I am performing core flooding experiments to compare percentage of additional oil recovered during surfactant flooding in a sand pack column. Is it necessary that after secondary waterflooding these cores should have the same residual oil saturation?
IF you are asking about actual core samples I would say no. The results should not necessarily have the same values. Here are a couple of reasons;
1-) In actual core (and reservoir condition) the porosity and tortuosity can affect the available paths of your flooding. In other words, in actual core conditions, the available pore volume is different. As a result, you do not have the same rock-fluids interactions.
2-) Additionally, due to the previous results, (changing the pathway of injection fluid), the front of your fluid, that contents surfactant solution, has different concentrations of chemicals. Consequently, fluid-fluids interactions are not the same.
3-) The type of your sand pack and amount of available Clay is another determining factor.
4-) You have to also consider that SPE 65402 found that the salinity of connate water was the primary factor controlling the oil recovery.
In nutshell, If you are asking about the quantity, I would say the amount of your recovery is not the same, however, the general trend of your flooding has to remain the same.
Hope this helps.
Thanks!
But the injected brine has the same composition. type of sand for all the core flooding experiments, mesh size is same. But oil recovered during water flooding is different. I think tortuosity should be the reason for that. But in such case making comparison of additional oil recovered by surfactant slugs having different composition can be made?
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