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El-hoshoudy AN. Experimental and Theoretical Investigation of Glycol-Based Hydrogels through Waterflooding Processes in Oil Reservoirs Using Molecular Dynamics and Dissipative Particle Dynamics Simulation. ACS OMEGA 2021; 6:30224-30240. [PMID: 34805657 PMCID: PMC8600538 DOI: 10.1021/acsomega.1c01533] [Citation(s) in RCA: 4] [Impact Index Per Article: 1.3] [Reference Citation Analysis] [Abstract] [Track Full Text] [Download PDF] [Figures] [Subscribe] [Scholar Register] [Received: 03/22/2021] [Accepted: 06/15/2021] [Indexed: 06/13/2023]
Abstract
Enhanced oil processing aims to retrieve petroleum fluids from depleted reservoirs after traditional processing. Hydrogels and polymeric macromolecules are considered effective displacing agents in oil reservoirs. In the current work, the authors used hydrophilic hydrogels based on poly(ethylene glycol)/poly(propylene glycol) (PEG/PPG) surfmers for oil displacement processes. Statistical modeling of the rheological properties at 80 °C for the two hydrogels indicates that the viscosity-shearing profile obeys the power-law model. Also, shear stress scanning follows the Herschel-Bulkley and the Bingham plastic models. The two hydrogels exhibit an initial yield stress owing to the formation of a three-dimensional (3D) structure at zero shearings. Furthermore, PEG and PPG hydrogels can retain the viscosity after a shear rate of 64.68 S-1. On the scale of surface activity, the two hydrogels exhibit higher surface areas (A m) of 0.1088 and 0.1058 nm2 and lower surface excess concentrations (Γm) of 1.529 and 1.567 × 1010 mol/cm2, respectively. A molecular dynamics (MD) simulation was conducted to explore the Flory-Huggins chi parameter, the solubility parameter, and the cohesive energy density. The results indicate a negative magnitude of chi parameter (χ ij ) for water and salt, which indicates that the two hydrogels have a good tendency toward saline formation water in the underground petroleum reservoir. Furthermore, the dissipative particle dynamics (DPD) was performed on a mesoscale to investigate the interfacial tension, the radius of gyration, the concentration profile, and the radial distribution function. The increased radius of gyration (R g) confirms that the two hydrogels are more overextended and can align perpendicularly toward the water/oil boundary. Experimental displacement was operated on a linear sandpack model using different slug concentrations. The oil recovery factor, the water-cut, and the differential pressure data during the flooding process were estimated as a function of the injected pore volume. The obtained results show that the oil recovery factor reaches 72 and 88% in the cases of PEG and PPG hydrogels at 80 °C with concentrations of 1.0 and 1.5 g/L, which reveals that both hydrogels are effective enhanced oil recovery (EOR) agents for the depleted reservoirs. This study establishes a new route that employs MD and DPD simulation in the field of enhanced oil recovery and the petroleum industry.
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Chen Q, Lu K, Zhang Y, Qin D, Xu H, Yang C, He N. Effect of DC electric field on coalescence and breakup behaviors of binary emulsion nanodroplets. J Mol Liq 2021. [DOI: 10.1016/j.molliq.2020.114939] [Citation(s) in RCA: 4] [Impact Index Per Article: 1.3] [Reference Citation Analysis] [Track Full Text] [Journal Information] [Subscribe] [Scholar Register] [Indexed: 11/29/2022]
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3
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Azad M, Patel V, Shah N, Sharma T, Trivedi JJ. Extensional Rheological Measurements of Surfactant-Polymer Mixtures. ACS OMEGA 2020; 5:30787-30798. [PMID: 33324788 PMCID: PMC7726756 DOI: 10.1021/acsomega.0c00481] [Citation(s) in RCA: 4] [Impact Index Per Article: 1.0] [Reference Citation Analysis] [Abstract] [Track Full Text] [Figures] [Subscribe] [Scholar Register] [Received: 02/03/2020] [Accepted: 10/21/2020] [Indexed: 06/12/2023]
Abstract
Polymer solutions flowing in the porous media during enhanced oil recovery (EOR) processes are subjected to both shear and extensional rheological deformation. However, the previous rheological studies conducted on a surfactant-polymer (SP) system or polymer systems were only shear-based. In this paper, the extensional rheological performance of hydrolyzed polyacrylamide (HPAM) in the presence of an anionic surfactant at various concentrations (0, 0.01, 0.05, 0.1, 0.2, and 0.3%) is studied with deionized water and 1% NaCl. Further, the extensional rheological behavior of HPAM in the presence of NaCl and CaCl2 is studied at varying ionic strengths (1-10%). A capillary break-up extensional rheometer is used for performing extensional rheological characterization. Results revealed that the extensional resistance of HPAM is enhanced in the presence of a surfactant. Particularly, around the critical micelle concentration value of the surfactant (0.1%), HPAM showed higher extensional resistance. Higher extensional resistance for the SP system is observed with deionized water when compared to 1% NaCl. HPAM showed improved performance at 1% NaCl salinity when compared to the higher concentration of NaCl salinity. However, the presence of even 1% of calcium ions is detrimental to the extensional properties of HPAM.
