We have previously used surface chemistry
analysis techniques to
optimize the functionalization of carbonate rocks with a silylated
polyacrylamide-based relative permeability modifier (RPM). The RPM
is expected to selectively reduce the permeability to water in a hydrocarbon
reservoir setting, resulting in a reduction in the amount of produced
water while maintaining the production of oil/gas. This study will
focus on using core flooding techniques with brine/crude oil under
reservoir conditions (i.e., 1500 psi pore pressure and 60 °C
temperature) to understand the impact of a silylated polyacrylamide-based
RPM on the fluid transport properties in carbonate rocks. The effects
of RPM concentration, brine salinity, rock permeability, and pore
structure on permeability characteristics were studied. Scanning electron
microscopy (SEM) combined with energy dispersive spectroscopy (EDX)
provided visual images of the polymer adsorbed onto the rock surfaces
and confirmed the attachment of the polymer on the surface of the
rock pore space after treatment. The relative percentage of Si increased
from 1.65 to 13.55%, and the relative percentage of N increased to
4.54%. Core flooding showed that increasing the PAM-co-AA (poly acrylamide-co-acrylic
acid partial sodium salt) concentration resulted in residual resistance
factors for oil (RRFoil) and brine (RRFbrine) that were greater than 1. However, there was a modest decrease
in the disproportionate permeability reduction (DRP) ratio (RRFbrine/RRFoil) from 1.75 to 1.60 when the polymer
concentration was increased from 0.05 to 0.1 wt %. Furthermore, the
RRFbrine values decreased slightly from 120 to 62 with
increasing salinity (i.e., 1–10% NaCl) because of electrostatic
shielding caused by charged ions in brine and the RPM. The cross-over
points of relative permeability in these four samples shifted to the
right because of the larger decrease in relative water permeability
compared with relative oil permeability. End-point relative permeability
to water in sample C-5 decreased by 80%, showing a reduction greater
than that in the sample C-2 (i.e., 74%). Kr curves indicated a stronger
formation damage in sample C-1, C-2, and C-4 than in sample C-5. Rock
samples with a higher initial permeability exhibited a higher RRFbrine to RRFoil ratio (i.e., 3.05) under similar
test conditions. This can be attributed to a larger pore radius, which
was verified by nuclear magnetic resonance (NMR) measurements. Furthermore,
a detailed mechanism has been proposed to understand the effects of
the RPM on fluid transport in porous carbonate cores. In this study,
SEM–EDX and NMR measurements combined with core flooding tests
provide insights into the performance of silylated polyacrylamide-based
RPMs and benefit its future implementation in carbonate reservoirs.