• Sumarli, Shieren
• Siagian, Utjok W. R.
• Siregar, Hasian P. Septoratno
• Santoso, Ryan Kurniawan
• Salam, Damian Dion

Abstract

<jats:sec><jats:title>Abstract</jats:title><jats:p>Corrosion is a critical problem during Oil/Gas production, especially in sour field, Hydrogen Sulfide is the biggest contributor in the corrosion of production facilities. During the production period, pipeline will be corroded with reaction between H2S and Fe. This reaction will be occured differently in various temperature which determines the rate of your pipeline becoming thinner and thinner then will be unsafe. This paper presents a study about corrosion phenomena in production pipeline in sour field by analyzing the heat transfer to determine the corrosion rate in every part of the pipeline. An analytical model for heat transfer is coupled with fluid flow model, frictional heat and considering the Joule Thomsoneffect for steady-state condition. Then, from the analysis of the heat transfer, the corrosion rate in every section of the pipeline, 300 ft, will be obtained. This corrosion rate is determined from the analytical model. This model is applicable to be used in onshore and deepwater cases, depending on the surrounding condition. Thus, the position in which corrosion happened worst can be located. Coating or doing material selection for the several part of the pipeline could be a solution to prolong the age of the pipeline. Effectiveness is about how long the coating or the material selecting would be placed. Then, it could finally contribute in economical analysis about how much would be invested to reduce the impact of corrosion to assure the better production.</jats:p><jats:sec><jats:title>1. Introduction</jats:title><jats:p>It is a fact that corrosion is always happened during oil/gas production and there is nothing to do to eliminate it. The only way to do is to make the process occur more slowly. Corrosion will damage production facilities which are exposed by the fluid and surrounding environment containing corroding agents such as H2S, CO2, etc. In this paper, the main concern is H2S as the agent which can trigger the corrosion process happens. The existence of corrosion on the production facilities will disturb the flow assurance and make the production cost increase. Corrosion will make the pipe wall become thinner, then reduce the diameter of the pipe. Corrosion will also change the pipe roughness. Thus, these two occuring phenomena will significantly change the flow characteristic, then damage the flow assurance. In order to ensure the flow assurance, preventive actions such as pipe coating, injecting inhibitor, etc are always done. In the other hand, all of those actions also have to be considered from the economic view. Thus, a right action has to be chosen to ensure the flow assurance and also be economically done. In this paper, authors develop mathematical model to choose and predict the right action to be executed. Authors also suggest pipe coating and material selection as a right solution to answer the flow assurance problems in that condition.</jats:p></jats:sec></jats:sec>

Topics

• impedance spectroscopy
• corrosion
• Hydrogen
• size-exclusion chromatography