Dear Experts, I have somehting to request/ learn from your valued end. For Injection Water ( i.e. water which will be forcing downhole for artificial life of oil ) it is best practise to have SRB = 0 to eliminate the issue of reservoir souring. But in practical irrespective of dosing of oxidising or other type biocide it may happen that some count ( say 4 or 3 or even 1 or say max. 10) of SRB may still exist in the Injection Water before pumping in the downhole. My question follows : (1) In practical scenario what should be / could be the maximum threshold level of SRB MPN which we can allow to retain in the Injection Water ? (2)It is evident that lesser the MPN SRB more the time it will take in reservoir to sour/ damage the prevailing condition. As such can you have some discussion w.r.t. MPN SRB vs. Time to take the reservoir to consider as sour or detrimental to liquid or metallic asset ? (3)It appears to me after studying some Capsis document that they ( some thumb rule ) donot consider a reservoir to be termed as sour if the H2S concentration in it’s gas or liquid phase is less than or equal to 3 ppmV. I know that there could be several other elements ( other than SRB) who can contribute to this 3 ppmV H2S . But for the sake of evaluation ( worst case) , let us consider this 3 ppmV H2S is solely due to SRB and if so is it possible from your expert test house to correlate corresponding MPN SRB responsible for generation of 3 ppmV H2S ? regards