Development of re-crosslinkable dispersed particle gels for conformance improvement in extremely high-temperature reservoirs

Zhu, Daoyi; Luo, Run-Tian; Liu, Yang; Qin, Junhui; Zhao, Qi; Zhang, Hongjun; Wang, Wansheng; Wang, Ziyuan; Zhu, Meng-Yang; Wang, Yipeng; Li, Pengbo

doi:10.1016/j.petsci.2022.05.017

Cited by 11 publications

(7 citation statements)

References 26 publications

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“…8−10 Among them, in situ cross-linked polymer gels are widely used in water management operations in high water-cut petroleum reservoirs due to their controllable gelation time and gel strength, simple injection equipment, low cost, etc. 11 The in situ cross-linked polymer gel system mainly includes a metal (chromium, 12−14 zirconium, 15,16 aluminum, 17 etc.) cross-linked polymer gels, aldehyde or phenolic resin crosslinked polymer gels, 1 and polyethylenimine (PEI) cross-linked polymer gels.…”

Section: Introductionmentioning

confidence: 99%

“…Commonly used chemical plugging systems mainly include in situ cross-linked polymer gels, particle gels, and foam gels. − Among them, in situ cross-linked polymer gels are widely used in water management operations in high water-cut petroleum reservoirs due to their controllable gelation time and gel strength, simple injection equipment, low cost, etc . The in situ cross-linked polymer gel system mainly includes a metal (chromium, − zirconium, , aluminum, etc.)…”

Section: Introductionmentioning

confidence: 99%

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Development of Nanomontmorillonite-Reinforced Terpolymer Gels for High-Temperature Petroleum Reservoirs

Zhu,

Zhang,

Gao

et al. 2024

Energy Fuels

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Conventional terpolymer/polyethylenimine (TP/ PEI) gel systems have excellent and controllable gel strength, making them popular gel systems for controlling excessive water production in ultrahigh-temperature reservoirs. To further enhance the strength of the gel, this article used nanomontmorillonite (nano-MMT) as a gel enhancer and investigated its influence mechanism on the gelation performance, rheological parameters, and temperature resistance of TP/PEI gel systems at 80 and 150 °C, respectively. Results show that the gel strength of conventional TP/PEI gels increased with increasing cross-linker PEI concentration at 80 °C. However, excessive cross-linking occurred in the gel system when the PEI concentration increased to 0.5% at 150 °C. Moreover, the addition of nano-MMT shortened the gelation time, and this effect became more significant at higher reaction temperatures. At the same time, the addition of nano-MMT increased the gel strength. When the amount of nano-MMT added was 0.1%, the gel strength and viscosity of the gel system reached their minimum values. It was because nano-MMT had hydroxyl groups that hindered the progress of the cross-linking reaction. When the concentration of nano-MMT was high, it filled in the microgrid and prevented the molecular structure skeleton from being destroyed by high-temperature thermal vibration. Therefore, the nano-MMT-reinforced TP/PEI gel system had high strength and good thermal stability and met the plugging strength requirements under high-temperature reservoir conditions. This study can further supplement the types of nanomaterial-reinforced TP/PEI gel systems and provide theoretical guidance for their further application in water management in high-temperature petroleum reservoirs.

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Section: Introductionmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

Development of Nanomontmorillonite-Reinforced Terpolymer Gels for High-Temperature Petroleum Reservoirs

Zhu,

Zhang,

Gao

et al. 2024

Energy Fuels

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“…Since phenolic resin has certain biological toxicity and is harmful to the human body, more and more oilfields have gradually adopted polyethyleneimine (PEI) as conformance control agent for reservoirs at high temperatures in recent years. ,, There are two main mechanisms of polymer gels cross-linked by PEI: one is through the amide reaction of the functional group -COOR on the side chain of the polymer, and the other is through the transamidation reaction of the functional group -CONH 2 on the side chain of the polymer . Studies found that PEI as the cross-linking agent can form high-strength gels with conventional polyacrylamide, copolymer PAtBA, and terpolymers synthesized from acrylamide (AM), 1-acrylanmido-2-methylpropanesulfonic acid (AMPS), and N -vinyl pyrrolidone (NVP) as conformance control agents at high temperatures ranging from 130 to 190 °C. , However, studies have shown using PEI as the cross-linking agent results in a polymer gel system with lower gel strength than chromium or phenolic resin cross-linkers.…”

