A Rheological Model for pH-Sensitive Ionic Polymer Solutions for Optimal Mobility Control Applications

2005 ◽  
Author(s):  
Chun Huh ◽  
Suk Kyoon Choi ◽  
Mukul Mani Sharma
Keyword(s):  
Rheological Model ◽  
Polymer Solutions ◽  
Ph Sensitive ◽  
Mobility Control ◽  
Control Applications ◽  
Ionic Polymer

Transport of a pH-Sensitive Polymer in Porous Media for Novel Mobility-Control Applications

2006 ◽  
Author(s):  
Choi Suk Kyoon ◽  
Youn Mee Ermel ◽  
Steven Lawrence Bryant ◽  
Chun Huh ◽  
Mukul Mani Sharma
Keyword(s):  
Porous Media ◽  
Ph Sensitive ◽  
Mobility Control ◽  
Control Applications ◽  
Ph Sensitive Polymer

Factors Influencing Mobility Control By Polymer Solutions

1971 ◽  
Vol 23 (03) ◽  
pp. 391-401 ◽  
Author(s):  
R.R. Jennings ◽  
J.H. Rogers ◽  
T.J. West
Keyword(s):  
Polymer Solutions ◽  
Mobility Control ◽  
Factors Influencing

scholarly journals Ionic Polymer Solutions

Kobunshi ◽  
1998 ◽  
Vol 47 (1) ◽  
pp. 24-25
Author(s):  
Norio ISE
Keyword(s):  
Polymer Solutions ◽  
Ionic Polymer

Laboratory Investigations of Factors Influencing Polymer Flood Performance

1975 ◽  
Vol 15 (04) ◽  
pp. 338-346 ◽  
Author(s):  
M.T. Szabo
Keyword(s):  
Oil Recovery ◽  
Polymer Solutions ◽  
Polymer Concentration ◽  
Polymer Flooding ◽  
Mobility Control ◽  
Sweep Efficiency ◽  
Experimental Conditions ◽  
Polymer Injection ◽  
Polymer Flood

Abstract Numerous polymer floods were performed in unconsolidated sand packs using a C14-tagged, cross-linked, partially hydrolyzed ployacrylamide, and the data are compared with brine-flood performance in the same sands. performance in the same sands. The amount of "polymer oil" was linearly proportional to polymer concentration up to a proportional to polymer concentration up to a limiting value. The upper limit of polymer concentration yielding additional polymer oil was considerably higher for a high-permeability sand than for a low-permeability sand. It is shown that a minimum polymer concentration exists, below which no appreciable polymer oil can be produced in high-permeability sands. The effect of polymer slug size on oil recovery is shown for various polymer concentrations, and the results from these tests are used to determine the optimum slug size and polymer concentration for different sands. The effect of salinity was studied by using brine and tap water during polymer floods under similar conditions. Decreased salinity resulted in improved oil recovery at low, polymer concentrations, but it had little effect at higher polymer concentrations. Polymer injection that was started at an advanced stage of brine flood also improved the oil recovery in single-layered sand packs. Experimental data are presented showing the effect of polymer concentration and salinity on polymer-flood performance in stratified reservoir polymer-flood performance in stratified reservoir models. Polymer concentrations in the produced water were measured by analyzing the radioactivity of effluent samples, and the amounts of retained polymer in the stratified models are given for each polymer in the stratified models are given for each experiment. Introduction In the early 1960's, a new technique using dilute polymer solutions to increase oil recovery was polymer solutions to increase oil recovery was introduced in secondary oil-recovery operations. Since then, this new technique has attained wide-spread commercial application. The success and the complexity of this new technology has induced many authors to investigate many aspects of this flooding technique. Laboratory and field studies, along with numerical simulation of polymer flooding, clearly demonstrated that polymer additives increase oil recovery. polymer additives increase oil recovery. Some of the laboratory results have shown that applying polymers in waterflooding reduces the residual oil saturation through an improvement in microscopic sweep efficiency. Other laboratory studies have shown that applying polymer solutions improves the sweep efficiency in polymer solutions improves the sweep efficiency in heterogeneous systems. Numerical simulation of polymer flooding, and a summary of 56 field applications, clearly showed that polymer injection initiated at an early stage of waterflooding is more efficient than when initiated at an advanced stage. Although much useful information has been presented, the experimental conditions were so presented, the experimental conditions were so variable that difficulties arose in correlating the numerical data. So, despite this good data, a systematic laboratory study of the factors influencing the performance of polymer flooding was still lacking in the literature. The purpose of this study was to investigate the effect of polymer concentration, polymer slug size, salinity in the polymer bank, initial water saturation, and permeability on the performance of polymer floods. The role of oil viscosity did not constitute a subject of this investigation. However, some of the data indicated that the applied polymer resulted in added recovery when displacing more viscous oil. The linear polymer-flood tests were coupled with tests in stratified systems, consisting of the same sand materials used in linear flood tests. Thus, it was possible to differentiate between the role of polymer in mobility control behind the flood front in each layer and its role in mobility control in the entire stratified system through improvement in vertical sweep efficiency. A radioactive, C14-tagged hydrolyzed polyacrylamide was used in all oil-recovery tests. polyacrylamide was used in all oil-recovery tests. SPEJ P. 338

Laboratory Study of Polymer Solutions Used for Mobility Control During In Situ NAPL Recovery

1998 ◽  
Vol 18 (3) ◽  
pp. 103-113 ◽  
Author(s):  
K. E. Martel ◽  
R. Martel ◽  
R. Lefebvre ◽  
P. J. Gélinas
Keyword(s):  
Laboratory Study ◽  
Polymer Solutions ◽  
Mobility Control

