Rate-dependent polymer adsorption in porous media

Idahosa, P.E.G.; Oluyemi, Gbenga; Oyeneyin, Babs; Prabhu, Radhakrishna

doi:10.1016/j.petrol.2016.02.020

Cited by 21 publications

(9 citation statements)

References 13 publications

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“…Some recent studies suggest that IPV may vary with the water-phase flow rate [14,23,47]. However, CMG-STARS model for IPV does not account for that.…”

Section: Inaccessible Pore Volumementioning

confidence: 99%

“…Recent literature reports that polymer retention by hydrodynamic effects is significant, although less important than adsorption. Besides that, hydrodynamic retention is a function of the water-phase flow rate [14,23,47].…”

Section: Introductionmentioning

confidence: 99%

“…Both effects are graphically determined by analyzing the concentration profiles of the tracer and the polymer at the effluent. The difference in polymer and tracer breakthroughs in the second polymer flush (i.e., when no retention is acting) is defined as the IPV [14,23,47].…”

Section: Introductionmentioning

confidence: 99%

See 2 more Smart Citations

History matching of experimental polymer flooding for enhanced viscous oil recovery

Zampieri

Ferreira

Quispe

et al. 2020

J Braz. Soc. Mech. Sci. Eng.

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Polymer flooding has been widely studied and applied for enhancing reservoir oil recovery. The key to evaluating the potential application of polymer injection is based on a clear understanding of the mechanisms involved in the recovery process. This work focuses on history matching of laboratory core flooding of heavy oil recovery by polymer flooding. We match the experiments through a small-scale simulation model and evaluate the challenges of representing the polymer behavior in porous media. The methodology we propose in this paper aims to model core-flooding experiments with laboratory-measured data. These data come from different experiments, including rheology, single-and two-phase core flooding and are separated into consolidated and uncertain data. Consolidated data include: core volume, permeability, porosity, oil viscosity and density, initial saturation conditions, test temperature and injection rate. The uncertain input parameters involve more complex variables, such as viscosity behavior against shear rate and concentration, residual resistance factor, adsorption, inaccessible pore volume and water-oil relative permeabilities. We compare the simulation output parameters with laboratory results and evaluate the quality of the match for four different two-phase core-flooding experiments. The output parameters include histories for differential pressure, recovery factor, water cut and cumulative produced water, oil and liquid. Our results show that the simulation models successfully matched the experimental data, for all the cases, using appropriate representation of the laboratory parameters. The contribution of this work relies on the proposed methodology, which allows integrating the laboratory data in the construction and validation of core scale simulation models appropriately.

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“…Some recent studies suggest that IPV may vary with the water-phase flow rate [14,23,47]. However, CMG-STARS model for IPV does not account for that.…”

Section: Inaccessible Pore Volumementioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

See 1 more Smart Citation

History matching of experimental polymer flooding for enhanced viscous oil recovery

Zampieri

Ferreira

Quispe

et al. 2020

J Braz. Soc. Mech. Sci. Eng.

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show abstract

“…Thus, the adsorption at the solidliquid interface takes place by the transfer of the molecule of the chemical to the solid-liquid interface from the bulk solution phase [21]. Meanwhile, polymer retention and inaccessible pore volume dictates the propagation of polymer flow in the reservoir [22]. Retention of polymer is alluded to any mechanism that leads to reduction or removal of polymer molecules from transported aqueous phase.…”

Section: Adsorption and Retentionmentioning

confidence: 99%

Nanotechnology Application in Chemical Enhanced Oil Recovery: Current Opinion and Recent Advances

Gbadamosi¹,

Junin²,

Manan³

et al. 2019

Enhanced Oil Recovery Processes - New Technologies

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Chemical enhanced oil recovery (EOR) has been adjudged as an efficient oil recovery technique to recover bypassed oil and residual oil trapped in the reservoir. This EOR method relies on the injection of chemicals to boost oil recovery. Recently, due to the limitations of the application of chemical EOR methods to reservoirs having elevated temperatures and high salinity and hardness concentrations, nanotechnology have been applied to enhance its efficiency and improve oil productivity. The synergistic combination of nanoparticles and conventional EOR chemicals has opened new routes for the synthesis and application of novel materials with sterling and fascinating properties. In this chapter, an up-to-date synopsis of nanotechnology applications in chemical EOR is discussed. A detailed explanation of the mechanism and applications of these novel methods for oil recovery are appraised and analyzed. Finally, experimental and laboratory results were outlined. This overview presents extensive information about new frontiers in chemical EOR applications for sustainable energy production.

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“…Therefore, PF is not a simple process of adding polymer to water [ 6 , 7 ]. To obtain a better PF performance, many experimental investigations have been comprehensively studied [ 8 , 9 ], and most of these studies have focused on polymer static degradation [ 10 , 11 ]. However, the study of polymer dynamic degradation in porous media is relatively rare and requires more research.…”

Section: Introductionmentioning

confidence: 99%

Polymer Flooding in Heterogeneous Heavy Oil Reservoirs: Experimental and Simulation Studies

Xin

et al. 2021

Polymers

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Polymer flooding (PF) in heterogeneous heavy oil reservoirs is not only closely related to polymer degradation, but also to non-Newtonian flow. In this paper, both experimental and simulation methods are combined to investigate this type of flooding. Through experiments, the degradation of polymer, rheological properties of fluids, and flow of fluids in porous media were determined. Based on the experimental results, a novel mathematical model was established, and a new PF simulator was designed, validated, and further applied to study the effects of polymer degradation, polymer solution shear thinning, and non-Newtonian flow on PF in heterogeneous heavy oil reservoirs. These experimental results demonstrated that the polymer first-order static degradation rate constant was lower than the polymer first-order dynamic degradation rate constant; the polymer solution and heavy oil were non-Newtonian fluids, with shear thinning and Bingham fluid properties, respectively; and the heavy oil threshold pressure gradient (TPG) in low-permeability porous media was higher than that in high-permeability porous media. All comparison results showed that the designed simulator was highly accurate and reliable, and could well describe both polymer degradation and non-Newtonian flow, with special emphasis on the distinction between polymer static and dynamic degradation and heavy oil TPG. Furthermore, the simulation results verified that polymer degradation, polymer solution shear thinning, and heavy oil TPG all had negative effects on the efficiency of PF in heterogeneous heavy oil reservoirs.

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Rate-dependent polymer adsorption in porous media

Cited by 21 publications

References 13 publications

History matching of experimental polymer flooding for enhanced viscous oil recovery

History matching of experimental polymer flooding for enhanced viscous oil recovery

Nanotechnology Application in Chemical Enhanced Oil Recovery: Current Opinion and Recent Advances

Polymer Flooding in Heterogeneous Heavy Oil Reservoirs: Experimental and Simulation Studies

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