High density bromide-based nanocomposite gel for temporary plugging in fractured reservoirs with multi-pressure systems

Jia, Hu; Zheng, Kun; Zhu, Jinzhi; Ren, Lingling; Cai, Mingjin; Wang, Tao; YibinXu,; Li, Zhijie

doi:10.1016/j.petrol.2021.108778

Cited by 29 publications

(6 citation statements)

References 33 publications

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“…Zitha et al 62 similarly found that the differential pressure of PAtBA/PEI gel at 120 °C for core displacement experiments was significantly higher than that at 100 and 80 °C. Based on the temperature-enhanced property of PEI gel, Jia et al 30 used PEI gel for a 160 °C reservoir and successfully weighted the system with NaBr to form a high-density gel, and the salt that precipitated under high-temperature conditions could form a protective layer on the gel surface to inhibit dehydration. ElKarsani et al 63 investigated the feasibility of PAM as an inexpensive alternative to PAtBA and showed that the samples prepared using seawater had better stability than distilled and river (field) water, and ammonium chloride (NH 4 Cl) retarded gelation better compared to sodium chloride (NaCl).…”

Section: Type Of In Situ Polymer Gelsmentioning

confidence: 99%

“…Polymer gels have been reportedly proposed to address partial and total loss problems in overbalanced operations, such as (1) fluid loss that occurs during drilling, completion, and workover, (2) well intervention cleanup for coiled tubing (CT) and hydraulic workover (HWO), (3) gravel packing, (4) replacement of artificial lift equipment (i.e., electrical submersible pumps), and (5) tubingconveyed perforating (UTCP), among others. 29 Jia et al 30 proposed a combination of high-density gel and high-density working fluid for well workovers, which provided an effective Table 1. Some Review Articles on Polymer Gel Types in Recent Years reference content of concern Han et al 4 • types of gels: monomer gels, inorganic or organic cross-linked gels • applications: lost circulation, profile control, water shutoff, chemical flooding, fracturing fluids • improving performance: temperature resistance, salinity resistance, rheological property, gelation strength, environmental friendliness Lei et al 5 • types of gels: monomer gels, inorganic or organic cross-linked gels, precross-linked polymer gels • types of gels: inorganic or organic cross-linked gels…”

Section: Fluid Loss Controlmentioning

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: Type Of In Situ Polymer Gelsmentioning

confidence: 99%

Section: Fluid Loss Controlmentioning

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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“…Although polymer hydrogels exhibit unique advantages in addressing lost circulation, − they are susceptible to hydrolysis under high temperatures and pressure, resulting in a reduction in gel strength and plugging effect. , Therefore, commonly used polymer hydrogels are only appropriate for lost circulation control in fractured formations at medium and low temperatures. − Numerous inorganic materials have been used to enhance the high-temperature stability and strength of hydrogels. ,, However, there are still issues, such as poor dispersion and high cost. Current research indicates that developing functional polymers with high-temperature resistance can improve the stability and strength of hydrogels under high temperatures − and is anticipated to play a significant role in lost circulation control of high-temperature formations.…”

Section: Introductionmentioning

confidence: 99%

Heat-Resistant Hydrogel for Temporary Plugging in High-Temperature and High-Pressure Fractured Reservoirs

Sun,

Yang,

et al. 2023

ACS Appl. Polym. Mater.

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Polymer hydrogels have shown considerable potential as materials for lost circulation control. Nevertheless, implementation in high-temperature and high-pressure (HTHP) formations has been challenging due to their poor thermal stability and strength. To overcome this limitation, a heat-resistant hydrogel (HT-Gel) composed of a terpolymer (PAAA) and chromium (III) acetate was developed in this study. PAAA was produced from acrylamide (AM), 2-acrylamido-2-methylpropane sulfonic acid (AMPS), and N-acryloyl morpholine (ACMO). The sulfonated groups of AMPS and the ring structure of ACMO endowed HT-Gel with favorable temperature resistance and pressure-bearing performance. HT-Gel gelled at 150 °C could effectively plug fractures of 0.1–5.0 mm, and the breakthrough pressure exceeded 4.0 MPa. After aging at 150 °C for 7 days, the elastic modulus only decreased by 14.29%. The gel strength and gelation time of HT-Gel could be adjusted by terpolymer concentration, cross-linker concentration, temperature, and salinity, which was beneficial for HT-Gel to enter and plug fractures smoothly. Additionally, HT-Gel exhibited exceptional resistance to shear and contamination. The viscosity of the gelants decreased by less than 16 mPa·s at high shear rates, and the elastic modulus of HT-Gel changed by less than 13% when combined with various drilling materials. Extensive laboratory experiments indicated that HT-Gel had outstanding thermal stability and pressure-bearing performance, making it a promising candidate for lost circulation control in high-temperature and high-pressure formations.

