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Journal articles on the topic 'Inaccessible pore volume'

Author: Grafiati

Published: 25 May 2024

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1

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

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2

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

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3

Bahadur, Jitendra, Cristian R. Medina, Lilin He, et al. "Determination of closed porosity in rocks by small-angle neutron scattering." Journal of Applied Crystallography 49, no. 6 (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 l

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4

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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5

Lund, T., E. Ø. Bjørnestad, A. Stavland, et al. "Polymer retention and inaccessible pore volume in North Sea reservoir material." Journal of Petroleum Science and Engineering 7, no. 1-2 (1992): 25–32. http://dx.doi.org/10.1016/0920-4105(92)90005-l.

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6

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;

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Lan, Yuzheng, Rouzbeh Ghanbarnezhad Moghanloo, and Davud Davudov. "Pore Compressibility of Shale Formations." SPE Journal 22, no. 06 (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

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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 estim

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9

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 (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 experimen

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10

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 (2016): 65–86. http://dx.doi.org/10.1007/s11242-016-0725-8.

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11

Meirer, Florian, Sam Kalirai, Darius Morris, et al. "Life and death of a single catalytic cracking particle." Science Advances 1, no. 3 (2015): e1400199. http://dx.doi.org/10.1126/sciadv.1400199.

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Fluid catalytic cracking (FCC) particles account for 40 to 45% of worldwide gasoline production. The hierarchical complex particle pore structure allows access of long-chain feedstock molecules into active catalyst domains where they are cracked into smaller, more valuable hydrocarbon products (for example, gasoline). In this process, metal deposition and intrusion is a major cause for irreversible catalyst deactivation and shifts in product distribution. We used x-ray nanotomography of industrial FCC particles at differing degrees of deactivation to quantify changes in single-particle macropo

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12

Ferreira, V. H. S., and R. B. Z. L. Moreno. "POLYMER APPARENT VISCOSITY DEPENDENCE ON INACCESSIBLE PORE VOLUME: LABORATORY AND FIELD STUDIES OF ITS INFLUENCE ON ENHANCED OIL RECOVERY." Brazilian Journal of Petroleum and Gas 12, no. 4 (2019): 205–18. http://dx.doi.org/10.5419/bjpg2018-0019.

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13

Jiang, Y., M. Lawrence, M. P. Ansell, and A. Hussain. "Cell wall microstructure, pore size distribution and absolute density of hemp shiv." Royal Society Open Science 5, no. 4 (2018): 171945. http://dx.doi.org/10.1098/rsos.171945.

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This paper, for the first time, fully characterizes the intrinsic physical parameters of hemp shiv including cell wall microstructure, pore size distribution and absolute density. Scanning electron microscopy revealed microstructural features similar to hardwoods. Confocal microscopy revealed three major layers in the cell wall: middle lamella, primary cell wall and secondary cell wall. Computed tomography improved the visualization of pore shape and pore connectivity in three dimensions. Mercury intrusion porosimetry (MIP) showed that the average accessible porosity was 76.67 ± 2.03% and pore

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14

Li, Jing, Keliu Wu, Zhangxin Chen, et al. "On the Negative Excess Isotherms for Methane Adsorption at High Pressure: Modeling and Experiment." SPE Journal 24, no. 06 (2019): 2504–25. http://dx.doi.org/10.2118/197045-pa.

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Summary An excess adsorption amount obtained in experiments is always determined by mass balance with a void volume measured by helium (He) –expansion tests. However, He, with a small kinetic diameter, can penetrate into narrow pores in porous media that are inaccessible to adsorbate gases [e.g., methane (CH4)]. Thus, the actual accessible volume for a specific adsorbate is always overestimated by an He–based void volume; such overestimation directly leads to errors in the determination of excess isotherms in the laboratory, such as “negative isotherms” for gas adsorption at high pressures, wh

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15

Manichand, R. N. N., and R. S. S. Seright. "Field vs. Laboratory Polymer-Retention Values for a Polymer Flood in the Tambaredjo Field." SPE Reservoir Evaluation & Engineering 17, no. 03 (2014): 314–25. http://dx.doi.org/10.2118/169027-pa.

