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

Author

Listed:
  • Gang Hu

    (Guangdong Research Center for Unconventional Energy Engineering Technology, Guangdong University of Petrochemical Technology, Maoming 525000, China
    Energy Resource School (State Key Laboratory of Oil and Gas Reservoir Geology and Exploitation), Chengdu University of Technology, Chengdu 610059, China)

  • Pengchun Li

    (Guangdong Research Center for Unconventional Energy Engineering Technology, Guangdong University of Petrochemical Technology, Maoming 525000, China
    CAS Key Laboratory of Ocean and Marginal Sea Geology, South China Sea Institute of Oceanology, Chinese Academy of Sciences, Guangzhou 510301, China
    State Key Laboratory of Geomechanics and Geotechnical Engineering, Institute of Rock and Soil Mechanics, Chinese Academy of Sciences, Wuhan 430071, China
    Southern Marine Science and Engineering Guangdong Laboratory (Guangzhou), Guangzhou 511458, 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
    Southern Marine Science and Engineering Guangdong Laboratory (Guangzhou), Guangzhou 511458, China
    Innovation Academy of South China Sea Ecology and Environmental Engineering, Chinese Academy of Sciences, Guangzhou 511458, 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
    Business School, University of Edinburgh, Edinburgh EH8 9JS, UK)

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.

Suggested Citation

  • Gang Hu & Pengchun Li & Linzi Yi & Zhongxian Zhao & Xuanhua Tian & Xi Liang, 2020. "Simulation of Immiscible Water-Alternating-CO 2 Flooding in the Liuhua Oilfield Offshore Guangdong, China," Energies, MDPI, vol. 13(9), pages 1-23, April.
    • Handle: RePEc:gam:jeners:v:13:y:2020:i:9:p:2130-:d:351352
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