Problems with catalytic cracking regeneration flue gas
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This post was last edited by OIAGF on 2017-2-13 at 15:45. I would like to ask everyone: does the flue gas from the FCC regeneration process contain H2O before it exits the waste heat boiler and enters the desulfurization tower? If so, what is the content level? Also, what do dry basis and wet basis mean when referring to the SO2 content in flue gas?
It must be due to water; otherwise, there would be no need to consider the issue of dew point corrosion! As for the specific values, no detailed analysis has been conducted in previous flue gas analyses! Dry basis means it excludes water, while wet basis includes water.
During the regeneration of catalytic cracking catalysts, the goal is to burn and remove the coke and heavy hydrocarbons remaining on the catalyst, which generates a considerable amount of water. At high temperatures, this water enters the flue gas and is carried along with it. When conducting flue gas analysis, moisture should be analyzed in order to identify potential dew point corrosion. There will be ones for analyzing data.
Regenerated flue gas definitely contains water. This includes water generated by regenerative coking (mainly from the hydrogen combustion reaction), as well as water introduced at various steam loosening points, plus water condensed from steam in safety systems; there is even more water if there is flue gas desuperheating steam.
Dry basis means it excludes water, while wet basis includes water
In the flue gas, H2O = 8~10% (vol), SO2 = 1000~3000 mg/m3·h, with a maximum of 6000~8000 mg/m3·h (very rarely)
Our data shows 11% moisture content