Abstract

Estimation of petro physical properties such as effective porosity, volume of shale, and water saturation using well log responses is a significant step for reservoir evaluation. The X field is a crucial chunk of the multi-billion-dollar project undertaken by State Owned Oil and Natural Gas Corp (ONGC).The paper highlights the application of Multi-component induction logging, Nuclear Magnetic Resonance, Full bore Resistivity Imager and Dynamic formation tester survey for accurate petro physical evaluation in a deep-water Pliocene turbidite formation composed of thin sand interbedded with shale. It has been suggested by many studies that, most of the time, conventional methods for petro physical evaluation (e.g. porosity and saturation calculation) in this kind of reservoir do not work properly. To reduce the uncertainty in the estimations of hydrocarbon in place and fluid contacts in clastic reservoirs, it is paramount to integrate various measurements such as log analysis, image logs, pressure data and fluid sampling results for a holistic and meaningful evaluation approach. The integrated approach and workflow that combined these independent measurement methods proved to be the key to the success for formation fluid characterization. Detailed geo mechanical analysis has been carried out and crucial reservoir parameters like pore pressure prediction, magnitude and direction of Horizontal stress, UCS, friction angle and Well bore stability model were estimated, The outputs were used in the design of gravel pack for completion and also played an important role in the production profile for the field.