Reservoir water injection is basically intended to increase the reservoir pressure, thus
remain oil in the pore space of the reservoir rock is displaced by water and moves
toward production wells. When one fluid displaces, there are density changes caused
by altering in fluid saturation and pressure. In the time lapse microgravity technique,
the density changes associated with water replacing oil can be detected with high
resolution surface gravity measurements.
The main objective of this preliminary study is to identify front of water injection
based on density and saturation value resulted in numerical simulation. We apply
numerical approximation of two-phase immiscible and incompressible problems
using IMPES method in conjunction with time lapse microgravity formulation. The
basic method used is finite volume scheme to approach the pressure equation and
finite difference scheme to discretize the saturation and density equations. Simulation
results show that water front and concentration history of the displacing fluid can be
identified