The presence of a substantial porosity usually (but not always) implies that pores will be interconnected. Therefore the porous medium is also “permeable.” The property that describes the ability of fluids to flow in the porous medium is permeability. In certain lithologies (e.g., sandstones), a larger porosity is associated with a larger permeability.
In other lithologies (e.g., chalks), very large porosities, at times over 0.4, are not necessarily associated with proportionately large permeabilities. Correlations of porosity versus permeability should be used with a considerable degree of caution, especially when going from one lithology to another.
For production engineering calculations these correlations are rarely useful, except when considering matrix stimulation. In this instance, correlations of the altered permeability with the altered porosity after stimulation are useful. The concept of permeability was introduced by Darcy (1856) in a classic experimental work from which both petroleum engineering and groundwater hydrology have benefited greatly. Figure 1-4 is a schematic of Darcy’s experiment.
The flow rate (or fluid velocity) can be measured against pressure (head) for different porous media. Darcy observed that the flow rate (or velocity) of a fluid through a specific porous medium is linearly proportional to the head or pressure difference between the inlet and the outlet and a characteristic property of the medium. Thus,
where k is the permeability and is a characteristic property of the porous medium. Darcy’s experiments were done with water. If fluids of other viscosities flow, the permeability must be divided by the viscosity and the ratio is known as the “mobility.”
