Relevant bibliographies by topics / Inaccessible pore volume

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  1. Journal articles
  2. Dissertations / Theses
  3. Book chapters
  4. Conference papers

Academic literature on the topic 'Inaccessible pore volume'

Author: Grafiati
Published: 25 May 2024

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Journal articles on the topic "Inaccessible pore volume"

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Gilman, J. R., and D. J. MacMillan. "Improved Interpretation of the Inaccessible Pore-Volume Phenomenon." SPE Formation Evaluation 2, no. 04 (December 1, 1987): 442–48. http://dx.doi.org/10.2118/13499-pa.

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Sotirchos, Stratis V., and Solon Zarkanitis. "Inaccessible pore volume formation during sulfation of calcined limestones." AIChE Journal 38, no. 10 (October 1992): 1536–50. http://dx.doi.org/10.1002/aic.690381006.

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Bahadur, Jitendra, Cristian R. Medina, Lilin He, Yuri B. Melnichenko, John A. Rupp, Tomasz P. Blach, and David F. R. Mildner. "Determination of closed porosity in rocks by small-angle neutron scattering." Journal of Applied Crystallography 49, no. 6 (November 2, 2016): 2021–30. http://dx.doi.org/10.1107/s1600576716014904.

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Small-angle neutron scattering (SANS) and ultra-small-angle neutron scattering (USANS) have been used to study a carbonate rock from a deep saline aquifer that is a potential candidate as a storage reservoir for CO2sequestration. A new methodology is developed for estimating the fraction of accessible and inaccessible pore volume using SANS/USANS measurements. This method does not require the achievement of zero average contrast for the calculation of accessible and inaccessible pore volume fraction. The scattering intensity at highQincreases with increasing CO2pressure, in contrast with the low-Qbehaviour where the intensity decreases with increasing pressure. Data treatment for high-Qscattering at different pressures of CO2is also introduced to explain this anomalous behaviour. The analysis shows that a significant proportion of the pore system consists of micropores (<20 Å) and that the majority (80%) of these micropores remain inaccessible to CO2at reservoir pressures.
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Xiong, Lei, Yu Huang, Yuewei Wu, Chaochao Gao, and Wenxi Gao. "Study on the Influence of Inaccessible Pore Volume of Polymer Development." IOP Conference Series: Earth and Environmental Science 170 (July 2018): 022045. http://dx.doi.org/10.1088/1755-1315/170/2/022045.

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Lund, T., E. Ø. Bjørnestad, A. Stavland, N. B. Gjøvikli, A. J. P. Fletcher, S. G. Flew, and S. P. Lamb. "Polymer retention and inaccessible pore volume in North Sea reservoir material." Journal of Petroleum Science and Engineering 7, no. 1-2 (April 1992): 25–32. http://dx.doi.org/10.1016/0920-4105(92)90005-l.

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Rusin, Zbigniew, Piotr Stępień, and Karol Skowera. "Influence of fly ash on the pore structure of mortar using a differential scanning calorimetry analysis." MATEC Web of Conferences 322 (2020): 01027. http://dx.doi.org/10.1051/matecconf/202032201027.

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In the paper a low-temperature thermoporometry using differential scanning calorimetry (DSC) was employed for analyse of influence of siliceous fly ash (FA) on pore structure of non-air-entrained mortars (pore size, connectivity). A method of interpreting a heat flux differential scanning calorimetry records in pore structure was used for this purpose. The results demonstrated that the: (i) fly ash mortars have virtually no pores inaccessible to water, unlike the mortars with plain Portland cement in which inaccessible pores constitute a significant fraction, growing with the increase in w/b; (ii) with a decrease in w/b the ink-bottle volume decreases. Fraction of this pore type is relatively larger in fly ash mortars; (iii) Siliceous fly ash increased the volume of pores greater than 8 nm, in particular in the group with radii larger than 20 nm at all w/b ratios.
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Lan, Yuzheng, Rouzbeh Ghanbarnezhad Moghanloo, and Davud Davudov. "Pore Compressibility of Shale Formations." SPE Journal 22, no. 06 (August 17, 2017): 1778–89. http://dx.doi.org/10.2118/185059-pa.

