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Salem KG, Tantawy MA, Gawish AA, Salem AM, Gomaa S, El-hoshoudy A. Key aspects of polymeric nanofluids as a new enhanced oil recovery approach: A comprehensive review. FUEL 2024; 368:131515. [DOI: 10.1016/j.fuel.2024.131515] [Citation(s) in RCA: 1] [Impact Index Per Article: 1.0] [Reference Citation Analysis] [Track Full Text] [Subscribe] [Scholar Register] [Indexed: 07/05/2024]
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Castro RH, Corredor LM, Llanos S, Causil MA, Arias A, Pérez E, Quintero HI, Romero Bohórquez AR, Franco CA, Cortés FB. Experimental Investigation of the Viscosity and Stability of Scleroglucan-Based Nanofluids for Enhanced Oil Recovery. NANOMATERIALS (BASEL, SWITZERLAND) 2024; 14:156. [PMID: 38251121 PMCID: PMC10818491 DOI: 10.3390/nano14020156] [Citation(s) in RCA: 0] [Impact Index Per Article: 0] [Reference Citation Analysis] [Abstract] [Key Words] [Track Full Text] [Subscribe] [Scholar Register] [Received: 09/30/2023] [Revised: 10/26/2023] [Accepted: 10/30/2023] [Indexed: 01/23/2024]
Abstract
Biopolymers emerge as promising candidates for enhanced oil recovery (EOR) applications due to their molecular structures, which exhibit better stability than polyacrylamides under harsh conditions. Nonetheless, biopolymers are susceptible to oxidation and biological degradation. Biopolymers reinforced with nanoparticles could be a potential solution to the issue. The nanofluids' stability and performance depend on the nanoparticles' properties and the preparation method. The primary objective of this study was to evaluate the effect of the preparation method and the nanoparticle type (SiO2, Al2O3, and TiO2) on the viscosity and stability of the scleroglucan (SG). The thickening effect of the SG solution was improved by adding all NPs due to the formation of three-dimensional structures between the NPs and the SG chains. The stability test showed that the SG + Al2O3 and SG + TiO2 nanofluids are highly unstable, but the SG + SiO2 nanofluids are highly stable (regardless of the preparation method). According to the ANOVA results, the preparation method and standing time influence the nanofluid viscosity with a statistical significance of 95%. On the contrary, the heating temperature and NP type are insignificant. Finally, the nanofluid with the best performance was 1000 ppm of SG + 100 ppm of SiO2_120 NPs prepared by method II.
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Affiliation(s)
- Rubén H. Castro
- Grupo de Investigación en Fenómenos de Superficie—Michael Polanyi, Facultad de Minas, Universidad Nacional de Colombia—Sede Medellín, Medellín 050034, Colombia; (M.A.C.); (C.A.F.); (F.B.C.)
| | - Laura M. Corredor
- Centro de Innovación y Tecnología—ICP, Ecopetrol S.A., Piedecuesta 681011, Colombia; (L.M.C.); (H.I.Q.)
| | - Sebastián Llanos
- Grupo de Investigación en Química Estructural (GIQUE), Escuela de Química, Universidad Industrial de Santander, Bucaramanga 680006, Colombia; (S.L.); (A.A.); (A.R.R.B.)
| | - María A. Causil
- Grupo de Investigación en Fenómenos de Superficie—Michael Polanyi, Facultad de Minas, Universidad Nacional de Colombia—Sede Medellín, Medellín 050034, Colombia; (M.A.C.); (C.A.F.); (F.B.C.)
| | - Adriana Arias
- Grupo de Investigación en Química Estructural (GIQUE), Escuela de Química, Universidad Industrial de Santander, Bucaramanga 680006, Colombia; (S.L.); (A.A.); (A.R.R.B.)
| | - Eduar Pérez
- Departamento de Ingeniería Mecánica, Universidad Francisco de Paula Santander, Ocaña 546551, Colombia;
| | - Henderson I. Quintero
- Centro de Innovación y Tecnología—ICP, Ecopetrol S.A., Piedecuesta 681011, Colombia; (L.M.C.); (H.I.Q.)
