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Article Type

Research Paper

Corresponding Author

Imamaddin Karimov

Highlights

Polymer–nano-silica consolidation was evaluated using lab tests and transport modeling in unconsolidated reservoir sand.

UCS increased up to 2670 psi, while permeability retention decreased due to partial pore blockage, defining a strength–flow trade-off.

An optimum formulation (0.5 wt.% polymer + 0.2 wt.% nano-silica) achieved UCS >2000 psi, permeability retention >70%, and sand retention ≥95%.

Under oil–N2multiphase flow, treated packs showed

Model predictions matched UCS and permeability within ±10%, and SEM supported polymer–nano-silica grain-bridging features.

Abstract

The objective of this study is to assess advanced polymer-nanoparticle systems for sand consolidation in unconsolidated reservoirs, particularly under multiphase flow conditions relevant to Azerbaijan and the Caspian region. The study aims to evaluate the impact of polymer types, nanoparticle concentrations, and operational parameters on mechanical strength, permeability retention, and overall sand control effectiveness, providing practical guidance for optimal sand consolidation treatments. A combined experimental and numerical simulation approach was employed. Laboratory experiments involved preparing sandpacks treated with varying concentrations of polymer-nanoparticle solutions, followed by evaluating uniaxial compressive strength (UCS), permeability retention, and sand retention efficiency under multiphase (oil and nitrogen gas) flow conditions. Scanning Electron Microscopy (SEM) analyses provided insights into microstructural characteristics. Numerical modeling was conducted using COMSOL Multiphysics software to simulate consolidant transport, penetration, and consolidation processes, with results validated against laboratory findings. The study found that increasing polymer and nanoparticle concentrations significantly enhanced mechanical strength (UCS up to 2670 psi) but negatively impacted permeability retention at higher concentrations due to pore blockage. An optimal formulation of 0.5 wt.% polymer and 0.2 wt.% nanoparticles achieved over 2000 psi UCS while maintaining permeability retention above 70%. Under simulated multiphase flow, this formulation demonstrated stable differential pressure profiles and negligible sand production (

Keywords

Sand consolidation; polymer-nanoparticle system; Multiphase flow; permeability retention; unconsolidated reservoir

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