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Summary This study introduces a novel outlook on a shale-pore system and on the potential effect of pore compressibility on the production performance. We divide porosity of the system into accessible and inaccessible pores, and incorporate inaccessible pores with grains into the part of the rock that is not accessible. In general, accessible pores contribute to flow directly, whereas inaccessible pores do not. We present a mathematical model that uses mercury-injection capillary pressure (MICP) data to determine the accessible-pore and inaccessible part of the rock (IRP) compressibility as a function of pressure. During MICP testing in a typical shale sample, the rock sample experiences conformance, compression, and intrusion as effective pressure increases. We characterize the compressibility value dependent on MICP data as a function of pressure. The calculated compressibility values for accessible pores generally appear to be much greater (two to three orders of magnitude) than those of IRP. Next, we evaluate how calculated accessible-pore-compressibility values affect gas recovery in several shale-gas plays. Our results suggest that substitution of total pore compressibility with accessible-pore compressibility can significantly change the reservoir-behavior prediction. The fundamental rock property used in many reservoir-engineering calculations including reserves estimates, reservoir performance, and production forecasting is the total pore-volume (PV) compressibility, which has an approximate value typically within the range of 1 × 10−6 to 1 × 10−4 psi−1 (Mahomad 2014). By recognizing the part of the pore system that actually contributes to production and identifying its compressibility, we can substitute total pore compressibility with accessible-pore compressibility. The result changes the value by nearly two orders of magnitude. The outcome of the paper changes the industry's take on prediction of reservoir performance, especially the rock-compaction mechanism. This study finds that production caused by rock compaction is in fact much greater than what has often been regarded, which will change the performance evaluation on a great number of reservoirs in terms of economic feasibility.
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Ferreira, V. H. S., and R. B. Z. L. Moreno. "Rheology-based method for calculating polymer inaccessible pore volume in core flooding experiments." E3S Web of Conferences 89 (2019): 04001. http://dx.doi.org/10.1051/e3sconf/20198904001.

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Polymer flooding is an enhanced oil recovery (EOR) method that reduces the mobility ratio between the displaced oil and the displacing injected water. The flow of polymer solutions through porous media is subject to some process-specific phenomena, such as the inaccessible pore volume (IAPV). Due to IAPV, polymer molecules move faster through the porous medium than smaller ones. Thus the IAPV value needs to be accounted for in experiments and field projects. Recent reports found that polymer in-situ rheology correlates with the IAPV. The objective of this paper is to develop a method for estimating IAPV based on the in-situ rheology of polymers. The methodology proposed here can be used in both single- and two-phase experiments. The technique requires measurement of polymer resistance factor (RF) and residual resistance factor (RRF) at steady state conditions. Core permeability, porosity, and residual oil saturation, as well as water and polymer bulk viscosities, also need to be taken into account. Correlations for polymer in-situ viscosity and shear rate are solved simultaneously, to wield an estimative for the IAPV. Aiming at to prove the method, we report 16 core-flooding experiments, eight single- and eight two-phase experiments. We used a flexible polymer and sandstone cores. All the tests were run using similar rock samples. In the single-phase experiments, we compare the alternative method with the classic tracer method to estimate IAPV. The results show an average relative difference of 11.5% between the methods. The two-phase results display, on average, an 18% relative difference to the IAPV measured in the single-phase experiments. The difference between single- and two-phase results can be an effect of the higher shear rates experienced in the two-phase floodings since, in these cases, the aqueous phase shear rate is also dependent on the phase saturation. Additionally, temperature, core length, pore pressure, and iron presence on the core did not show any influence on the IAPV for our two-phase experiments. The method proposed in this paper is limited by the accuracy of the pressure drop measurements across the core. For flexible polymers, the method is valid only for low and mid shear rates, but, accoording to literature, for rigid polymers the method should be accurate for a broad range of shear rates. The method proposed here allows the measurement of polymer IAPV on two- and single- phase core-flooding experiments when a tracer is not used.
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Leng, Jianqiao, Xindi Sun, Mingzhen Wei, and Baojun Bai. "A Novel Numerical Model of Gelant Inaccessible Pore Volume for In Situ Gel Treatment." Gels 8, no. 6 (June 13, 2022): 375. http://dx.doi.org/10.3390/gels8060375.

