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Shakeel M, Sagandykova D, Mukhtarov A, Dauyltayeva A, Maratbekkyzy L, Pourafshary P, Musharova D. Maximizing oil recovery: Innovative chemical EOR solutions for residual oil mobilization in Kazakhstan's waterflooded sandstone oilfield. Heliyon 2024; 10:e28915. [PMID: 38586411 PMCID: PMC10998114 DOI: 10.1016/j.heliyon.2024.e28915] [Citation(s) in RCA: 0] [Impact Index Per Article: 0] [Reference Citation Analysis] [Abstract] [Track Full Text] [Figures] [Journal Information] [Subscribe] [Scholar Register] [Received: 11/21/2023] [Revised: 03/26/2024] [Accepted: 03/26/2024] [Indexed: 04/09/2024] Open
Abstract
The results of an experimental study to design a chemical flood scheme for a massive Kazakhstani oilfield with high water cut are presented in this paper. A meticulously formulated chemical flooding procedure entails injecting a blend comprising interfacial tension (IFT) reducing agents, alkaline/nanoparticles to control chemical adsorption, and polymer to facilitate mobility control. Overall, this well-conceived approach leads to a significant enhancement in the mobilization and production of residual oil. Experiments were conducted in Kazakhstan's Field A, one of the country's oldest oilfields with over 90% water cut and substantial remaining oil, to assess the efficiency of various hydrolyzed polyacrylamide (HPAM) derived polymers and surfactant solutions. Additionally, the effectiveness of alkaline and nanoparticles in minimizing chemical adsorption for the screened surfactant and polymer was investigated. These assessments were conducted under reservoir conditions, with a temperature of 63 °C, and using 13,000 ppm Caspian seawater as makeup brine. The performance assessment of the selected chemicals was carried out through a set of oil displacement tests on reservoir cores. Critical parameters, including chemical adsorption, interfacial tension, resistance factor, and oil recovery factor, were compared to determine the most effective chemical flooding approach for Field A. Both the surfactant-polymer (SP) and alkali-surfactant-polymer (ASP) approaches were more successful in recovering residual oil by efficiently generating and delivering microemulsion, producing more than 90% of the remaining oil after waterflooding. Due to the low increase in recovery compared to SP and the complexity of applying ASP at the field scale, SP was recommended for the pilot test studies. This investigation underscores that the choice of chemicals is contingent upon the interplay between the specific characteristics of the oil, the geological formation, the injection water, and the reservoir rock. Consequently, assessing all potential configurations on reservoir cores is imperative to identify the most optimal chemical combination. The practical challenges at the field scale should also be considered for the final decision. The results of this study contribute to the successful design and implementation of tailored chemical flooding to challenging oilfields with excessive water cut and high residual oil.
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Affiliation(s)
- Mariam Shakeel
- School of Mining and Geosciences, Nazarbayev University, Astana, 010000, Kazakhstan
| | - Dilyara Sagandykova
- School of Mining and Geosciences, Nazarbayev University, Astana, 010000, Kazakhstan
| | - Aibek Mukhtarov
- School of Mining and Geosciences, Nazarbayev University, Astana, 010000, Kazakhstan
| | - Amina Dauyltayeva
- School of Mining and Geosciences, Nazarbayev University, Astana, 010000, Kazakhstan
| | - Laila Maratbekkyzy
- School of Mining and Geosciences, Nazarbayev University, Astana, 010000, Kazakhstan
| | - Peyman Pourafshary
- School of Mining and Geosciences, Nazarbayev University, Astana, 010000, Kazakhstan
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Hao H, Wu H, Diao H, Zhang Y, Yang S, Deng S, Li Q, Yan X, Peng M, Qu M, Li X, Xu J, Yang E. A study on the bio-based surfactant sodium cocoyl alaninate as a foaming agent for enhanced oil recovery in high-salt oil reservoirs. RSC Adv 2024; 14:4369-4381. [PMID: 38304559 PMCID: PMC10828935 DOI: 10.1039/d3ra07840j] [Citation(s) in RCA: 0] [Impact Index Per Article: 0] [Reference Citation Analysis] [Abstract] [Grants] [Track Full Text] [Download PDF] [Figures] [Journal Information] [Subscribe] [Scholar Register] [Received: 11/16/2023] [Accepted: 12/19/2023] [Indexed: 02/03/2024] Open
Abstract
Environmental awareness is receiving increasing attention in the petroleum industry, especially when associated with chemical agents applied in enhanced oil recovery (EOR) technology. The bio-based surfactant sodium cocoyl alaninate (SCA) is environmentally friendly and can be easily biodegraded, which makes it a promising alternative to traditional surfactants. Herein, the SCA surfactant is proposed as a foaming agent for enhanced oil recovery. Laboratory investigations on the surfactant concentration, foaming performance, microbubble characterization, interfacial tension, and foam-flooding of the traditional surfactants SDS and OP-10 have been conducted. In particular, the anti-salt abilities of these three surfactants have been studied, taking into consideration the reservoir conditions at Bohai Bay Basin, China. The results show that concentrations of 0.20 wt%, 0.20 wt% and 0.50 wt% for SCA, SDS and OP-10, respectively, can achieve optimum foaming ability and foaming stability under formation salinity conditions, and 0.20 wt% SCA achieved the best foaming ability and stability compared to 0.20 wt% SDS and 0.50 wt% OP-10. Sodium fatty acid groups and amino acid groups present in the SCA molecular structure have high surface activities under different salinity conditions, making SCA an excellent anti-salt surfactant for enhanced oil recovery. The microstructure analysis results showed that most of the SCA bubbles were smaller in size, with an average diameter of about 150 μm, and the distribution of SCA bubbles was more uniform, which can reduce the risk of foam coalescence and breakdown. The IFT value of the SCA/oil system was measured to be 0.157 mN m-1 at 101.5 °C, which was the lowest. A lower IFT can make liquid molecules more evenly distributed on the surface, and enhance the elasticity of the foam film. Core-flooding experimental results showed that a 0.30 PV SCA foam and secondary waterflooding can enhance oil recovery by more than 15% after primary waterflooding, which can reduce the mobility ratio from 3.7711 to 1.0211. The more viscous SCA foam caused a greater flow resistance, and effectively reduced the successive water fingering, leading to a more stable driving process to fully displace the remaining oil within the porous media. The bio-based surfactant SCA proposed in this paper has the potential for application in enhanced oil recovery in similar high-salt oil reservoirs.