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Summary During a polymer flood, polymer retention can have a major impact on the rate of polymer propagation through a reservoir, and consequently on oil recovery. A review of the polymer-retention literature revealed that iron and high-surface-area minerals (e.g., clays) dominate polymer-retention measurements in permeable rock and sand (&gt;100 md). A review of the literature on inaccessible pore volume (IAPV) revealed inconsistent and unexplained behavior. A conservative approach to design of a polymer flood in high-permeability (&gt;1 darcy) sands would assume that IAPV is zero. La

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FERNANDEZ, LAURA GABRIELA, Esteban Gonzalez, A. Pizarro, S. Abrigo, J. Choque, and M. Tealdi. "NANOFLUID INJECTIVITY STUDY FOR ITS APPLICATION IN A PROCESS OF ENHANCED OIL RECOVERY (CEOR)." Latin American Applied Research - An international journal 49, no. 2 (2019): 125–30. http://dx.doi.org/10.52292/j.laar.2019.37.

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The application of tertiary recovery techniques through chemical injection (CEOR) is in full development in the mature oil fields of Argentina. An experimental study of nanofluids intended for enhanced oil recovery is presented in this work. A polyacrylamide solution prepared in brine with addition of silica nanoparticles was used as the focus of the study. Dynamic sweep tests of the displacement fluids in a laboratory-scale triaxial cell using a standard Berea sandstone cores that simulates the formation of the reservoir allow the calculation of parameters related to its injectivity, which ta

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17

Ding, Lei, Qianhui Wu, Lei Zhang, and Dominique Guérillot. "Application of Fractional Flow Theory for Analytical Modeling of Surfactant Flooding, Polymer Flooding, and Surfactant/Polymer Flooding for Chemical Enhanced Oil Recovery." Water 12, no. 8 (2020): 2195. http://dx.doi.org/10.3390/w12082195.

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Fractional flow theory still serves as a powerful tool for validation of numerical reservoir models, understanding of the mechanisms, and interpretation of transport behavior in porous media during the Chemical-Enhanced Oil Recovery (CEOR) process. With the enrichment of CEOR mechanisms, it is important to revisit the application of fractional flow theory to CEOR at this stage. For surfactant flooding, the effects of surfactant adsorption, surfactant partition, initial oil saturation, interfacial tension, and injection slug size have been systematically investigated. In terms of polymer floodi

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18

Sui, Yingfei, Chuanzhi Cui, Yidan Wang, Shuiqingshan Lu, and Yin Qian. "Displacement Mechanism and Flow Characteristics of Polymer Particle Dispersion System Based on Capillary Bundle Model." International Journal of Energy Research 2024 (May 3, 2024): 1–11. http://dx.doi.org/10.1155/2024/4550335.

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During the development of oil reservoirs, a rapid increase in water cut following reservoir flooding leads to inefficient or ineffective circulation of injected water, rendering a significant portion of the remaining oil in the reservoir inaccessible. The displacement method using polymer particle dispersion systems effectively solves the issue of rapid water breakthrough in oil reservoirs. Owing to the particle phase separation phenomenon, polymer particles can selectively penetrate into the larger pores where water circulation is inefficient, enhance their flow resistance, and thereby achiev

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19

Nie, Xiang Rong, and Shi Qing Cheng. "Pressure Transient Analysis of Polymer Injection Wells." Advanced Materials Research 361-363 (October 2011): 370–76. http://dx.doi.org/10.4028/www.scientific.net/amr.361-363.370.

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Polymer solution is known as non-Newtonian Fluid. Hence, when a well is injected by polymer solution, the well test data analysis using Newtonian fluid flow model will be erroneous. However, the analysis results usually were inaccurate when generalized non-Newtonian fluid model which considering polymer solution as power law fluid and taking no account of physical and chemical behaviors. These results clearly suggest the need for a study to come up with a new model considering both physical and chemical behaviors when polymer solution flowing in the reservoirs. At first, this study modified tw

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20

Ferreira, Vitor H. S., and Rosangela B. Z. L. Moreno. "Experimental evaluation of low concentration scleroglucan biopolymer solution for enhanced oil recovery in carbonate." Oil & Gas Science and Technology – Revue d’IFP Energies nouvelles 75 (2020): 61. http://dx.doi.org/10.2516/ogst/2020056.

