Perpustakaan Digital ITB

CO2 injection wells for Carbon Capture Utilization and Storage (CCS/CCUS) operations require the injection of CO2 into deep underground rock formations for safe storage. During the CO2 injection process, the injection well will encounter significant corrosion issues as CO2 reacts with the casing or tubing. Addressing these corrosion issues is crucial to ensure the integrity and sustainability of the CO2 injection operations, as well as to prevent potential leaks that could harm the environment. Concerning Well Z, a production well considered for conversion into an injection well, further studies have been conducted to prevent potential issues. The focus of this discussion is on developing an Inflow Performance Relationship (IPR) and Vertical Lift Performance (VLP) model for CO2 injection. The obtained pressure and injection rate data are then used to analyze the corrosion rate on the tubing of Well Z during CO2 injection. This modeling utilizes a commercial software based on De Waard Model, which is employed to evaluate key aspects of corrosion control and material selection. The predicted corrosion rate results are estimated for cases with 100% CO2 and with impurities (14 ppm H2S and 8 ppm H2O) using low-alloy carbon steel, the results do not fulfill the allowable corrosion rate standard of 2 mm/year according to NORSOK (Norsk sokkles konkurranseposisjon – the competitive standing of the Norwegian offshore sector) M-001. If the corrosion rate standard is not fulfilled, the use of Corrosion-Resistant Alloys (CRA) is recommended for the tubing material. The appropriate tubing material for Well Z as a candidate for injection well is selected based on software and ISO 15156-3. Therefore, the results of this study can be used to determine whether Well Z is suitable for modification into a CO2 injection well.