Industry applications
In a generation train, boiler-side ash exposure and downstream condensation are different protection problems. Follow the gas path and operating cycle before selecting a system.
Waterwalls and tube banks operate within the heat-generation process. Heat exchangers, flues and gas-treatment equipment encounter a changing combination of gas, deposits and moisture further downstream.
The same plant therefore needs more than a single boiler-coating description. Separate tube-surface wear, hot equipment oxidation, acidic condensate and insulation requirements into distinct review areas.
A normal operating reading may not describe what a surface experiences during load change, cooling or a wet shutdown. Match inspection locations to operating history and identify where deposits or liquid remain after the unit stops.
Identify the fuel or gas information available, ash contact, cleaning practices and wet treatment media. Do not treat every deposit-covered surface as the same corrosion environment.
Finned exchangers, closely spaced tubes and welded details limit preparation and spray access. The outage plan must allow inspection of difficult faces and the specified curing process before service resumes.
Exposed tube faces and gas-path changes can show uneven particle damage. Locate the loss relative to flow and nearby tubes before deciding which surfaces require a wear-protection review.
Investigate boiler corrosion and erosionFlues and heat exchangers may encounter acidic condensate where local surface conditions change. Review cooldown periods, liquid retention and deposits rather than relying only on the bulk gas temperature.
Understand sulfuric acid dew point corrosionScrubbers and desulfurization equipment require identification of the actual liquid and exposure mode. Chemical compatibility, particle contact and continuity around joints need to be considered together.
Review gas-treatment chemical exposureRestricted access at tubes, fins and welds can leave hard-to-inspect areas. Preparation and coverage checks should be planned around the equipment geometry, not judged from an accessible flat area alone.
Use the waterwall application checklistSelection depends on the documented product scope and the actual surface conditions. The links below do not identify products used in the linked cases.
Review for compatible flue, scrubber and desulfurization surfaces with combined acid and particle exposure.
Typical equipmentDesulfurization tower · Scrubber
DY-13 flue-gas corrosion-protection system
Review the documented waterwall, economizer and superheater applications against the actual tube duty and preparation conditions.
Typical equipmentWaterwall tube · Economizer
DY-16 high-temperature ceramic wear-protection system
A thermal-insulation route for compatible boiler and high-temperature equipment surfaces, not a substitute for gas-side corrosion assessment.
Typical equipmentBoiler · Industrial kiln
DY-23 aerogel thermal-insulation coating
Review the existing example of water-bearing gas, acidic condensate and finned-tube geometry; no additional performance outcome is inferred.
Flue-gas heat-exchanger corrosion application
Application context for hot gas, ash, cycling and localized erosion. Product selection remains separate from the recorded case facts.
Boiler and flue wear review
See the documented dense-tube and restricted-angle application setting when planning coverage checks.
Boiler-waterwall spray applicationProvide a marked gas-path or equipment drawing with inspection photographs. Relate each defect to tube position, gas or ash contact, wet zones and the stage of operation in which it occurs.
They should be reviewed separately. Tube banks may be dominated by ash contact and heat duty, while downstream equipment can have changing moisture and condensate exposure.
Gas and surface conditions can differ from normal duty. Operating history helps relate damage to cooling, wet periods and condensate retention instead of a single temperature reading.
No. DY-13 is presented for its documented flue-gas and process exposure scope. Boiler-tube wear requires a separate equipment and material review.
Deposits, liquid retention, substrate condition and access between fins affect investigation and application. Coverage must be assessed on difficult geometry as well as visible faces.
A protective layer is not a substitute for assessment and repair of the underlying equipment. Remaining condition and any required engineering repairs must be resolved first.
Identify the affected equipment, damage location, operating and shutdown exposure, cleaning access and restart plan. Include photographs of tube spacing, joints and inaccessible areas.
DAYU-X
Tell us the equipment, process environment and current problem. We will help organize the next technical review.
