Perpustakaan Digital ITB

Hydrate formation poses a significant flow assurance risk in carbon capture and storage (CCS) pipelines, especially when CO? is transported with residual water. This study investigates hydrate risks and mitigation strategies in the Alfa Pipeline located in South Sumatra. Using dynamic simulation, hydrate-prone zones were identified based on pressure, temperature, Joule Thomson cooling effects, and water presence. The objective is to develop an effective and economical thermodynamic hydrate inhibitor strategy. The methodology includes literature review, data collection, transient simulation, and scenario evaluation. Fluid properties were modeled using the Cubic Plus Association equation of state. Simulations were conducted on full pipeline geometry under steady and transient CO? injection conditions. Three thermodynamic hydrate inhibitors, Monoethylene Glycol (MEG), Diethylene Glycol (DEG), and Triethylene Glycol (TEG), were tested in both single-point and multi-point injection strategies. Hydrate formation occurred in the main pipeline and near tubing entries due to subcooling effects. Single-point MEG injection at 13.5 kilograms per second was not sufficient to prevent hydrate formation. However, the multi- point injection setup, with 8.5 kilograms per second to the main pipeline and 2.5 kilograms per second to each branch, successfully eliminated hydrate risk. MEG provided superior thermal and pressure safety margins compared to DEG and TEG, and it also offered the lowest operational cost. This study concludes that multi-point MEG injection is the most reliable and economical option for hydrate prevention in tropical CCS pipelines. Future work is recommended to include MEG recovery modeling and dosage optimization. The combination of simulation, technical validation, and cost analysis in this study provides a solid foundation for planning hydrate mitigation in CO? transportation systems.