Observed alterations on the mineral surfaces (in all suspensions) are attributed to carbonate formation at different pH and salinity of rock suspensions as well as particle sizes of the rock samples in CO2-sparged aqueous solutions.
Decreasing resistivities are considered to be due to the increase of fluid salinity and/or rock alteration (e.g., Keller and Rapolla, 1974; Revil et al., 2002).
Unusual permeability growth has been observed at high salinities in rocks with low kaolinite concentrations.
The modified model captures the observed effect of permeability increase at high water salinities in rocks with low kaolinite concentrations.
The main objectives of this study are to investigate the influence of droplet volume, brine salinity, liquid saturated rocks, oil acid number, and temperature on rock wettability of carbonate reservoir rock using sessile droplet method.
For dolomites and limestone indistinctly, wettability alteration occurred also for both water salinities turning the rock less oil-wet.
It is also proven that the amount of permeability damage depends on the fabric of the rocks, salinity of the brine, and initial core permeability.
To examine the effects of depositional environment on relative abundance and absolute concentration of rearranged hopanes, the clay content, redox condition and water salinity of sedimentary rocks from two sample sets were analyzed.
Almehaideb et al. (2004) investigated the effect of salinity on the carbonate rock.
The main purpose of this paper is to study the effect of strong PPGs on low permeable zones/areas in mature reservoirs, including the effects of rock permeability, salinity, particle size of PPGs, PPG types, pore throat size in cores, gel strength, and the injection pump pressure.
The distinctive low Na/Cl and Br/Cl ratios, coupled with high silica contents and high 87Sr/86Sr ratios (up to 0.713) in the saline groundwater provide additional evidences for the link between salinity and the schist rocks.
