Enhancing Oil Recovery with Nanoemulsion Flooding

Braccalenti, E.; Gaudio, L. Del; Albonico, Paola; Belloni, A.; Bartošek, Martin

doi:10.3997/2214-4609.201412160

Cited by 4 publications

(7 citation statements)

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“…The properties of the in situ emulsions are quite uncertain as the stability, droplet size, IFT reduction efficiency, and miscibility with the trapped crude oil are highly dependent on the appropriate composition of formation fluids and salinity. Thus, to avoid these uncertainties and to replace surfactant slug with nanoemulsion slug, optimization of nanoemulsion properties is highly desirable prior to injection for enhanced oil recovery. , It helps in understanding the behavior and feasibility of emulsion in the reservoir. Nanoemulsion sample with 2 wt % surfactant Tween 40 was used to test the crude oil miscibility in emulsion.…”

Section: Resultsmentioning

confidence: 99%

“…The flow rate of brine through the sand pack system determines the absolute permeability ( k ) using Darcy’s equation (eq ): where A is the total cross-sectional area of the sand pack (cm 2 ), q is the volumetric flow rate (cm 3 /s), μ is the fluid viscosity (cP), is the pressure gradient (atm/cm), and k is the permeability in darcy. A flow rate of 1–2 mL/min was maintained during the injection of displacing fluid in the flooding experiment through the sand pack for the proper sweeping of displaced fluid, which is approximately equal to the water injection rate of 0.08–0.10 pore volume/year in an oil field . Depending on the saturation of oil and water in the sand pack system and the density and viscosity of the displacing fluid and also the interaction of the displacing and displaced fluid, the injection pressure was kept at 30 psig during brine saturation to calculate the absolute permeability, at 262 psig during injection of viscous crude oil, and at 35 psig for injection of chemical slug and chase water.…”

Section: Methodsmentioning

confidence: 99%

“…A flow rate of 1−2 mL/min was maintained during the injection of displacing fluid in the flooding experiment through the sand pack for the proper sweeping of displaced fluid, which is approximately equal to the water injection rate of 0.08−0.10 pore volume/year in an oil field. 57 Depending on the saturation of oil and water in the sand pack system and the density and viscosity of the displacing fluid and also the interaction of the displacing and displaced fluid, the injection pressure was kept at 30 psig during brine saturation to calculate the absolute permeability, at 262 psig during injection of viscous crude oil, and at 35 psig for injection of chemical slug and chase water. After brine saturation, the sand pack was flooded with crude oil up to irreducible water saturation and S wi , the initial water saturation, was calculated by mass balance.…”

Section: Miscibility Test Of Nanoemulsionmentioning

confidence: 99%

See 2 more Smart Citations

Surfactant Stabilized Oil-in-Water Nanoemulsion: Stability, Interfacial Tension, and Rheology Study for Enhanced Oil Recovery Application

2018

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Nanoemulsions are kinetically stable biphasic dispersion of two immiscible liquids typically stabilized by an emulsifier with droplet sizes in the range of 10–200 nm. Present work deals with the formulation and characterization of stable oil-in-water nanoemulsions using nonionic surfactant (Tween 40) and light mineral oil for their application in enhanced oil recovery. The stability study of the nanoemulsions formed by high energy and low energy method was accomplished by bottle testing method. The emulsions were characterized in terms of droplet size, morphology and inner structure, surface charge, interfacial tension, and rheology. Droplet sizes of 18–31 nm obtained by dynamic light scattering analysis and surface charge values above −35 mV obtained by ζ potential measurement prove the higher kinetic stability of the formed emulsions. Cryo-TEM micrographs reveal the surface morphology and inner structure of nanoemulsions. A miscibility test was performed to determine the dissolving ability of the nanoemulsions with crude oil. Measurement of interfacial tension (IFT) by pendant drop method shows a considerable reduction in IFT values with the increase of surfactant concentration and temperature, which is highly desirable for recovering trapped oil from the fine pores of the reservoirs. The viscosity of the nanoemulsions remains stable at a wide temperature (30–70 °C) range, denoting its thermal stability. The viscoelastic property of prepared nanoemulsions shows the increase of storage modulus (G′) and loss modulus (G″) with the increase in surfactant concentration and angular frequency (rad/s). Specific frequency (SF), the crossover point of G′ and G″, indicates the transition between elastic and viscous phases of nanoemulsions. A stable value of loss modulus after SF denotes better flowability of the emulsion. To test the efficiency of nanoemulsion in enhanced oil recovery, flooding experiment was performed by injection of a small pore volume of emulsion slug in a sand pack system, and an additional recovery of 28.94% was obtained after conventional water flooding.

