The large, naturally fractured reservoir under investigation is unique with its highly heterogeneous carbonate characteristics. The largest hydrocarbon bearing formations are not only naturally fractured, but also have matrix and vuggy porosity. Special relative permeability, capillary pressure, and compressibility relationships were developed to simulated multi-phase flow in this triple porosity system. Well and interference tests were re-analyzed at several stages in the project to provide input to geology on fracture properties and later to condition the fracture properties coming from the geologic model. The calibrated model acceptably matched the historical pressure and the production of oil, water, and gas for the reservoir complex.

Keywords:
fracture, vug, rock type, image log, saturation, numerical modeling, orientation, modeling & simulation, hydraulic fracturing, reservoir simulation
Subjects:
Hydraulic Fracturing, Well & Reservoir Surveillance and Monitoring, Reservoir Characterization, Fluid Characterization, Reservoir Fluid Dynamics, Improved and Enhanced Recovery, Reservoir Simulation, Formation Evaluation & Management, Unconventional and Complex Reservoirs, Information Management and Systems
Copyright 2000, Society of Petroleum Engineers
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