...: 100% Water-wet fraction: 100% Nx= 30, Ny=Nz=1   Single-phase injection of seawater to displace formation brine at 120 °C at 0.045 mL/min n.a. S2 Core: Indiana Limestone Porosity: 20% Permeability: 100 mD Length × Diameter (inches): 12 × 1.5 Initial brine saturation: 100% Water-wet...

... such as polymer injectivity, divalent ions, geochemical interactions, pore-scale heterogeneity, and oil-/mixed-wettability. This paper addresses the first two challenges: polymer transport in low permeability carbonate cores and surfactant interaction with formation brine during ASP floods. Since polymer...

... will be presented. Analyses were made using a compositional reservoir simulation (REVEAL) to predict the pore-pressure distribution, direction and movement of the injected fluid, as well as chemical reactions between formation brine/waste/formation rocks and the effect of these chemical reactions on formation...

... dried in the oven to a constant weight before processing. Cores were first characterized for air petrophysical properties, then vacuum-saturated with the formation brine. The brine permeability was then measured. Cores for oil-displacement experiments were then saturated with oil at pressure drops...

... reservoir Reservoir Conditions formation brine core-flooding experiment viscoelastic surfactant high temperature Oil Recovery Introduction EOR processes attempt to increase the recovery factor of mature fields. Currently, EOR is not a priority in most oil-producing Middle Eastern countries...

... be explained by reverse osmosis ( Bredehoeft et al., 1963 ). During burial processes, porous rock has been continuously compressed due to the overburden weight increasing. Consequently, the formation brine has been expelled from the formation. Only water molecules could leave as the membrane-like properties...

...- , and diluted seawater spontaneously imbibe into the originally oil-wet limestone cores. Modified seawater containing extra SO 4 2- and diluted seawater improve oil recovery from 40% OOIP (for formation brine waterflood) to about 80% OOIP in both secondary and tertiary modes. The residual oil saturation...

... fluid dynamics reservoir temperature waterflooding spe 166281 fb 2 0 upstream oil & gas fb 0 salinity expt spontaneous imbibition contact angle surfactant reservoir imbibition experiment oil recovery flow in porous media formation brine experiment imbibition wettability alteration...

... oilfield chemistry asphaltene remediation concentration scale inhibitor retention polymer loading formation brine scale inhibitor symposium remediation of hydrates viscosity spe 147006 paraffin remediation wax inhibition hydraulic fracturing asphaltene inhibition shear history formulation...

... by the presence of CO 2 , increased the adsorption of polar components onto clays, which normally will lead to enhanced oil recovery due to the low salinity water flooding effect. composition brine waterflooding morrow restoration low salinity effect spe 134459 formation brine seawater formation...

... brine hydraulic fracturing formation brine inconel 718 application formulation inconel 725 fluid system ppg cabr 2 friction pressure fracturing materials Upstream Oil & Gas crosslinker sandface fluid loss pill permeability sodium bromide cr 2535 Introduction Oil and gas...

... with ions in the formation brine: (1) 1 n Sw = [ FCt Cw ] (2) F = Cw Co = a . F = formation factor Cw = formation brine conductivity Co = rock conductivity at Sw=1 Ct = rock conductivity at partial saturation = porosity a, m and n are empirical constants...