Abstract:Wettability of subsurface reservoir
rocks is a key parameter that
influences multiphase flow characteristics of the fluid–rock
system, including relative permeability, capillary pressure, saturation
distribution, and displacement efficiency. To investigate such effects,
various techniques have been implemented to change wettability, including
nanoparticle injection, chemical treatment, surfactant injection,
brine salinity adjustment, etc. However, most studies have focused
on the use of model surfaces (e.g., m… Show more
“…The adsorption of polymers in porous media is considered necessary for DPR as it immobilizes the polymer within the rock matrix thus allowing subsequent DPR mechanisms to manifest. ,,− Furthermore, it is well-established that the fluid (water and oil/gas) and rock interactions (attraction/repulsion) govern rock wettability, and this controls fluid distributions, capillary pressure, relative permeabilities, fluid transportation, and oil/gas recovery. − Consequently, the adsorption of a polymer in porous media is also a strong function of rock wettability. More specifically, during injection, a DPR fluid that wets the porous medium will be segregated mainly in the preferred pathways for wetting fluid, thus promoting its adsorption onto the rock surface.…”
Several disproportionate permeability reduction (DPR) mechanisms have been proposed in the literature for water shutoff treatment using polymer relative permeability modifiers (RPM). However, none appear to be universally accepted. The lack of agreement may be because no single factor determines the success of DPR treatment. Moreover, there is still a lack of understanding of DPR mechanisms and the order of how these mechanisms work together. This paper provides a comprehensive review of the mechanisms behind the RPMs. We identify that sufficient polymer adsorption onto the rock surface is a primary condition for water shutoff treatment, while rock surface initial wettability and fluid−polymer−rock interaction/attraction plays a significant role in polymer adsorption. Furthermore, polymer concentration, polymer molecular weight, aging time, polymer injection volume, polymer injection rate, and reservoir temperature are also vital for polymer adsorption. After polymer adsorption, the mechanisms such as fluid segregation and wall effect help accomplish the required DPR. We also find that there is a more consistent agreement among the published studies on the order of DPR mechanisms e.g. initial rock wettability effect comes first, followed by initial segregation, adsorption wall effect (i.e., steric, lubrication, wettability alteration, and swelling/shrinkage), and then the final segregation. Depending on the RPM implementation, which depends on pore size, the polymer layer thickness can be adjusted after the placement permanently or temporarily by controlling swelling/shrinkage. The subject matter investigated in this review helps us understand the factors responsible for optimal performance of polymer solutions in controlling excess water production from hydrocarbon reservoirsthus assisting in more efficient oil/gas production.
“…The adsorption of polymers in porous media is considered necessary for DPR as it immobilizes the polymer within the rock matrix thus allowing subsequent DPR mechanisms to manifest. ,,− Furthermore, it is well-established that the fluid (water and oil/gas) and rock interactions (attraction/repulsion) govern rock wettability, and this controls fluid distributions, capillary pressure, relative permeabilities, fluid transportation, and oil/gas recovery. − Consequently, the adsorption of a polymer in porous media is also a strong function of rock wettability. More specifically, during injection, a DPR fluid that wets the porous medium will be segregated mainly in the preferred pathways for wetting fluid, thus promoting its adsorption onto the rock surface.…”
Several disproportionate permeability reduction (DPR) mechanisms have been proposed in the literature for water shutoff treatment using polymer relative permeability modifiers (RPM). However, none appear to be universally accepted. The lack of agreement may be because no single factor determines the success of DPR treatment. Moreover, there is still a lack of understanding of DPR mechanisms and the order of how these mechanisms work together. This paper provides a comprehensive review of the mechanisms behind the RPMs. We identify that sufficient polymer adsorption onto the rock surface is a primary condition for water shutoff treatment, while rock surface initial wettability and fluid−polymer−rock interaction/attraction plays a significant role in polymer adsorption. Furthermore, polymer concentration, polymer molecular weight, aging time, polymer injection volume, polymer injection rate, and reservoir temperature are also vital for polymer adsorption. After polymer adsorption, the mechanisms such as fluid segregation and wall effect help accomplish the required DPR. We also find that there is a more consistent agreement among the published studies on the order of DPR mechanisms e.g. initial rock wettability effect comes first, followed by initial segregation, adsorption wall effect (i.e., steric, lubrication, wettability alteration, and swelling/shrinkage), and then the final segregation. Depending on the RPM implementation, which depends on pore size, the polymer layer thickness can be adjusted after the placement permanently or temporarily by controlling swelling/shrinkage. The subject matter investigated in this review helps us understand the factors responsible for optimal performance of polymer solutions in controlling excess water production from hydrocarbon reservoirsthus assisting in more efficient oil/gas production.