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Injection of polymers is beneficial for Enhanced Oil Recovery (EOR) because it improves the mobility ratio between the displaced oil and the displacing injected water. Because of that benefit, polymer flooding improves sweep and displacing efficiencies when compared to waterflooding. Due to these advantages, polymer flooding has many successful applications in sandstone reservoirs. However, polymer flooding through carbonatic rock formations is challenging because of heterogeneity, high anionic polymer retention, low matrix permeability, and hardness of the formation water. The scleroglucan is

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21

Zhu, Changyu, Shiqing Cheng, Youwei He, et al. "Pressure Transient Behavior for Alternating Polymer Flooding in a Three-zone Composite Reservoir." Polymers and Polymer Composites 25, no. 1 (2017): 1–10. http://dx.doi.org/10.1177/096739111702500101.

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Alternating polymer flooding has achieved great attractions recently in oil industry, however, the research of pressure analysis in alternating polymer flooding reservoir is rare. This work presents a numerical pressure analysis method of three-zone composite model for formation evaluation. A new numerical pressure analysis model (three-zone composite model) is established by considering diffusion, convection, shear, and inaccessible pore volume, which is based on the rheology experiments. Based on this model, the type curves are then developed and sensitivity analysis is further conducted. Th

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22

Bryant, Steven, and Sue Raikes. "Prediction of elastic‐wave velocities in sandstones using structural models." GEOPHYSICS 60, no. 2 (1995): 437–46. http://dx.doi.org/10.1190/1.1443781.

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Elastic‐wave propagation in fluid‐saturated sandstones depends upon two sets of rock features: (1) the volume fractions and elastic constants of the rock constituents (quartz, clay, water, etc.) and (2) microstructural geometry (grain contacts, pore aspect ratios). While the former data are usually obtainable, the latter are relatively inaccessible. We present a new method for determining microstructural data using idealized but physically representative models of sandstone. The key to the method is the simulation of certain depositional and diagenetic processes in a manner that completely spe

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23

Liu, Yongge, Jian Hou, Lingling Liu, et al. "An Inversion Method of Relative Permeability Curves in Polymer Flooding Considering Physical Properties of Polymer." SPE Journal 23, no. 05 (2018): 1929–43. http://dx.doi.org/10.2118/189980-pa.

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Summary Reliable relative permeability curves of polymer flooding are of great importance to the history matching, production prediction, and design of the injection and production plan. Currently, the relative permeability curves of polymer flooding are obtained mainly by the steady-state, nonsteady-state, and pore-network methods. However, the steady-state method is extremely time-consuming and sometimes produces huge errors, while the nonsteady-state method suffers from its excessive assumptions and is incapable of capturing the effects of diffusion and adsorption. As for the pore-network m

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24

Muhammed, Nasiru Salahu, Md Bashirul Haq, Dhafer Al-Shehri, Mohammad Mizanur Rahaman, Alireza Keshavarz, and S. M. Zakir Hossain. "Comparative Study of Green and Synthetic Polymers for Enhanced Oil Recovery." Polymers 12, no. 10 (2020): 2429. http://dx.doi.org/10.3390/polym12102429.

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Several publications by authors in the field of petrochemical engineering have examined the use of chemically enhanced oil recovery (CEOR) technology, with a specific interest in polymer flooding. Most observations thus far in this field have been based on the application of certain chemicals and/or physical properties within this technique regarding the production of 50–60% trapped (residual) oil in a reservoir. However, there is limited information within the literature about the combined effects of this process on whole properties (physical and chemical). Accordingly, in this work, we prese

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Yu, Haiyang, Hui Guo, Youwei He, et al. "Numerical Well Testing Interpretation Model and Applications in Crossflow Double-Layer Reservoirs by Polymer Flooding." Scientific World Journal 2014 (2014): 1–11. http://dx.doi.org/10.1155/2014/890874.

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This work presents numerical well testing interpretation model and analysis techniques to evaluate formation by using pressure transient data acquired with logging tools in crossflow double-layer reservoirs by polymer flooding. A well testing model is established based on rheology experiments and by considering shear, diffusion, convection, inaccessible pore volume (IPV), permeability reduction, wellbore storage effect, and skin factors. The type curves were then developed based on this model, and parameter sensitivity is analyzed. Our research shows that the type curves have five segments wit

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26

Gaus, Garri, Anton Kalmykov, Bernhard M. Krooss, and Reinhard Fink. "Experimental Investigation of the Dependence of Accessible Porosity and Methane Sorption Capacity of Carbonaceous Shales on Particle Size." Geofluids 2020 (February 14, 2020): 1–13. http://dx.doi.org/10.1155/2020/2382153.

