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New Advances in Polymer-Based Surfactants
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New Advances in Polymer-Based Surfactants

A special issue of Polymers (ISSN 2073-4360). This special issue belongs to the section "Polymer Applications".

Deadline for manuscript submissions: closed (31 August 2024) | Viewed by 4140

Special Issue Editors

Dr. Yang Zhang

E-Mail Website
Guest Editor
State Key Laboratory of Oil and Gas Reservoir Geology and Exploitation, Southwest Petroleum University, Chengdu 610500, China
Interests: surfactant; polymer; hydrogel; smart systems; functional materials; fracturing fluids
Dr. Hailong Chen

E-Mail Website
Guest Editor
School of Petroleum and Natural Gas Engineering, Southwest Petroleum University, Chengdu 610500, China
Interests: surfactant; foaming agent; foaming stability; chemical flooding; EOR

Special Issue Information

Dear Colleagues,

With the development of the oil and gas industry, unconventional reservoirs with low porosity and low permeability are responsible for an increasing proportion of the total oil and gas resources. To develop unconventional reservoirs, the design and synthesis of high-performance polymer-based surfactants exhibiting both polymer and surfactant properties is urgent; these can be applied in oilfields, including fracking, acidizing, enhancing oil recovery, etc. Notwithstanding the enormous efforts of academic researchers and industry, a functional polymer-based surfactant solution with high performance and low cost remains to be found.

This Special Issue focuses on the recent advances, challenges, and fundamental aspects of the synthesis, characterization, properties, and application of polymer-based surfactants as a functional material used in oilfields. We aim to bring together researchers in the aforementioned fields to highlight the current development of new techniques, exchange the latest understanding of novel functional polymeric or surfactant active materials, present advanced concepts for design and preparation, and facilitate collaboration between researchers in different fields. We welcome the submission of both original research and review articles.

Dr. Yang Zhang
Dr. Hailong Chen
Guest Editors

Manuscript Submission Information

Manuscripts should be submitted online at www.mdpi.com by registering and logging in to this website. Once you are registered, click here to go to the submission form. Manuscripts can be submitted until the deadline. All submissions that pass pre-check are peer-reviewed. Accepted papers will be published continuously in the journal (as soon as accepted) and will be listed together on the special issue website. Research articles, review articles as well as short communications are invited. For planned papers, a title and short abstract (about 100 words) can be sent to the Editorial Office for announcement on this website.

Submitted manuscripts should not have been published previously, nor be under consideration for publication elsewhere (except conference proceedings papers). All manuscripts are thoroughly refereed through a single-blind peer-review process. A guide for authors and other relevant information for submission of manuscripts is available on the Instructions for Authors page. Polymers is an international peer-reviewed open access semimonthly journal published by MDPI.

Please visit the Instructions for Authors page before submitting a manuscript. The Article Processing Charge (APC) for publication in this open access journal is 2700 CHF (Swiss Francs). Submitted papers should be well formatted and use good English. Authors may use MDPI's English editing service prior to publication or during author revisions.

Keywords

  • surfactant
  • polymer
  • functional materials
  • surface treatment
  • hydrogel
  • foaming stability

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Published Papers (5 papers)

