Factors Influencing Productivity of Horizontal Wells With CO2 Inter-Fracture Flooding

doi:10.7657/XJPG20220415

Abstract

Abstract:

When tight oil reservoirs are developed by depletion mode, oil production declines rapidly. In order to explore a more effective development technique, a CO₂ inter-fracture flooding model for horizontal well was established using the CMG-GEM software to simulate how the factors such as CO₂ injection volume, injection pressure, reservoir temperature, fracture spacing and fracture length affect horizontal well productivity. The results show that CO₂ inter-fracture flooding in a horizontal well can greatly increase the CO₂ swept area, fully exploit the remaining oil, and improve the development effect. When the injection pressure is 25 MPa, the CO₂ injection volume is close to and not more than 10×10⁴ m³. The peak production rate rises with the increase of injection pressure, fracture spacing and fracture half-length. The peak production rate at the reservoir temperature of 80°C is higher than that at other temperatures; however, the higher the reservoir temperature, the less time will be needed to reach the peak daily production rate.

Key words: horizontal well, CO₂, inter-fracture displacement, tight reservoir, productivity, fracture, injection volume, injection pressure

CLC Number:

TE357

XIAO Hanmin, LUO Yongcheng, ZHAO Xinli, ZHANG Haiqin, LIU Xuewei. Factors Influencing Productivity of Horizontal Wells With CO₂ Inter-Fracture Flooding[J]. Xinjiang Petroleum Geology, 2022, 43(4): 479-483.

Figures/Tables 6

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Factors Influencing Productivity of Horizontal Wells With CO₂ Inter-Fracture Flooding

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