Polymer Gels for Oil Drilling and Enhanced Recovery

Topic Information

Dear Colleagues,

This Topics is devoted to the study of organic and inorganic polymer gels for oil- and gas-field applications, with the overarching goals of improving drilling efficiency and enhancing oil recovery. Contributions are invited on, but not limited to, innovative polymer gel synthesis, mathematical simulation and experimental assessment of polymer gel performance, and field-oriented applications in drilling and improved/enhanced oil recovery.

Polymer gels are elastomers with a three-dimensional (3D) network structure that is composed of polymers and cross-linkers as the main agents, along with other additives. They have been widely used in various aspects of oil–gas drilling and production engineering, such as drilling fluid, lost circulation control, fracturing, acidizing, conformance control, water shutoff, and enhanced oil recovery.

Polymer gels in oil–gas reservoirs are often subjected to high temperatures and salinity, and excessive temperatures and salinity can destroy the structural integrity of the polymer chains, resulting in a substantial decrease in stability. Therefore, maintaining good properties of polymer gels under high-temperature and high-salinity conditions is extremely difficult. So, many efforts should be performed to synthesize novel polymer gels, evaluate the physical and chemical properties of polymer gels in high-temperature and high-salinity conditions, and investigate the application effects of polymer gels in the drilling and enhanced oil recovery processes in the lab.

We look forward to your innovative research on organic or inorganic polymer gels aimed at advancing drilling efficiency and oil recovery.

Dr. Jingbin Yang
Prof. Dr. Yingrui Bai
Dr. Bauyrzhan Sarsenbekuly
Topic Editors

Keywords

Participating Journals

Journal Name	Impact Factor	CiteScore	Launched Year	First Decision (median)	APC
Applied Sciences applsci	2.5	5.5	2011	19.8 Days	CHF 2400	Submit
ChemEngineering ChemEngineering	3.4	4.9	2017	29.6 Days	CHF 1600	Submit
Energies energies	3.2	7.3	2008	16.2 Days	CHF 2600	Submit
Gels gels	5.3	7.6	2015	12.5 Days	CHF 2100	Submit
Processes processes	2.8	5.5	2013	16 Days	CHF 2400	Submit
Polymers polymers	4.9	9.7	2009	14 Days	CHF 2700	Submit

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Published Papers (5 papers)

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All Applied Sciences ChemEngineering Energies Gels Processes Polymers

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36 pages, 3413 KB  

Open AccessArticle

Toward Sustainable Green and Intelligent Profile Control Gels: An ETI–CFI-Based Structure–Environment Evaluation Framework

by Qiang Chen, Hanmin Xiao, Zhihua Chen, Tong Wu, Hao Chen and Keqiang Wei

Gels 2025, 11(12), 952; https://doi.org/10.3390/gels11120952 - 27 Nov 2025

Viewed by 403

Abstract

In the context of the “dual-carbon” strategy and the escalating challenges posed by ultra-high water-cut reservoirs, the development of green and intelligent profile control gels (PCGs) has become essential for balancing enhanced oil recovery (EOR) efficiency with environmental sustainability. In this study, a [...] Read more.

In the context of the “dual-carbon” strategy and the escalating challenges posed by ultra-high water-cut reservoirs, the development of green and intelligent profile control gels (PCGs) has become essential for balancing enhanced oil recovery (EOR) efficiency with environmental sustainability. In this study, a green performance evaluation framework integrating the Environmental Toxicity Index (ETI) and Carbon Footprint Intensity (CFI) is established to quantitatively assess the environmental friendliness of polymer gel systems. Representative gel types—including conventional chromium(III)–polyacrylamide(Cr(III)–PAM), citric acid–chitosan, and pH-responsive nanogels—are evaluated to reveal their structure–environment interactions. Comparative analysis shows that the Cr(III)–PAM system exhibits strong plugging capability but imposes the highest environmental burden (ETI = 1.45; CFI = 9.1 kg CO₂e/kg), whereas the citric acid–chitosan system significantly reduces both toxicity (ETI = 0.42) and carbon footprint (CFI = 2.1). Meanwhile, pH-responsive nanogels demonstrate superior reservoir stability and sustainability under harsh conditions. The proposed ETI–CFI evaluation framework not only enables quantitative benchmarking of green performance but also provides a unified criterion for molecular design, material screening, and engineering application of intelligent green gels. This framework offers practical guidance for the low-carbon transformation of oilfield chemical systems, aligning innovation with sustainability objectives and supporting the realization of dual-carbon goals. Full article

(This article belongs to the Topic Polymer Gels for Oil Drilling and Enhanced Recovery)

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21 pages, 2725 KB  

Open AccessArticle

Study on Self-Healing and Sealing Technology of Fractured Geothermal Reservoir

by Wenxi Wang and Yang Tian

Processes 2025, 13(12), 3817; https://doi.org/10.3390/pr13123817 - 26 Nov 2025

Viewed by 269

Abstract

Geothermal energy, recognized as a sustainable and clean resource, is playing an increasingly critical role in the global shift toward low-carbon energy systems. Nevertheless, the exploitation of fractured geothermal reservoirs is often impeded by severe lost circulation during drilling, where conventional plugging materials [...] Read more.

