|New method for inferring the mean pore size of shale using imbibition-diffusion data|
|Yang L(杨柳); Lu XB(鲁晓兵); Luo DS(罗大双)
|Source Publication||3rd Nordic Rock Mechanics Symposium, NRMS 2017
|Conference Name||3rd Nordic Rock Mechanics Symposium, NRMS 2017
|Conference Date||October 11, 2017 - October 12, 2017
|Conference Place||Helsinki, Finland
|Abstract||After the multistage hydraulic fracturing operations, it is generally observed that the shale gas well is characterized by low flowback rate and high-salinity flowback water. It can be explained by the high water imbibition and ion diffusion capacity of gas shale that is significantly different from conventional sandstone reservoirs. The research on imbibition and ion diffusion is significant for the understanding of shale formation characterization. A new method to evaluate the mean pore size was developed using the experimental data of water imbibition and ion diffusion in gas-saturated shale. The mathematical model was derived theoretically depending on Darcy's law and continuum equation. The results show that the imbibition and diffusion rate can be calculated by imbibition-diffusion curves, and the ratio of imbibition rate to diffusion rate is related to mean pore size. The value of mean pore size is inferred, which is verified by the mercury injection test. This research is significant for volumetric analysis and chemical analysis after fracturing operations to understand the characteristics of gas shale. © 2017 International Society for Rock Mechanics. All rights reserved.|
Flow of fluids
Fracturing (fossil fuel deposits)
Mean pore size
|Affiliation||Institute of Mechanics, Chinese Academy of Sciences, Beijing, China|
Yang L,Lu XB,Luo DS. New method for inferring the mean pore size of shale using imbibition-diffusion data[C],2017:155-162.
Items in the repository are protected by copyright, with all rights reserved, unless otherwise indicated.