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Research

12 pages, 10239 KiB  
Article
Development and Application of High-Internal-Phase Water-in-Oil Emulsions Using Amphiphilic Nanoparticle-Based Emulsifiers
by Chunhua Zhao, Xiujun Wang, Jian Zhang, Yigang Liu, Changlong Liu, Bo Huang and Yang Yang
Polymers 2024, 16(22), 3148; https://doi.org/10.3390/polym16223148 - 12 Nov 2024
Viewed by 503
Abstract
High-internal-phase water-in-oil (W/O) emulsions generated in situ have garnered considerable attention as novel profile control systems. However, conventional emulsifiers are unreactive and poorly dispersed in water, necessitating large dosages and resulting in poor injectivity. In this study, we synthesized amphiphilic nanoparticles (SiO2 [...] Read more.
High-internal-phase water-in-oil (W/O) emulsions generated in situ have garnered considerable attention as novel profile control systems. However, conventional emulsifiers are unreactive and poorly dispersed in water, necessitating large dosages and resulting in poor injectivity. In this study, we synthesized amphiphilic nanoparticles (SiO2–NH2–DAC NPs) containing amine and long-chain alkyl groups using a one-pot method and investigated the stabilized emulsion properties. Our results indicated that W/O emulsions with a water-to-oil ratio (WOR) of 7:3 to 8:2 could be prepared with just 0.1 wt% of SiO2–NH2–DAC NPs under neutral and basic conditions, with demulsification occurring under acidic conditions (pH = 2.1), demonstrating the pH-responsiveness of the W/O emulsions. The emulsion viscosity increased from 150 to 2555 mPa·s at different WORs. An additional 18.7% oil recovery was achieved using SiO2–NH2–DAC NPs in a heterogeneous core, highlighting their potential as a promising profile control candidate. Full article
(This article belongs to the Special Issue New Advances in Polymer-Based Surfactants)
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21 pages, 4590 KiB  
Article
Effect of CO2 Concentration on the Performance of Polymer-Enhanced Foam at the Steam Front
by Mingxuan Wu, Binfei Li, Liwei Ruan, Chao Zhang, Yongqiang Tang and Zhaomin Li
Polymers 2024, 16(19), 2726; https://doi.org/10.3390/polym16192726 - 26 Sep 2024
Viewed by 475
Abstract
This study examines the impact of CO2 concentration on the stability and plugging performance of polymer-enhanced foam (PEF) under high-temperature and high-pressure conditions representative of the steam front in heavy oil reservoirs. Bulk foam experiments were conducted to analyze the foam performance, [...] Read more.
This study examines the impact of CO2 concentration on the stability and plugging performance of polymer-enhanced foam (PEF) under high-temperature and high-pressure conditions representative of the steam front in heavy oil reservoirs. Bulk foam experiments were conducted to analyze the foam performance, interfacial properties, and rheological behavior of CHSB surfactant and Z364 polymer in different CO2 and N2 gas environments. Additionally, core flooding experiments were performed to investigate the plugging performance of PEF in porous media and the factors influencing it. The results indicate that a reduction in CO2 concentration in the foam, due to the lower solubility of N2 in water and the reduced permeability of the liquid film, enhances foam stability and flow resistance in porous media. The addition of polymers was found to significantly improve the stability of the liquid film and the flow viscosity of the foam, particularly under high-temperature conditions, effectively mitigating the foam strength degradation caused by CO2 dissolution. However, at 200 °C, a notable decrease in foam stability and a sharp reduction in the resistance factor were observed. Overall, the study elucidates the effects of gas type, temperature, and polymer concentration on the flow and plugging performance of PEF in porous media, providing reference for fluid mobility control at the steam front in heavy oil recovery. Full article
(This article belongs to the Special Issue New Advances in Polymer-Based Surfactants)
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16 pages, 2175 KiB  
Article
Study on the Control of Steam Front Mobility in High-Temperature and High-Salinity Conditions Using Polymer-Enhanced Foam
by Mingxuan Wu, Binfei Li, Liwei Ruan, Yongqiang Tang and Zhaomin Li
Polymers 2024, 16(17), 2478; https://doi.org/10.3390/polym16172478 - 30 Aug 2024
Viewed by 495
Abstract
This study investigated the enhancing effects of the temperature-resistant polymer Poly(ethylene-co-N-methylbutenoyl carboxylate-co-styrenesulfonate-co-pyrrolidone) (hereinafter referred to as Z364) on the performance of cocamidopropyl hydroxy sulfobetaine (CHSB) foam under high-temperature and high-salinity conditions. The potential of this enhanced foam system for mobility control during heavy [...] Read more.
This study investigated the enhancing effects of the temperature-resistant polymer Poly(ethylene-co-N-methylbutenoyl carboxylate-co-styrenesulfonate-co-pyrrolidone) (hereinafter referred to as Z364) on the performance of cocamidopropyl hydroxy sulfobetaine (CHSB) foam under high-temperature and high-salinity conditions. The potential of this enhanced foam system for mobility control during heavy oil thermal recovery processes was also evaluated. Through a series of experiments, including foam stability tests, surface tension measurements, rheological assessments, and parallel core flooding experiments, we systematically analyzed the interaction between the Z364 polymer and CHSB surfactant on foam performance. The results indicated that the addition of Z364 significantly improved the strength, thermal resistance, and salt tolerance of CHSB foam. Furthermore, the