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Crushing and grinding of carbonaceous shale samples is likely to enhance the accessibility of pores and embedded organic matter as compared to the intact rock. This may lead to an overestimation of the total (volume and sorptive) gas storage capacity. In order to investigate the importance of these effects we have measured unconfined apparent grain densities (helium pycnometry) and methane sorption capacities (high-pressure methane excess sorption) of four carbonaceous shales (Cambro-Ordovician Alum Shale, Jurassic Kimmeridge Clay, Jurassic/Cretaceous Bazhenov Shale, and Late Cretaceous Eagle

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27

Erfando, Tomi, and Rizqy Khariszma. "Sensitivity Study of The Effect Polymer Flooding Parameters to Improve Oil Recovery Using X-Gradient Boosting Algorithm." Journal of Applied Engineering and Technological Science (JAETS) 4, no. 2 (2023): 873–84. http://dx.doi.org/10.37385/jaets.v4i2.1871.

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Implementation of waterflooding sometimes cannot increase oil recovery effectively and requires additional methods to increase oil recovery. Polymer flooding is a common chemical EOR method that has been implemented in the last few decades and provides good effectiveness in increasing oil recovery and can reduce the amount of injection fluid injected into the reservoir. Seeing the success of polymer flooding in increasing oil recovery, it is necessary to know the parameters that influence the success of polymer flooding so that it can be evaluated and taken into consideration in creating a new

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Aadland, Reidun, Carter Dziuba, Ellinor Heggset, et al. "Identification of Nanocellulose Retention Characteristics in Porous Media." Nanomaterials 8, no. 7 (2018): 547. http://dx.doi.org/10.3390/nano8070547.

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The application of nanotechnology to the petroleum industry has sparked recent interest in increasing oil recovery, while reducing environmental impact. Nanocellulose is an emerging nanoparticle that is derived from trees or waste stream from wood and fiber industries. Thus, it is taken from a renewable and sustainable source, and could therefore serve as a good alternative to current Enhanced Oil Recovery (EOR) technologies. However, before nanocellulose can be applied as an EOR technique, further understanding of its transport behavior and retention in porous media is required. The research

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29

Clemens, Torsten, Markus Lüftenegger, Ajana Laoroongroj, Rainer Kadnar, and Christoph Puls. "The Use of Tracer Data To Determine Polymer-Flooding Effects in a Heterogeneous Reservoir, 8 Torton Horizon Reservoir, Matzen Field, Austria." SPE Reservoir Evaluation & Engineering 19, no. 04 (2016): 655–63. http://dx.doi.org/10.2118/174349-pa.

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Summary Polymer-injection pilot projects aim at reducing the uncertainty and risk of full-field polymer-flood implementation. The interpretation of polymer-pilot projects is challenging because of the complexity of the process and fluids moving out of the polymer-pilot area. The interpretation is increasingly more complicated with the heterogeneity of the reservoir. In the polymer pilot performed in the 8 Torton Horizon (TH) reservoir of the Matzen field in Austria, a polymer-injection well surrounded by a number of production wells was selected. A tracer was injected 1 week before polymer inj

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Wang, Dongmei, Randall S. Seright, Zhenbo Shao, and Jinmei Wang. "Key Aspects of Project Design for Polymer Flooding at the Daqing Oilfield." SPE Reservoir Evaluation & Engineering 11, no. 06 (2008): 1117–24. http://dx.doi.org/10.2118/109682-pa.

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Summary This paper describes the design procedures that led to favorable incremental oil production and reduced water production during 12 years of successful polymer flooding in the Daqing oil field. Special emphasis is placed on some new design factors that were found to be important on the basis of extensive experience with polymer flooding. These factors include (1) recognizing when profile modification is needed before polymer injection and when zone isolation is of value during polymer injection, (2) establishing the optimum polymer formulations and injection rates, and (3) time-dependen

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Nino J.C, Lizcano, Ferreira Vitor Hugo de Sousa, and Moreno Rosangela B. Z. L. "Less-Concentrated HPAM Solutions as a Polymer Retention Reduction Method in CEOR." Revista Fuentes el Reventón Energético 18, no. 1 (2020): 75–92. http://dx.doi.org/10.18273/revfue.v17n1-2020008.

