia | Same as 7EA; export readiness matters more |
| GE LM6000 | Aeroderivative | either, through gearbox | Peaking, bridge power, fast-start blocks of 40 to 50 MW | Core exchange history, SPRINT fitted, cycles |
| GE LM2500 | Aeroderivative | either, through gearbox | Industrial cogeneration, smaller fast-start blocks | Core hours and shop visit history |
Does 50 Hz or 60 Hz change what my unit is worth?
It changes who can buy it, which changes what it is worth. Heavy-frame machines are direct drive: a 7-series turbine turns at 3,600 rpm and makes 60 Hz, a 9-series turns at 3,000 rpm and makes 50 Hz, and neither can be economically converted. Your buyer universe is fixed by the grid your unit was built for.
60 Hz covers the Americas, Saudi Arabia, Korea, Taiwan, the Philippines and about half of Japan. 50 Hz covers Europe, Africa, most of Asia and Australia. A 7EA in North America sells into the deepest and fastest-moving market there is right now. A 9E in North America has to travel, and the price reflects the export.
Aeroderivatives are the exception. An LM6000 or LM2500 drives its generator through a gearbox, so the same core can serve either grid with a change of gearbox and generator. That flexibility is part of why they hold their value.
How much does the rest of the package matter?
A great deal. A turbine sold with its generator, auxiliary skids, inlet and exhaust, controls and step-up transformer is a power plant a buyer can install. A bare turbine is a component that needs everything else sourced, matched and commissioned. The complete package commands a much higher price per kW, and the gap widened as generator and transformer lead times stretched.
Three items inside the package are priced on their own:
- The generator. Large generators have their own lead-time problem and a unit with a healthy, tested generator, with recent electrical tests and a clean stator, is worth more than the same turbine with a generator of unknown condition.
- The controls. GE's Mark V and Mark VI panels are no longer in production; the Mark VIe has been the current system since around 2003. A buyer with a Mark V unit prices in a controls upgrade, because a modern project will not commission on a panel that is thirty years out of production even if it still runs.
- The combustion system. A unit with dry low NOx combustors fitted can meet a modern permit. A unit on standard combustors either needs a DLN retrofit or is limited to sites that can permit it, and both narrow the buyer pool.
The step-up transformer deserves its own mention. Large power transformers have their own multi-year lead times, and a sound GSU can be one of the more valuable things on the site. Do not scrap it or sell it separately without pricing it first.
What do missing records cost me?
Everything above depends on records. Operating logs establish hours and starts, inspection reports establish cycle position, OEM correspondence establishes modifications and known issues, and parts pedigree establishes what is actually inside the machine. Without them, a buyer cannot compute factored hours, cannot verify cycle position, and prices as if the worst case were true.
That is not a tactic. It is the only rational thing a buyer can do when it is taking title and carrying the risk of what it finds at the first teardown. A borescope shows the hot section today; it does not show how the machine was run for twenty years.
The short version: gather everything before the first buyer visit, not after.
Does the location of the unit matter?
Yes, because a buyer prices the machine delivered, and removal and transport come off the top. A heavy-frame turbine and its generator are oversize loads needing the right crane, a route survey, permits, and often a barge. A unit an hour from a port on good roads is worth more than the same unit inland behind a bridge weight limit.
What an owner can do in advance is establish the removal window. The single hardest term in most agreements is when the buyer can get on site, for how long, and with what access. A clear answer to that question is worth real money at the negotiating table.
What is the honest first step?
Establish cycle position and gather records before anyone visits, because those two things set the price and everything else adjusts it. Then decide whether you want to sell the unit outright or have it taken through recovery on your behalf, since those are different transactions with different economics.
At Genloop the first step is an assessment on site by our own engineers, who value the machine as it stands and the project it could power. The owner then chooses between direct acquisition, where we take title and carry the risk from that day, and a recovery mandate, where we take the unit through restoration and redeployment and the owner captures the spread. Either way the asset never goes to the open market, and there is one counterparty from valuation to settlement.