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Inaccessible pore volume (IAPV) can have an important impact on the placement of gelant during in situ gel treatment for conformance control. Previously, IAPV was considered to be a constant factor in simulators, yet it lacked dynamic characterization. This paper proposes a numerical simulation model of IAPV. The model was derived based on the theoretical hydrodynamic model of gelant molecules. The model considers both static features, such as gelant and formation properties, and dynamic features, such as gelant rheology and retention. To validate our model, we collected IAPV from 64 experiments and the results showed that our model fit moderately into these lab results, which proved the robustness of our model. The results of the sensitivity test showed that, considering rheology and retention, IAPV in the matrix dramatically increased when flow velocity and gelant concentration increased, but IAPV in the fracture maintained a low value. Finally, the results of the penetration degree showed that the high IAPV in the matrix greatly benefited gelant placement near the wellbore situation with a high flow velocity and gelant concentration. By considering dynamic features, this new numerical model can be applied in future integral reservoir simulators to better predict the gelant placement of in situ gel treatment for conformance control.
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Hilden, Sindre T., Halvor Møll Nilsen, and Xavier Raynaud. "Study of the Well-Posedness of Models for the Inaccessible Pore Volume in Polymer Flooding." Transport in Porous Media 114, no. 1 (June 15, 2016): 65–86. http://dx.doi.org/10.1007/s11242-016-0725-8.

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Dissertations / Theses on the topic "Inaccessible pore volume"

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Dongmo, Nguepi Guissel Lagnol. "Modèles mathématiques et numériques avancés pour la simulation du polymère dans les réservoirs pétroliers." Electronic Thesis or Diss., université Paris-Saclay, 2021. http://www.theses.fr/2021UPASG077.

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Une technique efficace pour accroître la production d’un champ pétrolier consiste à y injecter un mélange d’eau et de polymère. La viscosité du polymère réduit en effet la mobilité de l’eau, qui pousse alors mieux l’huile, d’où un taux d’extraction plus élevé. La simulation numérique d’un tel procédé de récupération d’hydrocarbures revêt donc d’une importance capitale. Or, malgré des décennies de recherche, la modélisation des écoulements avec polymère en milieu poreux et sa résolution numérique demeurent un sujet difficile. D’une part, les modèles habituellement employés par les ingénieurs de réservoir présentent, au mieux, des singularités de type résonance qui les rend faiblement hyperboliques. Ce défaut donne lieu à certaines complicationsD’une part, les modèles habituellement employés par les ingénieurs de réservoir présentent, au mieux, des singularités de type résonance qui les rend faiblement hyperboliques. Ce défaut donne lieu à certaines complications mais reste acceptable. Au pire, quand on veut incorporer l’effet du volume de pore inaccessible (IPV), les modèles deviennent non hyperboliques, ce qui aggrave les instabilités numériques susceptibles d’apparaître.D’autre part, les schémas numériques classiques ne conduisent pas à des résultats satisfaisants. Sans IPV, la diffusion excessive autour de l’onde de contact fait perdre les informations pertinentes. Avec IPV, l’existence des valeurs propres complexes crée des instabilités exponentielles au niveau continu qu’il faut traiter au niveau discret sous peine d’arrêt prématuré du code.L’objectif de cette thèse est de remédier à ces difficultés. Au niveau des modèles, nous analysons plusieurs lois d’IPV et établissons une équivalence entre deux d’entre elles. Nous proposons de surcroît des conditions suffisantes raisonnables sur la loi d’IPV en vue de l’hyperbolicité faible du système d’écoulement. Au niveau des schémas pour le problème sans IPV, nous préconisons une correction afin d’améliorer la précision des discontinuités de contact. Pour le problème avec IPV,nous élaborons une méthode de relaxation qui garantit la stabilité des calculs quelle que soit la loi IPV
An effective technique to increase production in an oil field is to inject a mixture of water and polymer. The viscosity of polymer reduces the mobility of water, which then pushes oil better, resulting in a higher extraction rate. The numerical simulation of such an enhanced oil recovery is therefore of paramount importance. However, despite decades of research, the modeling of polymer flows in porous media and its numerical resolution remains a difficult subject.On the one hand, the models traditionally used by reservoir engineers exhibit, in the best case, resonance-like singularities that make them weakly hyperbolic. Thisdefect gives rise to some complications but remains acceptable. In the worst case, when we wish to incorporate the effect of the inaccessible pore volume (IPV), themodels become non-hyperbolic, which exacerbates the numerical instabilities that are likely to appear.On the other hand, classical numerical schemes do not yield satisfactory results. Without IPV, the excessive diffusion around the contact wave causes the most relevant information to be lost. With IPV, the existence of complex eigenvalues generates exponential instabilities at the continuous level that must be addressed at the discrete level to avoid a premature stop of the code.The objective of this thesis is to remedy these difficulties. Regarding models, we analyze several IPV laws and show an equivalence between two of them. Furthermore, we propose reasonable sufficient conditions on the IPV law to enforce weak hyperbolicity of the flow system. Regarding schemes for the problem without IPV, we advocate a correction to improve the accuracy of contact discontinuities. For the problem with IPV, we design a relaxation method that guarantees the stability of the calculations for all IPV laws
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Book chapters on the topic "Inaccessible pore volume"