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Affiliation(s)
- Hongda Hao
- School of Petroleum and Natural Gas Engineering, School of Energy, Changzhou University Changzhou 213164 China +86 15261180955
| | - Hongze Wu
- School of Petroleum and Natural Gas Engineering, School of Energy, Changzhou University Changzhou 213164 China +86 15261180955
| | - Haoyu Diao
- CNPC Engineering Technology Research and Development Co. Ltd Beijing 100083 China
| | - Yixin Zhang
- School of Petroleum and Natural Gas Engineering, School of Energy, Changzhou University Changzhou 213164 China +86 15261180955
| | - Shuo Yang
- School of Petroleum and Natural Gas Engineering, School of Energy, Changzhou University Changzhou 213164 China +86 15261180955
| | - Song Deng
- School of Petroleum and Natural Gas Engineering, School of Energy, Changzhou University Changzhou 213164 China +86 15261180955
| | - Qiu Li
- School of Petroleum and Natural Gas Engineering, School of Energy, Changzhou University Changzhou 213164 China +86 15261180955
| | - Xiaopeng Yan
- School of Petroleum and Natural Gas Engineering, School of Energy, Changzhou University Changzhou 213164 China +86 15261180955
| | - Mingguo Peng
- School of Petroleum and Natural Gas Engineering, School of Energy, Changzhou University Changzhou 213164 China +86 15261180955
| | - Ming Qu
- Sanya Offshore Oil & Gas Research Institute, Northeast Petroleum University Sangya 572024 China
| | - Xinyu Li
- China Yangtze Power Co. Ltd Yichang 443000 China
| | - Jiaming Xu
- China Yangtze Power Co. Ltd Yichang 443000 China
| | - Erlong Yang
- School of Petroleum Engineering, Northeast Petroleum University Daqing 163318 China
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3
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Vicente-Garcia C, Colomer I. Lipopeptides as tools in catalysis, supramolecular, materials and medicinal chemistry. Nat Rev Chem 2023; 7:710-731. [PMID: 37726383 DOI: 10.1038/s41570-023-00532-8] [Citation(s) in RCA: 0] [Impact Index Per Article: 0] [Reference Citation Analysis] [Abstract] [MESH Headings] [Track Full Text] [Journal Information] [Subscribe] [Scholar Register] [Accepted: 08/03/2023] [Indexed: 09/21/2023]
Abstract
Lipopeptides are amphiphilic peptides in which an aliphatic chain is attached to either the C or N terminus of peptides. Their self-assembly - into micelles, vesicles, nanotubes, fibres or nanobelts - leads to applications in nanotechnology, catalysis or medicinal chemistry. Self-organization of lipopeptides is dependent on both the length of the lipid tail and the amino acid sequence, in which the chirality of the peptide sequence can be transmitted into the supramolecular species. This Review describes the use of lipopeptides to design synthetic advanced dynamic supramolecular systems, nanostructured materials or self-responsive delivery systems in the area of medical biotechnology. We examine the influence of external stimuli, the ability of lipopeptide-derived structures to adapt over time and their application as medicinal agents with antibacterial, antifungal, antiviral or anticancer activities. Finally, we discuss the catalytic efficiency of lipopeptides, with the aim of building minimal synthetic enzymes, and recent efforts to incorporate metals into lipopeptide assemblies.
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Affiliation(s)
| | - Ignacio Colomer
- IMDEA-Nanociencia, Madrid, Spain.
- Instituto de Química Orgánica General (IQOG-CSIC), Madrid, Spain.
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Lv J, Liao G, Ma C, Du M, Wang X, Tan F. Difference in Step-Wise Production Rules of SP Binary Flooding for Conglomerate Reservoirs with Different Lithologies. Polymers (Basel) 2023; 15:3119. [PMID: 37514507 PMCID: PMC10385760 DOI: 10.3390/polym15143119] [Citation(s) in RCA: 0] [Impact Index Per Article: 0] [Reference Citation Analysis] [Abstract] [Key Words] [Grants] [Track Full Text] [Journal Information] [Subscribe] [Scholar Register] [Received: 07/04/2023] [Revised: 07/17/2023] [Accepted: 07/19/2023] [Indexed: 07/30/2023] Open
Abstract
The purpose of this study is to clarify the difference in oil production rules of conglomerate reservoirs with different pore structures during surfactant-polymer (SP) binary flooding and to ensure the efficient development of conglomerate reservoirs. In this paper, the full-diameter natural cores from the conglomerate reservoir of the Triassic Kexia Formation in the seventh middle block of the Karamay Oilfield (Xinjiang, China) are selected as the research objects. Two schemes of single constant viscosity (SCV) and echelon viscosity reducing (EVR) are designed to displace oil from three main oil-bearing lithologies, namely fine conglomerate, glutenite, and sandstone. Through comprehensive analysis of parameters, such as oil recovery rate, water content, and injection pressure difference, the influence of lithology on the enhanced oil recovery (EOR) of the EVR scheme is determined, which in turn reveals the differences in the step-wise oil production rules of the three lithologies. The experimental results show that for the three lithological reservoirs, the oil displacement effect of the EVR scheme is better than that of the SCV scheme, and the differences in recovery rates between the two schemes are 9.91% for the fine conglomerate, 6.77% for glutenite, and 6.69% for sandstone. By reducing the molecular weight and viscosity of the SP binary system, the SCV scheme achieves the reconstruction of the pressure field and the redistribution of seepage paths of chemical micelles with different sizes, thus, achieving the step-wise production of crude oil in different scale pore throats and enhancing the overall recovery of the reservoir. The sedimentary environment and diagenesis of the three types of lithologies differ greatly, resulting in diverse microscopic pore structures and differential seepage paths and displace rules of SP binary solutions, ultimately leading to large differences in the enhanced oil recoveries of different lithologies. The fine conglomerate reservoir has the strongest anisotropy, the worst pore throat connectivity, and the lowest water flooding recovery rate. Since the fine conglomerate reservoir has the strongest anisotropy, the worst pore throats connectivity, and the lowest water flooding recovery, the EVR scheme shows a good "water control and oil enhancement" development feature and the best step-wise oil production effect. The oil recovery rate of the two schemes for fine conglomerate shows a difference of 10.14%, followed by 6.36% for glutenite and 5.10% for sandstone. In addition, the EOR of fine conglomerate maintains a high upward trend throughout the chemical flooding, indicating that the swept volume of small pore throats gradually expands and the producing degree of the remaining oil in it gradually increases. Therefore, the fine conglomerate is the most suitable lithology for the SCV scheme among the three lithologies of the conglomerate reservoirs.