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Polymer Flooding has become one of the most implemented EOR techniques, due to three factors: First, Polymer flooding has expanded the range of the screening criteria parameters. Second, this EOR method is more effective than water injection, while handling water management issues in high water-cut reservoirs. Nevertheless, polymer retention can turn a viable technical project into an uneconomical one. Polymer loss due to retention is an inevitable phenomenon, which happens during injection processes. The development of experimental analysis aiming to minimize or reduce polymer loss from the d

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32

Carpenter, Chris. "Low Polymer Retention Possible in Flooding of High-Salinity Carbonate Reservoirs." Journal of Petroleum Technology 73, no. 11 (2021): 60–61. http://dx.doi.org/10.2118/1121-0060-jpt.

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This article, written by JPT Technology Editor Chris Carpenter, contains highlights of paper SPE 202809, “Low Polymer Retention Opens for Field Implementation of Polymer Flooding in High-Salinity Carbonate Reservoirs,” by Arne Skauge, SPE, and Tormod Skauge, SPE, Energy Research Norway, and Shahram Pourmohamadi, Brent Asmari, et al., prepared for the 2020 Abu Dhabi International Petroleum Exhibition and Conference, Abu Dhabi, held virtually 9–12 November. The paper has not been peer reviewed. Polymer flooding has been a successful enhanced-oil-recovery method in sandstone reservoirs for decade

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Khorsandi, Saeid, Changhe Qiao, and Russell T. Johns. "Displacement Efficiency for Low-Salinity Polymer Flooding Including Wettability Alteration." SPE Journal 22, no. 02 (2016): 417–30. http://dx.doi.org/10.2118/179695-pa.

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Summary Polymer flooding can significantly improve sweep and delay breakthrough of injected water, thereby increasing oil recovery. Polymer viscosity degrades in reservoirs with high-salinity brines, so it is advantageous to inject low-salinity water as a preflush. Low-salinity waterflooding (LSW) can also improve local-displacement efficiency by changing the wettability of the reservoir rock from oil-wet to more water-wet. The mechanism for wettability alteration for LSW in sandstones is not very well-understood; however, experiments and field studies strongly support that cation-exchange (CE

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Wang, Dongmei, Chunxiao Li, and Randall S. Seright. "Laboratory Evaluation of Polymer Retention in a Heavy Oil Sand for a Polymer Flooding Application on Alaska's North Slope." SPE Journal 25, no. 04 (2020): 1842–56. http://dx.doi.org/10.2118/200428-pa.

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Summary For a polymer flooding field trial in a heavy oil reservoir on Alaska's North Slope, polymer retention is a key parameter. Because of the economic impact of retention, this parameter was extensively studied using field core material and conditions. In this paper, multiple types of laboratory measurements were used to assess hydrolyzed polyacrylamides (HPAM) polymer retention, including a brine tracer, effluent viscosity, total effluent organic carbon, and effluent chemiluminescent nitrogen. Retention tests were conducted in different Milne Point Schrader Bluff sands, with extensive per

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Souayeh, Maissa, Rashid S. Al-Maamari, Ahmed Mansour, Mohamed Aoudia, and Thomas Divers. "Injectivity and Potential Wettability Alteration of Low-Salinity Polymer in Carbonates: Role of Salinity, Polymer Molecular Weight and Concentration, and Mineral Dissolution." SPE Journal 27, no. 01 (2021): 840–63. http://dx.doi.org/10.2118/208581-pa.

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Summary Coupling polymer with low-salinity water (LSW) to promote enhanced oil recovery (EOR) in carbonate reservoirs has attracted significant interest in the petroleum industry. However, low-salinity polymer (LSP) application to improve oil extraction from such rocks remains a challenge because of the complex synergism between these two EOR agents. Thus, this paper highlights the main factors that govern the LSP displacement process in carbonate reservoirs in terms of wettability alteration and mobility control. A series of experiments including contact angle, spontaneous imbibition, injecti

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Santoso, Ryan, Victor Torrealba, and Hussein Hoteit. "Investigation of an Improved Polymer Flooding Scheme by Compositionally-Tuned Slugs." Processes 8, no. 2 (2020): 197. http://dx.doi.org/10.3390/pr8020197.

