Study on Emulsification Behavior and Optimized Separation Technology of High Concentration Polymer Flooding Produced Liquid in Daqing Oilfield

Liu, Yang; Wang, Zhihua; Zhuge, Xianglong; Wang, Shanzhe

doi:10.2118/172768-ms

Cited by 13 publications

(7 citation statements)

References 14 publications

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“…Likewise, an earlier study also showed that the zeta potential of the droplets increases after 800 ppm of alkali [41]. With the increasing polymer, the zeta potential ranges significantly from −20 mv to −35 mv and remains the same at the high water cut [42]. Importantly, when the TiO 2 nanoparticles were added to the emulsion, the zeta potential of the residual emulsion increases to −7 mV, which indicates the charge neutralization in the system and is advantageous for better o/w separation in the emulsion.…”

Section: Droplet Size and Zeta Potential Of Emulsion With And Without...mentioning

confidence: 54%

De-Emulsification and Gravity Separation of Micro-Emulsion Produced with Enhanced Oil Recovery Chemicals Flooding

Khan

Ullah

et al. 2021

Energies

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The present study investigates the effect of TiO2 nanoparticles on the stability of Enhanced Oil Recovery (EOR)-produced stable emulsion. The chemical precipitation method is used to synthesize TiO2 nanoparticles, and their properties were determined using various analytical characterization techniques such as X-ray Diffraction (XRD), High-Resolution Transmission Electron Microscopy (HRTEM), and Field Emission Scanning Electron Microscopy (FESEM). The effect of TiO2 nanoparticles is evaluated by measuring oil/water (o/w) separation, rag layer formation, oil droplet size, and zeta potential of the residual EOR produced emulsion. The laser scattering technique is used to determine the o/w separation. The results showed that spherical-shaped anatase phase TiO2 nanoparticles were produced with an average particle size of 122 nm. The TiO2 nanoparticles had a positive effect on o/w separation and the clarity of the separated water. The separated aqueous phases’ clarity is 75% and 45% with and without TiO2 nanoparticles, respectively. Laser scattering analysis revealed enhanced light transmission in the presence of TiO2 nanoparticles, suggesting higher o/w separation of the ASP-produced emulsion. The overall increase in the o/w separation was recorded to be 19% in the presence of TiO2 nanoparticles, indicating a decrease in the stability of ASP-produced emulsion. This decrease in the stability can be attributed to the improved coalescence’ action between the adjacent oil droplets and improved behavior of o/w interfacial film. An observable difference was found between the oil droplet size before and after the addition of TiO2 nanoparticles, where the oil droplet size increased from 3 µm to 35 µm. A similar trend of zeta potential is also noticed in the presence of TiO2 nanoparticles. Zeta potential was −13 mV to −7 mV, which is in the unstable emulsion range. Overall, the o/w separation is enhanced by introducing TiO2 nanoparticles into ASP-produced stable emulsion.

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Section: Droplet Size and Zeta Potential Of Emulsion With And Without...mentioning

confidence: 54%

De-Emulsification and Gravity Separation of Micro-Emulsion Produced with Enhanced Oil Recovery Chemicals Flooding

Khan

Ullah

et al. 2021

Energies

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“…• Water treatment costs required to meet water quality standards for polymer preparation, water re-injection and/or water disposal (Al-Kalbani et al, 2014c;Al-Maamari et al, 2014;Batonyi et al, 2016;Henthorne, Walsh & Llano, 2013;Jacob et al, 2015;Rambeau et al, 2014Rambeau et al, & 2015Wu et al, 2013;Yang, L., Zhihua, W., Xianglong, Z., & Shanzhe, W., 2015).…”

Section: Summary Discussionmentioning

confidence: 99%

“…However, most of the studies documented in the literature mainly focus its attention on emulsion stability and its impact on oil-water separation, water treatment and production facilities (i.e. nutshell filters, heater treaters) due to the back produced polymer (Al-Kalbani et al, 2014;Al-Maamari et al, 2014;Bartz and Gotterba, 2015;Delamaide et al, 2014b;Geremia, and Bennetzen, 2016;Jacob et al, 2015;Rambeau, O., Jacob, M., Jouenne, S., & Cordelier, P., 2014;Wu et al, 2013;Wylde, Slayer & Barbu, 2013;Yang, Zhihua, Xianglong & Shanzhe, 2015;Zheng, F., Quiroga, P., & Sams, G. W., 2011).…”

