Pseudointerpenetrating network nanocomposite hydrogel for temporary plugging in fractured reservoirs

Yang, Yang; He, Xiaoxuan; Sun, Dalong; Zhang, Hao; Zhang, Ying; She, Jiping

doi:10.1016/j.colsurfa.2022.130369

Cited by 8 publications

(3 citation statements)

References 32 publications

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“…The mechanism of the gel is shown in Figure , where nanocellulose forms the first cross-links with PAA and PAM chains through hydrogen bonding, and the coordination interactions between carboxyl groups and aluminum ions are stored to form a rigid and tough hydrogel. Yang et al compared the effect of CNF and SiO 2 on the improvement of the strength of PAM/PEI gels, and the elastic modulus with the addition of 1% CNF was 12 times higher than that of the blank sample, while 1% SiO 2 could only improve it by 1.17 times.…”

Section: Improved Gel Performancementioning

confidence: 99%

“…How to adjust the gel’s performance is generally a concern, especially the common concern of gelation, temperature resistance, strength, and gel breaking. However, to the best of our knowledge, although many papers have reported means of improving gel performances, such as high-strength multistage network gels, self-degradable systems, additives to adjust gelation, temperature resistance, strength, etc., − few papers have comprehensively reviewed the developments used for these techniques. Therefore, it is necessary to summarize the latest research progress of in situ polymer gels for sealing operations in wellbores and near-well zone and to fully understand the means and shortcomings of adjusting gel performance under these working conditions.…”

Section: Introductionmentioning

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: Introductionmentioning

confidence: 99%

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 engineering practice, the anisotropy of these reservoirs leads to various challenges, including wellbore instability and a loss of drilling fluid, and they are often referred to as fractured reservoirs [5]. As gas wells begin production, the formation pressure coefficient gradually decreases, resulting in a significant pressure differential between the wellbore fluid column and the formation pressure.…”

Section: Introductionmentioning

confidence: 99%

Plugging Efficiency in Fractured Carbonate Gas Reservoirs Using Fuzzy-Ball Fluids Combined with Solid Plugging Agents

Zhu,

Zheng,

Zhao

et al. 2023

Energies

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Loss encountered during workover operation is a common challenge in the development of fractured carbonate gas reservoirs. Fuzzy-ball fluid, a non-solid phase plugging material developed based on Fuzzy Sealaplugging Theory, has been widely used in killing the well. However, in the plugging of fractured carbonate gas reservoirs, a substantial volume of Fuzzy-ball fluid is required and the pressurization process is time-consuming, which greatly impairs its application. In this study, solid plugging agents including calcium carbonate and fibers are introduced into Fuzzy-ball fluids to improve the plugging efficiency of large-scale macro-fractures. In particular, the plugging performance was evaluated by the indoor plugging of a synthetic core containing a 5 mm wide wedge-shaped fracture, as well as by field trials in two wells. The results show that the plugging ability of the new fluid increases as the concentration of calcium carbonate or fiber increases. Moreover, a more significant enhancement of plugging efficiency was achieved by fibers. In field applications, the use of Fuzzy-ball fluids with calcium carbonate or fibers reduced the volume of fluid consumed by 33~74% and decreased the pressurization time by 33~69%. Therefore, by combining solid plugging agents with Fuzzy-ball fluids, the dual demand for plugging efficiency and cost-effectiveness for fractured carbonate gas reservoirs is achieved simultaneously, which provides an alternative technique for addressing fluid loss in fractured carbonate gas reservoirs.

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Research and performance evaluation of modified nano‐silica gel plugging agent

Zheng

Luo

2023

J of Applied Polymer Sci

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Due to the difficulties in plugging high-pressure injection wells, the short period of plugging, and the use of modified nano-silica, a novel chemical gel plugging agent has been created. Modification of silica using silane coupling agents, and using the aqueous free radical polymerization method synthesized chemical plugging agent with AM, AA, and DMDAAC. The optimum synthesis conditions were screened by single-factor analysis: mass ratio m(AM):m (AA):m(DMDAAC) = 8:1.5:1, modified nano-silica concentration of 1.0%, total monomer mass concentration of 8.0%, initiator concentration of 0.3%, the cross-linker concentration of 0.4%, and coagulant concentration of 0.6%. The performance of the chemical plugging agent was evaluated under the target oil formation conditions. The experimental results showed that the chemical plugging agent exhibited good temperature resistance at 40-100 C, good salt resistance at mineralization (0.5-2.5) Â 10 4 mg/L, and the chemical plugging agent breaks through pressure gradients of 1.12, 15.42 and 90.15 MPa/m in the wellbore, fracture and core, respectively, compared with most gel plugging agents, this plugging agent is more suitable for sealing with pressure work. After adding the breakout agent, the fluid after breakout is fluid-like with low viscosity, which is convenient for reverse discharge and will not cause harm to the reservoir and ensure the subsequent normal construction operation.

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Pseudointerpenetrating network nanocomposite hydrogel for temporary plugging in fractured reservoirs

Cited by 8 publications

References 32 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

Plugging Efficiency in Fractured Carbonate Gas Reservoirs Using Fuzzy-Ball Fluids Combined with Solid Plugging Agents

Research and performance evaluation of modified nano‐silica gel plugging agent

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