journal article·2026-01-27Open access

Mitigation of fine migration in low salinity water flooding of clay-rich sandstones Using Fe₃O₄/Saponin/Cu(II) nanocomposite

Kassem A. L. Attabi, Farag M. A. Altalbawy, Hana Ihsan Hassan, Ahmed Salih Sahib, Zahraa Saad Abdulali, Mariem Alwan, Mahmood Jawad, Hiba Mushtaq, Aseel Smerat, Ahmad Khalid

Discover Nano· Volume 21· Issue 1

Abstract

Fines migration is a major cause of formation damage in clay‑rich sandstones, particularly under low‑salinity waterflooding where electrostatic double‑layer expansion destabilizes clay–mineral adhesion and causes severe permeability loss. This study investigates, at the laboratory scale, the potential of a Fe₃O₄@saponin/Cu nanocomposite to mitigate fines release and permeability loss during simulated low-salinity water flooding of clay-rich sandstone. The nanocomposite was synthesized by co‑precipitating magnetite nanoparticles, coating them with a saponin biopolymer via hydrogen bonding and hydrophobic interactions, and introducing Cu 2 ⁺ through coordination with surface hydroxyl and glycosidic groups. Physicochemical characterization (FT‑IR, TGA, SEM, DLS) confirmed successful functionalization, enhanced thermal stability, controlled particle size, and colloidal stability up to 500 ppm loading. Zeta potential analysis revealed that the nanocomposite shifts mineral surface charge toward neutral or slightly positive values, reducing electrostatic repulsion between fines and the pore matrix. Core flooding of clay‑rich sandstone showed that untreated low‑salinity water caused catastrophic permeability loss (− 69.9%) and tripled injection pressure, whereas adding 500 ppm nanocomposite reduced impairment to − 4.1%, comparable to high‑salinity conditions without treatment. The mitigation mechanism involves synergistic electrostatic neutralization, steric stabilization from the saponin corona, and magnetic/coordination bridging that anchor fines to pore surfaces without plugging. These results demonstrate that Fe₃O₄@saponin/Cu nanofluid enables low‑salinity flooding while suppressing fines migration, providing a practical alternative to high‑salinity injection for enhanced oil recovery.
Source: openalex_inverted_index · Quality: baseline

Research context

OpenAlex topics: Enhanced Oil Recovery Techniques · Surface Modification and Superhydrophobicity · Pickering emulsions and particle stabilization

SciVX discovery tags are terminology-based. OpenAlex topics are source-provided classifications.

References (56)

