Synergetic effect between in-situ mobility control and micro-displacement for chemical enhanced oil recovery (CEOR) of a surface-active nanofluid

Liu, Rui; Lu, Jiayue; Pu, Wanfen; Xie, Quan; Lu, Yuanyuan; Du, Daijun; Yang, Xuerui

doi:10.1016/j.petrol.2021.108983

Cited by 30 publications

(12 citation statements)

References 50 publications

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“…Meanwhile, the nanoparticles spread along the rock surface, resulting in changes in the wettability of the rock surface. , In addition, the in situ surfactant molecules (surfactant 2) produced in the reaction of Na 2 CO 3 and acid in the oil, combined with the SDS molecules (surfactant 1) in the ASP system, has a synergistic effect with the SiO 2 NPs in altering the wettability of a rock surface . Furthermore, an interaction between the hydrophobic head of a surfactant monomer and the oil phase leads to the separation of the upper molecules, which facilitates the access of the NPs to the rock surface. , Eventually, the oil droplets fall off the rock surface automatically, which contributed to the efficiency of displacement.…”

Section: Resultsmentioning

confidence: 99%

“…63 Furthermore, an interaction between the hydrophobic head of a surfactant monomer and the oil phase leads to the separation of the upper molecules, which facilitates the access of the NPs to the rock surface. 64,65 Eventually, the oil droplets fall off the rock surface automatically, which contributed to the efficiency of displacement.…”

Section: Eor Mechanisms Of Asp + Siomentioning

confidence: 99%

“…The application of chemical agents in the field has been considered to be the most efficient tertiary recovery practice for heavy oil reservoirs. − Surfactant flooding has been applied extensively for enhanced oil recovery in a lot of conventional reservoirs around the world. − Studies showed that combinations of surfactants and other chemicals have great potential for enhanced oil recovery. Singh and Guo et al observed that a polymer–surfactant flooding contributed to improve oil washing efficiency and expand the swept volume. , Wang et al and Kumar et al observed that the surfactant–SiO 2 nanoparticles (NPs) contributed to enhancing the plugging ability of emulsion in porous media, resulting in increased recovery of oil. , Sharma et al and Chaturvedi et al observed that oil/water (O/W) emulsions stabilized by a surfactant–polymer-nanoparticles (SP-NPs) solution contributed to extending a swept volume, compared to emulsions stabilized by a surfactant–polymer (SP) only solution. , Meanwhile, alkaline was added to an SP/SP-NPs solution to create alkaline–surfactant–polymer/alkaline–surfactant–polymer-NPs (ASP/ASP-NPs) compound systems that had a very good effect on reducing interfacial tension (IFT) and wettability. − …”

Section: Introductionmentioning

confidence: 99%

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Synergistic Effects of Weak Alkaline–Surfactant–Polymer and SiO₂ Nanoparticles Flooding on Enhanced Heavy Oil Recovery

et al. 2022

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The alkaline–surfactant–polymer (ASP) enhanced oil recovery (EOR) is a promising tertiary oil recovery technique for maximizing oil production. However, strong alkaline (e.g., NaOH) or high concentration of an alkali may cause new problems, such as formation erosion, alkali deposition, and high production costs. In this study, a new EOR method was proposed by combining a traditional weak alkaline (Na2CO3) ASP flooding and nanotechnology. We investigated the synergistic effects of weak alkaline ASP chemicals and SiO2 nanoparticles on the EOR through comprehensive experiments. The efficacy of the mixtures was examined using a framework including interfacial tension and wettability characterizations, flow visualization experiments of emulsion, and oil recovery tests under reservoir temperature conditions. Moreover, the effects of weak alkaline ASP chemicals and SiO2 nanoparticles on interfacial properties and the EOR were carefully investigated by a comprehensive analysis. The experimental results show that the ASP + SiO2 nanoparticles mixture has a greater ability to reduce the interfacial tension (IFT) between oil and water as well as their contact angle, compared with a hydrolyzed polyacrylamide (HPAM)/ASP-only solution. The ASP + SiO2 nanoparticles mixture is better than the HPAM/ASP-only solution in profile control and displacement efficiency after water flooding. The SiO2 NPs/ASP mixture increases the oil recovery by 6.67% of original oil in place (OOIP), compared to the ASP-only solution. In visualization flooding experiments, the ASP + SiO2 nanoparticles mixture forms strong viscoelastic, thermodynamic, and kinetic stability of the droplets, thereby resulting in a larger sweep efficiency and better displacement efficiency by the stable blocking effects and strong scratch effect. It indicates that this new method can enhance oil recovery, have potential to reduce chemical agent cost, and avoid probable formation erosion and alkali deposition.