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Affiliation(s)
- Madhar
Sahib Azad
- School
of Mining and Petroleum Engineering, University
of Alberta, Edmonton, T6G1H9, Canada
| | - Viralkumar Patel
- School
of Mining and Petroleum Engineering, University
of Alberta, Edmonton, T6G1H9, Canada
| | - Nishit Shah
- School
of Mining and Petroleum Engineering, University
of Alberta, Edmonton, T6G1H9, Canada
| | - Tushar Sharma
- EOR
Laboratory, Rajiv Gandhi Institute of Petroleum
Technology, Jais-Amethi 229304, Uttar Pradesh, India
| | - Japan J. Trivedi
- School
of Mining and Petroleum Engineering, University
of Alberta, Edmonton, T6G1H9, Canada
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Synthesis and Evaluation of Zwitterionic Surfactants Bearing Benzene Ring in the Hydrophobic Tail. MATERIALS 2020; 13:ma13081858. [PMID: 32326587 PMCID: PMC7215865 DOI: 10.3390/ma13081858] [Citation(s) in RCA: 6] [Impact Index Per Article: 1.5] [Reference Citation Analysis] [Abstract] [Key Words] [Track Full Text] [Download PDF] [Figures] [Subscribe] [Scholar Register] [Received: 03/10/2020] [Revised: 03/28/2020] [Accepted: 04/10/2020] [Indexed: 11/23/2022]
Abstract
Surfactant tolerance in the presence of mono and divalent reservoir ions, as well as the solubility of surfactant in high salinity and low salinity brine, are the two major requirements for any surfactant that is subjected to oilfield application. Herein, six poly(ethylene oxide) zwitterionic surfactants having different ionic headgroups and hydrophobic tail were synthesized for oilfield applications. They were characterized by various instrumental techniques (Fourier-transform infrared spectroscopy (FTIR), matrix-assisted laser desorption/ionization time-of-flight mass spectrometry (MALDI-ToF-MS), Nuclear Magnetic Resonance (NMR)) and the combination of these techniques allowed for us to deduce the structure. All of the surfactants revealed prominent solubility in high salinity and low salinity brine due to the presence of ethoxy units between the aromatic ring and amide group. The surfactant samples were oven aged for 90 days at reservoir temperature and a clear solution implies their excellent aqueous stability. Rendering to thermal gravimetric results, decomposition of surfactants was found to occur around 300 °C, which is higher than the reservoir temperature (≥90 °C). It was observed that the hydrophilic headgroup has no significant impact on the critical micelle concentration and other surface properties. However, the hydrophobic tail bearing benzene ring significantly alters the critical micelle concentration and other surface properties.
