الفهرس 
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Abstract
In oil reservoirs, the pressure energy is declined due to production of reservoir fluids. Waters from sea or water – wells are usually injected into reservoirs to conserve this energy. Mixing of injected water with that existed in the reservoir (formation water) results in scale deposits which lead to plugging of porous media around well-bore in injection wells. Regarding the cost of drilling injection wells (5 million dollars / onshore and 20 million dollars / offshore well), we have to prevent or minimize the scale deposits in porous media. This problem can be bridged by using scale inhibitor. Therefore, the main objectives of this study is to first evaluate scale tendency in the porous media resulting from mixing of two incompatible waters and, second to evaluate scale tendency after adding proper scale inhibitor to the injection waters. In this study, experimental work and ScaleChem software were used to evaluate the scaling tendency of the commingling of two incompatible waters for Egyptian oil reservoirs existed in Gulf of Suez area. The chemical analyses of the two incompatible waters (injection and formation waters) have been used as input data to the computer simulator. The reservoirs characterized by a temperature range of 90-127oC, and salinity of 100,000-230,000 ppm. The scaling results for the commingling of both injection and formation water at reservoir temperatures and pressures were determined from experimental work and software. Results showed that mixing Abstract of injection water (60%) and formation water (40%) leads to deposits with considerable amounts of calcium carbonate and barium sulfate scales in absence of scale inhibitor. Adding scale inhibitors to the injection water reduces the porous media plugging by 21.325 to 29.2 %. The proper scale inhibitor for the studied reservoir was AII which has an efficiency of 67.09 and 78.012 % for formation type A and B, respectively. Keywords: Scale inhibitor, scale prediction, scale deposition and soft ware simulator List of.