Abstract:High molecular weight polymers used for heavy oil recovery exhibit viscoelasticity that can influence the oil recovery during chemical enhanced oil recovery. Different polymers having similar molecular weight and shear rheology may have different elongation flow behavior depending on their extensional properties. Displacing slugs are more likely to stretch than shear in tortuous porous media. Therefore, it is critical to seek an analytical tool that can characterize extensional parameters to improve polymer se… Show more
“…HAAKE CaBER (Thermo Scientific, USA) was used for characterizing the extensional properties of EOR polymers. The details about the CaBER experimentation can be found elsewhere [1] , [4] , [5] , [6] . The typical filament drainage schematic [4] during CaBER experimentation is shown in Fig.…”
Section: Experimental Design Materials and Methodsmentioning
confidence: 99%
“…2 (a)– 15 (a). Theories used to determine the extensional rheological data are briefed here, however, more details can be found in our previous publications [1] , [4] , [5] , [6] . Fig.…”
Section: Experimental Design Materials and Methodsmentioning
In this article, extensional rheological data of various polymer solutions, to be used in Azad Trivedi viscoelastic model (AT-VEM) for predicting the viscoelastic behavior of synthetic polymer in porous media are provided. Extensional rheology measurements are performed for different polymer solutions using Capillary breakup extensional Rheometer (CaBER) to obtain the filament diameter with respect to time. Extensional rheological parameters, such as the extensional relaxation time, maximum elongational viscosity at the critical Deborah number and strain hardening index are determined from observed filament diameter with time-based on the Upper Convected Maxwell model, the finite extensible non-linear elastic model, and the power law model.
“…HAAKE CaBER (Thermo Scientific, USA) was used for characterizing the extensional properties of EOR polymers. The details about the CaBER experimentation can be found elsewhere [1] , [4] , [5] , [6] . The typical filament drainage schematic [4] during CaBER experimentation is shown in Fig.…”
Section: Experimental Design Materials and Methodsmentioning
confidence: 99%
“…2 (a)– 15 (a). Theories used to determine the extensional rheological data are briefed here, however, more details can be found in our previous publications [1] , [4] , [5] , [6] . Fig.…”
Section: Experimental Design Materials and Methodsmentioning
In this article, extensional rheological data of various polymer solutions, to be used in Azad Trivedi viscoelastic model (AT-VEM) for predicting the viscoelastic behavior of synthetic polymer in porous media are provided. Extensional rheology measurements are performed for different polymer solutions using Capillary breakup extensional Rheometer (CaBER) to obtain the filament diameter with respect to time. Extensional rheological parameters, such as the extensional relaxation time, maximum elongational viscosity at the critical Deborah number and strain hardening index are determined from observed filament diameter with time-based on the Upper Convected Maxwell model, the finite extensible non-linear elastic model, and the power law model.
“…This rheometer separated the end plates at an exponential rate resulting in a constant deformation rate. Another common device for relaxation time measurements is the capillary break-up extensional rheometer (CaBER™) [ 27 , 78 , 79 ]. A schematic sketch of the measurement with a CaBER™ can be seen in Figure 9 .…”
Section: Viscoelasticity In Enhanced Oil Recoverymentioning
Polymer flooding most commonly uses partially hydrolyzed polyacrylamides (HPAM) injected to increase the declining oil production from mature fields. Apart from the improved mobility ratio, also the viscoelasticity-associated flow effects yield additional oil recovery. Viscoelasticity is defined as the ability of particular polymer solutions to behave as a solid and liquid simultaneously if certain flow conditions, e.g., shear rates, are present. The viscoelasticity related flow phenomena as well as their recovery mechanisms are not fully understood and, hence, require additional and more advanced research. Whereas literature reasonably agreed on the presence of these viscoelastic flow effects in porous media, there is a significant lack and discord regarding the viscoelasticity effects in oil recovery. This work combines the information encountered in the literature, private reports and field applications. Self-gathered laboratory data is used in this work to support or refuse observations. An extensive review is generated by combining experimental observations and field applications with critical insights of the authors. The focus of the work is to understand and clarify the claims associated with polymer viscoelasticity in oil recovery by improvement of sweep efficiency, oil ganglia mobilization by flow instabilities, among others.
“…In chemical EOR, different chemicals, such as polymers, surfactants, nanoparticles, and alkaline, are introduced to enhance oil recovery. Polymers tend to enhance the viscosity of the introduced water and increase the mobility ratio [17][18][19]. Alkalis are injected to reduce the surfactant adsorption and form surfactant inside the reservoir.…”
Long-term thermal stability of surfactants under harsh reservoir conditions is one of the main challenges for surfactant injection. Most of the commercially available surfactants thermally degrade or precipitate when exposed to high-temperature and high-salinity conditions. In this work, we designed and synthesized three novel betaine-based polyoxyethylene zwitterionic surfactants containing different head groups (carboxybetaine, sulfobetaine, and hydroxysulfobetaine) and bearing an unsaturated tail. The impact of the surfactant head group on the long-term thermal stability, foam stability, and surfactant–polymer interactions were examined. The thermal stability of the surfactants was assessed by monitoring the structural changes when exposed at high temperature (90 °C) for three months using 1H-NMR, 13C-NMR, and FTIR analysis. All surfactants were found thermally stable regardless of the headgroup and no structural changes were evidenced. The surfactant–polymer interactions were dominant in deionized water. However, in seawater, the surfactant addition had no effect on the rheological properties. Similarly, changing the headgroup of polyoxyethylene zwitterionic surfactants had no major effect on the foamability and foam stability. The findings of the present study reveal that the betaine-based polyoxyethylene zwitterionic surfactant can be a good choice for enhanced oil recovery application and the nature of the headgroup has no major impact on the thermal, rheological, and foaming properties of the surfactant in typical harsh reservoir conditions (high salinity, high temperature).
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