Recuperação de petróleo por injeção de solução polimérica em rochas carbonáticas com monitoramento da frente de saturação

Lopes, Leandro Freitas

doi:10.47749/t/unicamp.2017.991736

Cited by 2 publications

(3 citation statements)

References 80 publications

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“…The higher the concentration, the higher the viscosity. The diluted polymer solution viscosity (𝜂 𝑤 ) as a function of polymer concentration or weight fraction (𝑤 𝑝 ) can be modeled by a power-law model for the different regimes (Silveira, 2017;Lopes, 2017):…”

Section: Concentration Regimes and Solution Viscositymentioning

confidence: 99%

Assessment of grading polymer injection by simulation at laboratory scale

Alvaro Choquejahua Salcedo

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When the mobility ratio is unfavorable, or the heterogeneity in the reservoir is high, the water flooding losses its effectivity causing early water breakthrough and low recovery factors.Polymer flooding improves the unfavorable mobility ratio by increasing the water viscosity and reducing the permeability to water due to polymer adsorption. Typically, these projects inject a finite volume of the polymer due to economic aspects since the polymer cost predominantly affects operation expenditures. However, this injection scheme can present an abrupt viscosity transition at the polymer slug tailing. The chase water can form fingers, bypassing the polymer slug and destroying its integrity. Thus, grading viscous injection is proposed to mitigate that issue. Polymer slugs with different concentrations are sequentially injected, followed by chase water. According to the literature, graded polymer schemes are not usual in the field, and only a few studies are available at the laboratory scale, including simulation. This dissertation evaluates the viscous grading polymer scheme by numerical simulation at a laboratory scale through performance indicators. The specific objectives are to build a comprehensive workflow that integrates laboratory data and validates the proposed procedures on three experimental tests reported in the literature.The proposed workflow includes three parts. The input data preparation section describes how to integrate the data from rock-fluid studies and single-and two-phase polymer core floods to calculate the parameters required by the simulator. The simulation grid selection describes the usage of static and dynamic grids to reduce the numerical dispersion and speed up the simulation runs. And finally, the history matching stage presents a workflow to fit the model systematically.The results demonstrate the workflow applicability by simultaneously fitting the cumulative oil, water, and differential pressure histories of the graded and continuous flooding schemes. The integration of cumulative volume and pressure responses allowed detecting key events, and the dynamic grid amalgamation reduced the computational time compared with the static grid. The performance indicators based on fitted models helped identify the most efficient injection scheme according to the polymer mass used, oil recovery, injected/produced water, and injectivity compared to water flooding. The three-slugs strategy performed better than the two-slug one. The proposed workflow integrating laboratory data can be helpful to the researchers involved with core floods and small-scale simulation and, also, with modeling and simulations at pilot and field scales.

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Section: Concentration Regimes and Solution Viscositymentioning

confidence: 99%

Assessment of grading polymer injection by simulation at laboratory scale

Alvaro Choquejahua Salcedo

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“…One of the alternatives to reduce costs in polymer projects is the use of banks instead of continuous injection. Cattani (2018) evaluated the methodology of injection in twophase core flooding tests using sandstone samples and synthetic polymer HPAM at 40 o C. The results showed an improvement in the oil recovery factor and polymer mass ratio in the injection by banks than continuous Lopes (2017). evaluated the incremental oil produced by polymer flooding in comparison with conventional water flooding to determine the optimum polymer injected volume to optimize oil recovery, minimizing polymer consumption.2.4 Biopolymers and flooding mechanisms2.4.1 Chemical structure and properties of the biopolymers moleculesNatural polysaccharides biopolymers are attractive for EOR processes because of viscosity enhancement, high resistance to mechanical and thermal degradation, and susceptibility to biodegradation, which makes them environmentally friendly (AlQuraishi and Alsewailem 2011).…”

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confidence: 99%

“…The oleic phase was doped by adding 10% m/m of 1-iododecane (C10H21I). The doped chemical was selected based on the study developed byLopes (2017).…”

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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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Recuperação de petróleo por injeção de solução polimérica em rochas carbonáticas com monitoramento da frente de saturação

Cited by 2 publications

References 80 publications

Assessment of grading polymer injection by simulation at laboratory scale

Assessment of grading polymer injection by simulation at laboratory scale

Biopolymer for EOR

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