adsorption of CHSB on the polymer chains enhanced the salt resistance of the polymer itself, particularly demonstrating stronger blocking effects in high-permeability cores. The experimental findings showed that Z364 increased the viscosity of the liquid film, slowed down liquid drainage, and reduced gas diffusion, effectively extending the half-life of CHSB foam and improving its stability under high-temperature conditions. Additionally, in parallel core flooding experiments, the polymer-enhanced foam exhibited significant flow diversion effects in both high-permeability and low-permeability cores, effectively directing more fluid into low-permeability channels and improving fluid distribution in heterogeneous reservoirs. Overall, Z364 polymer-enhanced CHSB foam demonstrated superior mobility control during heavy oil thermal recovery, offering new technical insights for improving the development efficiency of high-temperature, high-salinity reservoirs. Full article
(This article belongs to the Special Issue New Advances in Polymer-Based Surfactants)
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18 pages, 5337 KiB  
Article
Research on Acid Aging and Damage Pattern Recognition of Glass Fiber-Reinforced Plastic Oil and Gas Gathering Pipelines Based on Acoustic Emission
by Haisheng Bi, Yuhong Zhang, Chen Zhang, Chunxun Ma, Yuxiang Li, Jiaxu Miao, Guang Wang and Haoran Cheng
Polymers 2024, 16(16), 2272; https://doi.org/10.3390/polym16162272 - 10 Aug 2024
Viewed by 951
Abstract
Pipelines extend thousands of kilometers to transport and distribute oil and gas. Given the challenges often faced with corrosion, fatigue, and other issues in steel pipes, the demand for glass fiber-reinforced plastic (GFRP) pipes is increasing in oil and gas gathering and transmission [...] Read more.
Pipelines extend thousands of kilometers to transport and distribute oil and gas. Given the challenges often faced with corrosion, fatigue, and other issues in steel pipes, the demand for glass fiber-reinforced plastic (GFRP) pipes is increasing in oil and gas gathering and transmission systems. However, the medium that is transported through these pipelines contains multiple acid gases such as CO2 and H2S, as well as ions including Cl−, Ca2+, Mg2+, SO42−, CO32−, and HCO3−. These substances can cause a series of problems, such as aging, debonding, delamination, and fracture. In this study, a series of aging damage experiments were conducted on V-shaped defect GFRP pipes with depths of 2 mm and 5 mm. The aging and failure of GFRP were studied under the combined effects of external force and acidic solution using acoustic emission (AE) techniques. It was found that the acidic aging solution promoted matrix damage, fiber/matrix desorption, and delamination damage in GFRP pipes over a short period. However, the overall aging effect was relatively weak. Based on the experimental data, the SSA-LSSVM algorithm was proposed and applied to the damage pattern recognition of GFRP. An average recognition rate of up to 90% was achieved, indicating that this method is highly suitable for analyzing AE signals related to GFRP damage. Full article
(This article belongs to the Special Issue New Advances in Polymer-Based Surfactants)
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17 pages, 5400 KiB  
Article
Enhancing Oil Recovery in Low-Permeability Reservoirs Using a Low-Molecular Weight Amphiphilic Polymer
by Yang Yang, Youqi Wang, Yiheng Liu and Ping Liu
Polymers 2024, 16(8), 1036; https://doi.org/10.3390/polym16081036 - 10 Apr 2024
Cited by 1 | Viewed by 913
Abstract
Polymer flooding has achieved considerable success in medium–high permeability reservoirs. However, when it comes to low-permeability reservoirs, polymer flooding suffers from poor injectivity due to the large molecular size of the commonly used high-molecular-weight (high-MW) partially hydrolyzed polyacrylamides (HPAM). Herein, an amphiphilic polymer [...] Read more.
Polymer flooding has achieved considerable success in medium–high permeability reservoirs. However, when it comes to low-permeability reservoirs, polymer flooding suffers from poor injectivity due to the large molecular size of the commonly used high-molecular-weight (high-MW) partially hydrolyzed polyacrylamides (HPAM). Herein, an amphiphilic polymer (LMWAP) with a low MW (3.9 × 106 g/mol) was synthesized by introducing an amphiphilic monomer (Allyl-OP-10) and a chain transfer agent into the polymerization reaction. Despite the low MW, LMWAP exhibited better thickening capability in brine than its counterparts HPAM-1800 (MW = 1.8 × 107 g/mol) and HPAM-800 (MW = 8 × 106 g/mol) due to the intermolecular hydrophobic association. LMWAP also exhibited more significant shear-thinning behavior and stronger elasticity than the two counterparts. Furthermore, LMWAP possesses favorable oil–water interfacial activity due to its amphiphilicity. The oil–water interfacial tension (IFT) could be reduced to 0.88 mN/m and oil-in-water (O/W) emulsions could be formed under the effect of LMWAP. In addition, the reversible hydrophobic association endows the molecular chains of LMWAP with dynamic association–disassociation transition ability. Therefore, despite the similar hydrodynamic sizes in brine, LMWAP exhibited favorable injectivity under low-permeability conditions, while the counterpart HPAM-1800 led to fatal plugging. Furthermore, LMWAP could enhance oil recovery up to 21.5%, while the counterpart HPAM-800 could only enhance oil recovery by up to 11.5%, which could be attributed to the favorable interfacial activity of LMWAP. Full article
(This article belongs to the Special Issue New Advances in Polymer-Based Surfactants)
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