Analysis of the reasons for poor hydrogen sulfide removal efficiency in the hydrogen sulfide stripping tower?
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The hydrogen sulfide stripping tower is primarily used for the stripping of hydrogen sulfide. I increase the temperature of the hot high-pressure gas entering the tower, discharge the cold high-pressure gas directly outside, and raise the amount of steam used for stripping – specifically, 8 kilograms of superheated steam at 240 degrees Celsius – in order to increase the control temperature at the top of the tower as well as the temperature at the bottom. However, no matter how these settings are adjusted, the corrosion of the copper sheets in the product remains unacceptable. I’m not sure what the reason is; please help analyze this issue. Thank you. Has hydrogen sulfide still not been vaporized? What other options are there?
Try reducing the pressure at the top of the tower, or consider whether the sulfur content in the feed oil has increased, which leads to an increased load due to desulfurization in the tower.
The tower pressure has dropped by 1 kilogram, while the sulfur content in the raw material remains unchanged.
Check the heat exchange process of the product – whether there is any heat exchange between the feed to the stripping tower and the product. Even a small amount of leakage from such a heat exchanger can lead to corrosion of the copper sheets.
How is the load? Is there an overload? Such as the tower’s processing capacity or the sulfur content in the raw material?
If the quantity is large, the effect of using just 10 kilograms of steam for stripping may not be sufficient; medium-pressure steam would be more appropriate in such cases
Reduce the pressure at the top of the tower, and vent more of the acidic gases from there
What is the typical steam pressure? Is 0.6 MPa steam okay? Are there any other methods to ensure improved removal efficiency?
Is it because there’s too much naphtha component in your raw materials, which prevents the tower top temperature from rising?
1. Reduce the tower pressure, thereby lowering the partial pressure of hydrogen sulfide in the oil product. 2. Increase the amount and temperature of superheated steam. 3. Check for any leaks in the shell and tube sides of the heat exchanger downstream
It seems that both the steam pressure and temperature are a bit low; normally, superheated steam has a pressure of over 250.