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Volume 13
Issue 1
10.3390/pr13010071
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Article

Physical Modeling of High-Pressure Flooding and Development of Oil Displacement Agent for Carbonate Fracture-Vuggy Reservoir

by
Jinghui Li
1,
Wen Zhang
1,*,
Bochao Qu
1,
Enlong Zhen
1,
Zhen Qian
1,
Shufen Ma
1,
Fei Qin
1 and
Qing You
2,*
1
Key Laboratory of Enhanced Oil Recovery in Carbonate Fractured-Vuggy Reservoirs, CNPC, Urumqi 830011, China
2
School of Energy Resources, China University of Geosciences, Beijing 100083, China
*
Authors to whom correspondence should be addressed.
Processes 2025, 13(1), 71; https://doi.org/10.3390/pr13010071
Submission received: 17 October 2024 / Revised: 15 December 2024 / Accepted: 30 December 2024 / Published: 1 January 2025
(This article belongs to the Special Issue Multiphase Flow, and Efficient Development Methodology and Technology in Unconventional Reservoirs (2nd Edition))
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Abstract

The fracture-cavity carbonate reservoir in Tahe oilfield is buried deep (more than 5000 m). The reservoir has low permeability, strong heterogeneity, large size, diverse forms of connectivity, and complex spatial distribution. In conventional water flooding, it is difficult to improve oil recovery effectively because of small water flood sweep and large injection pressure. Pressure flooding is a new water injection technique that can change the reservoir pore space. Combined with an oil displacement agent, pressure flooding is expected to improve the recovery rate of carbonate reservoirs. In this paper, the influence factors of pressure flooding technology are studied, and a set of surfactant systems suitable for high-temperature and high-salt reservoirs is developed. The results show that only an appropriate injection flow can produce microfractures. Only an appropriate displacement rate can optimize the effects of pressure flooding. With an increase in crude oil viscosity, the recovery rate after pressure flooding decreases gradually. A complex fracture network is formed in reservoirs after pressure flooding. The new surfactant system has good interfacial tension reduction properties and excellent stability. Pressure flooding experiments with the addition of a surfactant showed that the system can help to improve the recovery of pressure flooding.
Keywords: carbonate rock; fracture-cavity reservoir; oil displacement agent system; pressure flooding physical simulation; natural cracks; enhanced oil recovery carbonate rock; fracture-cavity reservoir; oil displacement agent system; pressure flooding physical simulation; natural cracks; enhanced oil recovery

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MDPI and ACS Style

Li, J.; Zhang, W.; Qu, B.; Zhen, E.; Qian, Z.; Ma, S.; Qin, F.; You, Q. Physical Modeling of High-Pressure Flooding and Development of Oil Displacement Agent for Carbonate Fracture-Vuggy Reservoir. Processes 2025, 13, 71. https://doi.org/10.3390/pr13010071

AMA Style

Li J, Zhang W, Qu B, Zhen E, Qian Z, Ma S, Qin F, You Q. Physical Modeling of High-Pressure Flooding and Development of Oil Displacement Agent for Carbonate Fracture-Vuggy Reservoir. Processes. 2025; 13(1):71. https://doi.org/10.3390/pr13010071

Chicago/Turabian Style

Li, Jinghui, Wen Zhang, Bochao Qu, Enlong Zhen, Zhen Qian, Shufen Ma, Fei Qin, and Qing You. 2025. "Physical Modeling of High-Pressure Flooding and Development of Oil Displacement Agent for Carbonate Fracture-Vuggy Reservoir" Processes 13, no. 1: 71. https://doi.org/10.3390/pr13010071

APA Style

Li, J., Zhang, W., Qu, B., Zhen, E., Qian, Z., Ma, S., Qin, F., & You, Q. (2025). Physical Modeling of High-Pressure Flooding and Development of Oil Displacement Agent for Carbonate Fracture-Vuggy Reservoir. Processes, 13(1), 71. https://doi.org/10.3390/pr13010071

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