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Affiliation(s)
- Jianrong Lv
- Institute of Porous Flow and Fluid Mechanics, Chinese Academy of Sciences, Langfang 065007, China
- Xinjiang Oilfield Company, PetroChina, Karamay 834000, China
| | - Guangzhi Liao
- Institute of Porous Flow and Fluid Mechanics, Chinese Academy of Sciences, Langfang 065007, China
- Oil, Gas and New Energies Company, PetroChina, Beijing 100007, China
| | - Chunmiao Ma
- College of Earth and Planetary Sciences, University of Chinese Academy of Sciences, Beijing 100049, China
| | - Meng Du
- Institute of Porous Flow and Fluid Mechanics, Chinese Academy of Sciences, Langfang 065007, China
| | - Xiaoguang Wang
- Xinjiang Oilfield Company, PetroChina, Karamay 834000, China
| | - Fengqi Tan
- College of Earth and Planetary Sciences, University of Chinese Academy of Sciences, Beijing 100049, China
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Tan F, Qin J, Wang X, Lv J, Ma C, Liu W, Zhang C. Study on the Oil Displacement Mechanism of Different SP Binary Flooding Schemes for a Conglomerate Reservoir Based on a Microfluidic Model. Ind Eng Chem Res 2023. [DOI: 10.1021/acs.iecr.3c00201] [Citation(s) in RCA: 0] [Impact Index Per Article: 0] [Reference Citation Analysis] [Track Full Text] [Journal Information] [Subscribe] [Scholar Register] [Indexed: 03/29/2023]
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Norouzpour M, Azdarpour A, Nabipour M, Santos RM, Khaksar Manshad A, Iglauer S, Akhondzadeh H, Keshavarz A. Red Beet Plant as a Novel Source of Natural Surfactant Combined with ‘Smart Water’ for EOR Purposes in Carbonate Reservoirs. J Mol Liq 2022. [DOI: 10.1016/j.molliq.2022.121051] [Citation(s) in RCA: 0] [Impact Index Per Article: 0] [Reference Citation Analysis] [Track Full Text] [Journal Information] [Subscribe] [Scholar Register] [Indexed: 12/14/2022]
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7
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Al-Asadi A, Rodil E, Soto A. Nanoparticles in Chemical EOR: A Review on Flooding Tests. NANOMATERIALS (BASEL, SWITZERLAND) 2022; 12:4142. [PMID: 36500766 PMCID: PMC9735815 DOI: 10.3390/nano12234142] [Citation(s) in RCA: 2] [Impact Index Per Article: 1.0] [Reference Citation Analysis] [Abstract] [Key Words] [Track Full Text] [Subscribe] [Scholar Register] [Received: 10/12/2022] [Revised: 11/07/2022] [Accepted: 11/19/2022] [Indexed: 06/17/2023]
Abstract
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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Affiliation(s)
- Akram Al-Asadi
- Cross-Disciplinary Research Center in Environmental Technologies (CRETUS), Department of Chemical Engineering, Universidade de Santiago de Compostela, E-15782 Santiago de Compostela, Spain
- Chemical and Petrochemical Techniques Engineering Department, Basra Engineering Technical College, Southern Technical University, Ministry of Higher Education and Scientific Research, Basra 61003, Iraq
| | - Eva Rodil
- Cross-Disciplinary Research Center in Environmental Technologies (CRETUS), Department of Chemical Engineering, Universidade de Santiago de Compostela, E-15782 Santiago de Compostela, Spain
| | - Ana Soto
- Cross-Disciplinary Research Center in Environmental Technologies (CRETUS), Department of Chemical Engineering, Universidade de Santiago de Compostela, E-15782 Santiago de Compostela, Spain
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8
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Zapata K, Rodríguez Y, Lopera SH, Cortes FB, Franco CA. Development of Bio-Nanofluids Based on the Effect of Nanoparticles' Chemical Nature and Novel Solanum torvum Extract for Chemical Enhanced Oil Recovery (CEOR) Processes. NANOMATERIALS (BASEL, SWITZERLAND) 2022; 12:3214. [PMID: 36145002 PMCID: PMC9504882 DOI: 10.3390/nano12183214] [Citation(s) in RCA: 0] [Impact Index Per Article: 0] [Reference Citation Analysis] [Abstract] [Key Words] [Track Full Text] [Figures] [Subscribe] [Scholar Register] [Received: 08/01/2022] [Revised: 08/24/2022] [Accepted: 08/31/2022] [Indexed: 06/16/2023]
Abstract
This study aimed to develop novel bio-nanofluids using Solanum torvum extracts in synergy with nanoparticles of different chemical nature as a proposal sustainable for enhanced oil recovery (EOR) applications. For this, saponin-rich extracts (SRE) were obtained from Solanum torvum fruit using ultrasound-assisted and Soxhlet extraction. The results revealed that Soxhlet is more efficient for obtaining SRE from Solanum torvum and that degreasing does not generate additional yields. SRE was characterized by Fourier transformed infrared spectrophotometry, thermogravimetric analysis, hydrophilic-lipophilic balance, and critical micelle concentration analyses. Bio-nanofluids based on SiO2 (strong acid), ZrO2 (acid), Al2O3 (neutral), and MgO (basic) nanoparticles and SRE were designed to evaluate the effect of the chemical nature of the nanoparticles on the SRE performance. The results show that 100 mg L-1 MgO nanoparticles improved the interfacial tension up to 57% and the capillary number increased by two orders of magnitude using this bio-nanofluid. SRE solutions enhanced with MgO recovered about 21% more than the system in the absence of nanoparticles. The addition of MgO nanoparticles did not cause a loss of injectivity. This is the first study on the surface-active properties of Solanum torvum enhanced with nanomaterials as an environmentally friendly EOR process.
