A Controlled Experiment to Determine the Effect of High Formation Water Salinity on Crude Oil in Hydrocarbon Bearing Rock

Having knowledge of formation water salinity can have dramatic consequences in the evaluation and assessment of a hydrocarbon bearing reservoir, produce water salinity analysis therefore plays a role in dynamic modelling of reservoirs, quantifying reserves and calculating completion cost, including how much will be spent on casing and surface equipment-capital expenditures (capex). Water analysis also helps operators estimate operating expenditures (opex), such as the cost of chemical injection. . This research work examined the effect of high formation water salinity on the physicochemical and thermophysical properties of crude oil system by injecting different concentration of synthetic brine solutions (25 %, 50 %and 75 % Brine solutions) in to the crude oil at different operating conditions and parameters like PH, Viscosity (Cst), Specific Gravity, API / Baume, TDS (mg/l), EC (Scm-1), Colour (PtCo), Density (lb/Gal. ) were determined. Test result indicated that formation water with highest salinity showed highest incremental values in the measured physicochemical and thermophysical properties at different operating conditions. This research analysis therefore, helps development planner determine whether new discoveries can be tied into existing infrastructure and is also crucial for designing water injection project.