Publications

Fracture has become a critical factor in enhancing the permeability potential of shale in producing gas. Shale gas may be stored as a free gas in fractures and intergranular porosity, so the developed well connectivity between pores and fractures is needed. A deeper understanding of the fracture shale gas of the Tanjung Formation, Barito Basin, South Kalimantan was carried out in this study. This area was covered because it has a high potential for shale gas, about 56.64 TCF from the previous study. All core samples from the field show that shale has a low porosity, consisting of intergranular, secondary porosity, micro fracture, and micro porosity. Pores seen from scanning electron microscopy (SEM) are not interconnected because of the abundance of detrital clay matrix, cementation, and replacement. Petrographical analyses of thin sections in the shale supported the SEM analyses. X-Ray Diffraction analysis showed that the Tanjung Formation has high quartz content and a low concentration of smectite as a swelling-clay mineral. From this analysis, the brittleness index (BI) could be obtained and could be used as a cut-off to calculate the volumetric of shale gas, along with the geochemical analysis. Lithofacies, porosity and permeability, geochemical characteristics, and geomechanical properties analyses are fundamental basic data in creating the shale volumetric, as a key to creating fracture modeling. We used the Discreet Fracture Network (DFN) Model to integrate the field and subsurface data. This DFN Model is created by using a fracture intensity guide that used the fracture intensity, BI, and FMI data. From this model, we know that the highest intensity of fracture is located at the zone near the fault and the high folded area with the highest BI. Keywords: Shale Gas, Fracture, Permeability