Model upsizing for integrated evaluation of polymer degradation and polymer flooding lab data

Zampieri, Marcelo Ferreira; Quispe, C. C.; Moreno, Rosângela Barros Zanoni Lopes

doi:10.1016/j.petrol.2019.01.047

Cited by 8 publications

(2 citation statements)

References 4 publications

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“…One of the major controlling parameters is viscosity of liquids locating in these lamellas. Thus, the addition of a thickening agent to improve the viscosity of bulk liquid phase could be beneficial to improve the lamellas stability [5][6][7][8][9]. Polymers are the most widely used materials to increase the solution viscosity and consequently increasing the lamellae characteristics.…”

Section: Introductionmentioning

confidence: 99%

Experimental Investigation of the Effects of Partially Hydrolyzed Polyacrylamide (PHPA) and Xanthan on Foam Stability

Afrouz

2019

Machines Review

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Foam flooding is one of the enhanced oil recovery (EOR) methods. Stability of the produced foam plays a significant role in overall efficiency of foam flooding. Polymers can be added to foam solutions to improve foam stability and enhance its characteristics. In this study the feasibility of improving foam stability by polymer addition is investigated. Alkyl Ethoxy Sulfate (AES) surfactant as the anionic surfactant and Cetyl Trimethyl Ammonium Bromide (CTAB) as the cationic surfactant are used as the foaming agents. The effects of polymer addition on foam stability is determined by the addition of different concentrations (0-3000 ppm) of PHPA and xanthan to foam solution and finally foam stability as the time taken for 80% of the foam to collapse was determined accordingly. The experimental results showed that CTAB performed better than AES as the foaming agent. Foam stability was enhanced by the addition of both PHPA and xanthan to foam solutions. Xanthan was more compatible with formation brine and PHPA was more compatible with fresh water to enhance foam stability.

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Section: Introductionmentioning

confidence: 99%

Experimental Investigation of the Effects of Partially Hydrolyzed Polyacrylamide (PHPA) and Xanthan on Foam Stability

Afrouz

2019

Machines Review

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“…Power Law (Bird, Stewart, and Lightfoot 1960) (Sorbie 1991 andHeinemann 2003). For example, in the study developed by Zampieri et al (2019), the influence of polymer degradation during heavy oil recovery processes was evaluated using a one dimension simulation model. The results showed the presence of two polymeric advance fronts in the porous media.…”

Section: Model and Reference Viscosity Form Constantsmentioning

confidence: 99%

Biopolymer for EOR

Plotegher¹

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The polymer injection is part of the tertiary methods used to enhance the oil recovery when the conventional water flooding is not efficient. The addition of polymer in low concentration can delay the breakthrough of the injected phase and improve the sweep and displacement efficiencies. The use of a biopolymer is an environmentally friendly alternative to take advantage of the properties of the polymeric solutions using biodegradable additives.On the other hand, the combination of chemical EOR methods with nanotechnology has received lots of attention due to the advantages of the nanoparticles in the reductions of the interfacial tension and contact angle, which can contribute to residual oil mobilization.This experimental study evaluates a workflow to design a biopolymer fluid for enhanced oil recovery (EOR) processes, from fluid characterization to core flooding tests, using water-wet porous media. Three criteria were applied to evaluate the biopolymers used in this study. In the first part, the fluids were tested in terms of fluid-fluid and fluid-solid performance.In the second part (microfluidic approach), the fluids were evaluated in three scenarios, combining the inclusion of different polymer and silica nanoparticles in the solution to be injected. In the last step of the methodology, the solution with the best performance was evaluated in a core flooding test.The fluids characterization showed that biopolymer's content did not affect the ability of the nanoparticles to reduce the interfacial tension and make the surface more waterwet. Additionally, the biopolymers reduced the aggregation of nanoparticles in the solution.Also, the viscosity of the solutions was not affected by the interaction of the biopolymers with the silica nanoparticles. The micromodel test performed with the nanoparticles-assisted Xanthan showed the smallest oil clusters and the highest ultimate oil recovery compared to the Xanthan Gum, Scleroglucan, brine, and nanofluid floodings. Finally, a core flooding test was run to evaluate Xanthan Gum flooding on oil recovery. As a result, the oil production was slightly anticipated, but water breakthrough delay was not evident. At the end of both processes, the polymeric solution increases the ultimate oil recovery factor by 9.4% when compared to conventional water injection.

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The Physical Experiment of Displacement in an Offshore Fluvial Heavy Oil Reservoir

Liu,

Tan,

2024

Springer Series in Geomechanics and Geoengineering

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Model upsizing for integrated evaluation of polymer degradation and polymer flooding lab data

Cited by 8 publications

References 4 publications

Experimental Investigation of the Effects of Partially Hydrolyzed Polyacrylamide (PHPA) and Xanthan on Foam Stability

Experimental Investigation of the Effects of Partially Hydrolyzed Polyacrylamide (PHPA) and Xanthan on Foam Stability

Biopolymer for EOR

The Physical Experiment of Displacement in an Offshore Fluvial Heavy Oil Reservoir

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