The hydroprocessing unit has an absorption and stabilization section; the crude naphtha product contains a high level of hydrogen sulfide
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Hydroprocessing units have absorption and stabilization sections. What are the reasons for the high hydrogen sulfide content in crude naphtha products, and what are the solutions?
My unit also uses hydrocracking, but it does not have an absorption and stabilization section; the sulfur content in the naphtha is below 10 ppm. There were two instances when the hydrogen sulfide content in the naphtha was high: once due to insufficient pressure steam in the stripping tower, and once because of contamination by acidic water. . . I don’t know what’s going on with yours. . .
It may be that the load on the absorption/desorption tower or the stabilizer bottom is insufficient, resulting in a high H2S concentration at the tower bottom; try increasing the load on the reboiler at the tower bottom and the condenser at the tower top
The sulfur content in the naphtha here is quite high; after letting it stand for a while, it becomes much lower. There is hydrogen sulfide inside. I haven’t started working on how to solve it yet; anyway, it will be sent to the subsequent device
Is it steam stripping? Increase the amount of stripping steam – a value slightly higher than the designed level is usually sufficient; it’s best to find an appropriate value through experimentation
The desulfurization of alcohol in the fourth bed of the modified reactor is not effective! The butane stripping column does not have good distillation efficiency! Bring it into the fractionation tower!
If the material is fed hot to the subsequent units, there is no major problem. If it is necessary to pass through the storage and transportation tank area, it is best to try to control the hydrogen sulfide content in the naphtha, as the hydrogen sulfide protection facilities, alarm systems, skill levels of the personnel, and hydrogenation units available in typical refineries are not all at the same standard. Naphtha with high hydrogen sulfide levels may not pose too great a risk to trained hydrogenation operators, but it can be fatal for those involved in storage and transportation
There is an absorption and stabilization section; crude naphtha products have a high hydrogen sulfide content. The reasons I have encountered include the following. 1. Stable feed water content 2. Fault in the system pressure control valve, resulting in severe fluctuations in the operating pressure of the stabilizer tower 3. Increased pressure drop across the salt-forming trays in the stabilizer tower 4. Corrosion and detachment of the inner wall of the stabilizer tower, covering the trays and downcomers 5. Excessively low temperature at the bottom of the stabilizer tower 6. Air blockage in the reboiler
How to make adjustments without a stabilizer tower. After heat exchange with low-grade oil, it enters the stripping tower; full reflux is used at the top of the stripping tower, while the oil from the bottom of the tower goes to the distillation tower. Naphtha is obtained from the top of the distillation tower, and diesel is obtained from the bottom. How to adjust the hydrogen sulfide content in naphtha?
Increase the steam flow; the iron ions in the water removed from the reflux tank at the top of the distillation tower are within acceptable limits.
Increase the steam supply for the stripping tower and raise the feed temperature appropriately