| | - Arnold R. Romero Bohórquez
- Grupo de Investigación en Química Estructural (GIQUE), Escuela de Química, Universidad Industrial de Santander, Bucaramanga 680006, Colombia; (S.L.); (A.A.); (A.R.R.B.)
| | - Camilo A. Franco
- Grupo de Investigación en Fenómenos de Superficie—Michael Polanyi, Facultad de Minas, Universidad Nacional de Colombia—Sede Medellín, Medellín 050034, Colombia; (M.A.C.); (C.A.F.); (F.B.C.)
| | - Farid B. Cortés
- Grupo de Investigación en Fenómenos de Superficie—Michael Polanyi, Facultad de Minas, Universidad Nacional de Colombia—Sede Medellín, Medellín 050034, Colombia; (M.A.C.); (C.A.F.); (F.B.C.)
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Yang Y, Cao X, Ji Y, Zou R. Mechanistic Insights into a Novel Controllable Phase-Transition Polymer for Enhanced Oil Recovery in Mature Waterflooding Reservoirs. NANOMATERIALS (BASEL, SWITZERLAND) 2023; 13:3101. [PMID: 38132998 PMCID: PMC10745705 DOI: 10.3390/nano13243101] [Citation(s) in RCA: 0] [Impact Index Per Article: 0] [Reference Citation Analysis] [Abstract] [Key Words] [Grants] [Track Full Text] [Subscribe] [Scholar Register] [Received: 10/24/2023] [Revised: 11/26/2023] [Accepted: 11/26/2023] [Indexed: 12/23/2023]
Abstract
Expanding swept volume technology via continuous-phase polymer solution and dispersed-phase particle gel is an important technique to increase oil production and control water production in mature waterflooding reservoirs. However, problems such as the low viscosity retention rate, deep migration, and weak mobility control of conventional polymers, and the contradiction between migration distance of particle gel and plugging strength, restrict the long-term effectiveness of oil displacement agents and the in-depth sweep efficiency expanding capability in reservoirs. Combined with the technical advantages of polymer and particle gel, a novel controllable phase-transition polymer was developed and systematically studied to gain mechanistic insights into enhanced oil recovery for mature waterflooding reservoirs. To reveal the phase-transition mechanism, the molecular structure, morphology, and rheological properties of the controllable phase-transition polymer were characterized before and after phase transition. The propagation behavior of the controllable phase-transition polymer in porous media was studied by conducting long core flow experiments. Two-dimensional micro visualization and parallel core flooding experiments were performed to investigate the EOR mechanism from porous media to pore level. Results show that the controllable phase-transition polymer could change phase from dispersed-phase particle gel to continuous-phase solution with the prolongation of ageing time. The controllable phase-transition polymer exhibited phase-transition behavior and good propagation capability in porous media. The results of micro visualization flooding experiments showed that the incremental oil recovery of the controllable phase-transition polymer was highest when a particle gel and polymer solution coexisted, followed by a pure continuous-phase polymer solution and pure dispersed-phase particle gel suspension. The recovery rate of the novel controllable phase-transition polymer was 27.2% after waterflooding, which was 8.9% higher than that of conventional polymer, providing a promising candidate for oilfield application.
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Affiliation(s)
- Yong Yang
- Shengli Oilfield, SINOPEC, Dongying 257001, China; (Y.Y.); (X.C.); (Y.J.)
- School of Materials Science and Engineering, Peking University, Beijing 100871, China
| | - Xiaopeng Cao
- Shengli Oilfield, SINOPEC, Dongying 257001, China; (Y.Y.); (X.C.); (Y.J.)
| | - Yanfeng Ji
- Shengli Oilfield, SINOPEC, Dongying 257001, China; (Y.Y.); (X.C.); (Y.J.)
