Mechanostratigraphic control on carbonate fractured reservoir evaluation: a PNG case study

Abstract

Interpretation of Schlumberger Fullbore Formation Microimager (FMI) logs in the Elk-1, Elk-2 and Triceratop-1 wells show that the limestone formation is heavily and heterogeneously fractured. As part of the Elk/Antelope gas field development, reservoir modelling using a dual porosity system is currently being conducted. The gas field discovered is believed to be flowing from a fractured carbonate reservoir and establishing fracture to bedding thickness relationship will assist in developing a dual porosity system. A key input into reservoir modelling and simulation is fracture density across the entire field. This study was aimed at understanding the relationship of bedding thickness to fracture density to facilitate fracture modelling and dynamic simulation.