Synthesis and aqueous solution properties of novel thermosensitive polyacrylamide derivatives

Zhu, Yaofeng; Xu, Yuntao; Huang, Guangsu

doi:10.1002/app.39192

Cited by 10 publications

(10 citation statements)

References 33 publications

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“…Table 1 shows the summary of the main scientific developments in this area and the evolution of the studies. Sarsenbekuly et al, 2017b;Su and Feng, 2018;Zhu et al, 2013). These structures behave like water-soluble macromolecules at room temperature, but above the critical association temperature (T ass ) or LCST, the thermosensitive sequences are reversibly self-aggregated by the formation of physical interactions, forming hydrophobic microdomains that increase the viscosity of the polymeric solution (Kamal and Sultan, 2017;Kamal et al, 2015a;Li et al, 2017;Wang et al, 2010).…”

Section: Hydrophobically Modified Associative Polymers (Hmaps)mentioning

confidence: 99%

“…After this initial study of TVP application in the oil industry, several authors carried out further research in this area (Chen et al, 2013;Leblanc et al, 2015;Li et al, 2017;Reichenbach-Klinke et al, 2018;Sarsenbekuly et al, 2017b;Wang et al, 2010Wang et al, , 2011Zhu et al, 2013). Wang et al (2010) developed a thermo-viscosifying system from free radical copolymerization of Acrylamide (AM) with the macromonomer MPAD, producing the water-soluble copolymer P(AM-co-MPAD).…”

Section: Hydrophobically Modified Associative Polymers (Hmaps)mentioning

confidence: 99%

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Polymer viscosifier systems with potential application for enhanced oil recovery: a review

Aguiar

Palermo

Mansur

2021

Oil Gas Sci. Technol. – Rev. IFP Energies nouvelles

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Due to the growing demand for oil and the large number of mature oil fields, Enhanced Oil Recovery (EOR) techniques are increasingly used to increase the oil recovery factor. Among the chemical methods, the use of polymers stands out to increase the viscosity of the injection fluid and harmonize the advance of this fluid in the reservoir to provide greater sweep efficiency. Synthetic polymers based on acrylamide are widely used for EOR, with Partially Hydrolyzed Polyacrylamide (PHPA) being used the most. However, this polymer has low stability under harsh reservoir conditions (High Temperature and Salinity – HTHS). In order to improve the sweep efficiency of polymeric fluids under these conditions, Hydrophobically Modified Associative Polymers (HMAPs) and Thermo-Viscosifying Polymers (TVPs) are being developed. HMAPs contain small amounts of hydrophobic groups in their water-soluble polymeric chains, and above the Critical Association Concentration (CAC), form hydrophobic microdomains that increase the viscosity of the polymer solution. TVPs contain blocks or thermosensitive grafts that self-assemble and form microdomains, substantially increasing the solution’s viscosity. The performance of these systems is strongly influenced by the chemical group inserted in their structures, polymer concentration, salinity and temperature, among other factors. Furthermore, the application of nanoparticles is being investigated to improve the performance of injection polymers applied in EOR. In general, these systems have excellent thermal stability and salinity tolerance along with high viscosity, and therefore increase the oil recovery factor. Thus, these systems can be considered promising agents for enhanced oil recovery applications under harsh conditions, such as high salinity and temperature. Moreover, stands out the use of genetic programming and artificial intelligence to estimate important parameters for reservoir engineering, process improvement, and optimize polymer flooding in enhanced oil recovery.

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Section: Hydrophobically Modified Associative Polymers (Hmaps)mentioning

confidence: 99%

Section: Hydrophobically Modified Associative Polymers (Hmaps)mentioning

confidence: 99%

Polymer viscosifier systems with potential application for enhanced oil recovery: a review

Aguiar

Palermo

Mansur

2021

Oil Gas Sci. Technol. – Rev. IFP Energies nouvelles

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“…That is, the viscosity of the TAP will increase with increasing temperature. L'alloret et al [16] and Zhu et al [38] report that the thickening effect is strongly shear-thinning.…”

Section: Introductionmentioning

confidence: 99%

Flow behavior of thermo-thickening associative polymers in porous media: effects of associative content, salinity, time, velocity, and temperature

