Impact of nanoparticles stability on rheology, interfacial tension, and wettability in chemical enhanced oil recovery: A critical parametric review

Lashari, Najeebullah; Ganat, Tarek Al-Arbi Omar; Elraies, Khaled Abdalla; Ayoub, Mohammed Abdalla; Kalam, Shams; Chandio, Tariq Ali; Qureshi, Saima; Sharma, Tushar

doi:10.1016/j.petrol.2022.110199

Cited by 45 publications

(29 citation statements)

References 148 publications

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“…Several important properties of nanoparticles such as higher surface-to-volume ratio, higher suspension stability, higher adsorption ability, and hydrophilic–hydrophobic interaction at the oil–water interface have contributed to IFT reduction at higher nanoparticle concentrations. − …”

Section: Influencing Factors In Polymeric Nanofluids Floodingmentioning

confidence: 99%

“…Several review articles on the applications of nanoparticles in EOR are available. − Some works only focus on the utilization of water-based nanofluids in additional oil recovery while other works emphasize the surfactant-based nanofluids in oil recovery. − Some review works only discuss the nanoparticle-assisted surfactant and polymer flooding for EOR applications. − However, although different review articles are available, only limited literature can be found on the applications of polymeric nanofluids in EOR and the governing factors associated with oil recovery. Therefore, it is essential to have an updated review on the applications of polymeric nanofluids in EOR that will provide a current scenario of research and development in the field.…”

Section: Introductionmentioning

confidence: 99%

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A Perspective Review on the Current Status and Development of Polymer Flooding in Enhanced Oil Recovery Using Polymeric Nanofluids

Ambaliya

Bera

2023

Ind. Eng. Chem. Res.

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The globally increasing demand for crude oil has prompted the oil industry to enhance oil production from primary, secondary, and tertiary recovery methods to fulfill the global requirement. Therefore, enhanced oil recovery (EOR) is expected to increase its importance in the coming years. Because of limited efficiency, applicability, and higher gas and thermal injection costs, chemical EOR processes have been considered as an alternative in some special cases. Chemical EOR processes are accepted widely because of their higher efficiency, economic and technical feasibility, and optimum capital cost. Therefore, research of novel chemical compounds is immense in the oil industry. Research of nanotechnology in the petroleum industry has attracted attention among all novel chemical compounds in the past few years. This work focuses on the review of previous research regarding the current scenario of polymer flooding, challenges of polymer flooding, polymeric nanofluid in EOR, recent developments in polymer flooding, characteristics of polymeric nanofluids, prospects, and economic feasibility for polymeric nanofluids’ applications in EOR. This paper also reviews the characterization of polymeric nanofluids such as rheology, stability, wettability alteration, interfacial tension reduction, and absorption control. It has been found from a literature review that polymeric nanofluids are more effective in oil recovery considering viscosity modification, stability enhancement, and chemical adsorption control. Oil recovery can be additionally increased by up to 10–15% original-oil-in-place applying polymeric nanofluids.

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Section: Influencing Factors In Polymeric Nanofluids Floodingmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

A Perspective Review on the Current Status and Development of Polymer Flooding in Enhanced Oil Recovery Using Polymeric Nanofluids

Ambaliya

Bera

2023

Ind. Eng. Chem. Res.

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“…In recent years, nanoparticles (NPs) have been extensively employed in different EOR methods, such as CEOR, to investigate their potential for enhancing oil recovery. , In this regard, Rezaei et al observed that the IFT of SDS solution–oil was decreased by 77% (from 32.5 to 7.5 mN/m) in the presence of 0.05 wt % ZnO NPs. Similarly, Mohajeri et al pointed out that 100 ppm of ZrO 2 NPs can reduce a cationic surfactant–oil IFT from 18.4 to 5.4 mN/m.…”

Section: Introductionmentioning

confidence: 99%

SDS–Aluminum Oxide Nanofluid for Enhanced Oil Recovery: IFT, Adsorption, and Oil Displacement Efficiency

