Pore characteristics of black shale in Da'anzhai member of Jurassic in central Sichuan Basin, China

The lacustrine shale in the Da'anzhai member of Jurassic in the central Sichuan Basin is a key exploration target for shale oil and gas resources in China in the future. This paper presents a detailed study of shale rock types and component characteristics, shale pore types and structural characteristics, and shale pore evolution characteristics under thermal simulation conditions through experimental analyses such as rock thin section and field emission scanning electron microscopy (FE-SEM) observation, conventional physical property test, X-ray diffraction (XRD) analysis, TOC test, liquid nitrogen adsorption (LNA) test, and thermal simulation (pore) experiment. The results show that minerals in the Da'anzhai shale are mainly clay minerals, quartz, and calcite, with a small amount of feldspar, dolomite, and pyrite. In the shale oil reservoirs, there are dominantly inorganic pores (e.g. clay intergranular pores), and relatively few organic pores. The specific surface area ranges from 1.064 m(2)/g to 9.227 m(2)/g, with an average of 4.949 m(2)/g. The pore volume is 0.003-0.016 cm(3)/g, with an average of 0.010 cm(3)/g. Mesopores contribute the most to the total pore volume and total specific surface area. With the increase of thermal simulation temperature, the degree of shale thermal evolution increases, and the shale porosity increases, predominantly, owing to the contribution of organic pores. It is concluded that inorganic pores, especially clay intergranular pores, are the dominant pore type in the Da'anzhai shale oil reservoirs, and the evolution degree, burial time and depth of organic matter can obviously improve the organic pores.

Automated summary

This study presents a detailed investigation of the shale rock types, pore types, and pore evolution characteristics of the lacustrine shale in the Da'anzhai member of Jurassic in the central Sichuan Basin. The results reveal that the dominant pore type in the shale oil reservoirs is inorganic pores, especially clay intergranular pores, while organic pores are relatively few. The increase in thermal simulation temperature leads to an increase in shale porosity, primarily due to the contribution of organic pores.