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Liu X, Yu Q, Song A, Dong S, Hao J. Progress in nuclear magnetic resonance studies of surfactant systems. Curr Opin Colloid Interface Sci 2020. [DOI: 10.1016/j.cocis.2019.10.006] [Citation(s) in RCA: 5] [Impact Index Per Article: 1.3] [Reference Citation Analysis] [Track Full Text] [Journal Information] [Subscribe] [Scholar Register] [Indexed: 01/23/2023]
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Role of Ionic Headgroups on the Thermal, Rheological, and Foaming Properties of Novel Betaine-Based Polyoxyethylene Zwitterionic Surfactants for Enhanced Oil Recovery. Processes (Basel) 2019. [DOI: 10.3390/pr7120908] [Citation(s) in RCA: 5] [Impact Index Per Article: 1.0] [Reference Citation Analysis] [Abstract] [Track Full Text] [Journal Information] [Subscribe] [Scholar Register] [Indexed: 02/06/2023] Open
Abstract
Long-term thermal stability of surfactants under harsh reservoir conditions is one of the main challenges for surfactant injection. Most of the commercially available surfactants thermally degrade or precipitate when exposed to high-temperature and high-salinity conditions. In this work, we designed and synthesized three novel betaine-based polyoxyethylene zwitterionic surfactants containing different head groups (carboxybetaine, sulfobetaine, and hydroxysulfobetaine) and bearing an unsaturated tail. The impact of the surfactant head group on the long-term thermal stability, foam stability, and surfactant–polymer interactions were examined. The thermal stability of the surfactants was assessed by monitoring the structural changes when exposed at high temperature (90 °C) for three months using 1H-NMR, 13C-NMR, and FTIR analysis. All surfactants were found thermally stable regardless of the headgroup and no structural changes were evidenced. The surfactant–polymer interactions were dominant in deionized water. However, in seawater, the surfactant addition had no effect on the rheological properties. Similarly, changing the headgroup of polyoxyethylene zwitterionic surfactants had no major effect on the foamability and foam stability. The findings of the present study reveal that the betaine-based polyoxyethylene zwitterionic surfactant can be a good choice for enhanced oil recovery application and the nature of the headgroup has no major impact on the thermal, rheological, and foaming properties of the surfactant in typical harsh reservoir conditions (high salinity, high temperature).
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Kamal MS, Hussain SMS, Fogang LT, Malik IA. Development of Polyoxyethylene Zwitterionic Surfactants for High‐Salinity High‐Temperature Reservoirs. J SURFACTANTS DETERG 2019. [DOI: 10.1002/jsde.12278] [Citation(s) in RCA: 10] [Impact Index Per Article: 2.0] [Reference Citation Analysis] [Track Full Text] [Journal Information] [Subscribe] [Scholar Register] [Indexed: 01/28/2023]
Affiliation(s)
- Muhammad Shahzad Kamal
- Center for Integrative Petroleum ResearchKing Fahd University of Petroleum & Minerals Dhahran, 31261 Saudi Arabia
| | - Syed M. Shakil Hussain
- Center for Integrative Petroleum ResearchKing Fahd University of Petroleum & Minerals Dhahran, 31261 Saudi Arabia
| | - Lionel Talley Fogang
- Center for Integrative Petroleum ResearchKing Fahd University of Petroleum & Minerals Dhahran, 31261 Saudi Arabia
| | - Izhar A. Malik
- Jubail Technical Institute Jubail Industrial Area Eastern Province KSA
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Rigamonti MG, Gatti FG, Patience GS. Experimental Methods in Chemical Engineering: Nuclear Magnetic Resonance. CAN J CHEM ENG 2019. [DOI: 10.1002/cjce.23409] [Citation(s) in RCA: 7] [Impact Index Per Article: 1.4] [Reference Citation Analysis] [Track Full Text] [Journal Information] [Subscribe] [Scholar Register] [Indexed: 12/19/2022]
Affiliation(s)
- Marco G. Rigamonti
- Department of Chemical Engineering; Polytechnique Montréal, C.P. 6079; Succ. CV Montréal, QC, H3C 3A7 Canada
| | - Francesco G. Gatti
- Dipartimento di Chimica; Materiali e Ingegneria Chimica “Giulio Natta”; Politecnico di Milano; P.zza Leonardo da Vinci 32, 20133, Milano Italy
| | - Gregory S. Patience
- Department of Chemical Engineering; Polytechnique Montréal, C.P. 6079; Succ. CV Montréal, QC, H3C 3A7 Canada
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Hussain SS, Fogang LT, Kamal MS. Synthesis and performance evaluation of betaine type zwitterionic surfactants containing different degrees of ethoxylation. J Mol Struct 2018. [DOI: 10.1016/j.molstruc.2018.07.069] [Citation(s) in RCA: 24] [Impact Index Per Article: 4.0] [Reference Citation Analysis] [Track Full Text] [Journal Information] [Subscribe] [Scholar Register] [Indexed: 11/28/2022]
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10
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Kamal MS, Hussain SMS, Fogang LT, Sultan AS. Impact of Spacer and Hydrophobic Tail on Interfacial and Rheological Properties of Cationic Amido-Amine Gemini Surfactants for EOR Application. TENSIDE SURFACT DET 2018. [DOI: 10.3139/113.110591] [Citation(s) in RCA: 10] [Impact Index Per Article: 1.7] [Reference Citation Analysis] [Abstract] [Track Full Text] [Journal Information] [Subscribe] [Scholar Register] [Indexed: 11/20/2022]
