Enhance Oil Recovery in Fracture-Cave Carbonate Reservoirs Using Zwitterion-Anionic Composite Surfactant System

Wei Peng, Qing You (), Xiaoqiang Liu, Bojie Zhou, Xingxing Ding, Yuechun Du and Liangfei Xiao
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Wei Peng: School of Energy Resources, China University of Geosciences, Beijing 100083, China
Qing You: School of Energy Resources, China University of Geosciences, Beijing 100083, China
Xiaoqiang Liu: School of Energy Resources, China University of Geosciences, Beijing 100083, China
Bojie Zhou: School of Energy Resources, China University of Geosciences, Beijing 100083, China
Xingxing Ding: School of Energy Resources, China University of Geosciences, Beijing 100083, China
Yuechun Du: School of Energy Resources, China University of Geosciences, Beijing 100083, China
Liangfei Xiao: School of Energy Resources, China University of Geosciences, Beijing 100083, China

Energies, 2025, vol. 18, issue 2, 1-12

Abstract: The carbonate fracture-cave reservoir in the Tahe oilfield, China, encounters development challenges because of its substantial burial depth (exceeding 5000 m). Its characteristics are low permeability, pronounced heterogeneity, extensive karst cavern systems, diverse connection configurations, and intricate spatial distribution. Prolonged conventional water flooding leads to predominant water channels, resulting in water channeling and limited sweep efficiency. Surfactant flooding is usually adopted in these conditions because it can mitigate water channeling and enhance sweep efficiency by lowering the interfacial tension (it refers to the force that is generated due to the unbalanced molecular attraction on the liquid surface layer and causes the liquid surface to contract) between oil and water. Nonetheless, the Tahe oilfield is a carbonate reservoir where surfactant is prone to loss near the well, thereby limiting its application. High-pressure injection flooding technology is an innovative method that utilizes injection pressure higher than the formation rupture pressure to alter reservoir permeability, specifically in low-permeability oil fields. Because of the high fluid flow rate, the contact time with the interface is decreased, enabling the ability for surfactants to reach the deep reservoir. In this article, based on the mixed adsorption mechanism of two surfactants and the hydrophilic and lipophilic equilibrium mechanisms, a set of high-temperature and high-salinity resistance surfactant systems appropriate for the Tahe oilfield is developed and its associated performance is evaluated. An oil displacement experiment is carried out to examine the effect of surfactant flooding by high-pressure injection. The results demonstrate that the ideal surfactant system can lower the interfacial tension to 10 −2 mN/m and its capacity to reduce the interfacial tension to 10 −2 mN/m after different aging periods. Besides, the surfactant system possesses excellent wettability (wetting angle changed from 135° to 42°) and certain emulsifying abilities. The oil displacement experiment shows that the oil recovery rate of surfactant flooding by high pressure reaches 26%. The effect of surfactant flooding by high-pressure injection is better than that of high-pressure injection flooding.

Keywords: surfactant system; enhancing oil recovery; high-temperature and high-salinity resistance; high-pressure injection (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: 2025
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