Method for evaluating carbon dioxide gas channeling coefficient of glutenite compact reservoir

By conducting CO2 flooding experiments under reservoir pressure, drawing gas flow curves and calculating the gas channeling coefficient, the accuracy and efficiency issues of CO2 channeling assessment in tight conglomerate reservoirs were resolved, achieving rapid and low-cost gas channeling judgment.

CN120719975APending Publication Date: 2025-09-30PETROCHINA CO LTD
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Patent Information

Application Number
CN202410365490.9
Authority / Receiving Office
CN · China
Patent Type
Applications(China)
Current Assignee / Owner
Filing Date
2024-03-28
Publication Date
2025-09-30

AI Technical Summary

Technical Problem

Existing technologies make it difficult to accurately, quickly and cost-effectively evaluate the CO2 crossover coefficient in sandstone and conglomerate tight oil reservoirs, which affects the effectiveness of CO2 flooding.

Method used

By conducting carbon dioxide flooding experiments under the corresponding reservoir pressure, recording the gas flow at the production end, drawing a carbon dioxide gas flow curve, dividing the gas-seeping stage according to the inflection point of the curve, calculating the gas flow change gradient and gas channeling coefficient, and judging the gas channeling phenomenon.

Benefits of technology

It is possible to judge the gas crosstalk phenomenon only by the change of carbon dioxide gas flow rate, providing a simple, fast and efficient method to provide guidance for on-site prevention and control of carbon dioxide gas crosstalk.

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Abstract

The invention provides a glutenite tight oil reservoir carbon dioxide gas channeling coefficient evaluation method, and relates to the technical field of oil and gas field development, the method comprises the following steps: S1, collecting and recording the gas flow at the extraction end until the gas flow at the extraction end is stable; s2, drawing a carbon dioxide gas flow curve; s3, dividing gas seeing stages according to different inflection points in the carbon dioxide gas flow curve, and determining a time change value delta tn and a gas flow change value delta Qn of each gas seeing stage; s4, determining gas flow change gradients lambda1, lambda2, lambda3... lambdan of each gas seeing stage; and S5, calculating a carbon dioxide gas channeling coefficient Phin, determining whether gas channeling occurs in the gas seeing stage or not according to the size of the Phin value, and if Phin is greater than the gas flow coefficient R, judging that gas channeling starts in the rock core in the time period. According to the gas flow in the production process, whether gas channeling occurs on site or not is judged, and a simple, rapid and efficient method is provided for on-site prevention and treatment of carbon dioxide gas channeling.
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