Abstract
AbstractThe impact of spacer length, spacer rigidity, trans and cis conformation of spacer double bond, and hydrophobic tail length of amido-amine cationic gemini surfactants was investigated by means of interfacial and rheological properties. For the study, six cationic amido-amine gemini surfactants were synthesized and used a cationic polyacrylamide. The interfacial tension (IFT) of the surfactants between crude oil and water was measured as a function of the surfactant concentration. It has been observed that the nature of the spacer and hydrophobic moiety have a significant effect on the oil/water interfacial tension. Rheological measurements of the surfactant-polymer hybrid system were performed at various surfactant concentrations, shear rates and temperatures. All synthesized cationic gemini surfactants were compatible with the cationic polyacrylamide since no precipitates were observed. By increasing the surfactant concentration, the storage modulus, as well as viscous properties of the cationic polyacrylamide, decreased at all temperatures because of the effect of charge shielding. On the other hand, the effect of concentration of surfactant was only significant at low shear rates. The storage modulus and viscous properties of the cationic polyacrylamide were also decreased significantly upon increasing surfactant tail length (C12 to C18). However, spacer rigidity, length, and conformation of spacer double bond caused a slight decrease in the storage modulus and viscous properties of cationic polyacrylamide. IFT, rheological properties, and compatibility tests showed huge potential of investigated surfactant-polymer system for enhanced oil production.
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Affiliation(s)
- Muhammad Shahzad Kamal
- 1Center for Integrative Petroleum Research, King Fahd University of Petroleum & Minerals, 31261 Dhahran, Saudi Arabia
| | - S. M. Shakil Hussain
- 1Center for Integrative Petroleum Research, King Fahd University of Petroleum & Minerals, 31261 Dhahran, Saudi Arabia
| | - Lionel Talley Fogang
- 1Center for Integrative Petroleum Research, King Fahd University of Petroleum & Minerals, 31261 Dhahran, Saudi Arabia
| | - Abdullah S. Sultan
- 2Department of Petroleum Engineering, King Fahd University of Petroleum & Minerals. 31261 Dhahran, Saudi Arabia
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Effect of internal olefin on the properties of betaine-type zwitterionic surfactants for enhanced oil recovery. J Mol Liq 2018. [DOI: 10.1016/j.molliq.2018.06.031] [Citation(s) in RCA: 28] [Impact Index Per Article: 4.7] [Reference Citation Analysis] [Track Full Text] [Journal Information] [Subscribe] [Scholar Register] [Indexed: 12/28/2022]
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12
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Development of Chelating Agent-Based Polymeric Gel System for Hydraulic Fracturing. ENERGIES 2018. [DOI: 10.3390/en11071663] [Citation(s) in RCA: 17] [Impact Index Per Article: 2.8] [Reference Citation Analysis] [Abstract] [Track Full Text] [Subscribe] [Scholar Register] [Indexed: 11/16/2022]
Abstract
Hydraulic Fracturing is considered to be one of the most important stimulation methods. Hydraulic Fracturing is carried out by inducing fractures in the formation to create conductive pathways for the flow of hydrocarbon. The pathways are kept open either by using proppant or by etching the fracture surface using acids. A typical fracturing fluid usually consists of a gelling agent (polymers), cross-linkers, buffers, clay stabilizers, gel stabilizers, biocide, surfactants, and breakers mixed with fresh water. The numerous additives are used to prevent damage resulting from such operations, or better yet, enhancing it beyond just the aim of a fracturing operation. This study introduces a new smart fracturing fluid system that can be either used for proppant fracturing (high pH) or acid fracturing (low pH) operations in sandstone formations. The fluid system consists of glutamic acid diacetic acid (GLDA) that can replace several additives, such as cross-linker, breaker, biocide, and clay stabilizer. GLDA is also a surface-active fluid that will reduce the interfacial tension eliminating the water-blockage effect. GLDA is compatible and stable with sea water, which is advantageous over the typical fracturing fluid. It is also stable in high temperature reservoirs (up to 300 °F) and it is also environmentally friendly and readily biodegradable. The new fracturing fluid formulation can withstand up to 300 °F of formation temperature and is stable for about 6 h under high shearing rates (511 s−1). The new fracturing fluid formulation breaks on its own and the delay time or the breaking time can be controlled with the concentrations of the constituents of the fluid (GLDA or polymer). Coreflooding experiments were conducted using Scioto and Berea sandstone cores to evaluate the effectiveness of the developed fluid. The flooding experiments were in reasonable conformance with the rheological properties of the developed fluid regarding the thickening and breaking time, as well as yielding high return permeability.
