Impact of Natural Surfactant (Reetha), Polymer (Xanthan Gum), and Silica Nanoparticles To Enhance Heavy Crude Oil Recovery

Saha, Rahul; Uppaluri, R.; Tiwari, Pankaj

doi:10.1021/acs.energyfuels.9b00790

Cited by 79 publications

(54 citation statements)

References 69 publications

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“…In addition, NPs play a key role in changing oil displacement mechanisms and wettability alteration. The results of flooding with NPs indicated that higher concentrations of NPs increase the recovery of oil more than normal polymer flooding (Figure 5a-d) [47,48]. However, high concentrations of NPs have a low effect on the viscosity and IFT, as well having a negative effect on reservoir permeability due to the blocking of porous media (Figure 5c,d).…”

Section: Effects Of Nanoparticles On Oil Recoverymentioning

confidence: 97%

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Nanotechnology in Enhanced Oil Recovery

2020

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Nanoparticles (NPs) are known as important nanomaterials for a broad range of commercial and research applications owing to their physical characteristics and properties. Currently, the demand for NPs for use in enhanced oil recovery (EOR) is very high. The use of NPs can drastically benefit EOR by changing the wettability of the rock, improving the mobility of the oil drop and decreasing the interfacial tension (IFT) between oil/water. This paper focuses on a review of the application of NPs in the flooding process, the effect of NPs on wettability and the IFT. The study also presents a review of several investigations about the most common NPs, their physical and mechanical properties and benefits in EOR.

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Section: Effects Of Nanoparticles On Oil Recoverymentioning

confidence: 97%

“…Figure 5. SEM images of sand samples with (a) 0.45 wt.% and (b) 0.90 wt.% clay NPs after polymer (c) Core sample before surfactant-polymer NP flooding, (d) deposition of NPs on the core sample after surfactant-polymer NP flooding[48]; (e,f) SEM images of core plug after flooding with NPs[36].…”

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confidence: 99%

Nanotechnology in Enhanced Oil Recovery

2020

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“…Moreover, S or and K rw alteration at the endpoint corresponds to the wettability alteration from intermediate wet to strongly water wet. This issue was investigated in previous literature to confirm these results [68,84,85].…”

Section: Relative Permeability Curvesmentioning

confidence: 63%

Hybrid Application of Nanoparticles and Polymer in Enhanced Oil Recovery Processes

Zhao

Dong

et al. 2021

Polymers

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Nowadays, the addition of nanoparticles to polymer solutions would be of interest; however, the feasible property of nanoparticles and their impact on oil recovery has not been investigated in more detail. This study investigates the rheology and capillary forces (interfacial tension and contact angle) of nanoparticles in the polymer performances during oil recovery processes. Thereby, a sequential injection of water, polymer, and nanoparticles; Nanosilica (SiO2) and nano-aluminium oxide (Al2O3) was performed to measure the oil recovery factor. Retention decrease, capillary forces reduction, and polymer viscoelastic behavior increase have caused improved oil recovery due to the feasible mobility ratio of polymer–nanoparticle in fluid loss. The oil recovery factor for polymer flooding, polymer–Al2O3, and polymer–SiO2 is 58%, 63%, and 67%, respectively. Thereby, polymer–SiO2 flooding would provide better oil recovery than other scenarios that reduce the capillary force due to the structural disjoining pressure. According to the relative permeability curves, residual oil saturation (Sor) and water relative permeability (Krw) are 29% and 0.3%, respectively, for polymer solution; however, for the polymer–nanoparticle solution, Sor and Krw are 12% and 0.005%, respectively. Polymer treatment caused a dramatic decrease, rather than the water treatment effect on the contact angle. The minimum contact angle for water and polymer treatment are about 21 and 29, respectively. The contact angle decrease for polymer treatment in the presence of nanoparticles related to the surface hydrophilicity increase. Therefore, after 2000 mg L−1 of SiO2 concentration, there are no significant changes in contact angle.

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“…All the constraints applied for the previous scenarios are kept constant for both polymer and PAG flooding. The polymer used is polyethylene glycols, PEG concentration used was 2000 ppm similar constant values were used in pilot test [21,22]. The selection of the polymer concentration was based on the acceptable range of polymer flood reported for similar range of porosity and permeability, which is between 500 and 3000 ppm [23].…”

Section: Polymer Floodingmentioning

confidence: 99%

Comparative numerical study for polymer alternating gas (PAG) flooding in high permeability condition

et al. 2020

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Polymers have been used in water alternative gas, to viscosify the water and improve the overall sweep efficiency. The use of polymer alternative gas was successful in increasing the oil production in high permeability zones. However, few practical factors affecting the field applicability have been overlooked. Therefore, this study is aimed at bridging the gap between the possibility of using several EOR such as water flooding, CO 2 flooding, water alternative gas, polymer flooding and polymer alternative gas. The research based on progressive comparison considering constant constraint. The numerical simulation STARS-CMG was used to predict the characteristics and behaviour of the fluid in the reservoir. The designed flooding pattern chosen was a single producer-single injection (P-I) scheme in homogeneous high permeable reservoir. The results of oil incremental recovery showed the following order compared to Water flooding < (3%) CO 2 flooding < (6.8%) < Water alternative gas (11.6%) Polymer flooding < (15%) Polymer alternative gas. The impact of polymer on enhancing the water alternative gas was mostly noticeable in the reduction of water cut% (83%). The controlled conformance by polymer aided in improving the sweep efficiency as indicated by the uninform U-shape. Moreover, the delayed gas breakthrough was significant and resulted in the lowest gas oil ratio of 5.17E + 04 ft3/bbl. The low gas oil ratio observation is indication of potential capturing of CO 2 in the reservoir and thus, good evidence to further implementation of CO 2 as green utilization.

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Impact of Natural Surfactant (Reetha), Polymer (Xanthan Gum), and Silica Nanoparticles To Enhance Heavy Crude Oil Recovery

Cited by 79 publications

References 69 publications

Nanotechnology in Enhanced Oil Recovery

Nanotechnology in Enhanced Oil Recovery

Hybrid Application of Nanoparticles and Polymer in Enhanced Oil Recovery Processes

Comparative numerical study for polymer alternating gas (PAG) flooding in high permeability condition

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