Influence of Weak Hydrophobic Interactions on in Situ Viscosity of a Hydrophobically Modified Water-Soluble Polymer

Viken, Alette Løbø; Spildo, Kristine; Reichenbach-Klinke, Roland; Djurhuus, Ketil; Skauge, Tormod

doi:10.1021/acs.energyfuels.7b02573

Cited by 21 publications

(8 citation statements)

References 83 publications

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“…Although the hydrogen bonding between carboxylic groups can typically promote viscosity [ 59 ], the hydrophobic interaction should be decisively considered. The hydrophobic interaction can enhance viscosity [ 60 ]; the long chain length of alkanes induces the increase in hydrophobic interaction, resulting in the high viscosity of silicone oil [ 61 ]. However, the results from the 35% w/v fatty acid series might not be distinct since the smaller number of fatty acid molecules were evident for high MW fatty acid-based solutions.…”

Section: Resultsmentioning

confidence: 99%

Saturated Fatty Acid-Based In Situ Forming Matrices for Localized Antimicrobial Delivery

et al. 2020

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In recent years, the world has faced the issue of antibiotic resistance. Methicillin-resistant Staphylococcus aureus (MRSA) is a significant problem in various treatments and control of infections. Biocompatible materials with saturated fatty acids of different chain lengths (C8–C18) were studied as matrix formers of localized injectable vancomycin HCl (VCM)-loaded antisolvent-induced in situ forming matrices. The series of fatty acid-based in situ forming matrices showed a low viscosity (5.47–13.97 cPs) and pH value in the range of 5.16–6.78, with high injectability through a 27-G needle (1.55–3.12 N). The preparations exhibited low tolerance to high concentrations of KH2PO4 solution (1.88–5.42% v/v) and depicted an electrical potential change during phase transformation. Their phase transition and matrix formation at the microscopic and macroscopic levels depended on the chain length of fatty acids and solvent characteristics. The VCM release pattern depended on the nucleation/crystallization and solvent exchange behaviors of the delivery system. The 35% w/v of C12–C16 fatty acid-based in situ forming matrix prolonged the VCM release over seven days in which C12, C14, C16 –based formulation reached 56, 84, and 85% cumulative drug release at 7th day. The release data fitted well with Higuchi’s model. The developed formulations presented efficient antimicrobial activities against standard S. aureus, MRSA, Escherichia coli, and Candida albicans. Hence, VCM-loaded antisolvent-induced fatty acid-based in situ forming matrix is a potential local delivery system for the treatment of local Gram-positive infection sites, such as joints, eyes, dermis of surgery sites, etc., in the future.

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Section: Resultsmentioning

confidence: 99%

Saturated Fatty Acid-Based In Situ Forming Matrices for Localized Antimicrobial Delivery

et al. 2020

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“…However, the viscosity of the DPS system substantially increases when the polymer concentration is greater than 0.15%. This may be related to the critical association concentration (CAC) of the HAP polymer in the DPS system. − When the HAP polymer concentration is lower than that of the CAC, the molecules are mainly present in the form of single molecules in the solution, which reduces the probability of hydrophobic interactions between polymer molecules. The structure viscosity of the HAP polymer cannot be formed, which produces a lower viscosity.…”

Section: Results and Discussionmentioning

confidence: 99%

Dispersed Particle Gel-Strengthened Polymer/Surfactant as a Novel Combination Flooding System for Enhanced Oil Recovery