| | - Ruqiang Zou
- School of Materials Science and Engineering, Peking University, Beijing 100871, China
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Salem KG, Tantawy MA, Gawish AA, Gomaa S, El-hoshoudy A. Nanoparticles assisted polymer flooding: Comprehensive assessment and empirical correlation. GEOENERGY SCIENCE AND ENGINEERING 2023; 226:211753. [DOI: 10.1016/j.geoen.2023.211753] [Citation(s) in RCA: 4] [Impact Index Per Article: 4.0] [Reference Citation Analysis] [Track Full Text] [Subscribe] [Scholar Register] [Indexed: 07/05/2024]
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Ambaliya M, Bera A. A Perspective Review on the Current Status and Development of Polymer Flooding in Enhanced Oil Recovery Using Polymeric Nanofluids. Ind Eng Chem Res 2023. [DOI: 10.1021/acs.iecr.2c04582] [Citation(s) in RCA: 0] [Impact Index Per Article: 0] [Reference Citation Analysis] [Track Full Text] [Journal Information] [Subscribe] [Scholar Register] [Indexed: 02/05/2023]
Affiliation(s)
- Meet Ambaliya
- Department of Petroleum Engineering, School of Energy Technology, Pandit Deendayal Energy University, Gandhinagar, Gujarat 382426, India
| | - Achinta Bera
- Department of Petroleum Engineering, School of Energy Technology, Pandit Deendayal Energy University, Gandhinagar, Gujarat 382426, India
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Ulasbek K, Hashmet MR, Pourafshary P, Muneer R. Laboratory Investigation of Nanofluid-Assisted Polymer Flooding in Carbonate Reservoirs. NANOMATERIALS (BASEL, SWITZERLAND) 2022; 12:4258. [PMID: 36500880 PMCID: PMC9738682 DOI: 10.3390/nano12234258] [Citation(s) in RCA: 1] [Impact Index Per Article: 0.5] [Reference Citation Analysis] [Abstract] [Key Words] [Track Full Text] [Figures] [Subscribe] [Scholar Register] [Received: 11/02/2022] [Revised: 11/22/2022] [Accepted: 11/24/2022] [Indexed: 06/17/2023]
Abstract
In the petroleum industry, the remaining oil is often extracted using conventional chemical enhanced oil recovery (EOR) techniques, such as polymer flooding. Nanoparticles have also greatly aided EOR, with benefits like wettability alteration and improvements in fluid properties that lead to better oil mobility. However, silica nanoparticles combined with polymers like hydrolyzed polyacrylamide (HPAM) improve polymer flooding performance with better mobility control. The oil displacement and the interaction between the rock and polymer solution are both influenced by this hybrid approach. In this study, we investigated the effectiveness of the injection of nanofluid-polymer as an EOR approach. It has been observed that nanoparticles can change rock wettability, increase polymer viscosity, and decrease polymer retention in carbonate rock. The optimum concentrations for hydrolyzed polyacrylamide (2000 ppm) and 0.1 wt% (1000 ppm) silica nanoparticles were determined through rheology experiments and contact angle measurements. The results of the contact angle measurements revealed that 0.1 wt% silica nanofluid alters the contact angle by 45.6°. The nano-silica/polymer solution resulted in a higher viscosity than the pure polymer solution as measured by rheology experiments. A series of flooding experiments were conducted on oil-wet carbonate core samples in tertiary recovery mode. The maximum incremental oil recovery of 26.88% was obtained by injecting silica nanofluid followed by a nanofluid-assisted polymer solution as an EOR technique. The application of this research will provide new opportunities for hybrid EOR techniques in maximizing oil production from depleted high-temperature and high-salinity carbonate reservoirs.
