The Interfacial Tension of Some Hydrocarbons against Water.

Rose, William E.; Seyer, William F.

doi:10.1021/j150486a011

Cited by 24 publications

(4 citation statements)

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“…44 The IFTs of the alkane+H 2 O system showed the typical trend cyclic > linear > branched alkanes; however, differences between the IFT of n-alkane+H 2 O and other systems are within 3 mN/m. 44,79 These observations agree with those reported by other simulations [17][18][19][22][23][24][25]27,28,31,37,40,42 and theoretical [51][52][53]56,57,61,65 investigations. It is important to note that there is a spread among the experimental data of the IFTs of the n-alkane+water system.…”

Section: Alkane+water Systemsupporting

confidence: 92%

An Overview of the Oil+Brine Two-Phase System in the Presence of Carbon Dioxide, Methane, and Their Mixture

Nair

Ruslan

Cui

et al. 2022

Ind. Eng. Chem. Res.

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An overview of the molecular simulation studies of the oil+brine two-phase system in the presence of CO2, CH4, and their mixture at geological conditions is presented. The simulation results agreed well with the experimental results and the density gradient theory predictions on the basis of the cubic–plus–association equation of state (CPA EoS) (withDebye–Hückel electrostatic term) and the perturbed chain statistical associating fluid theory (PC-SAFT) EoS. The interfacial tension (IFT) of the alkane+H2O system showed almost a linear increase with an increasing number of carbon atoms in the alkane molecule. These IFTs are approximately equal for linear, branched, and cyclic alkanes. Here, the negative surface excess of the alkanes might explain the increase in the IFTs with an increase in the pressure. The surface excesses of the alkanes increased with decreasing temperature. This may explain the decrease of the slopes in the IFT versus pressure plot with a decrease in the temperature. The IFT behavior of the alkane+water+CH4/CO2 system was found to be similar to that observed for the alkane+water system. The addition of CO2 had a more significant influence on the IFT than the addition of CH4. Here, CH4 and CO2 exhibited a positive surface excess. The negative surface excess of the salt ions probably explains the increase in the IFTs of the alkane+brine system with increasing salt content. The solubilities of CH4 and/or CO2 in the H2O-rich phase of the alkane+brine+CH4/CO2 system increased with decreasing salt content (salting-out effect). The IFT of the aromatic hydrocarbon+H2O system is much lower than that of the alkane+H2O system. The surface excess followed the order o-xylene > ethylbenzene > toluene > benzene for the aromatic hydrocarbon+H2O system. This trend has a direct correlation with the aromatic–aromatic interaction.

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Section: Alkane+water Systemsupporting

confidence: 92%

An Overview of the Oil+Brine Two-Phase System in the Presence of Carbon Dioxide, Methane, and Their Mixture

Nair

Ruslan

Cui

et al. 2022

Ind. Eng. Chem. Res.

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“…it is apparent that -, must be less than 22.2 dynes/cm for this series uf liquids. Reported values of S1, of -8.54 and -11.17 dynes/cm (15) and of -Y of 29.89 and 32.18 dynes/cm (23) for the cis and trans isomers of decahydronaphthalene, respectively, are consistent with this value of -,.. This result is in good agreement …”

Section: Sbo :=-Y -(-B + -Y) (1)supporting

confidence: 83%

“…Comparison of the data given previously for decahydronaphthalene (15,23) and in Table 1 for 1,2,3,4-tetrahydrcnaphthalene indicates that the substitution of an aromatic for a saturated ring in one balf of a fused ring system is sufficient to increase y, by 12 dynes/cn, if it is assumed that the data point for the nonspreading aromatic compound falls on a line with the same slope as that for the nonspreading naphthenic hydrocarbons. In this case, however, the difference in )o, corresponds to 13 dynes/cm or less when aromaticity is introduced in the condensed ring compour~d.…”

Section: Effect Of Unsaturated Bonds On Ymentioning

confidence: 60%

Critical surface tension for spreading on a liquid substrate

Shafrin¹,

Zisman²

1967

J. Phys. Chem.

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“…We did not set ourselves the goal of presenting in any detail the technical features of the methods of molecular modeling. Any reader can find all the necessary information about methods of interest by consulting the references provided. − There is a huge amount of journal literature on this topic, and we are limited in scope by the article format. In addition, it can defocus the main idea that we want to convey: the presence of effects that deviate from classical ideas that occur in complex systems at the nanoscale and critically affect the wetting properties of the rock.…”

Section: Molecular Modeling View On Wettingmentioning

confidence: 99%

Wettability Alteration in Gas Condensate Reservoirs: A Critical Review of the Opportunities and Challenges

Kazemi,

Khlyupin,

Azin

et al. 2024

Energy Fuels

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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.

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The Interfacial Tension of Some Hydrocarbons against Water.

Cited by 24 publications

References 0 publications

An Overview of the Oil+Brine Two-Phase System in the Presence of Carbon Dioxide, Methane, and Their Mixture

An Overview of the Oil+Brine Two-Phase System in the Presence of Carbon Dioxide, Methane, and Their Mixture

Critical surface tension for spreading on a liquid substrate

Wettability Alteration in Gas Condensate Reservoirs: A Critical Review of the Opportunities and Challenges

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