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Polymer flooding is an effective enhanced oil recovery technology used to reduce the mobility ratio and improve sweep efficiency. A new polymer injection scheme is investigated that relies on the cyclical injection of low-salinity, low-concentration polymer slugs chased by high-salinity, high-concentration polymer slugs. The effectiveness of the process is a function of several reservoir and design parameters related to polymer type, concentration, salinity, and reservoir heterogeneity. We use reservoir simulations and design-of-experiments (DoE) to investigate the effectiveness of the propose

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Najafiazar, Bahador, Dag Wessel-Berg, Per Eirik Bergmo, et al. "Polymer Gels Made with Functionalized Organo-Silica Nanomaterials for Conformance Control." Energies 12, no. 19 (2019): 3758. http://dx.doi.org/10.3390/en12193758.

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Deep placement of gel in waterflooded hydrocarbon reservoirs may block channels with high water flow and may divert the water into other parts of the reservoir, resulting in higher oil production. In order to get the gel constituents to the right reservoir depths, a delay in the gelling time in the order of weeks at elevated temperatures will be necessary. In this work, a methodology for controlled gelation of partially hydrolyzed polyacrylamide using hybrid nanomaterials with functional groups as cross-linkers was developed. Two delay mechanisms with hybrid materials and polyelectrolyte compl

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Smiraglia, Claudio. "L’Antartide è veramente un "awful place"? I caratteri ambientali del continente più freddo della Terra." ACME - Annali della Facoltà di Lettere e Filosofia dell’Università degli Studi di Milano, no. 03 (December 2012): 29–46. http://dx.doi.org/10.7358/acme-2012-003-smir.

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The Antarctic continent is certainly made an "awful" place by its harsh climate: in the past, explorers and researchers endured terrible hardships and the climate remains a challenge today, in spite of the many improvements in knowledge and technology. The Antarctic may be termed "the continent of the extremes", as it occupies an area unlike any other on earth. It is the farthest and most inaccessible and isolated continent; the most regular because of its rounded shape, with the South Pole at the centre; the coldest continent, with temperatures falling to -90°C; the driest (with an average of

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Yoshizawa, N., Y. Yamada, M. Shiraishi, K. Kaneko, and N. Setoyama. "Evaluation of Inaccessible Pore Structures in Random Porous Solids." MRS Proceedings 407 (1995). http://dx.doi.org/10.1557/proc-407-51.

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ABSTRACTA fine pore characterization method is investigated for a disordered solid including inaccessible pores. Here inaccessible pores denote ones into which N2 molecule cannot access at 77 K. Activated carbons prepared differently are examined. The basic idea of the method is as follows: (1) Pores are classified into effective micropores (further devided into smaller and larger micropores distinguished from DR (Dubinin-Radushkevich) analysis and inaccessible pores. (2) Volume fraction is determined for each type of pore considering densities. (3) Debye-Bueche plot derived from SAXS analysis

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Zhang, Chu, Yanbin Yao, Rudy Swennen, and Yuheng Zhang. "Re-evaluating the methane adsorption behavior in shale kerogen: Unifying experiment and molecular simulation." Physics of Fluids 36, no. 2 (2024). http://dx.doi.org/10.1063/5.0188365.

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The methane adsorption capacity is crucial for evaluating gas-in-place resources and the gas production potential in shale gas reservoirs. There are many reports concerning the interfacial interaction between methane fluid and rock using various thermodynamic models; however, little research has been performed to reveal how methane is adsorbed into nanopores with different scales. In this study, we did methane adsorption experiments on nine Longmaxi Formation shale kerogen. Then, molecular simulation and an improved Ono–Kondo model were used to analyze the methane adsorption behaviors. Results

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S. Seright, Randall, and Dongmei Wang. "Literature Review and Experimental Observations of the Effects of Salinity, Hardness, Lithology, and ATBS Content on HPAM Polymer Retention for the Milne Point Polymer Flood." SPE Journal, June 1, 2023, 1–16. http://dx.doi.org/10.2118/212946-pa.

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Summary 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 the efficiency of oil displacement until the full injected polymer concentration is regained [which requires several pore volumes (PVs) of throughput]. This work demonstrates that polymer retention on illite is not sensitive to monovalent ion concentration, but it increases

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Ramadani and Tomi Erfando. "Optimization of Polymer Flooding Using Genetic Algorithm." Journal of Earth Energy Science, Engineering, and Technology 6, no. 1 (2023). http://dx.doi.org/10.25105/jeeset.v6i1.16319.

