SiO2-g-Poly(sulfobetaine methacrylate) Inorganic–Organic Hybrids as Fracturing Fluids Under Harsh Reservoir Conditions
- 1School of Energy, China University of Geosciences (Beijing), Beijing 100190, China
- 2Shengli Oilfield Oil Development Center Co., Ltd., Dongying 257100, China
- 3Academy of Science and Technology, China University of Petroleum (East China), Dongying 257061, China
Abstract
Zwitterionic polymer-grafted inorganic nanoparticles have emerged as promising functional additives for hydraulic fracturing fluids under harsh reservoir conditions, yet achieving precise control over graft chain length and understanding its structure–performance relationship remain challenging. Herein, well-defined SiO2-g-poly(sulfobetaine methacrylate) (SiO2-g-PSBMA) inorganic–organic hybrid nanoparticles with tunable chain lengths were synthesized via surface-initiated atom-transfer radical polymerization (SI-ATRP) at 80 °C. The number-average molecular weight (Mn) of the grafted PSBMA chains was precisely tuned from 3.1 to 14.2 kg mol−1 with narrow dispersity (Đ = 1.64–1.78), and the corresponding grafting density was calculated to range from 0.12 to 0.45 chains nm−2 by combining TGA, GPC, and BET analyses. Interfacial tension measurements showed that the SiO2-g-PSBMA14k fluid reduced the oil–water interfacial tension from 28 to 5.1 mN m−1 at 90 °C and retained effective tension reduction (7.8 mN m−1) even at 20 wt% NaCl. Rock-adsorption studies on tight sandstone revealed that longer graft chains achieved a higher saturated adsorption capacity of 2.1 mg g−1. Core-flooding experiments using natural Xujiahe tight sandstone cores at 90 °C demonstrated that the SiO2-g-PSBMA14k fracturing fluid at an optimal concentration of 1.0 g L−1 achieved ultimate oil recovery (Roil) of approximately 41% for low-permeability cores (D = 5.1 × 103 μm2) and approximately 52% for higher-permeability cores (D = 112.5 × 103 μm2). These results establish the chain-length-dependent structure–performance relationship of SiO2-g-PSBMA hybrids under simulated reservoir conditions (up to 90 °C and 20 wt% NaCl) and provide guidance for the rational design of zwitterionic nanofluid additives for fracturing applications.
Related
- Numerical study on infill fracturing of mature wells under free-drainage boundary conditions
- Hydrogen Atom Transfer-Triggered Chemical Recycling of Commercial Poly(methyl methacrylate) Utilizing Continuous Monomer Removal.
- Systematic Design and Synthesis of Methacrylate- and Trimethoxysilane-Functionalized POSS and DDSQ Nanostructures
- Biobased Pressure-Sensitive Adhesives from Tulipalin A and Lauryl Methacrylate Synthesized via PhotoATRP
- Crosslinked Poly(methyl Methacrylate) Bone Cement Reinforced with a Bioactive Calcium–Olsalazine Metal–Organic Framework
BibTeX
@article{huang2026sio2gpolysulfobetaine,
title = {{SiO2-g-Poly(sulfobetaine methacrylate) Inorganic–Organic Hybrids as Fracturing Fluids Under Harsh Reservoir Conditions}},
author = {Cheng Huang and Hongyi Li and Xuefeng Gong},
journal = {Polymers},
year = {2026},
month = oct,
doi = {10.3390/polym18202497},
url = {https://www.mdpi.com/2073-4360/18/20/2497},
note = {CC BY 4.0},
}
RIS
TY - JOUR
TI - SiO2-g-Poly(sulfobetaine methacrylate) Inorganic–Organic Hybrids as Fracturing Fluids Under Harsh Reservoir Conditions
AU - Cheng Huang
AU - Hongyi Li
AU - Xuefeng Gong
PY - 2026
DA - 2026/10/01
JO - Polymers
DO - 10.3390/polym18202497
UR - https://www.mdpi.com/2073-4360/18/20/2497
AB - Zwitterionic polymer-grafted inorganic nanoparticles have emerged as promising functional additives for hydraulic fracturing fluids under harsh reservoir conditions, yet achieving precise control over graft chain length and understanding its structure–performance relationship remain challenging. Herein, well-defined SiO2-g-poly(sulfobetaine methacrylate) (SiO2-g-PSBMA) inorganic–organic hybrid nanoparticles with tunable chain lengths were synthesized via surface-initiated atom-transfer radical polymerization (SI-ATRP) at 80 °C. The number-average molecular weight (Mn) of the grafted PSBMA chains was precisely tuned from 3.1 to 14.2 kg mol−1 with narrow dispersity (Đ = 1.64–1.78), and the corresponding grafting density was calculated to range from 0.12 to 0.45 chains nm−2 by combining TGA, GPC, and BET analyses. Interfacial tension measurements showed that the SiO2-g-PSBMA14k fluid reduced the oil–water interfacial tension from 28 to 5.1 mN m−1 at 90 °C and retained effective tension reduction (7.8 mN m−1) even at 20 wt% NaCl. Rock-adsorption studies on tight sandstone revealed that longer graft chains achieved a higher saturated adsorption capacity of 2.1 mg g−1. Core-flooding experiments using natural Xujiahe tight sandstone cores at 90 °C demonstrated that the SiO2-g-PSBMA14k fracturing fluid at an optimal concentration of 1.0 g L−1 achieved ultimate oil recovery (Roil) of approximately 41% for low-permeability cores (D = 5.1 × 103 μm2) and approximately 52% for higher-permeability cores (D = 112.5 × 103 μm2). These results establish the chain-length-dependent structure–performance relationship of SiO2-g-PSBMA hybrids under simulated reservoir conditions (up to 90 °C and 20 wt% NaCl) and provide guidance for the rational design of zwitterionic nanofluid additives for fracturing applications.
SN - 2073-4360
ER -