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Dongmo Nguepi, Guissel Lagnol, Benjamin Braconnier, Christophe Preux, Quang-Huy Tran, and Christophe Berthon. "A Relaxation Method for the Simulation of Possibly Non-hyperbolic Polymer Flooding Models with Inaccessible Pore Volume Effect." In Finite Volumes for Complex Applications IX - Methods, Theoretical Aspects, Examples, 445–53. Cham: Springer International Publishing, 2020. http://dx.doi.org/10.1007/978-3-030-43651-3_41.

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Conference papers on the topic "Inaccessible pore volume"

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Pancharoen, Monrawee, Marco Roberto Thiele, and Anthony Robert Kovscek. "Inaccessible Pore Volume of Associative Polymer Floods." In SPE Improved Oil Recovery Symposium. Society of Petroleum Engineers, 2010. http://dx.doi.org/10.2118/129910-ms.

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Lotsch, T., T. Muller, and G. Pusch. "The Effect of Inaccessible Pore Volume on Polymer Coreflood Experiments." In SPE Oilfield and Geothermal Chemistry Symposium. Society of Petroleum Engineers, 1985. http://dx.doi.org/10.2118/13590-ms.

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Dongmo, G., B. Braconnier, C. Preux, Q. Tran, and C. Berthon. "Glimm and Finite Volume Schemes for Polymer Flooding Model with and Without Inaccessible Pore Volume Law." In ECMOR XVII. European Association of Geoscientists & Engineers, 2020. http://dx.doi.org/10.3997/2214-4609.202035090.

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Fedorov, Konstantin Mikhailovich, Tatyana Anatolyevna Pospelova, Aleksandr Vyacheslavovich Kobyashev, Aleksandr Yanovich Gilmanov, Tatyana Nikolaevna Kovalchuk, and Aleksand Pavlovich Shevelev. "Determination of Adsorption-Retention Constants and Inaccessible Pore Volume for High-Molecular Polymers." In SPE Russian Petroleum Technology Conference. SPE, 2021. http://dx.doi.org/10.2118/206428-ms.