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Affiliation(s)
- Karol Zapata
- Fenómenos de Superficie—Michael Polanyi, Facultad de Minas, Universidad Nacional de Colombia—Sede Medellín, Medellín 050034, Colombia
| | - Yuber Rodríguez
- Yacimientos de Hidrocarburos, Facultad de Minas, Universidad Nacional de Colombia—Sede Medellín, Medellín 050034, Colombia
| | - Sergio H. Lopera
- Yacimientos de Hidrocarburos, Facultad de Minas, Universidad Nacional de Colombia—Sede Medellín, Medellín 050034, Colombia
| | - Farid B. Cortes
- Fenómenos de Superficie—Michael Polanyi, Facultad de Minas, Universidad Nacional de Colombia—Sede Medellín, Medellín 050034, Colombia
| | - Camilo A. Franco
- Fenómenos de Superficie—Michael Polanyi, Facultad de Minas, Universidad Nacional de Colombia—Sede Medellín, Medellín 050034, Colombia
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Nourinia A, Manshad AK, Shadizadeh SR, Ali JA, Iglauer S, Keshavarz A, Mohammadi AH, Ali M. Synergistic Efficiency of Zinc Oxide/Montmorillonite Nanocomposites and a New Derived Saponin in Liquid/Liquid/Solid Interface-Included Systems: Application in Nanotechnology-Assisted Enhanced Oil Recovery. ACS OMEGA 2022; 7:24951-24972. [PMID: 35910115 PMCID: PMC9330196 DOI: 10.1021/acsomega.1c07182] [Citation(s) in RCA: 1] [Impact Index Per Article: 0.5] [Reference Citation Analysis] [Abstract] [Track Full Text] [Download PDF] [Figures] [Subscribe] [Scholar Register] [Indexed: 06/15/2023]
Abstract
Oil production faces challenges such as limited oil production from carbonate reservoirs, high oil production costs, and environmental issues. Chemical flooding as an enhanced oil recovery (EOR) method (CEOR) can increase oil production by the use of chemical additives such as surfactants into the reservoirs. Surfactants can increase oil recovery by interfacial tension (IFT) reduction and alteration of the rock wettability from oil-wet to water-wet. The synthesis of chemicals such as synthetic surfactants is usually costly and harmful to the environment. To solve these problems, many researchers have oriented on the use of natural surfactants instead of synthetic ones within the CEOR process. A new approach to increase the efficiency of CEOR is the synergizing of the chemical additives with nanoparticles as a hybrid fluid, which is known as the nanotechnology-assisted EOR method. In this research, a natural surfactant derived from Cyclamen persicum (CP) plant was extracted, and its performance was optimized with the zinc oxide/montmorillonite (ZnO/MMT) nanocomposite in a synergistic usage. At the optimum concentration of the surfactant, the measurements of the IFT and the contact angle show 57.78 and 61.58% optimizations, respectively. Also, in the presence of NaCl, the performance of CP is improved. IFT and contact angle measurements were also conducted for ZnO/MMT nanofluids and CP-ZnO/MMT as hybrid nanofluids. Results indicate that ZnO/MMT nanocomposites can alter the wettability of the carbonate rock to the water-wet state. Also, the CP-ZnO/MMT hybrid nanofluid shows a good potential in both IFT reduction and altering wettability from oil-wet to water-wet. Finally, to investigate the effects of solutions on increasing oil recovery factor (RF), the optimum concentrations of the surfactant, nanocomposite, and hybrid solutions were selected for dynamic core flooding experiments, and improvements showed oil RF increases of 8.2, 6, and 13%, respectively.
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Affiliation(s)
- Ahmad Nourinia
- Department
of Petroleum Engineering, Abadan Faculty of Petroleum, Petroleum University of Technology (PUT), Abadan 6318714331, Iran
| | - Abbas Khaksar Manshad
- Department
of Petroleum Engineering, Abadan Faculty of Petroleum, Petroleum University of Technology (PUT), Abadan 6318714331, Iran
| | - Seyed Reza Shadizadeh
- Department
of Petroleum Engineering, Abadan Faculty of Petroleum, Petroleum University of Technology (PUT), Abadan 6318714331, Iran
| | - Jagar A. Ali
- Department
of Petroleum Engineering, Faculty of Engineering, Soran University, Soran, Kurdistan
Region 44008, Iraq
| | - Stefan Iglauer
- Discipline
of Petroleum Engineering, School of Engineering, Edith Cowan University, 270 Joondalup Dr, Joondalup 6027, WA, Australia
| | - Alireza Keshavarz
- Discipline
of Petroleum Engineering, School of Engineering, Edith Cowan University, 270 Joondalup Dr, Joondalup 6027, WA, Australia
| | - Amir H. Mohammadi
- Discipline
of Chemical Engineering, School of Engineering, University of KwaZulu-Natal, Howard College Campus, King George V Avenue, Durban 4041, South Africa
| | - Muhammad Ali
- Discipline
of Petroleum Engineering, School of Engineering, Edith Cowan University, 270 Joondalup Dr, Joondalup 6027, WA, Australia
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10
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Development of a Novel Green Bio-Nanofluid from Sapindus Saponaria for Enhanced Oil Recovery Processes. Processes (Basel) 2022. [DOI: 10.3390/pr10061057] [Citation(s) in RCA: 0] [Impact Index Per Article: 0] [Reference Citation Analysis] [Abstract] [Track Full Text] [Journal Information] [Subscribe] [Scholar Register] [Indexed: 11/16/2022] Open
Abstract
The main objective of this study is to develop a novel green-nanofluid from Sapindus Saponaria for its application in enhanced oil recovery (EOR) processes. The bio-nanofluid is composed of a green active compound (AGC), bio-ethanol, and commercial surfactant (SB) at a low concentration. The AGC was obtained from soapberry “Sapindus Saponaria” using the alcoholic extraction method and characterized by Fourier transform infrared spectroscopy (FTIR), thermogravimetric analysis (TGA), and critical micellar concentration (CMC) to verify the content of saponins as active agents with surface-active behavior. Three types of silica-based nanoparticles were used and characterized by FTIR, TGA, and dynamic light scattering (DLS) analysis. Two commercial nanoparticles (SiO2-C1 and SiO2-C2) were evaluated, and a third one (SiO2-RH) was synthesized from rice husks as an ecological nanomaterial alternative. The performance of the adjusted systems was evaluated by capillary number (effective interfacial tension (σe), wettability and viscosity) and finally with coreflooding tests under reservoir conditions. The FTIR results confirm the presence of saponins in the AGC. In addition, according to the TGA, the AGC is stable under the reservoir temperature of interest. Regarding nanoparticles, siloxane and silanol groups were observed in all samples. For SiO2-C1 and SiO2-C2 samples, the weight loss was lower than 5% for temperatures up to 700 °C. Meanwhile, SiO2-RH had a weight loss of 12% at 800 °C, and 8% at reservoir temperature. Results show a decrease in the interfacial tension (IFT) of up to 83% of the tuned system with only 100 mg·L−1 of rice husk nanoparticles compared to the system without nanoparticles, reaching values of 1.60 × 10−1 mN·m−1. In the coreflooding test, increases of up to 13% of additional crude oil were obtained using the best bio-nanofluid. This work presents an excellent opportunity to include green alternatives to improve conventional techniques with added value during the injection of chemicals in chemical-enhanced oil recovery (CEOR) processes.