Mobility Control With Polymer Solutions

1967 ◽  
Vol 7 (02) ◽  
pp. 161-173 ◽  
Author(s):  
W.B. Gogarty
Keyword(s):  
Polymer Solution ◽  
Polymer Solutions ◽  
Control Mechanism ◽  
The United States ◽  
Mobility Control ◽  
High Shear ◽  
Polymer Flow ◽  
Shear Rates ◽  
High Shear Rates ◽  
Secondary Recovery

Abstract With the use of polymer solutions in secondary recovery operations, the need has developed to understand the mobility control mechanism. This study investigated mobility control by considering both permeability and rheological effects. Experiments used a high molecular weight, partially hydrolyzed polyacrylamide polymer. Flow studies took place in reservoir and Berea cores having zero oil saturation. Effective size of the polymer flow unit was inferred from Nuclepore filter tests. Clay studies indicated the particle size capable of decreasing the core permeability. Flushed permeabilities measured the approximate core permeabilities with flowing polymer solutions. These permeabilities were considerably lower than original values. With mobility data and the flushed permeability, maximum effective viscosities were determined for polymer solution flow in a core. Effective viscosities showed that rheological properties play an important part in mobility control with polymer solutions. The study showed that permeabilities decrease and stabilize with polymer flow. At the lower permeabilities, high shear rates exist in the cores. Because of the pseudoplastic character of the polymer solution, the high shear rates caused low effective viscosities. This condition pointed to the inefficient use of the potentially high viscosity of the polymer solution at low shear rates. Introduction In the oil industry, a great deal of interest is being shown in the use of polymer solutions for secondary recovery and a number of polymer floods are being performed in the United States. Some of these floods have become commercial while others have been reported as failures. A number of floods are still in progress and remain to be evaluated. With the advent of polymer flooding, the need developed to understand the mobility control mechanism in porous media.

Shear Degradation of Partially Hydrolyzed Polyacrylamide Solutions

1975 ◽  
Vol 15 (04) ◽  
pp. 311-322 ◽  
Author(s):  
J.M. Maerker
Keyword(s):  
Oil Recovery ◽  
Polymer Solutions ◽  
Significant Loss ◽  
Mobility Control ◽  
Mechanical Degradation ◽  
Elastic Solids ◽  
Shear Degradation ◽  
Flow Through ◽  
Hydrolyzed Polyacrylamide ◽  
Mobility Reduction

Abstract Partially hydrolyzed polyacrylamide solutions are highly shear degradable and may lose much of their effectiveness in reducing water mobility when sheared by flow through porous rock in the vicinity of an injection well. Degradation is investigated by forcing polymer solutions, prepared in brines of various salinities, through consolidated sandstone plugs differing in length and permeability, over a plugs differing in length and permeability, over a wide range of flow rates. A correlation for degradation based on a theoretical viscoelastic fluid model is developed that extends predictive capability to situations not easily reproduced in the laboratory. Mobility-reduction losses in field cores at reservoir flow rates are measured following degradation and are found to depend strongly on formation permeability. Consideration of field applications shows that injection into typical wellbore geometries can lead to more than an 80-percent loss of the mobility reduction provided by undegraded solutions. Also discussed are consequences for incremental oil recovery and the possibility of injecting through propped fractures. possibility of injecting through propped fractures Introduction Susceptibility of commercially available, partially hydrolyzed polyacrylamides to mechanical, or shear, degradation represents a serious problem regarding their applicability as mobility-control fluids for secondary and tertiary oil recovery applications. The approach taken in this work assumes that surface handling equipment in the field (pumps, flow controllers, etc.) have been adequately designed to minimize effects of shear degradation in all operations preceding actual delivery of the polymer solution to the sand face. The remaining problem is to assess the mechanical degradation a polymer solution experiences when it enters the porous matrix at the high fluxes prevailing around injection wells. Ability to predict the degree of mobility-control loss based on a laboratory investigation of the relevant parameters is desirable. White et al. were the first to attempt prediction of matrix-induced degradation, but the result was only a recommended injection-rate limit for minimizing polymer degradation for two specific wellbore completions. More recent papers offer limited data supporting the contention that matrix-induced degradation of polyacrylamide solutions results in significant loss polyacrylamide solutions results in significant loss of mobility control . This paper investigates the cause of mechanical degradation in dilute polymer solutions and presents experimental data on the effects of polymer concentration, water salinity, permeability, flow rate, and flow distance. permeability, flow rate, and flow distance. Several interesting and unexpected conclusions are drawn from the results. BACKGROUND - THEORETICAL CONCEPT The mechanical degradation of polymer solutions occurs when fluid stresses developed during deformation, or flow, become large enough to break the polymer molecular chains. Historically, the feeling has been that shearing stresses in laminar shear flow or turbulent pipe flow were responsible for chain scission. However, recent data reported by Culter et al. suggest that degradation of viscoelastic polymer solutions in capillary tubes may be dominated by large elongational or normal caresses occurring at the entrance to the squared-off capillaries. Such stresses result from Lagrangian unsteady flow, or elongational deformation, at the tube entrance. Flow through porous media also generates velocity fields that are sufficiently unsteady, in the Lagrangian sense, to lead one to anticipate large viscoelastic normal stresses. Viscoelastic fluids are materials that behave like viscous liquids at low rates of deformation and partially like elastic solids at high rates of partially like elastic solids at high rates of deformation. Several constitutive models are available for describing the stress-strain behavior of such fluids. SPEJ P. 311

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