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28 results on '"She, Jiping"'

26. Alkali Solution Erodes Shale: Influencing Factors and Structural Damage Characteristics.

Author

She, Jiping, Zhang, Hao, Zhong, Ying, Yuan, Yang, and You, Jiachun

Subjects
*DRILLING fluids, *SHALE gas, *HYDROGEN-ion concentration, *ALKALIES, *EROSION
Abstract

High-pH drilling fluids are often used for drilling shale gas wells. Alkali erosion of shale is one of the important factors of wellbore instability. Alkali erosion experiments of different kinds of minerals and shale were conducted in this paper. Experimental results show that the corrosion rate of kaolinite is the highest when the pH is 9, the corrosion rate of smectite is the highest when the pH is 10 or 11, and the corrosion rate of the quartz is the highest when the pH is 12. Both shale particle size and concentration of hydroxide ion all affect the reaction rate, and the former has a negative correlation with the reaction rate, and the latter has a positive correlation with the reaction rate. In addition, alkaline erosion can lead to the fracture propagation along the bedding planes of shale, which can easily result in wellbore instability. This study may offer some theoretical basis for wellbore instability induced by high-pH drilling fluids. [ABSTRACT FROM AUTHOR]

Published
2018
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27. Study of Phase Equilibrium of NaBr + KBr + H2O and NaBr + MgBr2 + H2O at 313.15 K.

Author

Chen, Qing, She, Jiping, and Xiao, Yang

Subjects
*PHASE equilibrium, *BROMINE compounds, *ISOTHERMAL processes, *PHASE diagrams, *SOLID state chemistry
Abstract

The phase equilibrium for the ternary systems NaBr + KBr + H2O and NaBr + MgBr2 + H2O at 313.15 K was investigated by isothermal solution saturation method. The solubilities of salts and the densities of saturated solutions in these ternary systems were determined by chemical methods, while the equilibrium solid phases were analyzed by Schreinermarker wet residues method. Based on the experimental data, phase diagrams and density versus composition diagrams were plotted. The two ternary systems were type of simple common-saturation and without complex salt and solid solution. There are in all two crystalline regions, two univariant curves, and one invariant point in these phase diagrams of two ternary systems at 313.15 K. The equilibrium solid phases in the ternary system NaBr + KBr + H2O are KBr and NaBr·2H2O, and those in the ternary system NaBr + MgBr2 + H2O are NaBr·2H2O and MgBr2·6H2O. [ABSTRACT FROM AUTHOR]

Published
2017
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28. Impact of drilling fluids on friction coefficient of brittle gas shale.

Author

Yan Xiaopeng, Kang Yili, Li Xiangchen, She Jiping, Xu Chengyuan, You Lijun, Yan Xiaopeng, Kang Yili, Li Xiangchen, She Jiping, Xu Chengyuan, and You Lijun

Abstract

Friction coefficient is proposed as a significant factor influencing brittle shale wellbore stability. Shale from the Longmaxi Formation in the Southern Sichuan Basin of China was used in laboratory studies to determine the effects of an oil-based and a water-based drilling fluid on the frictional properties. Results showed that the friction coefficient decreased with the infiltration of drilling fluids, and it was more sensitive to oil-based drilling fluid filtrate than water-based. The high-pH oil-based drilling fluid shortened the static friction stage, and smoothed the time vs friction coefficient curve, which created more likelihood of frictional sliding. High viscosity and good wettability led to the strong lubricity of oil-based drilling fluid. The surface properties of the shale samples (including fracture surface planarisation and floc-like particle generation) changed after the high alkalinity fluid immersion, causing an obvious reduction of friction coefficient between fracture surfaces. As a result of a decrease in rock strength after immersion into drilling fluids filtrate, the fracture surface was prone to shear failure in the process of frictional sliding, with the failure products migrating with the fracture surface movement. This not only decreased the roughness of the shale surface but also acted as a friction reduction agent between the sliding surfaces., Friction coefficient is proposed as a significant factor influencing brittle shale wellbore stability. Shale from the Longmaxi Formation in the Southern Sichuan Basin of China was used in laboratory studies to determine the effects of an oil-based and a water-based drilling fluid on the frictional properties. Results showed that the friction coefficient decreased with the infiltration of drilling fluids, and it was more sensitive to oil-based drilling fluid filtrate than water-based. The high-pH oil-based drilling fluid shortened the static friction stage, and smoothed the time vs friction coefficient curve, which created more likelihood of frictional sliding. High viscosity and good wettability led to the strong lubricity of oil-based drilling fluid. The surface properties of the shale samples (including fracture surface planarisation and floc-like particle generation) changed after the high alkalinity fluid immersion, causing an obvious reduction of friction coefficient between fracture surfaces. As a result of a decrease in rock strength after immersion into drilling fluids filtrate, the fracture surface was prone to shear failure in the process of frictional sliding, with the failure products migrating with the fracture surface movement. This not only decreased the roughness of the shale surface but also acted as a friction reduction agent between the sliding surfaces.

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