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11
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Tavakkoli O, Kamyab H, Junin R, Ashokkumar V, Shariati A, Mohamed AM. SDS-Aluminum Oxide Nanofluid for Enhanced Oil Recovery: IFT, Adsorption, and Oil Displacement Efficiency. ACS OMEGA 2022; 7:14022-14030. [PMID: 35559180 PMCID: PMC9089375 DOI: 10.1021/acsomega.2c00567] [Citation(s) in RCA: 9] [Impact Index Per Article: 4.5] [Reference Citation Analysis] [Abstract] [Grants] [Track Full Text] [Download PDF] [Figures] [Subscribe] [Scholar Register] [Received: 01/27/2022] [Accepted: 03/30/2022] [Indexed: 06/15/2023]
Abstract
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 (Al2O3) on the efficiency of surfactant flooding. Extensive series of interfacial tension and surfactant adsorption measurements were conducted at different concentrations of SDS and Al2O3 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-Al2O3 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 Al2O3 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-Al2O3 nanofluids for CEOR.
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Affiliation(s)
- Omid Tavakkoli
- Department
of Petroleum Engineering, Faculty of Chemical and Energy Engineering, Universiti Teknologi Malaysia, 81310 Skudai, Johor Bahru, Malaysia
| | - Hesam Kamyab
- Malaysia-Japan
International Institute of Technology, Universiti
Teknologi Malaysia, Jalan
Sultan Yahya Petra, 54100 Kuala Lumpur, Malaysia
- Department
of Biomaterials, Saveetha Dental College and Hospital, Saveetha Institute
of Medical and Technical Sciences, Saveetha
University, Chennai 600 077, India
| | - Radzuan Junin
- Department
of Petroleum Engineering, Faculty of Chemical and Energy Engineering, Universiti Teknologi Malaysia, 81310 Skudai, Johor Bahru, Malaysia
- Institute
for Oil and Gas, Universiti Teknologi Malaysia, 81310 Johor Bahru, Malaysia
| | - Veeramuthu Ashokkumar
- Center
for Transdisciplinary Research, Department of Pharmacology, Saveetha
Dental College, Saveetha Institute of Medical and Technical Sciences, Saveetha University, Chennai 600077, India
| | - Ali Shariati
- Institute
of Research and Development, Duy Tan University, Da Nang 550000, Viet Nam
| | - Abdeliazim Mustafa Mohamed
- College of
Engineering, Department of Civil Engineering, Prince Sattam bin Abdulaziz University, Alkharj 16273, Saudi Arabia
- Building
& Construction Technology Department, Bayan University, 210 Khartoum, Sudan
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12
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Interfacial Properties, Wettability Alteration and Emulsification Properties of an Organic Alkali-Surface Active Ionic Liquid System: Implications for Enhanced Oil Recovery. MOLECULES (BASEL, SWITZERLAND) 2022; 27:molecules27072265. [PMID: 35408664 PMCID: PMC9000228 DOI: 10.3390/molecules27072265] [Citation(s) in RCA: 5] [Impact Index Per Article: 2.5] [Reference Citation Analysis] [Abstract] [Key Words] [Track Full Text] [Download PDF] [Figures] [Subscribe] [Scholar Register] [Received: 02/28/2022] [Revised: 03/21/2022] [Accepted: 03/21/2022] [Indexed: 11/23/2022]
Abstract
Combinatory flooding techniques evolved over the years to mitigate various limitations associated with unitary flooding techniques and to enhance their performance as well. This study investigates the potential of a combination of 1-hexadecyl-3-methyl imidazolium bromide (C16mimBr) and monoethanolamine (ETA) as an alkali–surfactant (AS) formulation for enhanced oil recovery. The study is conducted comparative to a conventional combination of cetyltrimethylammonium bromide (CTAB) and sodium metaborate (NaBO2). The study confirmed that C16mimBr and CTAB have similar aggregation behaviors and surface activities. The ETA–C16mimBr system proved to be compatible with brine containing an appreciable concentration of divalent cations. Studies on interfacial properties showed that the ETA–C16mimBr system exhibited an improved IFT reduction capability better than the NaBO2–CTAB system, attaining an ultra-low IFT of 7.6 × 10−3 mN/m. The IFT reduction performance of the ETA–C16mimBr system was improved in the presence of salt, attaining an ultra-low IFT of 2.3 × 10−3 mN/m. The system also maintained an ultra-low IFT even in high salinity conditions of 15 wt% NaCl concentration. Synergism was evident for the ETA–C16mimBr system also in altering the carbonate rock surface, while the wetting power of CTAB was not improved by the addition of NaBO2. Both the ETA–C16mimBr and NaBO2–CTAB systems proved to form stable emulsions even at elevated temperatures. This study, therefore, reveals that a combination of surface-active ionic liquid and organic alkali has excellent potential in enhancing the oil recovery in carbonate reservoirs at high salinity, high-temperature conditions in carbonate formations.