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“…Gel and foam systems, as the two most widely used plugging agents, have achieved positive progress in both laboratory experiments and field applications in recent decades [ 4 , 5 ]. Gel-based plugging systems have been used on a large scale in the 1990s, and various modified gels, micro-nano microspheres, polyethylene glycol gels (PEG), and chitosan-based gels have been developed, including preformed particle gel (PPG) and HPAM weak gels with various particle sizes and compositions [ 6 , 7 , 8 , 9 , 10 ].…”

Section: Introductionmentioning

confidence: 99%

Enhanced Oil Recovery Mechanism and Technical Boundary of Gel Foam Profile Control System for Heterogeneous Reservoirs in Changqing

Wang

et al. 2022

Gels

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The gel plugging and flooding system has a long history of being researched and applied, but the Changqing reservoir geological characteristics are complex, and the synergistic performance of the composite gel foam plugging system is not fully understood, resulting in poor field application. Additionally, the technique boundary chart of the heterogeneous reservoir plugging system has hardly appeared. In this work, reservoir models of porous, fracture, and pore-fracture were constructed, a composite gel foam plugging system was developed, and its static injection and dynamic profile control and oil displacement performance were evaluated. Finally, combined with the experimental studies, a technical boundary chart of plugging systems for heterogeneous reservoirs is proposed. The research results show that the adsorption effect of microspheres (WQ-100) on the surface of elastic gel particles-1 (PEG-1) is more potent than that of pre-crosslinked particle gel (PPG) and the deposition is mainly on the surface of PPG. The adsorption effect of PEG-1 on the surface of PPG is not apparent, primarily manifested as deposition stacking. The gel was synthesized with 0.2% hydrolyzed polyacrylamide (HPAM) + 0.2% organic chromium cross-linking agent, and the strength of enhanced gel with WQ-100 was higher than that of PEG-1 and PPG. The comprehensive value of WQ-100 reinforced foam is greater than that of PEG-1, and PPG reinforced foam, and the enhanced foam with gel has a thick liquid film and poor foaming effect. For the heterogeneous porous reservoir with the permeability of 5/100 mD, the enhanced foam with WQ-100 shows better performance in plugging control and flooding, and the recovery factor increases by 28.05%. The improved foam with gel enhances the fluid flow diversion ability and the recovery factor of fractured reservoirs with fracture widths of 50 μm and 180 μm increases by 29.41% and 24.39%, respectively. For pore-fractured reservoirs with a permeability of 52/167 mD, the PEG + WQ-100 microsphere and enhanced foam with WQ-100 systems show better plugging and recovering performance, and the recovery factor increases are 20.52% and 17.08%, 24.44%, and 21.43%, respectively. The smaller the particle size of the prefabricated gel, the more uniform the adsorption on the foam liquid film and the stronger the stability of the foam system. The plugging performance of the composite gel system is stronger than that of the enhanced gel with foam, but the oil displacement performance of the gel-enhanced foam is better than that of the composite gel system due to the “plug-flooding-integrated” feature of the foam. Combined with the plugging and flooding performance of each plugging system, a technique boundary chart for the plugging system was established for the coexisting porous, fracture, and pore-fracture heterogeneous reservoirs in Changqing Oilfield.

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High density bromide-based nanocomposite gel for temporary plugging in fractured reservoirs with multi-pressure systems

Cited by 29 publications

References 33 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

Heat-Resistant Hydrogel for Temporary Plugging in High-Temperature and High-Pressure Fractured Reservoirs

Enhanced Oil Recovery Mechanism and Technical Boundary of Gel Foam Profile Control System for Heterogeneous Reservoirs in Changqing

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