Preparation and probing of the steady shear flow and viscoelastic properties of weakly crosslinked hydrogels based on sulfonated polyacrylamide for oil recovery applications

Aalaie, Jamal; Alvand, Ehsan; Hemmati, Mahmood; Sajjadian, Vali Ahmad

doi:10.1134/s0965545x15050016

Cited by 10 publications

(3 citation statements)

References 15 publications

(19 reference statements)

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“…Consequently, the rheological criteria were evaluated at different salinities and shearing behaviors at a constant temperature of 80 °C. Long-term thermal aging under high ionic strength reduces the viscosity of the gel system . During hydrogel injection in underground perforation, viscosity loss owing to mechanical, thermal, and ionic degradation takes place since the stress resistance of chemical bonds in the hydrogel architecture cannot resist the tensile stress enforced by severe underground conditions. , With further temperature increase, the molecular associations deteriorate, and the internal movement of the single bond increases, leading to molecular chain curling …”

Section: Resultsmentioning

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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Section: Resultsmentioning

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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“…For conformance control of oil reservoirs, these gelling systems must have good injectivity and propagation within the reservoir rock (viscosities below 30 mPa·s); predictable and controllable gelation time (>2 h to ensure safety and operational continuity); and long-term biological, chemical, and thermal stability [6,10]. Furthermore, the gelant must form a strong hydrogel under reservoir conditions—with Sydansk gel-strength code > G, and storage modulus (G’) and complex modulus (G*) preferably >10 (blocking-ability parameters)—in order to withstand the pressure gradients and water flow expected in the formation [11,12,13].…”

Section: Introductionmentioning

confidence: 99%

Gelation Kinetics of Hydrogels Based on Acrylamide–AMPS–NVP Terpolymer, Bentonite, and Polyethylenimine for Conformance Control of Oil Reservoirs

Tessarolli

Souza

Gomes

et al. 2019

Gels

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Relatively smaller volumes of gelling systems had been used to address conformance problems located near the wellbore in oil reservoirs with harsh temperature and salinity conditions. These gelling systems were formulated with high concentrations of low-molecular-weight acrylamide-based polymers crosslinked with polyethylenimine (PEI). However, for in-depth conformance control, in which large gelant volumes and long gelation times were required, lower-base polymer loadings were necessary to ensure the economic feasibility of the treatment. In this study, a gelling system with high-molecular weight 2-acrylamido-2-methylpropane sulfonic acid (AMPS), N-vinyl-2-pyrrolidone (NVP), acrylamide terpolymer, and PEI, with the addition of bentonite as a filler, was formulated. The influence of the gelant formulation and reservoir conditions on the gelation kinetics and final gel strength of the system was investigated through bottle tests and rheological tests. The addition of clay in the formulation increased the gelation time, thermal stability, and syneresis resistance, and slightly improved the final gel strength. Furthermore, samples prepared with polymer and PEI concentrations below 1 wt %, natural bentonite, and PEI with molecular weight of 70,000 kg/kmol and pH of 11: (i) presented good injectivity and propagation parameters (pseudoplastic behavior and viscosity ~25 mPa·s); (ii) showed suitable gelation times for near wellbore (~5 h) or far wellbore (~21 h) treatments; and (iii) formed strong composite hydrogels (equilibrium complex modulus ~10–20 Pa and Sydansk code G to H) with low syneresis and good long-term stability (~3 to 6 months) under harsh conditions. Therefore, the use of high-molecular-weight base polymer and low-cost clay as active filler seems promising to improve the cost-effectiveness of gelling systems for in-depth conformance treatments under harsh conditions of temperature and salinity/hardness.

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“…They act as flow modifiers to alter the viscosity of the displacing phase, improve the mobility ratio (the mobility ratio is defined as the ratio of the mobility of displacing fluid to that of the displaced fluid in the reservoir), increase the sweep efficiency and finally enhance oil recovery . Some studies, however, show that weakly crosslinked polymeric systems can widen the application of polymers in chemical EOR . For example, Wang et al introduced hydrolyzed polyacrylamide weak gels for chemical EOR applications .…”

Section: Introductionmentioning

confidence: 99%

Rheological and thermal stability of novel weak gels based on sulfonated polyacrylamide/scleroglucan/chromium triacetate

Alvand

Aalaie

Hemmati

et al. 2016

Polymer International

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The present study deals with weak gels based on sulfonated polyacrylamide (SPA)/scleroglucan (SC)/Cr 3+ with an exceptional thermal stability in electrolyte media. The rheological results showed that on increasing the SC concentration the shear viscosity and storage modulus of the SPA/SC/Cr 3+ system were increased and the dependence of the storage modulus on frequency became weaker. The yield stress of the SPA/SC/Cr 3+ system was higher than that of the corresponding SPA/SC system. The thermochemical stability increased with increasing relaxation time. The SPA/SC/Cr 3+ semi-interpenetrating network exhibited the lowest viscosity loss in electrolyte media; therefore this system may be a potential candidate for enhanced oil recovery applications.

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Preparation and probing of the steady shear flow and viscoelastic properties of weakly crosslinked hydrogels based on sulfonated polyacrylamide for oil recovery applications

Cited by 10 publications

References 15 publications

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

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

Gelation Kinetics of Hydrogels Based on Acrylamide–AMPS–NVP Terpolymer, Bentonite, and Polyethylenimine for Conformance Control of Oil Reservoirs

Rheological and thermal stability of novel weak gels based on sulfonated polyacrylamide/scleroglucan/chromium triacetate

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