Abstract
Secondary oil recovery represents a major part of oil production in many local oilfields. It involves injection of a source water to maintain the reservoir pressure. The source water will eventually mix with formation water as it breaks through to the production well. Mixing of incompatible brines leads to precipitation of various types of mineral scaling compounds such as barium sulfate, strontium sulfate, calcium sulfate, or calcium carbonate. This scale deposits at formation face, production tubing, subsurface valves, perforation may restrict fluids flow that result in production rate curtailment. A laboratory work is currently underway to set up a standard procedure for scale inhibitor selection. This paper presents the result of evaluating different types of commercially available scale inhibitors intended for use under downhole and surface production facilities conditions. In addition, a computer scaling modeling is performed to assess the compatibility of injection and formation brines at different ratios and various temperature and pressure conditions.