Abstract
Phase behaviour of hydrocarbon in a shale gas reservoir highly deviates from that in the conventional reservoir. The deviation resulted from the nanometer range of pore sizes and extremely low permeability. The small pore sizes increase capillary pressure and spatial confinement. The primary parameters affecting the fluid distributions and behaviour in shale are the pore size and distributions. Thus, it is crucial to determine the pore structures within the shale before any development conducted. This study focuses on applying the mercury injection capillary pressure method (MICP) to determine the pore size and distributions in the shale gas sample. The capillary pressure measurements were conducted by using Thermo Scientificâ„¢ Pascal Mercury Porosimeters PASCAL 240. The mercury injection was performed at ambient temperature, and the pressures applied was up to 200MPa. The results showed that the pressure requires to penetrates the nanopores could reach up to 100 MPa, with sizes between 7-12 nm.
Sign-in/Register to access full text options 
Free) 
Talk to us
Join us for a 30 min session where you can share your feedback and ask us any queries you have
Schedule a call
