Oil-particle separation in a falling sphere configuration: Effect of viscosity ratio &amp; interfacial tension

Mehrabian, Sasan; Acosta, Edgar; Bussmann, Markus

doi:10.1016/j.ijmultiphaseflow.2017.09.004

Cited by 8 publications

(4 citation statements)

References 43 publications

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“…However, according to the previous investigations about the considerable influence of different types of oil on the interfacial tension parameter, Mehrabian s. et al (2017) proposed that different oils have different interfacial tension and subsequently, due to the similar relationship between capillary pressure and interfacial tension, higher interfacial tension has higher capillary pressure. In this study, the proposed model was done for one type of oil in the studied oilfield and to investigate the considerable influence of this parameter it should require to provide more experimental investigations which would be done for further works by the utilization of this results and compare them (Mehrabian et al 2018).…”

Section: Governing Equations For Ppgmentioning

confidence: 99%

“…PPG is considered as one kind of efficient polymeric gel to increase the rate of sweep efficiency regarding the overcoming the drawbacks of in-situ gels. To improve the sweep efficiency of the reservoir after polymer flooding, the following steps are done sequentially [24][25][26][27]. First of all, PPG slug is injected into the high permeable zones.…”

Section: Introductionmentioning

confidence: 99%

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RETRACTED: Hybrid Chemical Enhanced Oil Recovery Techniques: A Simulation Study

Zhou

Davarpanah

2020

Symmetry

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Simultaneous utilization of surfactant and preformed particle gel (henceforth; PPG) flooding on the oil recovery enhancement has been widely investigated as a preferable enhanced oil recovery technique after the polymer flooding. In this paper, a numerical model is developed to simulate the profound impact of hybrid chemical enhanced oil recovery methods (PPG/polymer/surfactant) in sandstone reservoirs. Moreover, the gel particle conformance control is considered in the developed model after polymer flooding performances on the oil recovery enhancement. To validate the developed model, two sets of experimental field data from Daqing oil field (PPG conformance control after polymer flooding) and Shengli oil field (PPG-surfactant flooding after polymer flooding) are used to check the reliability of the model. Combination of preformed gel particles, polymers and surfactants due to the deformation, swelling, and physicochemical properties of gel particles can mobilize the trapped oil through the porous media to enhance oil recovery factor by blocking the high permeable channels. As a result, PPG conformance control plays an essential role in oil recovery enhancement. Furthermore, experimental data of PPG/polymer/surfactant flooding in the Shengli field and its comparison with the proposed model indicated that the model and experimental field data are in a good agreement. Consequently, the coupled model of surfactant and PPG flooding after polymer flooding performances has led to more recovery factor rather than the basic chemical recovery techniques.

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Section: Governing Equations For Ppgmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

RETRACTED: Hybrid Chemical Enhanced Oil Recovery Techniques: A Simulation Study

Zhou

Davarpanah

2020

Symmetry

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“…In this case, using the argument that particles stabilize submicron emulsions is not feasible because even clay particles, the finest among froth solids, tend to be larger than the 0.3 μm submicron drops identified in this work. However, the argument that particles could be involved in the formation of those drops is possible, as particles coated with a dispersed liquid can form thin jets as they move through a continuous liquid 52 simulating tip streaming behavior. 26 The largest correlation among all variables was between the final residual water content and the emulsion interfacial area per volume, as shown in Figure 11c.…”

Section: ■ Results and Discussionmentioning

confidence: 99%

Dewatering of Naphthenic Bitumen Froth

et al. 2020

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Bitumen froth is a water-in-bitumen emulsion (∼30 wt % water, 60 wt % bitumen, and 10 wt % of solids) stream obtained during the water-based extraction process of mined oil sands. The separation of water (to 2 wt % or less) and solids (to 0.5 wt % or less) from the froth is necessary to prevent corrosion, catalyst deactivation, and fouling in downstream processes. In naphthenic froth treatment (NFT), aromatic naphtha is added to reduce the density and viscosity of bitumen to aid in this separation, which often requires the addition of demulsifiers and centrifugation. This work looks at simulating the dewatering of froth using a bench-scale mixer and heptol 80/20 (80 vol % heptane; 20 vol % toluene) as a simulated naphtha solvent. Power dissipation during mixing, water contents, image analysis of micrographs, and acoustic spectroscopy were used to examine the dewatering process as a function of time for three froth samples with different compositions. Gravity drainage, in the absence of additives, led to a residual water content, after 2 h, ranging from 1.7 to 3.7 wt % for the three different samples, consistent with the typical residual water reported for these systems. Micrographs of the diluted froth show the eventual disappearance of large water drops and the prevalence of smaller emulsified drops (<10 μm) in the residual water. An examination of this residual water using acoustic spectroscopy showed that up to 0.8 wt % water is in the form of ∼0.3 μm submicron drops that cannot be removed by gravity or centrifugation. A dewatering model using an initial drop size distribution (DSD) of water drops also supports the existence of a substantial amount of submicron drops. A low-shear dewatering test suggests that most of this submicron water was in the froth before simulated froth treatment, formed potentially during bitumen extraction and transportation, prior to solvent dilution and dewatering. Cryo-SEM imaging further supports this hypothesis. Studies of water solubilization in toluene–asphaltene and toluene–naphthenic acid systems suggest that up to 0.5 wt % of this submicron water could be originated from water–asphaltene association. The presence of high solid contents in the froth correlated with high residual water and submicron water contents, pointing to the potential role of solids in the formation of submicron drops.

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“…In such a case, mixing within the droplet is important, for example, to accurately determine the reaction rate. Liquid–liquid contacting is required to transfer a solute from one phase to another for the reaction or extraction process. − The knowledge of droplet dynamics in liquid–liquid contactors is essential to increase the transfer efficiency. Understanding droplet behavior in a confined environment is crucial for the design of various micromixing devices.…”

Section: Introductionmentioning

confidence: 99%

Velocity Field within Droplets Falling in Liquid Media inside a Rectangular Channel

Mishra,

Gupta,

Singh

2024

Ind. Eng. Chem. Res.

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The concept of droplet microfluidics and droplet reactors is becoming popular in the chemical processing industry, especially to handle expensive specialty chemicals. The convective mixing within a single droplet or two coalescing droplets plays an important role during the reaction involving two-phase systems, which requires a good understanding of the internal fluid motion within the droplet. In this work, we study the flow field inside a liquid droplet falling through an immiscible liquid in a narrow-width rectangular vertical channel using particle image velocimetry (PIV). The droplet can be considered a representation of a midplane cutting through a spherical droplet. The effect of the size and release position of the droplet on the velocity field is examined. When the droplet is released at the center of the channel, a pair of symmetric counter-rotating vortices is observed inside the droplet. The vortices are positioned in the bottom half of the droplet and move toward its horizontal centerline as the diameter increases. However, when the droplet is released at an off-center position, the vortices are not symmetric. The terminal velocity of the droplet is observed to increase with an increase in droplet diameter, and therefore, coalescence occurs when a bigger droplet is released following a smaller one. The growth of the neck of the combined droplet with time and the velocity field at the neck are studied during coalescence.

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Oil-particle separation in a falling sphere configuration: Effect of viscosity ratio & interfacial tension

Cited by 8 publications

References 43 publications

RETRACTED: Hybrid Chemical Enhanced Oil Recovery Techniques: A Simulation Study

RETRACTED: Hybrid Chemical Enhanced Oil Recovery Techniques: A Simulation Study

Dewatering of Naphthenic Bitumen Froth

Velocity Field within Droplets Falling in Liquid Media inside a Rectangular Channel

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