In petroleum engineering, true effective mobility (TEM), also called TEM-function is a criterion to characterize dynamic two-phase flow characteristics of rocks (or dynamic rock quality). TEM is a function of relative permeability, porosity, absolute permeability and fluid viscosity, and can be determined for each fluid phase separately. TEM-function has been derived from Darcy's law for multiphase flow.
T E M = k k r ϕ μ {\displaystyle {\mathit {TEM}}={\frac {kk_{\mathit {r}}}{\phi \mu }}}
in which k {\displaystyle k} is the absolute permeability, k r {\displaystyle k_{\mathit {r}}} is the relative permeability, φ is the porosity, and μ is the fluid viscosity. Rocks with better fluid dynamics (i.e., experiencing a lower pressure drop in conducting a fluid phase) have higher TEM versus saturation curves. Rocks with lower TEM versus saturation curves resemble low quality systems. TEM-function in analyzing relative permeability data is analogous with Leverett J-function in analyzing capillary pressure data. Furthermore, TEM-function in two-phase flow systems is an extension of RQI (rock quality index) for single-phase systems. Also, TEM-function can be used for averaging relative permeability curves (for each fluid phase separately, i.e., water, oil, gas, CO2).
Average kr = ∑ i = 1 n T E M i ∑ i = 1 n ( k ϕ μ ) i = ∑ i = 1 n ( k k r ϕ μ ) i ∑ i = 1 n ( k ϕ μ ) i {\displaystyle {\text{Average kr}}={\frac {\sum _{i=1}^{n}{\mathit {TEM}}_{i}}{\sum _{i=1}^{n}\left({\frac {k}{\phi \mu }}\right)_{i}}}={\frac {\sum _{i=1}^{n}\left({\frac {kk_{\mathit {r}}}{\phi \mu }}\right)_{i}}{\sum _{i=1}^{n}\left({\frac {k}{\phi \mu }}\right)_{i}}}}
See also Lak wettability index USBM wettability index
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