Zhao

Cheng-lin

et al. 2018

Energy Fuels

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A novel dispersed particle gel-strengthened polymer–surfactant (DPS) combination flooding system was proposed and demonstrated for enhanced oil recovery in high water cut mature oilfields. As compared to a conventional polymer–surfactant (PS) combination flooding system, DPS systems have a higher viscosity and a more stable network structure. The polymer is mainly a source of the viscosity, while the surfactant plays a key role in reducing the interfacial tension (IFT). The added dispersed particle gel (DPG) has a synergistic viscosity increase effect, whereas for the DPG particles, the salinity and aging time have a slight effect on the IFT reduction capacity of the DPS system. On the basis of sand-pack flowing experiments, the DPS system has a better mobility control capacity than the PS system in the combination flooding stage and the following water flooding stage. Parallel sand-pack flowing experiments indicate that injection of a DPS system can effectively improve the profile control. The added DPG particles could intersperse in the three-dimensional network structure, which increases the stability of the DPS system in solution and porous media. Through the improved synergistic effect of the swept volume capacity and high displacement efficiency, the oil recovery capacity of the DPS system is significantly enhanced. The DPS system may be an alternative for enhanced oil recovery in other similar high water cut mature oilfields.

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“…Researchers have reported that associative polymer injection in porous media results in significantly higher resistance factors compared to traditional non-associative polymers 45 – 47 . This is because the restricted space during flow in porous media leads to higher hydrophobic interactions even at lower concentrations than in bulk 48 , 49 . The literature has also explored the viscoelastic properties of associative polymers employing a capillary breakup extensional rheometer (CaBER) 12 .…”

Section: Polymer Flooding Under Extreme Reservoir Conditionsmentioning

confidence: 99%

A comprehensive review of viscoelastic polymer flooding in sandstone and carbonate rocks

Zeynalli,

Mushtaq,

Al-Shalabi

et al. 2023

Sci Rep

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Polymer flooding is a proven chemical Enhanced Oil Recovery (cEOR) method that boosts oil production beyond waterflooding. Thorough theoretical and practical knowledge has been obtained for this technique through numerous experimental, simulation, and field works. According to the conventional belief, this technique improves macroscopic sweep efficiency due to high polymer viscosity by producing moveable oil that remains unswept after secondary recovery. However, recent studies show that in addition to viscosity, polymer viscoelasticity can be effectively utilized to increase oil recovery by mobilizing residual oil and improving microscopic displacement efficiency in addition to macroscopic sweep efficiency. The polymer flooding is frequently implemented in sandstones with limited application in carbonates. This limitation is associated with extreme reservoir conditions, such as high concentrations of monovalent and divalent ions in the formation brine and ultimate reservoir temperatures. Other complications include the high heterogeneity of tight carbonates and their mixed-to-oil wettability. To overcome the challenges related to severe reservoir conditions, novel polymers have been introduced. These new polymers have unique monomers protecting them from chemical and thermal degradations. Monomers, such as NVP (N-vinylpyrrolidone) and ATBS (2-acrylamido-2-methylpropane sulfonic acid), enhance the chemical resistance of polymers against hydrolysis, mitigating the risk of viscosity reduction or precipitation in challenging reservoir conditions. However, the viscoelasticity of these novel polymers and their corresponding impact on microscopic displacement efficiency are not well established and require further investigation in this area. In this study, we comprehensively review recent works on viscoelastic polymer flow under various reservoir conditions, including carbonates and sandstones. In addition, the paper defines various mechanisms underlying incremental oil recovery by viscoelastic polymers and extensively describes the means of controlling and improving their viscoelasticity. Furthermore, the polymer screening studies for harsh reservoir conditions are also included. Finally, the impact of viscoelastic synthetic polymers on oil mobilization, the difficulties faced during this cEOR process, and the list of field applications in carbonates and sandstones can also be found in our work. This paper may serve as a guide for commencing or performing laboratory- and field-scale projects related to viscoelastic polymer flooding.

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Influence of Weak Hydrophobic Interactions on in Situ Viscosity of a Hydrophobically Modified Water-Soluble Polymer

Cited by 21 publications

References 83 publications

Saturated Fatty Acid-Based In Situ Forming Matrices for Localized Antimicrobial Delivery

Saturated Fatty Acid-Based In Situ Forming Matrices for Localized Antimicrobial Delivery

Dispersed Particle Gel-Strengthened Polymer/Surfactant as a Novel Combination Flooding System for Enhanced Oil Recovery

A comprehensive review of viscoelastic polymer flooding in sandstone and carbonate rocks

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