Reservoir simulation is an area of reservoir engineering that, combining physics, mathematics, and computer programming to a reservoir model allows the analysis and the prediction of the fluid behavior in the reservoir over time.
It can be simply considered as the process of mimicking the behavior of fluid flow in a
petroleum reservoir system( including reservoir rock and fluids, aquifer,surface and subsurface facilities) through the use of either physical or mathematical models.
It’s a valuable tool to understand the oil and gas reservoir performance under various operating strategies.
Basically, reservoir simulation consists of:
Reservoir simulation is used for two main purposes:
To carry out reservoir simulation, it is necessary to perform several and complex studies which are normally made by teams of specialists from different disciplines – due to the large amount of data required for the preparation of the simulation input data set.
The main elements of a simulation study include
A description of the steps to undertake during a simulation study is presented in the table below
Main steps in a reservoir simulation study
Numerical techniques and approaches
Traditional finite difference simulators dominate both theoretical and practical work in reservoir simulation. Conventional Fluid Dynamics (FD) simulation is underpinned by three physical concepts: conservation of mass, isothermal fluid phase behavior, and the Darcy approximation of fluid flow through porous media. Thermal simulators (most commonly used for heavy crude oil applications) add conservation of energy to this list, allowing temperatures to change within the reservoir.
The simulation model computes the saturation change of three phases (oil, water and gas) and pressure of each phase in each cell at each time step. As a result of declining pressure as in a reservoir depletion study, gas will be liberated from the oil. If pressures increase as a result of water or gas injection, the gas is re-dissolved into the oil phase.
A simulation project of a developed field, usually requires “history matching” where historical field production and pressures are compared to calculated values. The model’s parameters are adjusted until a reasonable match is achieved on a field basis and usually for all wells. Commonly, producing water cuts or water-oil ratios and gas-oil ratios are matched.