Show source-provided references
1. Puntervold T, et al. Role of kaolinite clay minerals in enhanced oil recovery by low salinity water injection. Energy Fuels. 2018;32(7):7374–82.10.1021/acs.energyfuels.8b00790 ↗
2. Sheng JJ. Formation damage in chemical enhanced oil recovery processes. Asia-Pac J Chem Eng. 2016;11(6):826–35.10.1002/apj.2035 ↗
3. Khojastehmehr M, Madani M, Daryasafar A. Screening of enhanced oil recovery techniques for Iranian oil reservoirs using TOPSIS algorithm. Energy Rep. 2019;5:529–44.10.1016/j.egyr.2019.04.011 ↗
4. Madani M, et al. Fundamental investigation of an environmentally-friendly surfactant agent for chemical enhanced oil recovery. Fuel. 2019;238:186–97.10.1016/j.fuel.2018.10.105 ↗
5. Takassi MA, et al. The preparation of an amino acid-based surfactant and its potential application as an EOR agent. Pet Sci Technol. 2017;35(4):385–91.10.1080/10916466.2016.1238933 ↗
6. Maini B, Wassmuth F, Schramm LL. Fines Migration in Petroleum Reservoirs. In: Suspensions: Fundamentals and Applications in the Petroleum Industry. American Chemical Society; 1996. p. 321–75.
7. Moghadasi R, Rostami A, Hemmati-Sarapardeh A. Application of nanofluids for treating fines migration during hydraulic fracturing: experimental study and mechanistic understanding. Adv Geo-Energy Res. 2019;3(2):198–06.10.26804/ager.2019.02.09 ↗
8. Lemon, P., et al. Effects of injected water chemistry on waterflood sweep efficiency via induced fines migration. in SPE International Symposium on Oilfield Chemistry. 2011. OnePetro.10.2118/140141-MS ↗
9. Ouyang Z, Mayne PW. Effective stress friction angle of normally consolidated and overconsolidated intact clays from piezocone tests. Geotechn Eng J SEAGS AGSSEA. 2020;51(2):111–6.
10. Ouyang, Z. and P.W. Mayne, Effective friction angle of soft to firm clays from flat dilatometer. Proceedings of the Institution of Civil Engineers-Geotechnical Engineering, 2017. 170(2): p. 137-147.10.1680/jgeen.16.00073 ↗
11. Russell T, et al. Effects of kaolinite in rocks on fines migration. J Nat Gas Sci Eng. 2017;45:243–55.10.1016/j.jngse.2017.05.020 ↗
12. Wang Y, et al. Effect of temperature on mineral reactions and fines migration during low-salinity water injection into Berea sandstone. J Pet Sci Eng. 2021;202:108482.10.1016/j.petrol.2021.108482 ↗
13. Russell T, et al. Effects of delayed particle detachment on injectivity decline due to fines migration. J Hydrol. 2018;564:1099–109.10.1016/j.jhydrol.2018.07.067 ↗
14. Austad, T., A. RezaeiDoust, and T. Puntervold, Chemical Mechanism of Low Salinity Water Flooding in Sandstone Reservoirs, in SPE Improved Oil Recovery Symposium. 2010. p. SPE-129767-MS.10.2118/129767-MS ↗
15. Khezerloo-ye Aghdam S, Kazemi A, Ahmadi M. Theoretical and experimental study of fine migration during low-salinity water flooding: effect of brine composition on interparticle forces. SPE Reserv Eval Eng. 2023;26(02):228–43.10.2118/212852-PA ↗
16. Mansouri M, Nakhaee A, Pourafshary P. Effect of SiO2 nanoparticles on fines stabilization during low salinity water flooding in sandstones. J Pet Sci Eng. 2019;174:637–48.10.1016/j.petrol.2018.11.066 ↗
17. Habibi A, et al. Reduction of fines migration by nanofluids injection: an experimental study. SPE J. 2012;18(02):309–18.10.2118/144196-PA ↗
18. Khezerloo-ye Aghdam S, Kazemi A, Ahmadi M. Studying the effect of surfactant assisted low-salinity water flooding on clay-rich sandstones. Petroleum. 2024;10(2):306–18.10.1016/j.petlm.2023.09.006 ↗
19. Muneer R, Hashmet MR, Pourafshary P. Fine migration control in sandstones: surface force analysis and application of DLVO theory. ACS Omega. 2020;5(49):31624–39.10.1021/acsomega.0c03943 ↗