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Agi A, Junin R, Zaidi Jaafar M, Aishah Saidina Amin N, Akhmal Sidek M, Bevan Nyakuma B, Yakasai F, Gbadamosi A, Oseh J, Bashirah Azli N. Ultrasound-Assisted Nanofluid Flooding to Enhance Heavy Oil Recovery in a Simulated Porous Media. ARAB J CHEM 2022. [DOI: 10.1016/j.arabjc.2022.103784] [Citation(s) in RCA: 2] [Impact Index Per Article: 1.0] [Reference Citation Analysis] [Track Full Text] [Journal Information] [Subscribe] [Scholar Register] [Indexed: 11/29/2022] Open
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Zhao M, Cheng Y, Wu Y, Dai C, Gao M, Yan R, Guo X. Enhanced oil recovery mechanism by surfactant-silica nanoparticles imbibition in ultra-low permeability reservoirs. J Mol Liq 2022. [DOI: 10.1016/j.molliq.2021.118010] [Citation(s) in RCA: 5] [Impact Index Per Article: 2.5] [Reference Citation Analysis] [Track Full Text] [Journal Information] [Subscribe] [Scholar Register] [Indexed: 11/25/2022]
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Hoseini-Moghadam SMA, Ghiasimehr B, Torkaman M, Mirmarghabi P. The role of temperature and porous media morphology on the performance of anionic and cationic surfactants for enhanced heavy oil recovery. J Mol Liq 2021. [DOI: 10.1016/j.molliq.2021.116051] [Citation(s) in RCA: 2] [Impact Index Per Article: 0.7] [Reference Citation Analysis] [Track Full Text] [Journal Information] [Subscribe] [Scholar Register] [Indexed: 11/28/2022]
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Zhai M, Gong P, Li H, Peng J, Xu W, Song S, Liu X, Liu J, Liu J, Liu Z. Metastable interface biomimetic synthesis of a smart nanosystem for enhanced starvation/gas therapy. J Colloid Interface Sci 2021; 599:149-157. [PMID: 33940438 DOI: 10.1016/j.jcis.2021.04.042] [Citation(s) in RCA: 15] [Impact Index Per Article: 5.0] [Reference Citation Analysis] [Abstract] [Key Words] [MESH Headings] [Track Full Text] [Journal Information] [Subscribe] [Scholar Register] [Received: 01/22/2021] [Revised: 03/26/2021] [Accepted: 04/09/2021] [Indexed: 12/12/2022]
Abstract
Glucose oxidase (GOx)-mediated starvation therapy holds great promise in cancer treatment. However, the worse hypoxia conditions result into low therapeutic efficiency, and undegradability of carriers poses potential threats to living bodies. To address this, herein a bioinspired MnO2 nanosystem with controllable surface was developed for highly efficient starvation/gas synergistic enhanced therapy. Biomimetic design and further surface modification unprecedentedly endowed the nanosystem with ultrahigh loading capacity for GOx and l-Arginine (l-Arg) and special selectivity toward cancer cells. Especially, the dissipative O2 during starvation therapy was well replenished by a positive cycle formed by the nanosystem, which continuously reproduced O2 and accelerated glucose consumption. The abundant H2O2 was further used to oxidize l-Arg into nitric oxide to realize gas therapy. In vitro and in vivo testing confirmed that this new treatment effectively blocked the nutrition and energy sources of cells to obtain excellent therapeutic effect. We reported the first experimental item of this nanosystem for inhibiting cancer cell migration. Considering the novel design concept with facile biomimetic methods, effective co-loading of endogenous substances, and good anti-tumor and anti-migration effects, this work provided new theoretical and experimental basis for starvation therapy and inspired people to design more delicate platform for cancer treatment.
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Affiliation(s)
- Mingzhu Zhai
- The Key Laboratory of Life-Organic Analysis, School of Chemistry and Chemical Engineering, Qufu Normal University, Qufu 273165, PR China
| | - Peiwei Gong
- The Key Laboratory of Life-Organic Analysis, School of Chemistry and Chemical Engineering, Qufu Normal University, Qufu 273165, PR China; State Key Laboratory of Solidification Processing, Center of Advanced Lubrication, and Seal Materials, Northwestern Polytechnical University, 517, Xi'an 710072, PR China.
| | - Hui Li
- The Key Laboratory of Life-Organic Analysis, School of Chemistry and Chemical Engineering, Qufu Normal University, Qufu 273165, PR China
| | - Jingyi Peng
- The Key Laboratory of Life-Organic Analysis, School of Chemistry and Chemical Engineering, Qufu Normal University, Qufu 273165, PR China
| | - Wenyu Xu
- The Key Laboratory of Life-Organic Analysis, School of Chemistry and Chemical Engineering, Qufu Normal University, Qufu 273165, PR China
| | - Shaohua Song
- The Key Laboratory of Life-Organic Analysis, School of Chemistry and Chemical Engineering, Qufu Normal University, Qufu 273165, PR China
| | - Xicheng Liu
- The Key Laboratory of Life-Organic Analysis, School of Chemistry and Chemical Engineering, Qufu Normal University, Qufu 273165, PR China
| | - Jianxi Liu
- State Key Laboratory of Solidification Processing, Center of Advanced Lubrication, and Seal Materials, Northwestern Polytechnical University, 517, Xi'an 710072, PR China.
| | - Jinfeng Liu
- The Key Laboratory of Life-Organic Analysis, School of Chemistry and Chemical Engineering, Qufu Normal University, Qufu 273165, PR China
| | - Zhe Liu
- The Key Laboratory of Life-Organic Analysis, School of Chemistry and Chemical Engineering, Qufu Normal University, Qufu 273165, PR China.
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Awan FUR, Al-Yaseri A, Akhondzadeh H, Iglauer S, Keshavarz A. Influence of mineralogy and surfactant concentration on zeta potential in intact sandstone at high pressure. J Colloid Interface Sci 2021; 607:401-411. [PMID: 34509114 DOI: 10.1016/j.jcis.2021.08.015] [Citation(s) in RCA: 6] [Impact Index Per Article: 2.0] [Reference Citation Analysis] [Abstract] [Key Words] [Track Full Text] [Journal Information] [Subscribe] [Scholar Register] [Received: 04/08/2021] [Revised: 07/23/2021] [Accepted: 08/03/2021] [Indexed: 10/20/2022]
Abstract
HYPOTHESIS Zeta-potential in the presence of brine has been studied for its application within hydrocarbon reservoirs. These studies have shown that sandstone's zeta-potential remains negatively charged, non-zero, and levels-off at salinities > 0.4 mol.dm-3, thus becoming independent of salinity when ionic strength is increased further. However, research conducted to date has not yet considered clay-rich (i.e. clay ≥ 5 wt%) sandstones. EXPERIMENTS Firstly, streaming potential measurements were conducted on Bandera Gray sandstones (clay-rich and clay-poor) with 0.6 and 2 mol.dm-3 NaCl brine-saturated in pressurised environments (6.895 MPa overburden and 3.447 MPa back-pressure). Secondly, the streaming potential was determined at identical conditions for the effect of two surfactants, SDBS and CTAB, at concentrations of 0.01 and 0.1 wt% on the clay-poor sample in 0.6 mol.dm-3 NaCl. Thirdly, a comparison of zeta potentials determined via electrophoretic and streaming potential was conducted. Accordingly, this work analyses the effects of mineralogy and surfactants within this process. FINDINGS Clay-rich sandstone possessed lower zeta-potentials than clay-poor sandstone at the two tested salinities. SDBS reduced zeta-potential and yielded higher repulsive forces rendering the rock more hydrophilic. Additionally, electrophoretic zeta-potentials were higher when compared to streaming zeta-potentials. Mechanisms for the observed phenomena are also provided.
