Research on Gas Injection Limits and Development Methods of CH 4 /CO 2 Synergistic Displacement in Offshore Fractured Condensate Gas Reservoirs

Chenxu Yang (), Jintao Wu, Haojun Wu, Yong Jiang, Xinfei Song, Ping Guo, Qixuan Zhang and Hao Tian
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Chenxu Yang: Tianjin Branch of CNOOC Ltd., Tianjin 300459, China
Jintao Wu: Tianjin Branch of CNOOC Ltd., Tianjin 300459, China
Haojun Wu: Tianjin Branch of CNOOC Ltd., Tianjin 300459, China
Yong Jiang: Tianjin Branch of CNOOC Ltd., Tianjin 300459, China
Xinfei Song: Tianjin Branch of CNOOC Ltd., Tianjin 300459, China
Ping Guo: State Key Laboratory of Oil and Gas Reservoir Geology and Exploitation, Southwest Petroleum University, Chengdu 610500, China
Qixuan Zhang: Tianjin Branch of CNOOC Ltd., Tianjin 300459, China
Hao Tian: State Key Laboratory of Oil and Gas Reservoir Geology and Exploitation, Southwest Petroleum University, Chengdu 610500, China

Energies, 2024, vol. 17, issue 13, 1-12

Abstract: Gas injection for enhanced oil and gas reservoir recovery is a crucial method in offshore Carbon Capture, Utilization, and Storage (CCUS). The B6 buried hill condensate gas reservoir, characterized by high CO 2 content, a deficit in natural energy, developed fractures and low-pressure differentials between formation and saturation pressures, requires supplementary formation energy to mitigate retrograde condensation near the wellbore area through gas injection. However, due to the connected fractures, the B6 gas reservoir exhibits strong horizontal and vertical heterogeneity, resulting in severe gas channeling and a futile cycle, which affects the gas injection efficiency at various levels of fracture development. Based on these findings, we conducted gas injection experiments and numerical simulations on fractured cores. A characterization method for oil and gas relative permeability considering dissolution was established. Additionally, the gas injection development boundary for this type of condensate gas reservoir was quantified according to the degree of fracture development, and the gas injection mode of the B6 reservoir was optimized. Research indicates that the presence of fractures leads to the formation of a dominant gas channel; the greater the permeability difference, the poorer the gas injection effect. The permeability gradation (fracture permeability divided by matrix permeability) in the gas injection area should be no higher than 15; gas injection in wells A1 and A2 is likely to achieve a better development effect under the existing well pattern. Moreover, early gas injection timing and pulse gas injection prove beneficial in enhancing the recovery rate of condensate oil. The study offers significant guidance for the development of similar gas reservoirs and for reservoirs with weakly connected fractures; advancing the timing of gas injection can mitigate the retrograde condensation phenomenon, whereas initiating gas injection after depletion may reduce the impact of gas channeling for reservoirs with strongly connected fractures.

Keywords: condensate gas reservoir; fracture; gas injection; physical simulation (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: 2024
References: View references in EconPapers View complete reference list from CitEc
Citations: View citations in EconPapers (1)

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