The interplay between microbial reservoir souring and barite scale formation in hydrocarbon reservoirs

The injection of seawater into a hydrocarbon reservoir (seawater flooding) as secondary or tertiary oil recovery method is associated with two possibly significant challenges. First, the formation and deposition various types scale may happen due to incompatibility between brine. Especially, addition sulfate ions trigger scales (e.g., barium sulfate, strontium calcium sulfate). Second, microbial souring activation Sulfate Reducing Bacteria (SRBs), which reduce hydrogen sulfide. This mainly result drop in temperature reservoir, from presence Dissolved Organic Carbon (DOC) coming hydrocarbon. Since both these processes include consumption ions, competition expected them. there concern about whether an efficient mitigation strategy for nitrate treatment) will less turn more scales. study tests this theory investigates effect intensity on severity barite inside reservoir. In study, non-isothermal multi-component bio-chemical model simultaneously simulate developed. Several simulation cases one dimensions are investigated different conditions order three influential parameters, namely ion concentration sweater, DOC content hydrocarbon, flow rate formation, souring, treatment, interplay among results show that small (a maximum 4 percent reduction total generated sulfide) whereas treatment significantly influence formation. Depending case, can cause complete removal especially around production well (positive effect) 8 times increase amount (negative effect). Moreover, all cases, although sulfide (up full souring), generation zone moves closer well. Therefore, insufficient earlier twice early). other trends observed set also presented paper.