EGU22-4295, updated on 27 Mar 2022
EGU General Assembly 2022
© Author(s) 2022. This work is distributed under
the Creative Commons Attribution 4.0 License.

Characteristics of microscopic pore throat changes in shale reservoir after CO2 fracturing

Mengqing He1,2, Tiantai Li2, Xing Huang2, Xiang Li3, and Ke Wu4
Mengqing He et al.
  • 1China University of Petroleum-Beijing, College of Petroleum Engineering, Beijing, China
  • 2Xi'an Shiyou University, School of Petroleum Engineering, Xi’an, China
  • 3The University of Tulsa, School of Petroleum Engineering, Tulsa, OK, U.S
  • 4Northwest University, Department of Geology, Xi’an, China

The interaction of CO2 with the shale reservoir in the process of CO2 fracturing can change the pore-throat structure characteristics of the rock. In order to determine the microscopic pore throat change characteristics in shale reservoir after CO2 fracturing , typical shale core samples before and after fracturing were selected, combined with casting thin slice(CST), field emission scanning electron microscope(FESEM), CT scan, high pressure mercury injection(HPMI), and nuclear magnetic resonance(NMR) test results, and quantitatively evaluate the change characteristics of micro pore throats in shale  reservoir after CO2 fracturing. The results show that various storage spaces such as intergranular pores, intragranular pores, organic pores, and microfractures can be observed in shale reservoirs before CO2 fracturing, which are with poor pore throat connectivity, and most of them are distributed in a dispersed and isolated state. The discharge pressure is low, 0.89Mpa on average, the mercury removal efficiency is low, and the maximum mercury saturation difference is large. Movable fluid saturation ranges from 2.72% to 41.24%, with an average of 26.78%. After CO2 fracturing the shale reservoir, FE-SEM photos often show dissolved pores. The proportion of micro-cracks increased, and the number of cracks observed for a single sample ranged from 1 to 11, with an average of 4. The average length, opening and spacing of micro-cracks are 27.75μm, 286.63μm, and 3.70μm. The average porosity and permeability of micro-cracks are 9.03% and 1.74×10-3μm2. The pore throat connectivity of the shale samples becomes better, the degree of development is higher, the displacement pressure is increased to 3.05MPa, and the mercury removal efficiency and the maximum mercury saturation are both increased. NMR results showed that the movable fluid saturation of shale core samples increased significantly after CO2 fracturing, and the movable fluid saturation was between 1.57% and 50.25%, with an average of 38.14%. CO2 fracturing shale reservoirs will not only produce secondary fractures, but also easily form complex fracture networks. In addition, it will also improve the dense micro-pore throat structure of the shale reservoir itself, increase fluid seepage capacity, and increase oil and gas recovery.

How to cite: He, M., Li, T., Huang, X., Li, X., and Wu, K.: Characteristics of microscopic pore throat changes in shale reservoir after CO2 fracturing, EGU General Assembly 2022, Vienna, Austria, 23–27 May 2022, EGU22-4295,, 2022.