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Abstract The application of chemical enhanced oil recovery methods is based mainly on data from experiments. Determining the adsorption constants without destroying the sample remains a relevant problem. It is necessary for accurate data. The determination of filtration parameters of high-molecular polymers in a porous medium using special model is considered in this paper. The aim of the investigation is the solution of inverse problem of polymer transport with adsorption. The key data for this are the characteristic times of the polymer front propagation, water and rock densities, porosity, and initial polymer concentration. The solutions of the direct problem and the inverse problem from the characteristic form of equations are obtained. The algorithm of interpretation of adsorption-retention parameters and inaccessible pore volume form non-destructive experimental studies is developed. Comparison of the calculated values of the inaccessible pore volume with the results of laboratory studies leads to an error within 10%. The practical application of the algorithm was carried out using the data obtained in previously conducted experiments.
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Alves Fortunato, Maira, Samir Bekri, David Rousseau, Tiphaine Courtaud, and Nicolas Wartenberg. "Transport of EOR Surfactant in Reservoirs: Impact of Polymer on Apparent Surfactant Inaccessible Pore Volume." In SPE EuropEC - Europe Energy Conference featured at the 84th EAGE Annual Conference & Exhibition. SPE, 2023. http://dx.doi.org/10.2118/214411-ms.

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Abstract Designing chemical EOR processes requires reservoir simulations that need to be backed by a good understanding of the mechanisms at play when injecting surfactant-based solutions in porous media. One of the main challenges is that laboratory coreflood tests often show early surfactant breakthroughs that cannot be easily history matched. Indeed, contrary to polymer macromolecules, smaller surfactant molecules are not supposed to experience the inaccessible pore volume (IPV) effect. The study's aim was to determine if, in surfactant-polymer flooding, the polymer could influence the transport of the surfactant in such a way that it would not be able to invade a fraction of the pore space. To that end, two multi-steps coreflood tests were performed with cores of outcrop rock in conditions representative of a reference field case. In the first test, the surfactant was injected without polymer and then, after a brine injection flush, with polymer. In the second test, the surfactant was directly injected with polymer. For both tests, in order to bypass the adsorption effect, the surfactant injected volumes at breakthrough were determined on rocks having their surface already fully saturated by surfactant. Namely, a first surfactant slug was injected in order to fulfill maximum rock adsorption capacity, then, immediately after, a second at a higher concentration of which the breakthrough was potentially influenced by IPV only. The polymer IPV were estimated by the conventional two-slugs method. In the first test, the result showed that, without polymer, the surfactant accessed all of the pore volume of the core while, in presence of polymer, the surfactant could not access about 2% of the pore volume, which corresponded to the polymer IPV. In the second test, the surfactant was not able to access 12% of the pore volume, which also corresponded to the polymer IPV. These outcomes stand as evidence that the presence of polymer impacts the transport of surfactant, leading it to experience an "apparent" surfactant IPV effect equal to the polymer's one. This suggests that interactions between polymer and surfactant molecules take place at the pore level. This study illustrates that surfactant transport properties in reservoirs can be more complex than conventionally accounted for in dynamic reservoir simulation. As history-matching of the coreflood essays is needed to build a representative dataset for surfactant-based EOR processes, improvements of the simulation software appear required for cases where IPV cannot be neglected.
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Swadesi, Boni, Erdico Prasidya Saktika, Mahruri Sanmurjana, Septoratno Siregar, and Dyah Rini. "An experimental study of inaccessible pore volume on polymer flooding and its effect on oil recovery." In 2ND INTERNATIONAL CONFERENCE ON EARTH SCIENCE, MINERAL, AND ENERGY. AIP Publishing, 2020. http://dx.doi.org/10.1063/5.0006957.

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Swadesi, Boni, Roiduz Zumar, Mahruri Sanmurjana, Septoratno Siregar, and Dedy Kristanto. "The effect of inaccessible pore volume and adsorption on polymer flooding for field scale injection in RZ field." In 3RD INTERNATIONAL CONFERENCE ON EARTH SCIENCE, MINERAL, AND ENERGY. AIP Publishing, 2021. http://dx.doi.org/10.1063/5.0065527.

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Li, Z., R. M. Dean, H. Lashgari, H. Luo, J. W. Driver, W. Winoto, G. A. Pope, et al. "Recent Advances in Modeling Polymer Flooding." In SPE Improved Oil Recovery Conference. SPE, 2024. http://dx.doi.org/10.2118/218219-ms.

