High‐temperature performance and cross‐linking mechanism of different types of gel systems in saline environment

Liu, Jianbin; Zhong, Liguo; Cao, Zijuan; Hao, Tongchun; Liu, Yigang; Wu, Wen‐Wei

doi:10.1002/app.51452

Cited by 9 publications

(6 citation statements)

References 31 publications

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“…Cross-linking mechanism of different types of cross-linker systems (adopted from Liu et al) (a) reaction mechanism of phenol, formaldehyde, and amide group; (b) reaction mechanism of resorcinol, formaldehyde, and amide group; (c) reaction mechanism of bisphenol-A, formaldehyde, and amide group. Reproduced with permission from ref . Copyright 2022 Wiley Online Library.…”

Section: Improved Gel Performancementioning

confidence: 99%

“…The dehydration rate usually quantifies the thermal stability of a gel: the higher the dehydration rate, the weaker the thermal stability of the gel. Liu et al 144 compared the thermal stability of gels formed by different combinations of cross-linkers. The dehydration rate was bisphenol-A/HMTA < resorcinol/HMTA < phenol/ HMTA, and bisphenol-A/HMTA had the best thermal stability, with a strength code of "D" for 120 days of aging at 150 °C, and the dehydration rate was only 1.6%.…”

Section: Used Starchmentioning

confidence: 99%

“…Finally, the above reaction products undergo a dehydration/condensation reaction, forming a gel system with a three-dimensional network structure. 144 Liu et al 145 used AM/acrylamide-sodium tert-butyl sulfonate (ATBS)/NVP copolymer, HMTA, and bisphenol-A to prepare gels resistant to temperatures ranging from 150 to 200 °C. Chen et al 137 prepared a gel using AM/AA/AMPS polymers, hydroquinone, and hexamethylenetetramine, and the dehydration rate of this system was only 5% after aging at 130 °C for 120 days.…”

Section: Used Starchmentioning

confidence: 99%

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Progress and Prospects of In Situ Polymer Gels for Sealing Operation in Wellbore and Near-Well Zone

Kang,

Liu,

Jia

et al. 2024

Energy Fuels

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In situ polymer gels have been received as a useful tool for sealing operations such as fluid loss control during well drilling and workover and completion, well stimulation, water shutoff, wellbore integrity, and wellbore pressure management. With the development of deep-sea, deep-earth, and unconventional reservoirs, various harsh conditions such as high temperature, high pressure, and complex working conditions pose great challenges to the performance of gels. This paper first summarizes the application and operating mechanism of in situ polymer gels for sealing operations in wellbore and near-wellbore zones. Then, the in situ polymer gels are categorized into three types, in situ monomer gels, in situ cross-linked gels, and in situ generated foam gels, and the advantages and disadvantages of these three types of gels are introduced. Second, an overview of performance improvement methods for in situ polymer gels is highlighted, including improved temperature resistance and strength, accelerated gelation, retarded gelation, gel-breaking methods, and self-degradation systems. Finally, the challenges and prospects of in situ polymer gels for sealing operation in wellbores and near-well zones are presented, to provide references for the application, formulation, and performance improvement of in situ polymer gels.

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Section: Improved Gel Performancementioning

confidence: 99%

Section: Used Starchmentioning

confidence: 99%

Section: Used Starchmentioning

confidence: 99%

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Progress and Prospects of In Situ Polymer Gels for Sealing Operation in Wellbore and Near-Well Zone

Kang,

Liu,

Jia

et al. 2024

Energy Fuels

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“…At present, there are a lot of research on hightemperature gel systems, but most of them are based on the research of gelation dynamic, static high-temperature resistance, and stability. 31,42,43 However, under actual reservoir conditions, the gel solution first flow in the formation porous media for a period before forming a highviscosity gel system. And there are few studies on the anti-shear properties of gel systems and the gelation properties of porous media.…”

Section: Introductionmentioning

confidence: 99%

“…Asghari 30 reported a foam gel using nitrogen as a blowing agent, which has a residual resistance coefficient of 64–180 and is good for blocking in high‐permeability layers. Based on previous studies, Liu et al 31 studied the gelation and long‐term stability characteristics of different polymers and crosslinked systems, analyzed their crosslinked mechanism, which provided a foundation for the development of gel systems.…”

Section: Introductionmentioning

confidence: 99%

A gel system with long‐term high‐temperature stability for deep profile modification of high‐temperature oil and gas reservoirs

Tian,

Liu,

Liu

et al. 2023

J of Applied Polymer Sci

Self Cite

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Profile modification is the key for efficient development of oil and gas reservoirs, especially high‐temperature reservoirs, which requires the system to have good high‐temperature resistance. According to the characteristics of high‐temperature reservoir, a high temperature gel composed of terpolymer, modified phenolic resin, aromatic amine curing agent and thiourea was developed. The effects of different components on the properties of the gel system were clarified. Then, the long‐term thermal stability under high‐temperature conditions was studied. In addition, the plugging performance of gel system under different permeability and injection volume was studied. Finally, the gelation properties and plugging properties of gel system with the flow distance were studied by simulating the flow of porous media. The results show that the gel system has high strength and suitable gelation time, and it can be adjusted in real time according to different oilfield requirements. In the range of 75–150°C, the gel system had excellent long‐term stability. When the temperature was 75°C, no free water after 120 days, and the viscosity only decreased from 13,131 to 11,254 mPa·s. Even at 150°C, the viscosity was as high as 8350 mPa·s after 120 days, and the free water was only 5.5%. The gel system had good adhesion ability on the porous media surface and strong anti‐flooding properties. When the injection volume was 0.1 pore volume (PV in short), the plugging rate to the sand packed tube was 72.7%. When the injection volume was 0.5 PV, the plugging rate was as high as 97.6%. The plugging rate of the gel system for the sand packed tube with permeability of 500 mD was 98.7% when the injection volume was 0.5 PV. When the permeability increased to 3000 mD, the plugging rate still reached 92.3%. The gel system also had an excellent deep profile control ability, and the viscosity retention of at 60 cm was as high as 96%. When the flow distance was 2 m, the viscosity retention also reached 75%. The rheological properties also shown that the gel system had excellent shearing resistance and adsorption resistance. Finally, combined with the state of the gel system on the surface of the porous media, there was no cementation between the formation sand before the injection, and the sand particles did not stick to each other. After the gel was injected, the adhesion of gel system on the porous media surface was very strong. The 3D network structure was also very dense, the sand particles could have good cementation effect under the adhesion of gel system.

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Improving temperature and salinity tolerance of polymer gels by modifying with lignin-containing nanocellulose

Yang,

Gao,

Guo

et al. 2025

Fuel

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High‐temperature performance and cross‐linking mechanism of different types of gel systems in saline environment

Cited by 9 publications

References 31 publications

Progress and Prospects of In Situ Polymer Gels for Sealing Operation in Wellbore and Near-Well Zone

Progress and Prospects of In Situ Polymer Gels for Sealing Operation in Wellbore and Near-Well Zone

A gel system with long‐term high‐temperature stability for deep profile modification of high‐temperature oil and gas reservoirs

Improving temperature and salinity tolerance of polymer gels by modifying with lignin-containing nanocellulose

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