Section: Introductionmentioning

confidence: 99%

Carbon Nanofiber-Enhanced HPAM/PEI Gels for Conformance Control in Petroleum Reservoirs with High Temperatures

et al. 2022

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Nanoparticles have recently been widely used in polymer gel systems to enhance gel strength. However, it is yet unclear how various types of nanoparticles affect the gelation characteristics of polymer gels. In addition, nanomaterials are rarely studied for enhancing the temperature resistance of polyethyleneimine (PEI) cross-linked polyacrylamide gels (i.e., HPAM/PEI gels). Under the urgent requirements of global carbon neutrality, this paper intends to use carbon nanofibers as gel performanceenhancing materials. Furthermore, the mechanism of their influence on the gelation properties and temperature resistance of HPAM/PEI gels was investigated. We evaluated the gelation time of the carbon nanofiber-enhanced HPAM/PEI gels at both 80 and 150 °C by the Sydansk method. The gelation properties and microscopic network structure of the gels were evaluated by rheometer, differential calorimetry scanning/thermogravimetry, and scanning electron microscopy. Results show that adding carbon nanofibers could delay the gelation time at 80 °C, and the gelation time of the polymer gel system reaching F was more than 6 days. On the other hand, the addition of carbon nanofibers could slightly shorten the gelation time of the polymer gel at an ultrahigh temperature of 150 °C. Moreover, the gel strength reached the highest when the addition amount of carbon nanofibers was 0.1%. The gel strength (G′) was as high as 12 Pa, and its stability was as long as 30 days, which was more temperature-resistant than that without adding nanofibers. The microstructure of carbon nanofiber-enhanced HPAM/PEI gels showed many tiny pore-like structures, which might be more conducive to heat dissipation and prevent dehydration. As a result, the carbon nanofiber-enhanced HPAM/PEI gel system had outstanding thermal stability and could be applied in ultrahigh-temperature reservoir conditions while maintaining high plugging strength. This study can present new ideas for improving the nanoparticle-enhanced HPAM/PEI gels in high-temperature petroleum reservoirs and further improving oil recovery, which has essential reference significance.

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“…However, waterflooding typically yields only 30 to 40 percent of the oil, and only a fraction of the geological reserves can be recovered, with most of the oil remaining in the original reservoir. The injection of chemicals, including polymers [ 4 , 5 ], alkalis [ 6 ], and surfactants [ 7 ], enhances recovery by improving the water–oil fluidity ratio, altering wettability, or reducing the oil–water interfacial tension. Polymer flooding is the most widely used of these technologies.…”

Section: Introductionmentioning

confidence: 99%

Experimental Study on Phenol-Formaldehyde Resin Aggregates as In-Depth Conformance Control Agents Stabilized by Polymer

et al. 2022

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To improve the dispersion stability of phenol-formaldehyde resin (PFR) particles in simulated oilfield injection water and their propagation ability in petroleum reservoir, a hydrophobically associating polymer (HAP) was employed as a stabilizer in this paper. The dispersion stability of PFR in the injection water was studied by measuring turbidity as a function of time. In addition, the migration property of the PFR/HAP dispersion was evaluated by both cellulose membrane filtration and sand packs-flooding experiments. The results show that HAP can stabilize the PFR dispersion prepared with the simulated injection water by forming PFR/HAP complex molecular aggregates. These aggregates can migrate in sand packs with strong flow resistance due to deformation or disaggregation of the aggregates when passing through the pore throat. Oil recovery was improved by up to 21.1% on the basis of water flooding, and the higher the concentration of PFR/HAP dispersion system, the better the oil recovery effect. Moreover, the cycle of log-jamming/dispersion of the aggregates leads to their penetrations through the bigger pores in the sand packs with a higher flow resistance than water. This process can improve the conformance of water in high permeability sand packs on a micro/macro scale and thus divert more water into low permeability sand packs. Therefore, more oil could be recovered from the low permeability sand packs. Moreover, the bigger the sand pack’s permeability ratio, the lower the oil recovery rate by waterflood, and the more the incremental oil can be recovered by the PFR/HAP flood.

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Development of re-crosslinkable dispersed particle gels for conformance improvement in extremely high-temperature reservoirs

Cited by 11 publications

References 26 publications

Development of Nanomontmorillonite-Reinforced Terpolymer Gels for High-Temperature Petroleum Reservoirs

Development of Nanomontmorillonite-Reinforced Terpolymer Gels for High-Temperature Petroleum Reservoirs

Carbon Nanofiber-Enhanced HPAM/PEI Gels for Conformance Control in Petroleum Reservoirs with High Temperatures

Experimental Study on Phenol-Formaldehyde Resin Aggregates as In-Depth Conformance Control Agents Stabilized by Polymer

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