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Section: Resultsmentioning

confidence: 99%

Section: Eor Mechanisms Of Asp + Siomentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

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Synergistic Effects of Weak Alkaline–Surfactant–Polymer and SiO₂ Nanoparticles Flooding on Enhanced Heavy Oil Recovery

et al. 2022

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“…The principle of NMR monitoring of spontaneous imbibition processes is that the oil phase displays a T 2 spectral signal under magnetic field conditions. , In porous media, the amplitude of the NMR signal is proportional to the number of hydrogen atoms. Therefore, T 2 spectral profiles can characterize the oil saturation and distribution in the pores of different shale cores and can be used to explore oil-phase migration during spontaneous imbibition.…”

Section: Experimental Studiesmentioning

confidence: 99%

Interfacial Properties and Efficient Imbibition Mechanism of Anionic–Nonionic Surfactants in Shale Porous Media

Liu

Shi

et al. 2023

Energy Fuels

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Due to their unique properties, surfactants have been widely used as effective chemical additives for enhanced recovery in shale reservoirs. However, despite extensive research on the spontaneous imbibition of surfactant solutions in shale reservoirs, the underlying mechanisms of surfactants for improving the shale wettability, reducing the flow resistance, and expanding the relative permeability still need to be studied. This study reports the successful construction of an anionic/nonionic surfactant mixture named LMEA−DPS (LMEA = laurel monoethanolamide; DPS = N-decyl-N,N-dimethyl-3-ammonio-1-propane sulfonate) and interfacial properties between crude oil and LMEA−DPS, including interfacial tension (IFT) reduction, wettability alteration, and emulsification ability, were investigated. The imbibition efficiency of LMEA−DPS under different conditions was also explored, and the oil utilization and the oil distribution in the rock pores were evaluated by using the nuclear magnetic resonance (NMR) technique. Experimental results showed that LMEA− DPS exhibited superior IFT reduction, wettability modification ability, and an emulsification viscosity reduction effect compared to brine. The imbibition recovery of LMEA−DPS displayed a trend of increase and decrease with increased permeability with a more remarkable imbibition recovery for smaller crude oil viscosities. NMR analysis further revealed that macropores were the main pore spaces developed in the rock and contributed the most to the imbibition recovery efficiency. In addition, the imbibition of LMEA− DPS initially took place in macropores before moving into mesopores and micropores. This study also proposed efficient imbibition mechanisms of anionic−nonionic surfactants in shale reservoirs, including IFT reduction, altered wettability, and emulsion imbibition.

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“…The combination of amine-terminated silica nanoparticles with other surfactants was also tested. The nonionic surfactant laurel anolamide was selected by Liu et al [ 73 ] to form thermodynamically unstable but kinetically stable Pickering emulsions. Flooding tests in three-layered (of different permeabilities) heterogeneous rectangular cores were carried out.…”

Section: Reviewmentioning

confidence: 99%

Nanoparticles in Chemical EOR: A Review on Flooding Tests

2022

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The use of nanofluids is showing promise as an enhanced oil recovery (EOR) method. Several reviews have been published focusing on the main mechanisms involved in the process. This new study, unlike previous works, aims to collect information about the most promising nano-EOR methods according to their performance in core-flooding tests. As its main contribution, it presents useful information for researchers interested in experimental application of nano-EOR methods. Additional recoveries (after brine flooding) up to 15% of the original oil in place, or higher when combined with smart water or magnetic fields, have been found with formulations consisting of simple nanoparticles in water or brine. The functionalization of nanoparticles and their combination with surfactants and/or polymers take advantage of the synergy of different EOR methods and can lead to higher additional recoveries. The cost, difficulty of preparation, and stability of the formulations have to be considered in practical applications. Additional oil recoveries shown in the reviewed papers encourage the application of the method at larger scales, but experimental limitations could be offering misleading results. More rigorous and systematic works are required to draw reliable conclusions regarding the best type and size of nanoparticles according to the application (type of rock, permeability, formation brine, reservoir conditions, other chemicals in the formulation, etc.)

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Synergetic effect between in-situ mobility control and micro-displacement for chemical enhanced oil recovery (CEOR) of a surface-active nanofluid

Cited by 30 publications

References 50 publications

Synergistic Effects of Weak Alkaline–Surfactant–Polymer and SiO₂ Nanoparticles Flooding on Enhanced Heavy Oil Recovery

Synergistic Effects of Weak Alkaline–Surfactant–Polymer and SiO₂ Nanoparticles Flooding on Enhanced Heavy Oil Recovery

Interfacial Properties and Efficient Imbibition Mechanism of Anionic–Nonionic Surfactants in Shale Porous Media

Nanoparticles in Chemical EOR: A Review on Flooding Tests

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Synergetic effect between in-situ mobility control and micro-displacement for chemical enhanced oil recovery (CEOR) of a surface-active nanofluid

Cited by 30 publications

References 50 publications

Synergistic Effects of Weak Alkaline–Surfactant–Polymer and SiO2 Nanoparticles Flooding on Enhanced Heavy Oil Recovery

Synergistic Effects of Weak Alkaline–Surfactant–Polymer and SiO2 Nanoparticles Flooding on Enhanced Heavy Oil Recovery

Interfacial Properties and Efficient Imbibition Mechanism of Anionic–Nonionic Surfactants in Shale Porous Media

Nanoparticles in Chemical EOR: A Review on Flooding Tests

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Synergistic Effects of Weak Alkaline–Surfactant–Polymer and SiO₂ Nanoparticles Flooding on Enhanced Heavy Oil Recovery

Synergistic Effects of Weak Alkaline–Surfactant–Polymer and SiO₂ Nanoparticles Flooding on Enhanced Heavy Oil Recovery