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The saturation pressure difference of several tight reservoirs in Mahu area is small, and it is easy to accelerate the formation degassing by using horizontal well volume fracturing and depletion development in the previous test, so it is urgent to change the development mode. In order to clarify the feasibility of gas drive energy-increasing development after fracturing in tight reservoirs and the suitable gas drive well pattern under the coupling of well pattern and fracture pattern, combined with the minimum miscible pressure experiment, crude oil PVT and expansion experiment, the contact characteristics of different injection media (dry gas, rich gas and CO2) with crude oil are revealed. The miscibility and swelling capacity of different injection media in crude oil are quantitatively evaluated. The experiment shows that the three gases can be miscible under the reservoir pressure of 49.3 MPa, and CO2 can reach the state of oil–gas miscibility at the bubble point pressure of 38.2 MPa, and the miscibility is the strongest. After injecting 35.8 mol% CO2, the volume of crude oil expands by 32.1%, which is 2.14 times of that of hydrocarbon injection, and the viscosity of crude oil decreases by 29.35%, which is 2.25 times of that of hydrocarbon injection. CO2 injection has stronger solubility, better expansion effect and viscosity reduction effect, which makes it clear that gas injection is feasible to develop the target reservoir. Based on the above experimental phase parameters, the effects of different gas injection well patterns, well types and horizontal well directions on gas injection development are further compared by using the component numerical simulation method, and the suitable well pattern for tight oil volume fracturing + gas drive development mode is constructed: vertical well injection-horizontal well production-gas drive well pattern with horizontal well direction nearly parallel to the maximum principal stress direction, thus providing a new idea for tight oil reservoirs to convert development mode and optimize development deployment.

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Feasibility Evaluation and Well Pattern Optimization of Gas Flooding After Fracturing in Mahu Tight Reservoir

  • 会议论文

  • 发表日期：

    2025年

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  • Xin-yu Chen,
  • You-xiao Qu,
  • Jia-cheng Dang,
  • Zhong-chen Ba

摘要

The saturation pressure difference of several tight reservoirs in Mahu area is small, and it is easy to accelerate the formation degassing by using horizontal well volume fracturing and depletion development in the previous test, so it is urgent to change the development mode. In order to clarify the feasibility of gas drive energy-increasing development after fracturing in tight reservoirs and the suitable gas drive well pattern under the coupling of well pattern and fracture pattern, combined with the minimum miscible pressure experiment, crude oil PVT and expansion experiment, the contact characteristics of different injection media (dry gas, rich gas and CO2) with crude oil are revealed. The miscibility and swelling capacity of different injection media in crude oil are quantitatively evaluated. The experiment shows that the three gases can be miscible under the reservoir pressure of 49.3 MPa, and CO2 can reach the state of oil–gas miscibility at the bubble point pressure of 38.2 MPa, and the miscibility is the strongest. After injecting 35.8 mol% CO2, the volume of crude oil expands by 32.1%, which is 2.14 times of that of hydrocarbon injection, and the viscosity of crude oil decreases by 29.35%, which is 2.25 times of that of hydrocarbon injection. CO2 injection has stronger solubility, better expansion effect and viscosity reduction effect, which makes it clear that gas injection is feasible to develop the target reservoir. Based on the above experimental phase parameters, the effects of different gas injection well patterns, well types and horizontal well directions on gas injection development are further compared by using the component numerical simulation method, and the suitable well pattern for tight oil volume fracturing + gas drive development mode is constructed: vertical well injection-horizontal well production-gas drive well pattern with horizontal well direction nearly parallel to the maximum principal stress direction, thus providing a new idea for tight oil reservoirs to convert development mode and optimize development deployment.