20. Khezerlooe-ye Aghdam S, et al. Mechanistic assessment of Seidlitzia Rosmarinus-derived surfactant for restraining shale hydration: A comprehensive experimental investigation. Chem Eng Res Des. 2019;147:570–8.10.1016/j.cherd.2019.05.042 ↗
21. Khezerloo-ye Aghdam S, Kazemi A, Ahmadi M. Performance evaluation of different types of surfactants to inhibit clay swelling during chemical enhanced oil recovery. Can J Chem Eng. 2024;102(1):481–94.10.1002/cjce.25028 ↗
22. Ganat T, et al. Effect of metal oxide nanoparticles on the properties of nanocomposite gels for water shutoff applications: a review. Arab J Sci Eng. 2025. https://doi.org/10.1007/s13369-025-10189-8.10.1007/s13369-025-10189-8 ↗
23. Dordzie G, Dejam M. Enhanced oil recovery from fractured carbonate reservoirs using nanoparticles with low salinity water and surfactant: a review on experimental and simulation studies. Adv Colloid Interface Sci. 2021;293:102449.10.1016/j.cis.2021.102449 ↗
24. Olayiwola SO, Dejam M. A comprehensive review on interaction of nanoparticles with low salinity water and surfactant for enhanced oil recovery in sandstone and carbonate reservoirs. Fuel. 2019;241:1045–57.10.1016/j.fuel.2018.12.122 ↗
25. Huang T, Clark DE. Enhancing oil recovery with specialized nanoparticles by controlling formation-fines migration at their sources in waterflooding reservoirs. SPE J. 2015;20(04):743–6.10.2118/166294-PA ↗
26. Ahmadi M, et al. Zeta-potential investigation and experimental study of nanoparticles deposited on rock surface to reduce fines migration. SPE J. 2013;18(03):534–44.10.2118/142633-PA ↗
27. Wan S, et al. An overview of inorganic polymer as potential lubricant additive for high temperature tribology. Tribol Int. 2016;102:620–35.10.1016/j.triboint.2016.06.010 ↗
28. Erdemir A, Martin JM. Superior wear resistance of diamond and DLC coatings. Curr Opin Solid State Mater Sci. 2018;22(6):243–54.10.1016/j.cossms.2018.11.003 ↗
29. Cao H, et al. Hydrogels: a promising therapeutic platform for inflammatory skin diseases treatment. J Mater Chem B. 2024;12(33):8007–32.10.1039/D4TB00887A ↗
30. Sui, Y., T. Guo, and G. Cao, Characteristics of sodium p-styrenesulfonate modified polyacrylamide at high temperature under dual scale boundary. Physics of Fluids, 2025. 37(7).10.1063/5.0276165 ↗
31. Belessi V, et al. Removal of reactive red 195 from aqueous solutions by adsorption on the surface of TiO2 nanoparticles. J Hazard Mater. 2009;170(2–3):836–44.10.1016/j.jhazmat.2009.05.045 ↗
32. Giammar DE, Maus CJ, Xie L. Effects of particle size and crystalline phase on lead adsorption to titanium dioxide nanoparticles. Environ Eng Sci. 2007;24(1):85–95.10.1089/ees.2007.24.85 ↗
33. Zaki MI, et al. TiO2 nanoparticle size dependence of porosity, adsorption and catalytic activity. Colloids Surf A Physicochem Eng Asp. 2011;385(1–3):195–200.10.1016/j.colsurfa.2011.06.010 ↗
34. Yang Y, et al. Review on physical and chemical factors affecting fines migration in porous media. Water Res. 2022;214:118172.10.1016/j.watres.2022.118172 ↗
35. El-Monier, I.A. and H.A. Nasr-El-Din. Mitigation of Fines Migration Using a New Clay Stabilizer: A Mechanistic Study. in SPE European Formation Damage Conference. 2011.10.2118/144180-MS ↗
36. Hou B, et al. Wettability Alteration of an Oil-Wet Sandstone Surface by Synergistic Adsorption/Desorption of Cationic/Nonionic Surfactant Mixtures. Energy Fuels. 2018;32(12):12462–8.10.1021/acs.energyfuels.8b03450 ↗
37. Dehaghani AHS, Daneshfar R. How much would silica nanoparticles enhance the performance of low-salinity water flooding? Pet Sci. 2019;16(3):591–605.10.1007/s12182-019-0304-z ↗
