Chen Fangwen, Zheng Qiang, Zhao Hongqin, Ding Xue, Ju Yiwen, Lu Shuangfang
Key Laboratory of Deep Oil and Gas, China University of Petroleum (East China), Qingdao 266580, China.
College of Chemical Engineering, China University of Petroleum (East China), Qingdao 266580, China.
J Nanosci Nanotechnol. 2021 Jan 1;21(1):698-706. doi: 10.1166/jnn.2021.18453.
To evaluate the gas content characteristics of nanopores developed in a normal pressure shale gas reservoir, the Py1 well in southeast Chongqing was selected as a case study. A series of experiments was performed to analyze the total organic carbon content, porosity and gas content using core material samples of the Longmaxi Shale from the Py1 well. The results show that the adsorbed gas and free gas content in the nanopores developed in the Py1 well in the normal pressure shale gas reservoir range from 0.46-2.24 m₃/t and 0.27-0.83 m₃/t, with average values of 1.38 m₃/t and 0.50 m₃/t, respectively. The adsorbed gas is dominant in the shale gas reservoir, accounting for 53.05-88.23% of the total gas with an average value of 71.43%. The Gas Research Institute (GRI) porosity and adsorbed gas content increase with increasing total organic carbon content. The adsorbed gas and free gas contents both increase with increasing porosity value, and the rate of increase in the adsorbed gas content with porosity is larger than that of free gas. Compared with the other five shale reservoirs in America, the Lower Silurian Longmaxi Shale in the Py1 well developed nanopores but without overpressure, which is not favorable for shale gas enrichment.