Section: Water Emulsions In the Presence Of Polymersmentioning

confidence: 99%

Historical and recent observations in polymer floods: An update review

Manrique¹,

Ahmadi²,

Samani³

2017

CT&F Cienc. Tecnol. Futuro

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Polymer flooding has been the most widely used chemical enhanced oil recovery (EOR) method. The experience gained over the past decades from laboratory studies to project design and field implementation has been well documented in the literature. The main objectives of this paper are to evaluate recent observations of polymer floods that report injection rates leading to pressure values above the formation fracture pressure (FFP), high polymer production, formation of tight emulsions and/or productivity losses.Based on this review, it can be concluded that no direct evidence exists to support that injecting polymer above the FFP will lead to more polymer production. However, uncertainties associated with the estimation of fracture propagation/dimensions using pressure Fall-Off Tests (FOT) still remain. High polymer production, other than severe channeling, is generally reported in large scale/commercial projects. The impact of oil geochemistry/ composition and water salinity on oil-water-polymer emulsions is commonly overlooked in polymer flood studies. The formation of in-situ emulsions can also explain the injectivity and/or productivity reduction and well test interpretation (i.e. FOT) reported in polymer floods. It was also identified that the OPEX (Operational Expenditures) associated with oil-water separation in the presence of polymer and productivity losses (i.e. workovers, stimulation costs) are generally underestimated. Finally, this review is expected to contribute with the planning, design and implementation of future polymer flood pilots and field expansions. OBSERVACIONES HISTÓRICAS Y RECIENTES EN INYECCIÓN DEPOLÍMEROS: REVISIÓN ACTUALIZADA. OBSERVAÇÕES HISTÓRICAS E RECENTES DE INJEÇÃO DE POLÍMEROS:REVISÃO ACTUALIZADA. EDUARDO MANRIQUE et. al. 18 L a inyección de polímeros es el método químico de recobro mejorado con mayor número de implementaciones a escala de campo. La experiencia adquirida en las últimas décadas desde estudios de laboratorio hasta el diseño e implementación de campo ha sido bien documentada en la literatura. El objetivo principal de este trabajo es evaluar observaciones recientes de proyectos de inyección de polímero reportando tasas de inyección por encima de la presión de fractura de la formación, alta producción de polímero, formación de emulsiones viscosas y/o pérdidas de productividad.Basados en esta revisión, se puede concluir de que no existen evidencias directas de que la inyección de polímero a tasas que impliquen superar la presión de fractura induzcan a una mayor producción de polímeros. Sin embargo, existen incertidumbres relacionadas con la estimación de las dimensiones y propagación de fracturas utilizando pruebas de caídas de presión (FOT). La alta producción de polímero, por razones diferentes a canalizaciones severas, generalmente se reportan en proyectos a escala comercial. Por otra parte, el impacto de la composición y geoquímica del crudo y de la salinidad del agua en la formación de emulsiones agua:petróleo:polímero ha sido subestimado en estudios de in...

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“…HCPF produced liquid is characterized by high viscosity, and strong emulsification tendency and stability. The emulsification effect of the low water cut produced liquid is more obvious as the polymercontaining concentration rising up, leads to the phase inversion point, at which the emulsion transformed from water-in-oil (W/O) to oil-in-water (O/W) or water-in-oil-in-water (W/O/W) (Yang et al, 2015).…”

Section: Polymer Concentration Analysismentioning

confidence: 99%

The Key Parameter Effect Analysis Of Polymer Flooding On Oil Recovery Using Reservoir Simulation

Erfando

Rita

Ramadhan

2019

J. Geoscience Eng. Environ. Technol.

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As time goes by, there will be decreasing of production rates of a field along with decreasing pressure. This led to the necessity for further efforts to increase oil production. Therefore, pressure support is required to improve the recovery factor. Supportable pressure that can be used can be either water flooding and polymer flooding. This study aims to compare recovery factor to scenarios carried out, such as polymer flooding with different concentrations modeled in the same reservoir model to see the most favorable scenario. The method used in this research is reservoir simulation method with Computer Modeling Group (CMG) STARS simulator. The study was carried out by observing at the pressure, injection rate, and polymer concentration on increasing field recovery factor. This study used cartesian grid with the assumption of homogeneous reservoir, there are no faults or other geological condition in the reservoir, and driving mechanism is only solution gas drive. This reservoir, oil type is light oil with API gravity 40.3˚API and layer of conglomerate rock. The simulation result performed with various scenarios provides a good result. Where the conditions case base case field recovery factor of 6.7%, and after water flooding produced 25.5% of oil, whereas with tertiary recovery method is polymer flooding was carried out with four concentrations of 640 ppm, 1,500 ppm, 3,000 ppm, and 4,000 ppm obtained optimum values at 4,000 ppm polymer concentration with recovery factor 28.9%, SOR reduction final value 0,5255, polymer adsorption of 818,700 ppm, reservoir final pressure 1,707 psi, and an increase in water viscosity to 0.94 cP.

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Study on Emulsification Behavior and Optimized Separation Technology of High Concentration Polymer Flooding Produced Liquid in Daqing Oilfield

Cited by 13 publications

References 14 publications

De-Emulsification and Gravity Separation of Micro-Emulsion Produced with Enhanced Oil Recovery Chemicals Flooding

De-Emulsification and Gravity Separation of Micro-Emulsion Produced with Enhanced Oil Recovery Chemicals Flooding

Historical and recent observations in polymer floods: An update review

The Key Parameter Effect Analysis Of Polymer Flooding On Oil Recovery Using Reservoir Simulation

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