Simulation of Immiscible Water-Alternating-CO 2 Flooding in the Liuhua Oilfield Offshore Guangdong, China

Gang Hu, Pengchun Li, Linzi Yi, Zhongxian Zhao, Xuanhua Tian and Xi Liang
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Gang Hu: Guangdong Research Center for Unconventional Energy Engineering Technology, Guangdong University of Petrochemical Technology, Maoming 525000, China
Pengchun Li: Guangdong Research Center for Unconventional Energy Engineering Technology, Guangdong University of Petrochemical Technology, Maoming 525000, China
Linzi Yi: Key Laboratory of Renewable Energy, Guangzhou Institute of Energy Conversion, Chinese Academy of Sciences, Guangzhou 510640, China
Zhongxian Zhao: CAS Key Laboratory of Ocean and Marginal Sea Geology, South China Sea Institute of Oceanology, Chinese Academy of Sciences, Guangzhou 510301, China
Xuanhua Tian: Guangdong Research Center for Unconventional Energy Engineering Technology, Guangdong University of Petrochemical Technology, Maoming 525000, China
Xi Liang: UK-China (Guangdong) CCUS Centre, Guangzhou 510663, China

Energies, 2020, vol. 13, issue 9, 1-23

Abstract: In this paper, the immiscible water-alternating-CO 2 flooding process at the LH11-1 oilfield, offshore Guangdong Province, was firstly evaluated using full-field reservoir simulation models. Based on a 3D geological model and oil production history, 16 scenarios of water-alternating-CO 2 injection operations with different water alternating gas (WAG) ratios and slug sizes, as well as continuous CO 2 injection (Con-CO 2 ) and primary depletion production (No-CO 2 ) scenarios, have been simulated spanning 20 years. The results represent a significant improvement in oil recovery by CO 2 WAG over both Con-CO 2 and No-CO 2 scenarios. The WAG ratio and slug size of water affect the efficiency of oil recovery and CO 2 injection. The optimum operations are those with WAG ratios lower than 1:2, which have the higher ultimate oil recovery factor of 24%. Although WAG reduced the CO 2 injection volume, the CO 2 storage efficiency is still high, more than 84% of the injected CO 2 was sequestered in the reservoir. Results indicate that the immiscible water-alternating-CO 2 processes can be optimized to improve significantly the performance of pressure maintenance and oil recovery in offshore reef heavy-oil reservoirs significantly. The simulation results suggest that the LH11-1 field is a good candidate site for immiscible CO 2 enhanced oil recovery and storage for the Guangdong carbon capture, utilization and storage (GDCCUS) project.

Keywords: immiscible flooding; CO 2 storage; water-alternating-CO 2; heavy crude oil; reef reservoir; offshore Guangdong province (search for similar items in EconPapers)
JEL-codes: Q Q0 Q4 Q40 Q41 Q42 Q43 Q47 Q48 Q49 (search for similar items in EconPapers)
Date: 2020
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