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September 10, 2025Frontiers in Earth ScienceOpen Access

Feasibility study of CO2 injection at the top of tight conglomerate reservoir in Mahu Sag, Junggar Basin, China

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Authors

WZWenya ZhaiResearch Institute of Petroleum Exploration and Development CCChengqiang CuiNorth University of China XHXiuquan HuSecond Hospital of Yichang

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Implication

Feasibility study evaluates CO2 injection effects on enhanced oil recovery in declining tight conglomerate reservoirs, indicating improved efficiency.

Key Points

Top CO2 injection enhances recovery in tight conglomerate reservoirs when formation dip exceeds 10° and permeability is greater than 0.85 mD.
CO2 injection leads to improved pressure maintenance, delaying gas breakthrough by 13.5 years compared to 6.5 years for N₂, achieving 38.7% recovery.
Long-core gravity drainage experiments and numerical simulations assessed influence of formation dip angle and permeability on recovery.
The hybrid well pattern combining vertical injectors and horizontal producers optimizes sweep efficiency and stability.

Cite This Study

Zhai et al. (2025) studied this question.

synapsesocial.com/papers/68c1bd4254b1d3bfb60eeaf9 https://doi.org/10.3389/feart.2025.1586641

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Implication

Feasibility study evaluates CO2 injection effects on enhanced oil recovery in declining tight conglomerate reservoirs, indicating improved efficiency.

Feasibility study of CO2 injection at the top of tight conglomerate reservoir in Mahu Sag, Junggar Basin, China

Discussion

Member takes

Implication

Key Points

Cite This Study

Feasibility study of CO2 injection at the top of tight conglomerate reservoir in Mahu Sag, Junggar Basin, China

Discussion

Member takes

Implication

Key Points

Cite This Study

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