Assessment of continuous and alternating CO 2 injection under Brazilian-pre-salt-like conditions
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Assessment of continuous and alternating CO2 injection under Brazilian‑pre‑salt‑like conditions R. O. Lima1 · A. de L. Cunha2 · J. A. O. Santos2 · A. J. V. Garcia2 · J. P. L. dos Santos2 Received: 18 October 2019 / Accepted: 30 July 2020 © The Author(s) 2020
Abstract Carbonate rocks have become very important in Brazil with pre-salt reservoir discoveries in Santos and Campos Basins. Since then, great efforts in research and technology have been made to characterize and develop these reservoirs. In this sense, outcrop analogue studies have become a powerful tool for helping the recognition of geological heterogeneities responsible for controlling the fluid flow in hydrocarbon reservoirs. Besides that, pre-salt oil recovery is associated with high carbon dioxide (CO2) production, and due environmental issues, it is required a sustainable destination for this contaminant. CO2 injection in the reservoir, either pure or mixed to the produced gas stream, could be a good manner to deal with this undesirable component and increase the oil recovery. This work uses outcrop analogue characterization to understand how carbonate reservoir characteristics impact the selection of the best recovery strategy under Brazilian-pre-salt-like conditions. Numerical simulation models were run using the flow simulator TEMPEST MORE (version 7.1) with isothermal compositional modeling. The oil recovery process was modeled by continuous and alternating injection of CO2 and water. The recovered oil fractions for the simulation case with water alternating CO2 injection were higher than with the use of continuous injection of CO2 or water. Keywords Compositional simulation · CO2 injection · Water alternating CO2 injection · Carbonate rocks · Pre-salt
Introduction In Brazil, carbonate rocks have become very important since giant pre-salt reservoirs discovered in Santos and Campos Basins. Great efforts in research and technology have been made to characterize and develop these reservoirs, such as analogue outcrop studies. Analogue outcrop information may be helpful for understanding physical processes that caused sediments to settle, allowing the prediction of lateral changes in geometry and facies distribution of hydrocarbon reservoirs. It is important to note that diagenetic differences between the reservoir and the analogue outcrop must be respected (Aderaldo 1994; Gauw 2007). * R. O. Lima [email protected] 1
Department of Civil Engineering, Federal University of Pernambuco, Av. Acadêmico Hélio Ramos, s/n, Campus of UFPE, Recife 50740‑530, Brazil
Undergraduate Center of Petroleum Engineering, Federal University of Sergipe, Av. Marechal Rondon, s/n, Campus of UFS, São Cristóvão 49100‑000, Brazil
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Although carbonate rocks form most oil reservoirs in the world, the knowledge about these reservoirs is still low if compared to siliciclastic reservoirs. Due to their more prominent reactive nature, carbonate rocks usually suffer a more intense chemical diagenesis, resulting in more
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