Wellbore stability evolution law of underbalanced horizontal well in argillaceous siltstone reservoirs

被引：1
|
作者：
Qiu Y. [1 ]
Ma T. [1 ]
Chen Y. [2 ]
Yang Y. [3 ]
Deng C. [4 ]
机构：
[1] State Key Laboratory of Oil and Gas Reservoir Geology and Exploitation, Southwest Petroleum University, Chengdu
[2] Tight Oil and Gas Project Division, PetroChina Southwest Oil & Gas Field Company, Chengdu
[3] Drilling and Production Engineering Technology Research Institute, Chuanqing Drilling Engineering Co. Ltd., CNPC, Xi'an
[4] PetroChina Tarim Oilfield Company, Korla
来源：
Zhongnan Daxue Xuebao (Ziran Kexue Ban)/Journal of Central South University (Science and Technology) | 2023年 / 54卷 / 03期
基金：
中国国家自然科学基金;
关键词：
argillaceous siltstone; evolution law; horizontal well; tight sand gas; underbalanced drilling; wellbore stability;
D O I：
10.11817/j.issn.1672-7207.2023.03.015
中图分类号：
学科分类号：
摘要：
Taking the argillaceous siltstone reservoir of Chang 7 group in Sulige gas field as the object, the wellbore stability evolution law of underbalanced horizontal well in argillaceous siltstone reservoirs was investigated. Firstly, the mineral composition, microstructure and mechanical property tests of argillaceous siltstone rocks were conducted to analyze the microscopic mechanisms of wellbore instability. Secondly, based on the multi-field coupling theory, the rock strength weaking characteristics caused by water absorption and diffusion was considered, the multi-field coupled finite element model(FEM) of wellbore stability was established for the underbalanced horizontal well, and the correctness of the model was verified. Finally, the hole diameter obtained by FEM simulation and wireline logging was compared, and the wellbore stability evolution law of underbalanced horizontal well in argillaceous siltstone reservoirs was analyzed. The results show that the simulated hole diameter with considering argillaceous hydration is in good agreement with the actual hole diameter measured by wireline logging, which confirms the accuracy of the FEM. When the effect of argillaceous hydration is considered, the normalized yield zone area (AN) increases rapidly within 50 h after drilling into the formation, the increasing rate then gradually decreases, and the increasing amplitude reaches 98.72% after 240 h. It is mainly caused by rock strength weaking after argillaceous hydration, but AN<0.20 can meet the requirements of wellbore stability of underbalanced drilling. As time goes on, the AN ratio of underbalanced to overbalanced conditions decreases from 2.73 to 2.20, and the AN ratio of near-balanced to overbalanced conditions decreases from 1.90 to 1.50. It indicates that the wellbore pressure is the dominant factor affecting wellbore instability, but the influence of argillaceous hydration increases with time. When the solute concentration of drilling fluid is higher than that of formation fluid, the larger the reflection coefficient, chemical expansion coefficient, solute transfer coefficient, and solute concentration, the lower the AN and the more stable the wellbore; while the smaller the diffusion coefficient of water absorption and permeability of rock, the higher the AN and the less stable the wellbore. © 2023 Central South University of Technology. All rights reserved.
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页码：967 / 983
页数：16
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