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Affiliation(s)
- Faisal Ur Rahman Awan
- School of Engineering, Edith Cowan University, 270 Joondalup Drive, Joondalup 6027, Western Australia, Australia; Centre for Sustainable Energy and Resources, Edith Cowan University, 270 Joondalup Drive, Joondalup 6027, Western Australia, Australia; Department of Petroleum and Gas Engineering, New M. A. Jinnah Road Ext., Dawood University of Engineering and Technology, Karachi 74800, Sindh, Pakistan
| | - Ahmed Al-Yaseri
- School of Engineering, Edith Cowan University, 270 Joondalup Drive, Joondalup 6027, Western Australia, Australia
| | - Hamed Akhondzadeh
- School of Engineering, Edith Cowan University, 270 Joondalup Drive, Joondalup 6027, Western Australia, Australia; Centre for Sustainable Energy and Resources, Edith Cowan University, 270 Joondalup Drive, Joondalup 6027, Western Australia, Australia
| | - Stefan Iglauer
- School of Engineering, Edith Cowan University, 270 Joondalup Drive, Joondalup 6027, Western Australia, Australia; Centre for Sustainable Energy and Resources, Edith Cowan University, 270 Joondalup Drive, Joondalup 6027, Western Australia, Australia.
| | - Alireza Keshavarz
- School of Engineering, Edith Cowan University, 270 Joondalup Drive, Joondalup 6027, Western Australia, Australia; Centre for Sustainable Energy and Resources, Edith Cowan University, 270 Joondalup Drive, Joondalup 6027, Western Australia, Australia.
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Kadim EJ, Noorden ZA, Adzis Z, Azis N. Nanoparticles Application in High Voltage Insulation Systems. IEEE TRANSACTIONS ON DIELECTRICS AND ELECTRICAL INSULATION 2021; 28:1380-1399. [DOI: 10.1109/tdei.2021.009531] [Citation(s) in RCA: 1] [Impact Index Per Article: 0.3] [Reference Citation Analysis] [Track Full Text] [Subscribe] [Scholar Register] [Indexed: 09/01/2023]
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Shayan Nasr M, Esmaeilnezhad E, Choi HJ. Effect of silicon-based nanoparticles on enhanced oil recovery: Review. J Taiwan Inst Chem Eng 2021. [DOI: 10.1016/j.jtice.2021.04.047] [Citation(s) in RCA: 7] [Impact Index Per Article: 2.3] [Reference Citation Analysis] [Track Full Text] [Journal Information] [Subscribe] [Scholar Register] [Indexed: 11/30/2022]
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21
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Awan FUR, Keshavarz A, Azhar MR, Akhondzadeh H, Ali M, Al-Yaseri A, Abid HR, Iglauer S. Adsorption of nanoparticles on glass bead surface for enhancing proppant performance: A systematic experimental study. J Mol Liq 2021. [DOI: 10.1016/j.molliq.2021.115398] [Citation(s) in RCA: 25] [Impact Index Per Article: 8.3] [Reference Citation Analysis] [Track Full Text] [Journal Information] [Subscribe] [Scholar Register] [Indexed: 10/22/2022]
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Olayiwola SO, Dejam M. Comprehensive experimental study on the effect of silica nanoparticles on the oil recovery during alternating injection with low salinity water and surfactant into carbonate reservoirs. J Mol Liq 2021. [DOI: 10.1016/j.molliq.2020.115178] [Citation(s) in RCA: 29] [Impact Index Per Article: 9.7] [Reference Citation Analysis] [Track Full Text] [Journal Information] [Subscribe] [Scholar Register] [Indexed: 11/25/2022]
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Mousavi SP, Hemmati-Sarapardeh A, Norouzi-Apourvari S, Jalalvand M, Schaffie M, Ranjbar M. Toward mechanistic understanding of wettability alteration in calcite and dolomite rocks: The effects of resin, asphaltene, anionic surfactant, and hydrophilic nano particles. J Mol Liq 2021. [DOI: 10.1016/j.molliq.2020.114672] [Citation(s) in RCA: 12] [Impact Index Per Article: 4.0] [Reference Citation Analysis] [Track Full Text] [Journal Information] [Subscribe] [Scholar Register] [Indexed: 10/23/2022]
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Atta DY, Negash BM, Yekeen N, Habte AD. A state-of-the-art review on the application of natural surfactants in enhanced oil recovery. J Mol Liq 2021. [DOI: 10.1016/j.molliq.2020.114888] [Citation(s) in RCA: 24] [Impact Index Per Article: 8.0] [Reference Citation Analysis] [Track Full Text] [Journal Information] [Subscribe] [Scholar Register] [Indexed: 10/22/2022]
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Abstract
The drilling of clay-rich formations, such as shale, is an extremely demanding technical and technological process. Shale consists of mixed clay minerals in different ratios and in contact with water from drilling mud. It tends to swell and cause different wellbore instability problems. Usually, the petroleum industry uses various types of salt and/or polymers as shale hydration inhibitors. The aim of this research was to determine whether nanoparticles can be used as shale swelling inhibitors because due to their small size they can enter the shale nanopores, plug them and stop further penetration of mud filtrate into the shale formation. Swelling of bentonite-calcium carbonate pellets after 2 and 24 h in water and drilling mud (water, bentonite, PAC and NaOH) without nanoparticles and with addition of TiO2 (0.5, 1 and 1.5 wt%) and SiO2 (0.5, 1 and 1.5 wt%) nanoparticles was measured using a linear swell meter. Additionally, granulometric analyses of bentonite as well as the zeta potential of tested muds containing nanoparticles were performed. Based on the laboratory research, it can generally be concluded that the addition of SiO2 and TiO2 nanoparticles in water and base drilling mud reduces the swelling of pellets up to 40.06%.