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Affiliation(s)
| | - Muhammad Rehan Hashmet
- Department of Chemical and Petroleum Engineering, United Arab Emirates University, Al-Ain 15551, United Arab Emirates
| | - Peyman Pourafshary
- School of Mining and Geosciences, Nazarbayev University, Astana 010000, Kazakhstan
| | - Rizwan Muneer
- School of Mining and Geosciences, Nazarbayev University, Astana 010000, Kazakhstan
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Meng X, Zhang G, Wu J, Zhao X, Wang L, Zhang F. Experimental Study on Phenol-Formaldehyde Resin Aggregates as In-Depth Conformance Control Agents Stabilized by Polymer. Polymers (Basel) 2022; 14:polym14153159. [PMID: 35956674 PMCID: PMC9370900 DOI: 10.3390/polym14153159] [Citation(s) in RCA: 3] [Impact Index Per Article: 1.5] [Reference Citation Analysis] [Abstract] [Track Full Text] [Download PDF] [Figures] [Journal Information] [Subscribe] [Scholar Register] [Received: 07/10/2022] [Revised: 07/25/2022] [Accepted: 07/27/2022] [Indexed: 02/01/2023] Open
Abstract
To improve the dispersion stability of phenol-formaldehyde resin (PFR) particles in simulated oilfield injection water and their propagation ability in petroleum reservoir, a hydrophobically associating polymer (HAP) was employed as a stabilizer in this paper. The dispersion stability of PFR in the injection water was studied by measuring turbidity as a function of time. In addition, the migration property of the PFR/HAP dispersion was evaluated by both cellulose membrane filtration and sand packs-flooding experiments. The results show that HAP can stabilize the PFR dispersion prepared with the simulated injection water by forming PFR/HAP complex molecular aggregates. These aggregates can migrate in sand packs with strong flow resistance due to deformation or disaggregation of the aggregates when passing through the pore throat. Oil recovery was improved by up to 21.1% on the basis of water flooding, and the higher the concentration of PFR/HAP dispersion system, the better the oil recovery effect. Moreover, the cycle of log-jamming/dispersion of the aggregates leads to their penetrations through the bigger pores in the sand packs with a higher flow resistance than water. This process can improve the conformance of water in high permeability sand packs on a micro/macro scale and thus divert more water into low permeability sand packs. Therefore, more oil could be recovered from the low permeability sand packs. Moreover, the bigger the sand pack’s permeability ratio, the lower the oil recovery rate by waterflood, and the more the incremental oil can be recovered by the PFR/HAP flood.
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Affiliation(s)
- Xianxing Meng
- School of Chemistry and Chemical Engineering, Ankang University, Ankang 725000, China;
- Ankang Research Centre of New Nano-Materials Science and Technology, Ankang University, Ankang 725000, China
- Correspondence:
| | - Guiqing Zhang
- CNPC Engineering Technology Research Co., Ltd., Tianjin 300451, China;
| | - Jian Wu
- Changqing Downhole Technology CoMPany, CNPC Chuanqing Drilling Engineering Co., Ltd., Xi’an 710000, China;
| | - Xiong Zhao
- Shixi Production Plant, Xinjiang Oilfield Company, PetroChina, Karamay 834000, China;
| | - Lin Wang
- Karamay Drilling Company of CNPC Xibu Drilling Engineering Company Co., Ltd., Karamay 834000, China;
| | - Fang Zhang
- School of Chemistry and Chemical Engineering, Ankang University, Ankang 725000, China;
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Recovery Observations from Alkali, Nanoparticles and Polymer Flooding as Combined Processes. Polymers (Basel) 2022; 14:polym14030603. [PMID: 35160592 PMCID: PMC8838911 DOI: 10.3390/polym14030603] [Citation(s) in RCA: 0] [Impact Index Per Article: 0] [Reference Citation Analysis] [Abstract] [Track Full Text] [Download PDF] [Figures] [Journal Information] [Subscribe] [Scholar Register] [Received: 11/23/2021] [Revised: 01/28/2022] [Accepted: 01/31/2022] [Indexed: 12/10/2022] Open
Abstract
We have studied wettability alterations through imbibition/flooding and their synergy with interfacial tension (IFT) for alkalis, nanoparticles and polymers. Thus, the total acid number (TAN) of oil may determine the wetting-state of the reservoir and influence recovery and IFT. Data obtained demonstrate how the oil TAN number (low and high), chemical agent and reservoir mineralogy influence fluid–fluid and rock–fluid interactions. We used a laboratory evaluation workflow that combines complementary assessments such as spontaneous imbibition tests, IFT, contact angle measurements and selected core floods. The workflow evaluates wettability alteration, IFT changes and recovery when injecting alkalis, nanoparticles and polymers, or a combination of them. Dynamics and mechanisms of imbibition were tracked by analyzing the recovery change with the inverse bond number. Three sandstone types (outcrops) were used, which mainly differed in clay content and permeability. Oils with low and high TANs were used, the latter from the potential field pilot 16 TH reservoir in the Matzen field (Austria). We have investigated and identified some of the conditions leading to increases in recovery rates as well as ultimate recovery by the imbibition of alkali, nanoparticle and polymer aqueous phases. This study presents novel data on the synergy of IFT, contact angle Amott imbibition, and core floods for the chemical processes studied.