38. Hou B, et al. Wettability alteration of oil-wet carbonate surface induced by self-dispersing silica nanoparticles: Mechanism and monovalent metal ion’s effect. J Mol Liq. 2019;294:111601.10.1016/j.molliq.2019.111601 ↗
39. Yue L, et al. Insights into mechanism of low salinity water flooding in sandstone reservoir from interfacial features of oil/brine/rock via intermolecular forces. J Mol Liq. 2020;313:113435.10.1016/j.molliq.2020.113435 ↗
40. Tariq Z, et al. Novel gemini surfactant as a clay stabilizing additive in fracturing fluids for unconventional tight sandstones: Mechanism and performance. J Petrol Sci Eng. 2020;195:107917.10.1016/j.petrol.2020.107917 ↗
41. Li, X., et al., A Thermo-Stable Polymeric Surfactant for Enhanced Heavy Oil Recovery via Hot Water Chemical Flooding. Langmuir, 2025.10.2139/ssrn.5213922 ↗
42. Aghdam SK-y, Kazemi A, Ahmadi M. Studying the effect of various surfactants on the possibility and intensity of fine migration during low-salinity water flooding in clay-rich sandstones. Results Eng. 2023;18:101149.10.1016/j.rineng.2023.101149 ↗
43. Wen P, et al. Multiobjective optimization of a pressure maintaining ball valve structure based on RSM and NSGA-II. Sci Rep. 2025;15(1):21342.10.1038/s41598-025-02158-w ↗
44. Madadizadeh A, Sadeghein A, Riahi S. The use of nanotechnology to prevent and mitigate fine migration: a comprehensive review. Rev Chem Eng. 2022;38(1):1–16.10.1515/revce-2019-0055 ↗
45. Cha M-H, et al. Proteomic identification of macrophage migration-inhibitory factor upon exposure to TiO2 particles. Mol Cell Proteomics. 2007;6(1):56–63.10.1074/mcp.M600234-MCP200 ↗
46. Yan Z, et al. Effects of CO2 pressure on the dynamic wettability of the kerogen surface: insights from a molecular perspective. Appl Surf Sci. 2025;694:162822.10.1016/j.apsusc.2025.162822 ↗
47. Huang, T., J.B. Crews, and J.R. Willingham. Nanoparticles for formation fines fixation and improving performance of surfactant structure fluids. European Association of Geoscientists & Engineers.
48. Yan, J., et al., Highly sulfur-doped porous carbon enhances sodium-ion storage with superior rate capability and long cycling stability. Journal of Materials Science, 2025: p. 1–13.
49. Liu G, Wei X, Hou Z. A multiscale comprehensive index for evaluating the development level of surface granite discontinuities. PLoS ONE. 2025;20(5):e0323393.10.1371/journal.pone.0323393 ↗
50. Chen L, et al. Mechanism of sodium tripolyphosphate inhibiting the syneresis of HPAM hydrogel. RSC Adv. 2015;5(103):84872–8.10.1039/C5RA19465B ↗
51. Sun F, et al. Effect of composition of HPAM/Chromium(III) acetate gels on delayed gelation time. J Dispersion Sci Technol. 2016;37(6):753–9.10.1080/01932691.2015.1041034 ↗
52. Jia H, et al. Research on the gelation performance of low toxic PEI cross-linking PHPAM gel systems as water shutoff agents in low temperature reservoirs. Ind Eng Chem Res. 2010;49(20):9618–24.10.1021/ie100888q ↗
53. Arabloo M, Pordel SM, Zamani M. Characterization of colloidal gas aphron-fluids produced from a new plant-based surfactant. J Dispers Sci Technol. 2013;34(5):669–78.10.1080/01932691.2012.683989 ↗
54. Heidarpour M, et al. New magnetic nanocomposite Fe3O4@Saponin/Cu(II) as an effective recyclable catalyst for the synthesis of aminoalkylnaphthols via Betti reaction. Steroids. 2023;191:109170.10.1016/j.steroids.2022.109170 ↗
55. Aghdam SK-y, Kazemi A, Ahmadi M. A laboratory study of a novel bio-based nonionic surfactant to mitigate clay swelling. Petroleum. 2021;7(2):178–87.10.1016/j.petlm.2020.09.002 ↗
56. Sharifi O, et al. Laboratory study of the application of a novel bio-based polymer to synthesize aphron drilling fluids. J Pet Sci Technol. 2022;12(2):42–50.