Synthesis and evaluation of acryloylated starch-g-poly (Acrylamide/Vinylmethacrylate/1-Vinyl-2-pyrrolidone) crosslinked terpolymer functionalized by dimethylphenylvinylsilane derivative as a novel polymer-flooding agent

El-hoshoudy, A.N.; Desouky, S.M.

doi:10.1016/j.ijbiomac.2018.05.056

Cited by 26 publications

(10 citation statements)

References 78 publications

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“…Water-soluble polymers are used to increase the viscosity of the injected water, reducing the mobility ratio of water relative to crude oil inside the reservoir; this results in the formation of a uniform oil displacement front, facilitating the mobilization of the residual oil and improving the overall sweep efficiency of water flooding. Several studies (including laboratory and field assays) demonstrated that polymer flooding can increase oil recovery by 20% over water flooding [3][4][5][6][7].…”

Section: Introductionmentioning

confidence: 99%

The biopolymer produced by Rhizobium viscosum CECT 908 is a promising agent for application in microbial enhanced oil recovery

et al. 2019

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Polymer flooding is one of the most promising techniques used to increase the productivity of mature oil reservoirs. Polymers reduce the mobility ratio of the injected water relative to the crude oil, improving the displacement of the entrapped oil and consequently, increasing oil recovery. Biopolymers such as xanthan gum have emerged as environmentally friendly alternatives to the chemical polymers commonly employed by the oil industry. However, in order to seek more efficient biomolecules, alternative biopolymers must be studied. Here, the applicability of a biopolymer produced by Rhizobium viscosum CECT 908 in Microbial Enhanced Oil Recovery (MEOR) was evaluated. This biopolymer exhibited better rheological properties (including higher viscosity) when compared with xanthan gum. Its stability at high shear rates (up to 300 s −1), temperatures (up to 80°C) and salinities (up to 200 g/L of NaCl) was also demonstrated. The biopolymer exhibited better performance than xanthan gum in oil recovery assays performed with a heavy crude oil, achieving 25.7 ± 0.5% of additional recovery. Thus the R. viscosum CECT 908 biopolymer is a promising candidate for application in MEOR.

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Section: Introductionmentioning

confidence: 99%

The biopolymer produced by Rhizobium viscosum CECT 908 is a promising agent for application in microbial enhanced oil recovery

et al. 2019

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“…Polymer flooding in underground reservoirs is affected by salinity, temperature, and shearing action of fluids. However, polymer assessment was conducted relative to these factors individually, as discussed in our previous studies. ,− In this section, the performance of two hydrogels is screened as a function of simulated reservoir conditions collectively. The reservoir temperature is a constant value, while the salinity and shearing action vary vigorously depending on variation of the injection and producing zones, pumping action, and heterogeneous reservoir nature.…”

Section: Resultsmentioning

confidence: 99%

“…Poly(ethylene glycol)dimethacrylate (PEG) and poly(propylene glycol)dimethacrylate (PPG) surfmers were synthesized according to the method reported by Shukla and Rai . Spectroscopic characterization was conducted according to the literature. ,,, Thermogravimetric analysis (TGA) was performed by SDT Q600 V20.5 Build 15 (TA Instruments). PEG and PPG hydrogels with weight 10 mg were treated thermally on a platinum pan from 25 to 623.15 °C under a nitrogen atmosphere and a heating rate of 10 °C/min.…”

Section: Methodsmentioning

confidence: 99%

Experimental and Theoretical Investigation of Glycol-Based Hydrogels through Waterflooding Processes in Oil Reservoirs Using Molecular Dynamics and Dissipative Particle Dynamics Simulation

