The coefficient of oil recovery (RE) depends on both connate water saturation as well as the residue oil after water, gas, or chemical flooding. In turn, the respective initial and residual fluids saturation depends on petrophysical and reservoir conditions like temperature, reservoir pressure, and overburden pressure. The current study is aimed at developing an empirical model for predicting the coefficient of oil recovery based on the above mentioned parameters, as measured in commercial laboratories during routine and special core analysis studies. The preliminary based on a 100 sandstone- and carbonates-samples database, yielded an excellent diagnostic correlation with R-2 > 0.95. The correlation is characteristic for each given reservoir, and hence the ultimate goal of this study is to develop oil recovery coefficient signature charts for each reservoir. The signature charts will be useful in the design of water, gas, and chemical, flooding improved oil recovery projects. Klinkenburg and, Forchheimer corrections have been applied, in order to extend the correlation application to different reservoir fluids and formations. The correlation provides a tool for determining a reservoir's RE where data is scanty.