How do pressure relief devices address corrosion issues?
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How can a pressure relief device effectively address the problem of dew point corrosion? Corrosion inhibitors are now also injected, but due to the high iron content, the equipment is severely corroded.
Dew point corrosion, in a general sense, occurs when the process gas reaches its phase transition point as it cools down, resulting in the formation of liquid dew (i.e., the dew point). Conversely, the process in which a liquid rises in temperature until it reaches the point of vaporization–boiling is called the boiling point; the temperatures are the same, but the energy level differs by the latent heat of vaporization. At this time, if there are some acidic substances in the medium (such as sulfur, chlorine, nitrogen, etc.), they will accumulate in the condensed water to form acids.
Pressure relief devices generally do not suffer from dew point corrosion; rather, the issue arises from the effects of triple vacuum pumping, especially as corrosion resulting from secondary and tertiary vacuum pumping is usually difficult to control. Most factories only perform primary vacuum pumping and add corrosion inhibitors, without considering how to prevent corrosion thereafter. All the condensate water flows into the oil-water separation tank, which causes the iron ions in the condensate water to fluctuate, and the water often turns black. At the same time, water is also prone to emulsification. Choosing a suitable neutralizing and corrosion-inhibiting agent is necessary to address the corrosion issue at the top of the vacuum tower.
Thank you very much for your answer. We are currently only injecting a corrosion inhibitor in front of the primary heat exchanger. Do you think it would be more effective to inject the corrosion inhibitor simultaneously in front of all three heat exchangers? With our current manufacturing process, can the problem be solved by screening the chemicals? Thank you.
When selecting agents, it is necessary to determine which corrosive substances are present in larger amounts in the crude oil, in order to ensure appropriateness
Do different crude oils require different corrosion inhibitors? If the sulfur content in the raw materials is relatively high, how should the components of the corrosion inhibitor be adjusted?
If there were corrosion inhibitors specifically designed for sulfur corrosion,
How can corrosion inhibitors be adjusted based on changes in crude oil?
How can one determine whether it is sulfur corrosion or chlorine corrosion? Based on the sulfur content in crude oil?