2022

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Above a critical temperature, thermo-thickening associative polymers (TAPs) have a superior ability to decrease the mobility of the water phase, compared to traditional polymers for enhanced oil recovery. The ability to decrease the mobility, will be amplified at low flow velocities, and by the presence of salt, and is much higher in porous media than would be expected from bulk viscosity. In this work, we have examined TAPs ability to reduce the mobility, i.e., to increase the resistance factor. We have studied the effect of increasing the associative content, changing the porous media, changing the salinity, and scaling up the size of the porous media. How the resistance factor evolved, was studied as a function of temperature, velocity, and time. We found that a critical associative content or critical concentration of polymer was needed to achieve thermo-thickening in the porous media. As expected, thermo-thickening increased by increasing the salinity. For the relative homogenous clastic porose media investigated here, ranging from ~ 1Darcy sandstone to multidarcy sand, type of porous media did not seem to have a significant impact on the resistance factor. Time and amount of polymer injected is a critical factor: The buildup of thermo-thickening is delayed compared to the polymer front. For our tests with the weaker systems, we also observed a breakdown of the associative network at very low injection rates, possibly caused by the formation of intramolecular association. Article highlights Key findings from our tests of thermo-thickening associative polymer for enhance oil recovery operations: At high temperature, the polymer solutions mobility in porous media is much lower than expected from viscosity At low temperature, the flow behavior is like that of a traditional synthetic polymer This will mean good injectivity and superior sweep, compared to a traditional polymer for enhanced oil recovery

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“…In this case such an automorphism is unique, and called the duali The literature contains many examples of self-dual Leonard pairs. For instance (i ated with an irreducible module for the Terwilliger algebra of the hypercube (see [4, C Leonard pair of Krawtchouk type (see [10, De nition 6.1]); (iii) the Leonard pair assoc module for the Terwilliger algebra of a distance-regular graph that has a spin model bra (see [1,Theorem], [3, Theorems 4.1, 5.5]); (iv) an appropriately normalized total (see [11,Lemma 14.8]); (v) the Leonard pair consisting of any two of a modular Leon De nition 1.4]); (vi) the Leonard pair consisting of a pair of opposite generators for bra, acting on an evaluation module (see [5,Proposition 9.2]). The example (i) is a sp examples (iii), (iv) are special cases of (v).…”

Section: Introductionmentioning

confidence: 99%

“…However, the gel system generally only works as a plug in the oil layer near the water injection well, and water will quickly enter the high-permeability zone again, which results in limited deep-displacement. Therefore, the effective migration of the polymer gel system in the pore space and the effective sealing of the large pores after the gelation of polymer gel are the key parts of the deep profile control technology (3)(4)(5).…”

Section: Introductionmentioning

confidence: 99%

Study on the variation of rock pore structure after polymer gel flooding

2020

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AbstractPolymer gels have received an increasing attention as profile control agents in the heterogeneous reservoir water-flooded layers. The article focus on the profile control mechanism of polymer gels by plugging macropore. The micro-structures of polymer gel and pore were characterized by scanning electron microscopy (SEM). And the core displacement equipment was used to evaluate the properties of plugging properties. The variation of pore structure is measured by SEM, mercury intrusion meter and nuclear magnetic resonance instrument. Investigation results show that the molecules form a network structure with many dense layers after 15 days of cross-linking reaction, which results in the increase of the viscosity of the system from 15.3 to 6325 mPa‧s. After the polymer gel forms a micelle at the middle end of the core and blocks the pores, the plugging rate of the core reaches 99.2%. The results obtained in this paper reveal the mechanism of plugging characteristics of polymer gels, and further prove the great potential of polymer gels to enhance oil recovery in oilfields.

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Synthesis and aqueous solution properties of novel thermosensitive polyacrylamide derivatives

Cited by 10 publications

References 33 publications

Polymer viscosifier systems with potential application for enhanced oil recovery: a review

Polymer viscosifier systems with potential application for enhanced oil recovery: a review

Flow behavior of thermo-thickening associative polymers in porous media: effects of associative content, salinity, time, velocity, and temperature

Study on the variation of rock pore structure after polymer gel flooding

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