Application of Lauryl Betaine in enhanced oil recovery: A comparative study in micromodel

Yarveicy, Hamidreza; Javaheri, Ali

doi:10.1016/j.petlm.2017.09.004

Cited by 44 publications

(6 citation statements)

References 21 publications

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“…Because of the very low pore volume (PV) of the micromodel, the tests were carried out in the absence of initial water in this study. Each two-phase flooding experiment was initiated by washing the micromodel with toluene and DI water consecutively . Separation of the fluids was done by adding a little bit of blue food coloring to DI water while preparing the GONs suspensions.…”

Section: Methodsmentioning

confidence: 99%

“…Each twophase flooding experiment was initiated by washing the micromodel with toluene and DI water consecutively. 29 Separation of the fluids was done by adding a little bit of blue food coloring to DI water while preparing the GONs suspensions. To see the micromodel wettability, it was first flooded with the crude oil until fully saturated.…”

Section: Acs Applied Nano Materialsmentioning

confidence: 99%

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Graphene Oxide Nanosheets for Oil Recovery

Khoramian

Ramazani

Hekmatzadeh

et al. 2019

ACS Appl. Nano Mater.

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In this study, graphene oxide nanosheets (GONs) are introduced as a prospective candidate for enhanced oil recovery, so they were first synthesized and then fully characterized. Next, various suspensions were prepared to monitor the impacts of GONs and NaCl on the viscosity, interfacial tension (IFT), emulsification, wettability, and stability. The viscosity of the suspensions witnessed a 34% increase when their concentration was increased to 800 ppm. Mixing NaCl and 400 ppm GONs showed that the NaCl amount had a major effect on the viscosity. The viscosity rose steadily to 3 cSt by increasing NaCl to 30000 ppm but fluctuated at 40000 and 60000 ppm. Moreover, even though increments in the GON concentration decreased the IFT between oil and water to 19.4 mN/m, the IFT increased slightly from 400 ppm onward. GONs lessened the IFT as much as roughly 2.5 units by adding each 0.02 wt % NaCl to 400 ppm GONs. Besides, GONs made smaller and smaller emulsions when their concentrations rose from 100 to 400 and 800 ppm. Interestingly, 400 ppm GONs with 2 and 4 wt % NaCl produced oil-in-water emulsions of less than 10 μm. From contact-angle (CA) tests, it was found that GONs were amphiphilic and could not noticeably alter the wettability alone unless 2 wt % NaCl was added, and, consequently, CA varied from 13° to 75°. Also, the stability of GONs in an aqueous phase was immensely impressed by 4 and 6 wt % NaCl after 14 days but stable at 2 wt % NaCl. Last, in the micromodel flooding tests, the ultimate recovery achieved by nanofluid was 28% higher compared with brine. Wettability alteration and mobility improvement were obviously witnessed by flooding nanofluid into an oil-wet micromodel. The viscous fingering phenomenon could be decreased by increasing the breakthrough time from 55 to 98 min.

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Section: Methodsmentioning

confidence: 99%

Section: Acs Applied Nano Materialsmentioning

confidence: 99%

Graphene Oxide Nanosheets for Oil Recovery

Khoramian

Ramazani

Hekmatzadeh

et al. 2019

ACS Appl. Nano Mater.

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“…The polar portion might be ionic or nonionic. The polar portion is referred to as the head, while the nonpolar portion, which is a hydrocarbon chain, is referred to as the surfactant chain. , …”

Section: Introductionmentioning

confidence: 99%

“…The polar portion is referred to as the head, while the nonpolar portion, which is a hydrocarbon chain, is referred to as the surfactant chain. 14,15 Many researchers found that demulsification was strongly associated with a change in the interfacial rheology from high to low viscoelasticity. 16−18 The demulsifier's role has been established as changing the interfacial rheological characteristics through reducing the interfacial viscoelasticity and film strength to destabilize the emulsions.…”

Section: Introductionmentioning

confidence: 99%

The Influence of Newly Synthesized Demulsifiers on the Interfacial Rheological Properties of a Naturally Occurring Water/Oil Emulsion

2022

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This research aimed to synthesize new polymeric nonionic demulsifiers (DA, DB, and DC) to break 50% of naturally occurring water/oil emulsions. The prepared demulsifiers were synthesized in only two stages utilizing simple techniques. 1 H and 13 CNMR, MS, and FTIR spectroscopies were performed to validate the chemical composition of the synthesized demulsifiers. The relative solubility number (RSN) and partition coefficient ( K p ) were determined for the three demulsifiers. The interfacial tension (IFT) and dehydration ratios of DA, DB, DC, and their triblock copolymers were investigated. Also, interfacial rheological properties for the three demulsifiers were measured. The findings demonstrate that DB possesses a higher RSN value than DA and DC owing to its hydrophilicity. DC exhibited the lowest IFT value compared to DA, DB, and their corresponding triblock copolymers. DB and DC are more effective in demulsifying than DA and triblock copolymers. DC achieved a 100% dehydration ratio at a low dosage of 75 ppm after 120 min. DC’s remarkable performance can be attributed to its aromatic core, molecular weight, and high interfacial activity. According to the rheological data, a higher dehydrating ratio is attained when the demulsifier has a great capacity to lower the viscoelasticity of the W/O emulsion interface. The maximum decrease in G ′ and G ″ values was attained by DC. The mechanism of DC’s demulsifying interaction on a naturally occurring W/O emulsion was elucidated.

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“…The core displacement efficiency increases with the increase in injection times. It is observed that when the water cut reaches 99.98%, the oil displacement efficiency can still be improved by increasing the injection times (Yushuang et al 1999;Yarveicy et al 2018;Yarveicy and Javaheri 2019).…”

Section: Introductionmentioning

confidence: 99%

Study on oil displacement efficiency of offshore sandstone reservoir with big bottom water

Tan

Liu

et al. 2021

J Petrol Explor Prod Technol

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X oilfield is a typical sandstone reservoir with big bottom water in the Bohai Sea. The viscosity of crude oil ranges from 30 to 425 cp. Single sand development with the horizontal well is adopted. At present, the water content is as high as 96%. The water cut of the production well is stable for a long time in the high water cut period. The recoverable reserves calculated by conventional methods have gradually increased, and even the partial recovery has exceeded the predicted recovery rate. This study carried out an oil displacement efficiency experiment under big water drive multiple to accurately understand an extensive bottom water reservoir's production law in an ultra-high water cut stage. It comprehensively used the scanning electron microscope date, casting thin section, oil displacement experiment, and production performance to analyze the change law of physical properties and relative permeability curve from the aspects of reservoir clay minerals, median particle size, pore distribution, and pore throat characteristics. Therefore, the development law of horizontal production wells in sandstone reservoirs with big bottom water is understood. It evaluates the ultimate recovery of sandstone reservoirs with big bottom water. It provides a fundamental theoretical basis and guidance for dynamic prediction and delicate potential tapping of sandstone reservoirs with big bottom water at a high water cut stage.

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Application of Lauryl Betaine in enhanced oil recovery: A comparative study in micromodel

Cited by 44 publications

References 21 publications

Graphene Oxide Nanosheets for Oil Recovery

Graphene Oxide Nanosheets for Oil Recovery

The Influence of Newly Synthesized Demulsifiers on the Interfacial Rheological Properties of a Naturally Occurring Water/Oil Emulsion

Study on oil displacement efficiency of offshore sandstone reservoir with big bottom water

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