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The hydrocarbon migration in a porous rock after waterflooding is a complex process. Mathematical models were developed through years to simulate the fluid flow, but input data from experimental works are needed to calibrate equations and/or trends. Routine and special laboratory analysis and measurements allow to determine the crucial input parameters. Knowledge of mineralogy, porosity, permeability, capillary pressure and relative permeability helps the reservoir engineers to predict and manage the future oil re...

The analysis of naturally fractured reservoirs is very comprehensive because of their structure, which includes the matrix of high porosity and low permeability as well as fractures of low porosity and high permeability. The situation is more complex in gas-condensate reservoirs in which the condensate accumulates in the fractures, what prevents them to maintain their base role as the most permeable conduit for the hydrocarbon flow. One of the most successful process to enhance recovery from dual porosity reservoi...

Wettability as a rock-fluid interaction property is well recognized to affect the multiphase flow in hydrocarbons reservoirs. It impacts on the petrophysical properties of reservoir rock including relative permeability, capillary pressure, electrical properties and enhanced oil recovery. The three most commonly states are differed of wettability for hydrocarbon fields, these include: water wet, oil wet and mixed. USBM and Amott- Harvey laboratory methods are proposed as petroleum industry standards to estimate roc...