In more details, the project is about making a comparison between the recovery factor from a clean sandstone plug which is once flooded by sea water and in the second time it is supposed to be flooded by a sample of low salinity water. Empirical correlations could be appreciable.
I suggest using the fractional water analysis (Buckley Levertt Theory) to find the dimensionless oil recovery which will be equal to the dimensionless water injected at breakthrough.
The dimensionless water injected is the injection rate times the injection period of time divided by the pore volume.
You can vary the injection rate and find the breakthrough time for every value of injection rate. Depending on the optimum breakthrough time, you can select the injection rate.
This is a simple approach but it does not consider front distortion and fingering as the injection rate increases.
I found the following critical injection rates from an SPE paper:
The critical injection rate depends on the properties of the
rock. The critical injection rate for Berea core in lab
experiments and 40-acre field dimensions is 20 cc/hr and
1013 STB/D, respectively, and for Spraberry core, the
critical injection rate is 10.0 cc/hr and 393 STB/D,
respectively.
You can read the paper from this link
http://www.pe.tamu.edu/schechter/baervan/paper/SPE56431.pdf
Yaseen answer is right but it depends what you aim is.
The old rule of thumb was to use 1 ft/ day as represented the frontal velocity deep in the reservoir. Other critiria will be to keep your capillary number below 10-5 as at higher values your residual oil saturation become rate dependant.
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