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One of the methods to achieve optimal conditions in increasing oil recovery through injecting polymers is by optimizing the parameters that influence the success of injecting polymers to provide information and be considered when determining new schemes for implementation in the future. Optimization to obtain the optimum value of the recovery factor and the best value of the parameters PV, injection rate, injection time, injection pressure, adsorption, residual resistance factor (RRF), and inaccessible pore volume (IPV) using a genetic algorithm with three training ratios and testing 70: 30, 8

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Scholz, Gunthard, Mario Zauer, Jan Van den Bulcke, et al. "Investigation on wax-impregnated wood. Part 2: Study of void spaces filled with air by He pycnometry, Hg intrusion porosimetry, and 3D X-ray imaging." Holzforschung 64, no. 5 (2010). http://dx.doi.org/10.1515/hf.2010.090.

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Abstract The quantification of wax and remaining voids filled with air in wax-treated wood has not been described in detail in the literature, although such products are commercially available. In this paper, Scots pine (Pinus sylvestris L.) and beech (Fagus sylvatica L.) samples were impregnated with a hot melting amide wax and characterized. The apparent densities were measured with helium pycnometry and mercury intrusion porosimetry. The pore size distribution was determined by means of mercury intrusion porosimetry and samples were visualized with 3D X-ray tomography. The remaining void sp

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Song, Haofeng, Pinaki Ghosh, Miguel Mejia, and Kishore Mohanty. "Polymer Transport in Low-Permeability Carbonate Rocks." SPE Reservoir Evaluation & Engineering, April 1, 2022, 1–14. http://dx.doi.org/10.2118/206024-pa.

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Summary The efficiency of a polymer flood depends on polymer transport and retention. Most studies on polymer transport in the literature have been focused on high-permeability sandstones. A limited number of investigations have been conducted in carbonates with permeability 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 was studied in 1-ft-long Edwards Yellow outcrop cores (permeability &lt; 50 md) with and without residual oil. The retention of polymers was estimated by bo

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Jia, Hu, Pengwu Li, and Yufei Zhang. "Polymer Gel for Water Shutoff in Complex Oil and Gas Reservoirs: Mechanisms, Simulation, and Decision-Making." SPE Journal, September 1, 2023, 1–17. http://dx.doi.org/10.2118/217457-pa.

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Summary Gel treatment is often used for water shutoff in high water-cut oil or gas wells. Although the properties and usage methods of gel have been well documented by different investigators, gel treatment performance is not always satisfactory in field application, especially in oil or gas reservoirs with complex conditions, such as strong bottomwater reservoirs, high-permeability-ratio oil reservoirs, and fractured gas reservoirs. In this work, we attempt to improve gel treatment application in complex situations according to the causes of disappointing performance, including unreliable num

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Alfazazi, Umar, Nithin Chacko Thomas, Emad Walid Al-Shalabi, and Waleed AlAmeri. "Investigation of the Effect of Residual Oil and Wettability on Sulfonated Polymer Retention in Carbonate under High-Salinity Conditions." SPE Journal, November 1, 2023. http://dx.doi.org/10.2118/207892-pa.

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Summary Polymer flooding in carbonate reservoirs is greatly affected by polymer retention, which is mainly due to adsorption by polymer-rock surface interactions. Consequently, this leads to a delay in polymer front propagation and related oil recovery response. This work investigates the effects of residual oil (Sor) and wettability on sulfonated-based (ATBS) polymer retention under the conditions of high salinity and moderate temperature. Polymer single- and two-phase dynamic adsorption tests as well as bulk and in-situ rheological experiments were conducted on outcrop carbonate cores in the

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Zhang, Bingjun, Abdelhalim I. A. Mohamed, Lamia Goual, and Mohammad Piri. "Pore-scale experimental investigation of oil recovery enhancement in oil-wet carbonates using carbonaceous nanofluids." Scientific Reports 10, no. 1 (2020). http://dx.doi.org/10.1038/s41598-020-74450-w.

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Abstract This study investigates the pore-scale displacement mechanisms of crude oil in aged carbonate rocks using novel engineered carbon nanosheets (E-CNS) derived from sub-bituminous coal. The nanosheets, synthesized by a simple top-down technique, were stable in brine without any additional chemicals. Owing to their amphiphilic nature and nano-size, they exhibited dual properties of surfactants and nanoparticles and reduced the oil/brine interfacial tension (IFT) from 14.6 to 5.5 mN/m. X-ray micro-computed tomography coupled with miniature core-flooding was used to evaluate their ability t

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