Any thermal plant, be it a gas, oil or coal fired steam plant, a nuclear steam generator or geothermal all have limitations with heat transfer surface.
In the case of coal fired steam plants, the fouling problem is dealt with by using tubes cast into a slightly conductive refractory, keeping the metal temperatures within limits for the pressure involved yet the refractory surface is maintained at relatively high temperatures to keep fouling at a minimum. Since coal fire temps are in the 1600 C range, all that is needed for the design is thickness of the refractory.
Same in gas fired plants. And peak shaving aero-derivative gas turbine plants have little fouling problems from the very pure, but expensive, natural gas/propane. Fouling here is pof principle concern to the turbine blades which is why atomized coal, while a possible fuel for gas turbines, isn't practical. Gas fire cogeneration still has a problem with corrosive condensation on the final heat recovery stage, limiting the overall efficiency.
For the nuclear plant, all heat transfer fluids are kept very clean, preventing any fouling. The temperatures are somewhat lower on the primary heat transfer surfaces but the efficiency high because of the clean fluids.
Not so in geothermal. Geothermal water is HIGHLY contaminated with minerals and dissolved gas, some of which are highly corrosive. Couple the very low temperature means a low boiling point fluid must be used, hence the reference to R134a. Where the coal fired plant has a practical solution with refractory-covered primary tubes, this is not possible with geothermal due to the low availability of the source. Primary heat transfer surface fouling is the problem.