Geothermal energy, recognized as a sustainable and clean resource, is playing an increasingly critical role in the global shift toward low-carbon energy systems. Nevertheless, the exploitation of fractured geothermal reservoirs is often impeded by severe lost circulation during drilling, where conventional plugging materials fail under high-temperature, high-salinity, and high-pressure conditions due to inadequate mechanical strength, poor thermal resistance, and lack of self-adaptive sealing behavior. In response, self-healing materials have emerged as an innovative strategy for developing intelligent lost circulation control technologies. Herein, we report a novel self-healing gel (XFFD) synthesized via inverse emulsion polymerization using acrylamide (AM), acrylic acid (AA), p-nitroblue tetrazolium (PNBT), and modified silica nanoparticles (PAS). The resulting material exhibits exceptional thermal stability, with decomposition onset above 356 °C, as determined by thermogravimetric analysis. Rheological and mechanical assessments reveal outstanding viscoelasticity, moderate swelling capacity (4.17-fold in deionized water), and a high self-recovery efficiency of 91.15%, accompanied by a bearing strength of 3.65 MPa. Mechanistic investigations indicate that the autonomous repair capability stems from dynamic non-covalent interactions—primarily hydrogen bonding and ionic associations—enabled by amide and carboxyl groups within the polymer network. Sand bed filtration tests under simulated geothermal conditions (150 °C, 8% salinity) demonstrate that XFFD forms a robust sealing barrier with significantly shallower invasion depth compared to conventional materials such as sulfonated asphalt and calcium carbonate. This work presents an effective self-healing gel system that ensures reliable wellbore strengthening and fluid loss control in challenging high-temperature, high-salinity geothermal drilling operations. Full article

(This article belongs to the Topic Polymer Gels for Oil Drilling and Enhanced Recovery)

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23 pages, 3792 KB  

Open AccessArticle

Optimization of the Synthesis of Low Viscosity and High Shear Sulfonated Guar Gum for Enhancing Its Performance in Drilling Fluids

by Yifei Zhao, Yansong Pan, Le Xue, Yongfei Li, Weichao Du and Gang Chen

Gels 2025, 11(12), 939; https://doi.org/10.3390/gels11120939 - 22 Nov 2025

Viewed by 377

Abstract

Guar gum (GG) is a classic polysaccharide gel former in drilling fluids, but its native network is hindered by high water-insoluble residue, modest yield-point (YP) build-up and poor tolerance to temperature ≥ 120 °C and salinity ≥ 12 wt% NaCl. Here we transformed [...] Read more.

Guar gum (GG) is a classic polysaccharide gel former in drilling fluids, but its native network is hindered by high water-insoluble residue, modest yield-point (YP) build-up and poor tolerance to temperature ≥ 120 °C and salinity ≥ 12 wt% NaCl. Here we transformed GG into a sulfonated guar gum (SGG) hydrogel via alkaline etherification with sodium 3-chloro-2-hydroxy-propane sulfonate. FTIR, EA and TGA corroborate the grafting of –SO₃⁻ groups (DS = 0.18), while rheometry shows that a 0.3 wt% SGG aqueous gel exhibits 34% higher YP/PV ratio and stronger shear-thinning than native GG, indicating a denser yet still reversible three-dimensional network. In 4 wt% Ca-bentonite mud the SGG gel film reduces API fluid loss by 12% and maintains YP/PV = 0.33 after hot-rolling at 120 °C, a retention 4.7-fold that of GG; likewise, in 12 wt% NaCl brine the gel still affords YP/PV = 0.44, evidencing electrostatically reinforced hydration layers that resist ionic compression. Linear-swell tests reveal shale inhibition improved by 14%. The introduced –SO₃⁻ functions strengthen inter-chain repulsion and water binding, yielding a thermally robust, salt-tolerant polysaccharide gel network. As a green, high-performance gel additive, SGG offers a promising route for next-generation water-based drilling fluids subjected to high temperature and high salinity. Full article

(This article belongs to the Topic Polymer Gels for Oil Drilling and Enhanced Recovery)

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23 pages, 1275 KB  

Open AccessReview

Research Progress of Micro-Nano Bubbles (MNBs) in Petroleum Engineering

by Yubo Lan, Dongyan Qi, Jiawei Li, Tong Yu, Tianyang Liu, Wenting Guan, Min Yuan, Kunpeng Wan and Zhengxiao Xu

Gels 2025, 11(11), 866; https://doi.org/10.3390/gels11110866 - 29 Oct 2025

Viewed by 804

Abstract

Micro-nano bubbles (MNBs), typically characterized by diameters ranging from tens of micrometers to hundreds of nanometers, have gained significant attention in recent years due to advancements in nanotechnology and related characterization methods. This technology has shown great promise in the field of petroleum [...] Read more.