et al. 2022

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Surfactant flooding is one of the most promising chemical enhanced oil recovery (CEOR) methods to produce residual oil in reservoirs. Recently, nanoparticles (NPs) have attracted extensive attention because of their significant characteristics and capabilities to improve oil recovery. The aim of this study is to scrutinize the synergistic effect of sodium dodecyl sulfate (SDS) as an anionic surfactant and aluminum oxide (Al 2 O 3 ) on the efficiency of surfactant flooding. Extensive series of interfacial tension and surfactant adsorption measurements were conducted at different concentrations of SDS and Al 2 O 3 NPs. Furthermore, different surfactant adsorption isotherm models were fitted to the experimental data, and constants for each model were calculated. Additionally, oil displacement tests were performed at 25 °C and atmospheric pressure to indicate the suitability of SDS–Al 2 O 3 for CEOR. Analysis of this study shows that the interfacial tension (IFT) reduction between aqueous phase and crude oil is enhanced considerably by 76%, and the adsorption density of SDS onto sandstone rock is decreased remarkably from 1.76 to 0.49 mg/g in the presence of these NPs. Although the effectiveness of NPs gradually increases with the increase of their concentration, there is an optimal value of Al 2 O 3 NP concentration. Moreover, oil recovery was increased from 48.96 to 64.14% by adding 0.3 wt % NPs to the surfactant solution, which demonstrates the competency of SDS–Al 2 O 3 nanofluids for CEOR.

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“… 23 The current use of clay stabilizers includes surfactants like quaternary ammonium-based dicationic surfactants 24 and polyoxyethylene quaternary ammonium surfactants; 25 plant extracts like okra mucus extracted from okra plants; 26 , 27 polymers; 28 and nanoparticles. 29 , 30 …”

Section: Introductionmentioning

confidence: 99%

“…In the oil field industry, potassium chloride (KCl) is the most commonly used clay stabilizer to prevent wellbore instability caused by swelling in sandstone upon its hydration . The current use of clay stabilizers includes surfactants like quaternary ammonium-based dicationic surfactants and polyoxyethylene quaternary ammonium surfactants; plant extracts like okra mucus extracted from okra plants; , polymers; and nanoparticles. , …”

Section: Introductionmentioning

confidence: 99%

Study on the Effect of Fracturing Fluid on the Structure and Mechanical Properties of Igneous Rock

et al. 2022

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Igneous rock oil and gas reservoirs have great development potential. Hydraulic fracturing is an important means for the development of these reservoirs. In the process of fracturing and increasing production, fracturing fluid is prone to a hydration reaction with clay minerals in igneous rock, and then, the structure and mechanical properties of the igneous rock are changed, affecting increased production. Therefore, it is necessary to establish a systematic water–rock reaction experiment method to understand the influence of fracturing fluid on the structure and mechanical properties of igneous rocks and to optimize the fracturing fluid system of igneous rock reservoirs. In this experiment, four solutions were used: slickwater, guar fracturing fluid, 2% KCl aqueous solution, and 4% KCl aqueous solution. Acoustic testing, porosity and permeability testing, XRD analysis, micro-CT scanning, and displacement experiments were performed. The influence of different fracturing fluids on the structure and mechanical properties of igneous rocks was studied. Igneous rock samples with a permeability of 0.05–0.1 mD and average porosity of 7–14% were used. The results show that all four liquid systems will reduce the permeability, Young’s modulus, and brittleness index and increase the porosity and Poisson’s ratio of the rock after fracturing. Among them, the permeability damage rate is as high as 37.37%, which may be related to the plugging of pores with solid residues in the gel breaking liquid; CT results show that there are microcracks in the rock, which increase over time, up to 13.54%. The brittleness index decreases. Among the fluids, the influence of slickwater on the rock brittleness index is the smallest, no more than 5%. Guar gum had the greatest effect on the Gel breaking liquid, up to 58%. One of the reasons for the increase in porosity is that adding a clay stabilizer composed of inorganic salts and organic cationic polymers to the slickwater fracturing fluid can effectively reduce the damage caused by the fracturing fluid to the rock during the fracturing process and can reduce the maximum by 50%. This paper can clarify the damage law of fracturing fluid systems to igneous rock reservoirs and provide the theoretical basis for the hydraulic fracturing of igneous rock reservoirs.

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Impact of nanoparticles stability on rheology, interfacial tension, and wettability in chemical enhanced oil recovery: A critical parametric review

Cited by 45 publications

References 148 publications

A Perspective Review on the Current Status and Development of Polymer Flooding in Enhanced Oil Recovery Using Polymeric Nanofluids

A Perspective Review on the Current Status and Development of Polymer Flooding in Enhanced Oil Recovery Using Polymeric Nanofluids

SDS–Aluminum Oxide Nanofluid for Enhanced Oil Recovery: IFT, Adsorption, and Oil Displacement Efficiency

Study on the Effect of Fracturing Fluid on the Structure and Mechanical Properties of Igneous Rock

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