The effectiveness of completion fluids prior to the actual cost and risk of implementation is critical to evaluate. High salinity/ high pH brine can cause formation damage to sandstone formation following well completion operations. The magnitude of damage depended on the fluid/fluid and fluid/rock proprerties.

This work demonstrates the experimental results to evaluate the effect of completion fluid pH on sandstone minerals and the compatibility with the formation water.

Solids and core plugs analysis were conducted using XRD. ICP analysis of three completion fluid samples was performed to determine its elemental composition. Fluid/rock interactions assessment were conducted using zeta potential analysis.

Scaling of calcium sulfate andsalt self-precipitation occurred when high pH completion fluid was mixed with formation water. Zeta potential results showed that sand stone minerals were less stables at high pH.

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