Publications

Tangguh gas is mainly methane with 7-15% carbon dioxide. Current LNG operations are emitting 5 mtpa of CO2 and will increase to 8 mtpa when train-3 starts up. Approximately 45% of the emission comes from reservoir gas while the remaining is from LNG operations. CCUS/EGR project fits strategically to address the dual challenges that the oil and gas industry faces today: the resilient hydrocarbon production as part of energy transition, and the ambition for net zero emission. With this project, CO2 from the reservoir will be injected back into the flank of the producing Vorwata Field. The project will create value from the incremental gas recovery, while storing CO2 permanently. This project will reduce 30-40% of carbon emission between 2026-2055 and will put Tangguh on the top quartile of lowest emission LNG plants. The incremental gas recovery and value as LNG product are the key enablers to execute the project and they have been embedded into project valuation. The project will be able to protect Tangguh LNG value with the increasing demand for low carbon intensity LNG from carbon sensitive buyers. This project benefits from the integration with existing LNG operations where CO2 is readily available from LNG processes, the close distance between source and sink for CO2, and the knowledge and experience pool to deliver the project. In this paper, we will discuss the range of carbon disposal options during the concept selection, and the reasons for acceptance or rejection will be elaborated. The criteria for concept selection include technical and commercial suitability and availability, potential applicability for Tangguh, and regulation readiness. Screening and ranking of potential subsurface strata and location candidates will be discussed. The preferred geological structure for CO2 injection location and storage target must allow disposal in an ecologically and environmentally safe manner, be technically feasible, economically sound, and sustainable for long-term post-injection. The selected option requires reservoir rock with sufficient pore volume and permeability to allow storage and injection at reasonable rates. It also requires a cap rock with adequate seal capacity, and seal integrity. Scoring matrices have been constructed to rate and rank each formation and structure’s suitability. Feasibility studies have been conducted on the selected option and locations. BP internal and independent party's evaluations have been completed to include a comprehensive geological evaluation at Vorwata structure covering primary storage reservoir, primary and secondary overburden and underburden seals, storage capacity and injectivity. Modelling studies have been completed on various aspects of the processes to ensure reliable prediction on CO2 injectivity and the plume movement in the reservoir, and to assess the risk and opportunities of CO2 injection on the overall Vorwata production. Finally, the development plan for Tangguh EGR/CCUS will be described.