“…This includes various characteristics such as relative permeability, capillary pressure, saturation distribution, and displacement efficiency. 40 Wettability alteration appears to be the only permanent technique available for recovery enhancement of gas condensate reservoirs. Liquid-wetting state of the rock surface around the wellbore leads to decreased mobility which is an important factor in liquid accumulation.…”
Section: Introductionmentioning
confidence: 99%
“…The wettability of reservoir rocks in subsurface formations is a crucial factor that impacts the behavior of multiphase flow within the fluid-rock system. This includes various characteristics such as relative permeability, capillary pressure, saturation distribution, and displacement efficiency . Wettability alteration appears to be the only permanent technique available for recovery enhancement of gas condensate reservoirs.…”
The gas condensate reservoir is classified as a natural gas resource that produces condensate liquid in the reservoir when the pressure in the reservoir drops below the dew point. An innovative strategy to address condensate blockage near the wellbore involves modifying the wettability of the surface of the reservoir rock. This is achieved through chemical treatment, transitioning the surface from a state of strong liquid-wetting to either strong or intermediate gas-wetting. This modern approach effectively mitigates condensate blockage and its associated challenges. Adjusting and sustaining wettability conditions within gas reservoirs requires proper chemicals for a certain reservoir condition. The paper presents a thorough review of wettability and the processes involved in wettability alteration specifically in gas condensate reservoirs. Then, the commonly used wettability alteration chemicals along with their induced flow mechanisms are discussed and reviewed together with a molecular modeling point of view on modern problems of wetting and interfacial phenomena. This paper also focuses on using nanoparticles and fluorochemicals as wettability alteration agents, given that fluorinated nanoparticles are allegedly superior to the chemical wettability altering agents as they change the wettability of the rock surface by modifying both surface energy and surface roughness. This Review indicates the promising use of various nanoparticles along with fluoro materials to enhance ultimate hydrocarbon recovery in gas condensate reservoirs. In the next part, molecular dynamic simulation of imbibition of n-alkanes in kerogen organic slits are presented. The influence of competitive adsorption on multicomponent flows of crude oil and wetting transition on surfaces with molecular roughness are discussed. Actual problems and challenges of molecular modeling methods are also presented.
“…A more comprehensive study was carried out with different silanes and different sandstone samples using either supercritical CO 2 or toluene as the silane solvent carriers. All combinations of surfaces, silanes, and carrier fluids resulted in a water contact angle of more than 140°, indicating that the surfaces were rendered hydrophobic, with a slight improvement when using scCO 2 . Both of these studies investigated the use of silanes to alter wettability with a particular focus on the use of scCO 2 instead of conventional toluene to mitigate any environmental or safety concerns.…”
Wettability is a
main component that determines multiphase
flow
characteristics in a porous medium. Altering the wettability of a
rock has a wide range of applications in the field of geosystems engineering,
such as enhanced oil recovery, improving gas well deliverability,
and geological CO2 sequestration. Considering how injectivity
in many field water-alternating-gas (WAG) processes is lower than
expected, wettability alteration is especially suitable to address
the reduction in relative permeability encountered during water injection.
Several methods for injectivity improvement exist, including the use
of surfactants, nanoparticles, salts, and alkalis. Using silanes to
modify wettability has been a prominent technique in surface chemistry
for decades but has very rarely been applied to porous mineral rocks,
especially carbonates. This work explores the use of silanes to render
sandstone and limestone surfaces more hydrophobic, thereby reducing
gas blockage that causes injectivity loss. Contact angle measurements
were taken and showed good wettability alteration away from water
wet, exhibiting contact angles well above 90°, regardless of
treatment conditions. Centrifuge tests were carried out, and the resulting
residual fluid saturations and capillary pressure curves proved that
the treatment is also effective on the pore scale. Corefloods conducted
in sandstone and limestone cores showed a 45 and 65% increase in water
relative permeability after WAG cycles after treatment, respectively.
This translates directly to improvements in injectivity based on this
treatment method.
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