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Hou J, Sui H, Du J, Sun L. Synergistic effect of silica nanofluid and biosurfactant on bitumen recovery from unconventional oil. J DISPER SCI TECHNOL 2020. [DOI: 10.1080/01932691.2020.1844741] [Citation(s) in RCA: 2] [Impact Index Per Article: 0.5] [Reference Citation Analysis] [Track Full Text] [Journal Information] [Subscribe] [Scholar Register] [Indexed: 10/23/2022]
Affiliation(s)
- Jinjian Hou
- School of Chemical Engineering and Technology, Tianjin University, Tianjin, China
- National Engineering Research Centre of Distillation Technology, Tianjin, China
| | - Hong Sui
- School of Chemical Engineering and Technology, Tianjin University, Tianjin, China
- National Engineering Research Centre of Distillation Technology, Tianjin, China
- Collaborative Innovation Center of Chemical Science and Engineering, Tianjin, China
| | - Jinze Du
- School of Chemical Engineering and Technology, Tianjin University, Tianjin, China
- National Engineering Research Centre of Distillation Technology, Tianjin, China
| | - Lingyu Sun
- School of Chemical Engineering and Technology, Tianjin University, Tianjin, China
- National Engineering Research Centre of Distillation Technology, Tianjin, China
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Synthesis, Characterization, and Assessment of a CeO 2@Nanoclay Nanocomposite for Enhanced Oil Recovery. NANOMATERIALS 2020; 10:nano10112280. [PMID: 33213039 PMCID: PMC7698500 DOI: 10.3390/nano10112280] [Citation(s) in RCA: 15] [Impact Index Per Article: 3.8] [Reference Citation Analysis] [Abstract] [Key Words] [Track Full Text] [Download PDF] [Figures] [Subscribe] [Scholar Register] [Received: 09/04/2020] [Revised: 11/09/2020] [Accepted: 11/10/2020] [Indexed: 01/11/2023]
Abstract
In this paper, synthesis and characterization of a novel CeO2/nanoclay nanocomposite (NC) and its effects on IFT reduction and wettability alteration is reported in the literature for the first time. The NC was characterized using scanning electron microscopy (SEM), X-ray diffraction (XRD), Fourier-transform infrared spectroscopy (FTIR), thermogravimetric analysis (TGA), energy-dispersive X-ray spectroscopy (EDS), and EDS MAP. The surface morphology, crystalline phases, and functional groups of the novel NC were investigated. Nanofluids with different concentrations of 100, 250, 500, 1000, 1500, and 2000 ppm were prepared and used as dispersants in porous media. The stability, pH, conductivity, IFT, and wettability alternation characteristics of the prepared nanofluids were examined to find out the optimum concentration for the selected carbonate and sandstone reservoir rocks. Conductivity and zeta potential measurements showed that a nanofluid with concentration of 500 ppm can reduce the IFT from 35 mN/m to 17 mN/m (48.5% reduction) and alter the contact angle of the tested carbonate and sandstone reservoir rock samples from 139° to 53° (38% improvement in wettability alteration) and 123° to 90° (27% improvement in wettability alteration), respectively. A cubic fluorite structure was identified for CeO2 using the standard XRD data. FESEM revealed that the surface morphology of the NC has a layer sheet morphology of CeO2/SiO2 nanocomposite and the particle sizes are approximately 20 to 26 nm. TGA analysis results shows that the novel NC has a high stability at 90 °C which is a typical upper bound temperature in petroleum reservoirs. Zeta potential peaks at concentration of 500 ppm which is a sign of stabilty of the nanofluid. The results of this study can be used in design of optimum yet effective EOR schemes for both carbobate and sandstone petroleum reservoirs.
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Experimental investigation of the behaviour of a novel amino acid-based surfactant relevant to EOR application. J Mol Liq 2020. [DOI: 10.1016/j.molliq.2020.113848] [Citation(s) in RCA: 21] [Impact Index Per Article: 5.3] [Reference Citation Analysis] [Track Full Text] [Journal Information] [Subscribe] [Scholar Register] [Indexed: 11/19/2022]
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Omidi A, Manshad AK, Moradi S, Ali JA, Sajadi S, Keshavarz A. Smart- and nano-hybrid chemical EOR flooding using Fe3O4/eggshell nanocomposites. J Mol Liq 2020. [DOI: 10.1016/j.molliq.2020.113880] [Citation(s) in RCA: 18] [Impact Index Per Article: 4.5] [Reference Citation Analysis] [Track Full Text] [Journal Information] [Subscribe] [Scholar Register] [Indexed: 12/17/2022]
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Nanomaterial-Based Drilling Fluids for Exploitation of Unconventional Reservoirs: A Review. ENERGIES 2020. [DOI: 10.3390/en13133417] [Citation(s) in RCA: 53] [Impact Index Per Article: 13.3] [Reference Citation Analysis] [Abstract] [Track Full Text] [Subscribe] [Scholar Register] [Indexed: 11/16/2022]
Abstract
The world’s energy demand is steadily increasing where it has now become difficult for conventional hydrocarbon reservoir to meet levels of demand. Therefore, oil and gas companies are seeking novel ways to exploit and unlock the potential of unconventional resources. These resources include tight gas reservoirs, tight sandstone oil, oil and gas shales reservoirs, and high pressure high temperature (HPHT) wells. Drilling of HPHT wells and shale reservoirs has become more widespread in the global petroleum and natural gas industry. There is a current need to extend robust techniques beyond costly drilling and completion jobs, with the potential for exponential expansion. Drilling fluids and their additives are being customized in order to cater for HPHT well drilling issues. Certain conventional additives, e.g., filtrate loss additives, viscosifier additives, shale inhibitor, and shale stabilizer additives are not suitable in the HPHT environment, where they are consequently inappropriate for shale drilling. A better understanding of the selection of drilling fluids and additives for hydrocarbon water-sensitive reservoirs within HPHT environments can be achieved by identifying the challenges in conventional drilling fluids technology and their replacement with eco-friendly, cheaper, and multi-functional valuable products. In this regard, several laboratory-scale literatures have reported that nanomaterial has improved the properties of drilling fluids in the HPHT environment. This review critically evaluates nanomaterial utilization for improvement of rheological properties, filtrate loss, viscosity, and clay- and shale-inhibition at increasing temperature and pressures during the exploitation of hydrocarbons. The performance and potential of nanomaterials, which influence the nature of drilling fluid and its multi-benefits, is rarely reviewed in technical literature of water-based drilling fluid systems. Moreover, this review presented case studies of two HPHT fields and one HPHT basin, and compared their drilling fluid program for optimum selection of drilling fluid in HPHT environment.
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