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Pryazhnikov MI, Minakov AV, Pryazhnikov AI, Denisov IA, Yakimov AS. Microfluidic Study of the Effect of Nanosuspensions on Enhanced Oil Recovery. NANOMATERIALS 2022; 12:nano12030520. [PMID: 35159865 PMCID: PMC8838448 DOI: 10.3390/nano12030520] [Citation(s) in RCA: 4] [Impact Index Per Article: 2.0] [Reference Citation Analysis] [Abstract] [Track Full Text] [Download PDF] [Figures] [Subscribe] [Scholar Register] [Received: 12/27/2021] [Revised: 01/24/2022] [Accepted: 01/28/2022] [Indexed: 01/02/2023]
Abstract
The essential advantages of microfluidic studies are the excellent visualization of the processes of oil displacement from the porous medium model, simple cleaning, and the possibility of the repeated use of the microfluidic chip. The present article deals with the process of oil displacement by suspension flooding using a microfluidic chip, simulating a porous medium, and the suspensions of silicon dioxide nanoparticles (22 nm). The mass concentration of nanoparticles in suspensions ranged from 0.1 to 2 wt%. Five mass concentrations (0.125 wt%, 0.25 wt%, 0.5 wt%, 1 wt% and 2 wt%) were considered. The article presents the experimental photographs of the oil displacement process by water and SiO2 suspension. It is shown that, with the increasing concentration of nanoparticles, the oil recovery factor increases. A significant effect is observed at 0.5 wt% concentration of nanoparticles. It is shown that the increase in oil recovery during flooding by SiO2 suspension with the maximum concentration was 16%.
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Affiliation(s)
- Maxim I. Pryazhnikov
- Department of Science and Innovation, Siberian Federal University, 660041 Krasnoyarsk, Russia; (M.I.P.); (A.I.P.); (I.A.D.); (A.S.Y.)
- Laboratory of Heat Exchange Control in Phase and Chemical Transformations, Kutateladze Institute of Thermophysics, 630090 Novosibirsk, Russia
| | - Andrey V. Minakov
- Department of Science and Innovation, Siberian Federal University, 660041 Krasnoyarsk, Russia; (M.I.P.); (A.I.P.); (I.A.D.); (A.S.Y.)
- Laboratory of Heat Exchange Control in Phase and Chemical Transformations, Kutateladze Institute of Thermophysics, 630090 Novosibirsk, Russia
- Correspondence:
| | - Andrey I. Pryazhnikov
- Department of Science and Innovation, Siberian Federal University, 660041 Krasnoyarsk, Russia; (M.I.P.); (A.I.P.); (I.A.D.); (A.S.Y.)
| | - Ivan A. Denisov
- Department of Science and Innovation, Siberian Federal University, 660041 Krasnoyarsk, Russia; (M.I.P.); (A.I.P.); (I.A.D.); (A.S.Y.)
| | - Anton S. Yakimov
- Department of Science and Innovation, Siberian Federal University, 660041 Krasnoyarsk, Russia; (M.I.P.); (A.I.P.); (I.A.D.); (A.S.Y.)
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Application of Nanoparticles for Oil Recovery. NANOMATERIALS 2021; 11:nano11051063. [PMID: 33919167 PMCID: PMC8143076 DOI: 10.3390/nano11051063] [Citation(s) in RCA: 3] [Impact Index Per Article: 1.0] [Reference Citation Analysis] [Track Full Text] [Download PDF] [Subscribe] [Scholar Register] [Received: 04/07/2021] [Accepted: 04/20/2021] [Indexed: 11/29/2022]
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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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