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Abstract New and improved physical property models have been added to the UTCHEM reservoir simulator to accommodate a broader range of polymer flooding applications and to improve its predictive capabilities. Accurate simulations of the chemistry and physics of polymer flooding are needed to design and optimize a polymer flood including the selection of the best polymer to use for specific reservoir conditions. The new polymer viscosity model implemented in UTCHEM can be used to calculate polymer viscosity more accurately as a function of polymer concentration, shear rate, salinity and hardness, temperature, and intrinsic viscosity. The new model is based on extensive polymer viscosity and rheological measurements. The improved polymer rheology is important for more reliable predictions of polymer injectivity and reservoir sweep. A hydrolysis model has been added to UTCHEM to aid in the selection of polymers as a function of temperature, brine composition and pH. A new cation exchange model that includes hydrolyzed polyacrylamide has been implemented to account for the effect of different cations in the brine on the polymer properties as a function of the degree of hydrolysis. The inaccessible pore volume model has been modified to include the exclusion of large polymer molecules from pores below a certain size in addition to the effect of polymer size on the velocity of the polymer molecules within the pores that are large enough for the polymer to enter. The new inaccessible pore volume model serves as a useful tool for selecting reservoir- compatible polymers and improving the accuracy of the simulations. Extensive high-quality lab data were used to validate the new models. Simulation cases were built to illustrate how the models can be used to upscale lab results to field scale.
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Seright, Randall Scott, and Dongmei Wang. "Impact of Salinity, Hardness, Lithology, and ATBS Content on HPAM Polymer Retention for the Milne Point Polymer Flood." In SPE Western Regional Meeting. SPE, 2023. http://dx.doi.org/10.2118/212946-ms.

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Abstract At the Milne Point polymer flood (North Slope of Alaska), polymer retention is dominated by the clay, illite. Illite (and kaolinite) cause no delay in polymer propagation in Milne Point core material, but they reduce the effective polymer concentration and viscosity by a significant amount (e.g., 30%), thus reducing in efficiency of oil displacement until the full injected polymer concentration is regained (which requires several pore volumes of throughput). This work demonstrates that polymer retention on illite is not sensitive to monovalent ion concentration, but it increases significantly with increased divalent cation concentration. Incorporation of a small percentage of ATBS monomers into HPAM polymers is shown to dramatically reduce retention. Results are discussed in context with previous literature reports. Interestingly, an extensive literature review reveals that polymer retention is typically only modestly sensitive to the presence of oil. Extensive examination of literature on inaccessible pore volume suggests the parameter was commonly substantially overestimated, especially in rock/sand more permeable than 500 md (which comprises the vast majority of existing field polymer floods).
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Song, Haofeng, Pinaki Ghosh, and Kishore Mohanty. "Transport of Polymers in Low Permeability Carbonate Rocks." In SPE Annual Technical Conference and Exhibition. SPE, 2021. http://dx.doi.org/10.2118/206024-ms.

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Abstract Polymer transport and retention affect oil recovery and economic feasibility of EOR processes. Most studies on polymer transport have focused on sandstones with permeabilities (k) higher than 200 mD. A limited number of studies were conducted in carbonates with k less than 100 mD and very few in the presence of residual oil. In this work, transport of four polymers with different molecular weights (MW) and functional groups are studied in Edwards Yellow outcrop cores (k&lt;50 mD) with and without residual oil saturation (Sor). The retention of polymers was estimated by both the material balance method and the double-bank method. The polymer concentration was measured by both the total organic carbon (TOC) analyzer and the capillary tube rheology. Partially hydrolyzed acrylamide (HPAM) polymers exhibited high retention (&gt; 150 μg/g), inaccessible pore volume (IPV) greater than 7%, and high residual resistance factor (&gt;9). A sulfonated polyacrylamide (AN132), showed low retentions (&lt; 20 μg/g) and low IPV. The residual resistance factor (RRF) of AN132 in the water-saturated rock was less than 2, indicating little blocking of pore throats in these tight rocks. The retention and RRF of the AN132 polymer increased in the presence of residual oil saturation due to partial blocking of the smaller pore throats available for polymer propagation in an oil-wet core.
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