El-hoshoudy

2021

ACS Omega

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Enhanced oil processing aims to retrieve petroleum fluids from depleted reservoirs after traditional processing. Hydrogels and polymeric macromolecules are considered effective displacing agents in oil reservoirs. In the current work, the authors used hydrophilic hydrogels based on poly(ethylene glycol)/poly(propylene glycol) (PEG/PPG) surfmers for oil displacement processes. Statistical modeling of the rheological properties at 80 °C for the two hydrogels indicates that the viscosity–shearing profile obeys the power-law model. Also, shear stress scanning follows the Herschel–Bulkley and the Bingham plastic models. The two hydrogels exhibit an initial yield stress owing to the formation of a three-dimensional (3D) structure at zero shearings. Furthermore, PEG and PPG hydrogels can retain the viscosity after a shear rate of 64.68 S–1. On the scale of surface activity, the two hydrogels exhibit higher surface areas (A m) of 0.1088 and 0.1058 nm2 and lower surface excess concentrations (Γm) of 1.529 and 1.567 × 1010 mol/cm2, respectively. A molecular dynamics (MD) simulation was conducted to explore the Flory–Huggins chi parameter, the solubility parameter, and the cohesive energy density. The results indicate a negative magnitude of chi parameter (χ ij ) for water and salt, which indicates that the two hydrogels have a good tendency toward saline formation water in the underground petroleum reservoir. Furthermore, the dissipative particle dynamics (DPD) was performed on a mesoscale to investigate the interfacial tension, the radius of gyration, the concentration profile, and the radial distribution function. The increased radius of gyration (R g) confirms that the two hydrogels are more overextended and can align perpendicularly toward the water/oil boundary. Experimental displacement was operated on a linear sandpack model using different slug concentrations. The oil recovery factor, the water-cut, and the differential pressure data during the flooding process were estimated as a function of the injected pore volume. The obtained results show that the oil recovery factor reaches 72 and 88% in the cases of PEG and PPG hydrogels at 80 °C with concentrations of 1.0 and 1.5 g/L, which reveals that both hydrogels are effective enhanced oil recovery (EOR) agents for the depleted reservoirs. This study establishes a new route that employs MD and DPD simulation in the field of enhanced oil recovery and the petroleum industry.

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“…AMPS-AM-N,N-dimethylacrylamide/PEI Stable system within the temperature interval ranging from 120 to 176 °C, also has good gel quality and excellent gelation time, but is very sensitive to pH and salinity [135] AM-AMPS/PEI Stable system within the temperature interval ranging from 100 to 150 °C [136,137] PAM-VP-AMPS/HMTA-phenolic compounds Suitable for water shutoff under extreme conditions, but these gels lacked long stability; syneresis began after only 3-12 days keeping the systems at 150 °C [138] PAM-VP-AMPS/HMTA-resorcinol Stable gels at 150 °C for five months [130,139,140] AM-4-dodecyl-benzenesulfonate-1-vinylimidazol-3ium/divinyl sulfone Stable system up to 270 °C [141] Acryloylated starch-g-poly (acrylamide/vinylmethacrylate/1-vinyl-2-pyrrolidone) / dimethylphenylvinylsilane Hydrogel stable until 240 °C and 80 000 of TDS [142] AA-AM-attapulgite power/N,N-methylenebisacylamide Superabsorbent polymer clays infiltrated with bentonite presented high thermal performance until 200 °C [143] AM-isopropyl acrylamide(IAA)-3-acrylamidopropyltrimetilammnoium chloride (ATAC)-or 2-acrylamido 2-methyl-1-propanosulfonic acid (APSA)-or 4-4-azo-bis 4-cyanopantenoic acid (ACPA)-MWCNTs…”

Section: Syntheticx Polymersmentioning

confidence: 99%

Water Control with Gels Based on Synthetic Polymers under Extreme Conditions in Oil Wells

et al. 2022

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A bibliographic review of research works dealing with gels based on synthetic polymers and their application in water control under harsh conditions was compiled. The extreme conditions were defined to be above 100 °C with 100 000 ppm of total dissolved solids, including divalent ions. Works describing laboratory experiments and oilfield implementations were also considered. According to current literature, some gels based on synthetic polymers have displayed desirable properties for water control, but in many cases, research is still at laboratory level. Therefore, further studies are required to understand the mode of action and stability of gels and polymers submitted to hard conditions in order to produce high‐performance prototypes.

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Synthesis and evaluation of acryloylated starch-g-poly (Acrylamide/Vinylmethacrylate/1-Vinyl-2-pyrrolidone) crosslinked terpolymer functionalized by dimethylphenylvinylsilane derivative as a novel polymer-flooding agent

Cited by 26 publications

References 78 publications

The biopolymer produced by Rhizobium viscosum CECT 908 is a promising agent for application in microbial enhanced oil recovery

The biopolymer produced by Rhizobium viscosum CECT 908 is a promising agent for application in microbial enhanced oil recovery

Experimental and Theoretical Investigation of Glycol-Based Hydrogels through Waterflooding Processes in Oil Reservoirs Using Molecular Dynamics and Dissipative Particle Dynamics Simulation

Water Control with Gels Based on Synthetic Polymers under Extreme Conditions in Oil Wells

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