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Section: Resultsmentioning

confidence: 99%

Section: Methodsmentioning

confidence: 99%

Section: Miscibility Test Of Nanoemulsionmentioning

confidence: 99%

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Surfactant Stabilized Oil-in-Water Nanoemulsion: Stability, Interfacial Tension, and Rheology Study for Enhanced Oil Recovery Application

2018

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“…На сегодняшний день исследовательские группы по всему миру ве-дут лабораторные тестирования технологических жидкостей с содер-жанием наночастиц различных минералов [9][10][11][12][13][14][15][16][17][18][19][20][21][22][23] для их применения в МУН и ИДН. Разработанные технологические жидкости с новыми фи-зико-химическими свойствами должны отвечать следующим основным требованиям: экологичность, селективность и экономическая эффек-тивность.…”

Section: The Results Of the Specialists' And Scientists' Researchesunclassified

Experimental research of stability of emulsion systems with SiO2 nanoparticles

Zeigman¹,

Belenkova²,

Sergeev³

2017

Nanotehnol. stroit.

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ExtEndEd AbstrAct:Since the beginning of the 21 st century scientific research devoted to properties of nanosized particles and their industrial application in the industry of oil and gas fields development has been rapidly evolving. The use of nanosized particles can significantly rise efficiency of technological solutions, and that fact determines this research area as the most promising today.in the area of oil and gas fields development one of the general application for nanoparticles is the development of high-performance technological fluids with new or improved physico-chemical properties. The ability of nanoparticles to modify wettability of the rock surface and to be fixed on the adsorption-solvation stratums of globules makes them a unique tool to regulate physicochemical properties of technological fluids and physical properties of rocks.The THE RESULTS OF THE SPECIALISTS' AND SCIENTISTS' RESEARCHES MAchinE-rEAdAblE inforMAtion on cc-licEnsEs (htMl-codE) in MEtAdAtA of thE pApErReferences:

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“…In many such deposits, primary or both primary and second enhanced oil recovery (EOR) methods have been used. Large deposits are especially interesting, from the point of view of the application of EOR methods [1][2][3]. Various classifications of enhanced oil recovery methods and conditions for their use have been provided in the literature, defined for very heavy, heavy, and other hydrocarbons [2,[4][5][6].…”

Section: Introductionmentioning

confidence: 99%

Laboratory Testing of Novel Polyfraction Nanoemulsion for EOR Processes in Carbonate Formations

et al. 2020

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Nanoemulsions and polymers are widely used for increasing the efficiency of enhanced oil recovery (EOR) processes. The application of both these additives enables the synergistic use of several physical phenomena that are crucial to the process. One of the methods used for assessing these processes is laboratory core flooding tests using natural cores. In various experiments, carbonate rocks are subjected to oil displacement under high pressure and temperature. Polymer solutions and a newly developed polyfraction nanoemulsion are tested. The test results confirm the usefulness of these products for EOR processes and demonstrate their stability under high pressure, high temperature, and in the presence of H2S. Under these conditions the polymers maintain high efficiency in displacing crude oil from carbonate rocks, while the tested nanoemulsion improves the wettability of carbonate rocks and reduces interfacial tension, factors which increase the efficiency of oil displacement.The best result in the laboratory EOR simulation was obtained for polymer and nanoemulsion concentrations in dilute reservoir water of 0.05% and 1%, respectively. In this case, the measured oil recovery was 37.5% higher than that obtained when using water without additives.

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Enhancing Oil Recovery with Nanoemulsion Flooding

Cited by 4 publications

References 0 publications

Surfactant Stabilized Oil-in-Water Nanoemulsion: Stability, Interfacial Tension, and Rheology Study for Enhanced Oil Recovery Application

Surfactant Stabilized Oil-in-Water Nanoemulsion: Stability, Interfacial Tension, and Rheology Study for Enhanced Oil Recovery Application

Experimental research of stability of emulsion systems with SiO2 nanoparticles

Laboratory Testing of Novel Polyfraction Nanoemulsion for EOR Processes in Carbonate Formations

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