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Saha R, Uppaluri RV, Tiwari P. Influence of emulsification, interfacial tension, wettability alteration and saponification on residual oil recovery by alkali flooding. J IND ENG CHEM 2018. [DOI: 10.1016/j.jiec.2017.10.034] [Citation(s) in RCA: 45] [Impact Index Per Article: 7.5] [Reference Citation Analysis] [Track Full Text] [Journal Information] [Subscribe] [Scholar Register] [Indexed: 11/29/2022]
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14
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Kamal MS, Shakil Hussain SM, Fogang LT. A Zwitterionic Surfactant Bearing Unsaturated Tail for Enhanced Oil Recovery in High-Temperature High-Salinity Reservoirs. J SURFACTANTS DETERG 2018. [DOI: 10.1002/jsde.12024] [Citation(s) in RCA: 42] [Impact Index Per Article: 7.0] [Reference Citation Analysis] [Track Full Text] [Journal Information] [Subscribe] [Scholar Register] [Indexed: 11/10/2022]
Affiliation(s)
- Muhammad Shahzad Kamal
- Center for Integrative Petroleum Research; King Fahd University of Petroleum & Minerals; 31261 Dhahran Saudi Arabia
| | - Syed M. Shakil Hussain
- Center for Integrative Petroleum Research; King Fahd University of Petroleum & Minerals; 31261 Dhahran Saudi Arabia
| | - Lionel Talley Fogang
- Center for Integrative Petroleum Research; King Fahd University of Petroleum & Minerals; 31261 Dhahran Saudi Arabia
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15
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Yan LM, Ma J, Li YL, Cui ZG, Jiang JZ. Surface and interfacial properties of 1,3-dialkyl glyceryl ether hydroxypropyl sulfonates as surfactants for enhanced oil recovery. J DISPER SCI TECHNOL 2017. [DOI: 10.1080/01932691.2017.1402339] [Citation(s) in RCA: 7] [Impact Index Per Article: 1.0] [Reference Citation Analysis] [Track Full Text] [Journal Information] [Subscribe] [Scholar Register] [Indexed: 10/18/2022]
Affiliation(s)
- Li-min Yan
- The Key Laboratory of Synthetic and Biological Colloids, Ministry of Education, School of Chemical and Material Engineering, Jiangnan University, Jiangsu, P. R. China
| | - Ji Ma
- The Key Laboratory of Synthetic and Biological Colloids, Ministry of Education, School of Chemical and Material Engineering, Jiangnan University, Jiangsu, P. R. China
| | - Yuan-li Li
- The Key Laboratory of Synthetic and Biological Colloids, Ministry of Education, School of Chemical and Material Engineering, Jiangnan University, Jiangsu, P. R. China
| | - Zheng-gang Cui
- The Key Laboratory of Synthetic and Biological Colloids, Ministry of Education, School of Chemical and Material Engineering, Jiangnan University, Jiangsu, P. R. China
| | - Jian-zhong Jiang
- The Key Laboratory of Synthetic and Biological Colloids, Ministry of Education, School of Chemical and Material Engineering, Jiangnan University, Jiangsu, P. R. China
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de Castro Dantas TN, de Souza TTC, Dantas Neto AA, Moura MCPDA, de Barros Neto EL. Experimental Study of Nanofluids Applied in EOR Processes. J SURFACTANTS DETERG 2017. [DOI: 10.1007/s11743-017-1992-2] [Citation(s) in RCA: 20] [Impact Index Per Article: 2.9] [Reference Citation Analysis] [Track Full Text] [Journal Information] [Subscribe] [Scholar Register] [Indexed: 01/23/2023]
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