Micro-nano bubbles (MNBs), typically characterized by diameters ranging from tens of micrometers to hundreds of nanometers, have gained significant attention in recent years due to advancements in nanotechnology and related characterization methods. This technology has shown great promise in the field of petroleum engineering. Among the various applications, the integration of MNBs with gel technology plays a critical role in enhancing drilling safety. This paper aims to systematically review the current status, challenges, and optimization strategies for the application of MNBs in petroleum engineering, with a particular focus on their combined use with gel technology in oilfield applications. The paper first introduces the preparation methods and physicochemical properties of MNBs tailored for oilfield applications. It then systematically reviews the use of MNBs in the following three key areas of petroleum engineering: drilling, enhanced oil recovery (EOR), and oil–water separation. The paper also compares domestic and international technological approaches, highlighting the challenges associated with the large-scale application of MNBs in China. Notably, in the areas of drilling and enhanced oil recovery, the synergistic use of MNBs and gel technology has demonstrated significant potential. The gel–MNB combined technology demonstrates particular promise for China’s special reservoirs, as gel’s high molecular weight compensates for MNBs’ sedimentation defects, while their synergistic effects on interfacial tension reduction and drilling fluid stabilization provide an eco-efficient approach for extreme conditions. Additionally, focusing on the combined application of gel and MNB technology, along with adjustments in gel stability and MNB size, could offer a promising solution for the efficient and sustainable development of special reservoirs (such as those with high temperature, pressure, and salinity) in China. Full article

(This article belongs to the Topic Polymer Gels for Oil Drilling and Enhanced Recovery)

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22 pages, 4279 KB  

Open AccessArticle

Development and Mechanism of the Graded Polymer Profile-Control Agent for Heterogeneous Heavy Oil Reservoirs Under Water Flooding

by Tiantian Yu, Wangang Zheng, Xueqian Guan, Aifen Li, Dechun Chen, Wei Chu and Xin Xia

Gels 2025, 11(11), 856; https://doi.org/10.3390/gels11110856 - 26 Oct 2025

Viewed by 442

Abstract

During water flooding processes, the high viscosity of heavy oil and significant reservoir heterogeneity often lead to severe water channeling and low sweep efficiency. Addressing the limitations of traditional hydrophobically associating polymer-based profile-control agents—such as significant adsorption loss, mechanical degradation during reservoir migration, [...] Read more.

During water flooding processes, the high viscosity of heavy oil and significant reservoir heterogeneity often lead to severe water channeling and low sweep efficiency. Addressing the limitations of traditional hydrophobically associating polymer-based profile-control agents—such as significant adsorption loss, mechanical degradation during reservoir migration, resulting in a limited effective radius and short functional duration—this study developed a polymeric graded profile-control agent suitable for highly heterogeneous conditions. The physicochemical properties of the system were comprehensively evaluated through systematic testing of its apparent viscosity, salt tolerance, and anti-aging performance. The microscopic oil displacement mechanisms in porous media were elucidated by combining CT scanning and microfluidic visual displacement experiments. Experimental results indicate that the agent exhibits significant hydrophobic association behavior, with a critical association concentration of 1370 mg·L⁻¹, and demonstrates a “low viscosity at low temperature, high viscosity at high temperature” rheological characteristic. At a concentration of 3000 mg·L⁻¹, the apparent viscosity of the solution is 348 mPa·s at 30 °C, rising significantly to 1221 mPa·s at 70 °C. It possesses a salinity tolerance of up to 50,000 mg·L⁻¹, and a viscosity retention rate of 95.4% after 90 days of high-temperature aging, indicating good injectivity, reservoir compatibility, and thermal stability. Furthermore, within a concentration range of 500–3000 mg·L⁻¹, the agent can effectively emulsify Gudao heavy oil, forming O/W emulsion droplets with sizes ranging from 40 to 80 μm, enabling effective plugging of pore throats of corresponding sizes. CT scanning and microfluidic displacement experiments further reveal that the agent possesses a graded control function: in the near-wellbore high-concentration zone, it primarily relies on its aqueous phase viscosity-increasing capability to control the mobility ratio; upon entering the deep reservoir low-concentration zone, it utilizes “emulsion plugging” to achieve fluid diversion, thereby expanding the sweep volume and extending the effective treatment period. This research outcome provides a new technical pathway for the efficient development of highly heterogeneous heavy oil reservoirs. Full article

(This article belongs to the Topic Polymer Gels for Oil Drilling and Enhanced Recovery)

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