An Advanced Placement Approach for Chemical Sand and Fines Control Using Zeta Potential Altering Chemistry

Singh, Pratyush; Smith, Kern; Rao, Bharath

doi:10.2118/24690-ms

Cited by 8 publications

(2 citation statements)

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“…Zeta potential modifiers are generally cationic and require negatively charged formations such as sandstones, so they are not applicable in positively charged carbonate formations. , This method can be used in formations with a permeability of several millidarcies to several darcies with low risk. For this purpose, modeling can be used to find operational parameters such as type of injection, pressure, and injection rate. , …”

Section: Chemical Treatment For Sand Controlmentioning

confidence: 99%

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A Review on Chemical Sand Production Control Techniques in Oil Reservoirs

et al. 2022

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This review aims to bring together the studies on petroleum reservoirs’ sand production control in a comprehensive guide for the researcher to compare various methods for the chemical consolidation of sand. Sand production can be considered one of the major challenges in the petroleum production industry, causing severe operational issues. This study introduces various methods to control and prevent sand production in petroleum wells and evaluates their advantages and performance in tabular form. The use of chemical procedures is considered to be more efficient in counteracting the production and migration of sand. Various chemicals and polymers have been proposed for this purpose. These chemicals should increase the consolidation of the formation rock while not reducing its permeability. The complexity and simplicity of the substances will be the two main factors. Novelties are generally tied with complex chemical structures. Conversely, simplicity makes them affordable, which is essential for industrialization. Success is obtained when the two are combined. This Review is expected to allow individual experts to compare various methods and be a handbook guiding them in the pursuit of finding the appropriate method of sand control for each reservoir.

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Section: Chemical Treatment For Sand Controlmentioning

confidence: 99%

“…For this purpose, modeling can be used to find operational parameters such as type of injection, pressure, and injection rate. 104,105 Use of Nanofluids in Sand Control. Nanofluids are fluids in which small nanoparticles (particles with diameters between 1−100 nm) are dissolved.…”

Section: Application Of Chemicals For Sand Consolidationmentioning

confidence: 99%

A Review on Chemical Sand Production Control Techniques in Oil Reservoirs

et al. 2022

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Critical Conditions for Massive Fines Detachment Induced by Single-Phase Flow in Coalbed Methane Reservoirs: Modeling and Experiments

et al. 2017

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Fines migration has posed a great challenge to gas and water production in CBM reservoirs, resulting not only in dramatic permeability reduction but also in excessive wear on equipment. The objective of this study was to investigate critical flow conditions for massive fines detachment in the dewatering phase, for the purpose of yielding an improved understanding of fines detachment mechanisms and their effective control in the field. First, fines migration experiments under saturated conditions, including effluent concentration and permeability measurements, were conducted at elevated pressure gradients on fractured coal samples with various apertures. Experimental results indicate the existence of a critical pressure gradient (CPG) for massive fines detachment. Second, a mathematical model was developed to describe single particle detachment in the fracture, accounting for the coupling effects of hydrodynamic and extended-DLVO forces. Effects of fines size and fracture aperture on fines detachment were analyzed, and CPGs were determined from the proposed model. Modeling results revealed that the pressure gradient required for fines detachment first decreased with increasing fines size, reached a minimum value, and then increased; these minimum values are defined as CPGs, which exhibit a strong negative correlation with fracture aperture. CPGs obtained from modeling were slightly smaller than those determined from experiments, due to the assumptions of homogeneous surfaces and spherical particles in the model. Finally, the implications of this research on field-scale fines control in coal were thoroughly discussed.

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Consolidating Sand with New Generation Zeta Potential Altering Systems

Treybig¹,

Saini²,

Vigderman³

et al. 2016

SPE International Conference and Exhibition on Formation Damage Control

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This paper describes a new zeta potential altering system (ZPAS) that is based on an inner salt developed between an organic polymer (OP) and an ester for fines, sand and proppant flowback control. The objective of this work was to develop a ZPAS with an enhanced environmental profile and better product performance as it relates to intensity of particle agglomeration and thermal stability under wide range of downhole operating conditions. The effect of molecular weight of the organic polymer after blending with different esters on zeta potential, rheology, agglomeration, fines production, sand production, regain permeability, fracture conductivity, flash point and EC50 concentration was investigated and compared to the performance of the existing ZPAS. Zeta potential was measured using a Zetasizer Nano Z System manufactured by Malvern, rheology with Anton Paar and ARES G2, sand production with a Maximum Sand Free Rate (MSFR) Test, regain permeability with a Chandler Engineering Formation Response Tester, fracture conductivity, indentation force with a Texture Analyzer, flash point with Miniflash FLP/FLPH/FLPL and EC50 concentration with a Modern Water Microtox Model 500 Analyzer. When the organic polymer was blended with an ester, the odor was minimized substantially and toxicity reduced 400 times as compared to the current ZPAS. This organic polymer has a considerably higher molecular weight than the prior oligomeric ZPAS system. 1 This molecular weight enhancement improves the degree of agglomeration as measured by indentation testing and provides better thermal stability. Force in grams as measured with the indentation tester increased as the organic polymer concentration and molecular weight was increased in the new ZPAS formulation. The force in grams is an indicator of the effectiveness of sand consolidation. There was no sand produced at 180° F with 20/40 mesh sand and a confining pressure of 400 psi in the MSFR test. Regain permeability of 60 to 82% was obtained in low permeability sandstone. High MW ZPAS was more effective than medium MW ZPAS at 2,000 psi closure stress while medium MW ZPAS was more effective at 6,000 psi closure stress. The oscillatory rheometer indicated that the polymeric ZPAS is a Newtonian fluid which makes it easy to pump. After sand is agglomerated with the ZPAS, the agglomerated sand becomes viscoelastic. The elasticity is maintained to a temperature of at least 180°F. The stronger sand consolidation and more deformable agglomerate provided by this new generation ZPAS as compared to the current ZPAS is useful in producing more oil without incremental sand production.

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An Advanced Placement Approach for Chemical Sand and Fines Control Using Zeta Potential Altering Chemistry

Cited by 8 publications

References 0 publications

A Review on Chemical Sand Production Control Techniques in Oil Reservoirs

A Review on Chemical Sand Production Control Techniques in Oil Reservoirs

Critical Conditions for Massive Fines Detachment Induced by Single-Phase Flow in Coalbed Methane Reservoirs: Modeling and Experiments

Consolidating Sand with New Generation Zeta Potential Altering Systems

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