Abstract:Relative permeability modifiers (RPMs) are chemicals that can be injected into a reservoir to change its fluid/gas transport characteristics. For example, RPMs can reduce the relative permeability to water in a subterranean reservoir while having minimal impact on hydrocarbon production. Most commercially available RPMs are specifically designed for silica surfaces which are dominant in sandstone reservoirs. However, the concentration of silica in carbonate rocks is very low and many of these RPMs are unsuitab… Show more
“…Generally, the concentration of uncross-linked polymers used in sandstone reservoirs is less than 0.3 wt %; higher concentrations of polymer can lead to undesirably large reductions in the permeability for both oil and brine. , Given that carbonate core samples contain narrow pores with a small average pore radius and generally weak pore connectivity compared to typical sandstone core samples of similar permeability/porosity, the polymer concentration will likely need to be less. The RPM formulation we used in a previous study had a higher concentration of a polymer of 0.6 wt % (and correspondingly higher amounts of formaldehyde, sodium silicate, and APTES) and a higher viscosity; however, there was a concern that 0.6 wt % might cause a blockage of high-permeability channels in the carbonate core sample when PAM-co-AA is immobilized onto the pore walls after the RPM flooding. As a result, for all the RPM formulations used in this study, a polymer concentration less than 0.3 wt % was used.…”
Section: Results
and Discussionmentioning
confidence: 99%
“…Regardless of the precise mechanism, to date, very little research has been done utilizing RPM formulations in carbonate rocks. , This can be attributed to the significant differences (i.e., mineral compositions, pore structure, and permeability characteristics) between carbonate rocks and sandstones. Aiming at making a new RPM applied in carbonate rocks, based on our previous studies, , we have shown that we can efficiently functionalize/immobilize polyacrylamides onto the pore surface of carbonate rocks. ,, In our previous study, sodium silicate was used to functionalize the carbonate surface with silicate groups, and then, 2-aminopropyltriethyoxysilane (APTES) reacted with the Si–O bonds to functionalize the surface with amine groups. ,, An organic linker such as formaldehyde can then be used to attach the polyacrylamide to the surface (i.e., the amides within the polyacrylamide would attach via the organic linker to the amines on the rock surface).…”
Section: Introductionmentioning
confidence: 99%
“…Aiming at making a new RPM applied in carbonate rocks, based on our previous studies, 31,33 we have shown that we can efficiently functionalize/immobilize polyacrylamides onto the pore surface of carbonate rocks. 31,33,34 In our previous study, sodium silicate was used to functionalize the carbonate surface with silicate groups, and then, 2-aminopropyltriethyoxysilane (APTES) reacted with the Si−O bonds to functionalize the surface with amine groups. 31,33,34 An organic linker such as formaldehyde can then be used to attach the polyacrylamide to the surface (i.e., the amides within the polyacrylamide would attach via the organic linker to the amines on the rock surface).…”
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.
“…Generally, the concentration of uncross-linked polymers used in sandstone reservoirs is less than 0.3 wt %; higher concentrations of polymer can lead to undesirably large reductions in the permeability for both oil and brine. , Given that carbonate core samples contain narrow pores with a small average pore radius and generally weak pore connectivity compared to typical sandstone core samples of similar permeability/porosity, the polymer concentration will likely need to be less. The RPM formulation we used in a previous study had a higher concentration of a polymer of 0.6 wt % (and correspondingly higher amounts of formaldehyde, sodium silicate, and APTES) and a higher viscosity; however, there was a concern that 0.6 wt % might cause a blockage of high-permeability channels in the carbonate core sample when PAM-co-AA is immobilized onto the pore walls after the RPM flooding. As a result, for all the RPM formulations used in this study, a polymer concentration less than 0.3 wt % was used.…”
Section: Results
and Discussionmentioning
confidence: 99%
“…Regardless of the precise mechanism, to date, very little research has been done utilizing RPM formulations in carbonate rocks. , This can be attributed to the significant differences (i.e., mineral compositions, pore structure, and permeability characteristics) between carbonate rocks and sandstones. Aiming at making a new RPM applied in carbonate rocks, based on our previous studies, , we have shown that we can efficiently functionalize/immobilize polyacrylamides onto the pore surface of carbonate rocks. ,, In our previous study, sodium silicate was used to functionalize the carbonate surface with silicate groups, and then, 2-aminopropyltriethyoxysilane (APTES) reacted with the Si–O bonds to functionalize the surface with amine groups. ,, An organic linker such as formaldehyde can then be used to attach the polyacrylamide to the surface (i.e., the amides within the polyacrylamide would attach via the organic linker to the amines on the rock surface).…”
Section: Introductionmentioning
confidence: 99%
“…Aiming at making a new RPM applied in carbonate rocks, based on our previous studies, 31,33 we have shown that we can efficiently functionalize/immobilize polyacrylamides onto the pore surface of carbonate rocks. 31,33,34 In our previous study, sodium silicate was used to functionalize the carbonate surface with silicate groups, and then, 2-aminopropyltriethyoxysilane (APTES) reacted with the Si−O bonds to functionalize the surface with amine groups. 31,33,34 An organic linker such as formaldehyde can then be used to attach the polyacrylamide to the surface (i.e., the amides within the polyacrylamide would attach via the organic linker to the amines on the rock surface).…”
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.
“…This phenomenon ideally aims to selectively reduce the water permeability, while causing a minimal effect on the oil/gas permeability. The polymer adsorption on the rock pore walls is considered to be the underlying reason for this phenomenon [ 58 , 59 , 60 ]. Besides polymer adsorption, several mechanisms that contribute to polymer selectivity, including swelling/shrinking [ 61 ] fluid partitioning [ 62 ], lubrication, and steric and wettability effects [ 63 ], have been discussed and debated among scholars.…”
Conformance problems often exist in natural gas-related activities, resulting in excessive water production from natural gas production wells and/or excessive natural gas production from oil production wells. Several mechanical and chemical solutions were reported in the literature to mitigate the conformance problems. Among the chemical solutions, two classes of materials, namely polymer gels and water-soluble polymers, have been mostly reported. These systems have been mainly reviewed in several studies for their applications as water shutoff treatments for oil production wells. Natural gas production wells exhibit different characteristics and have different properties which could impact the performance of the chemical solutions. However, there has not been any work done on reviewing the applications of these systems for the challenging natural gas-related shutoff treatments. This study provides a comprehensive review of the laboratory evaluation and field applications of these systems used for water control in natural gas production wells and gas shutoff in oil production wells, respectively. The first part of the paper reviews the in-situ polymer gel systems, where both organically and inorganically crosslinked systems are discussed. The second part presents the water-soluble polymers with a focus on their disproportionate permeability reduction feature for controlling water in gas production wells. The review paper provides insights into the reservoir conditions, treatment design and intervention, and the success rate of the systems applied. Furthermore, the outcomes of the paper will provide knowledge regarding the limitations of the existing technologies, current challenges, and potential paths forwards.
“…Excessive water production is a major challenge in the oil and gas industry as water production can subsequently cause a significant reduction in hydrocarbon productivity − and increase the operational costs related to surface water treatment and handling. ,− Three different types of methods (i.e., chemical, mechanical, and biological) can be applied to regulate or decrease water production. ,,,, This review will focus on chemical treatments which have been extensively utilized to reduce water production. One class of chemical materials that have received widespread attention, − due to their potential performance, low cost, and ease of implementation, , are relative permeability modifiers (RPMs) that can selectively reduce the permeability to water while ideally having minimal effect on oil/gas permeability.…”
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.
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