Evaluation of Polymeric Materials for Chemical Enhanced Oil Recovery

Scott, Alison J.; Romero‐Zerón, Laura; Penlidis, Alexander

doi:10.3390/pr8030361

Cited by 75 publications

(73 citation statements)

References 142 publications

(555 reference statements)

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“…This work serves as a complementary review article to some recent publications by [ 16 , 22 , 32 , 131 , 132 ]. Based on the report presented by [ 22 ] and other modifications to obtain salinity tolerance [ 15 , 39 , 78 , 133 , 134 ], we have summarized, in detail, the concise chemistry conditions behind the application of these polymeric materials.…”

Section: Summary Of Comparisonmentioning

confidence: 97%

“…In contrast to HPAM, XG is thermally stable with good resistance to hardness and good salt compatibility. However, it is also biodegradable and has a potential plugging effect when applied in excess [ 32 ]. In regards to its biodegradability, a study by [ 33 , 34 ] has shown that salt-tolerant (aerobic and anaerobic) microorganisms can degrade XG, causing it to lose its viscosity strength.…”

Section: Polyacrylamides and Polysaccharidesmentioning

confidence: 99%

“…Kamal et al [ 11 ] and Scott et al [ 32 ] have provided brief overviews of the rheological properties of HPAM across various parameters, including changes in polymer concentration, temperature, and salt. Changes in polymer concentration indicate that with a higher concentration of HPAM polymer, the effect of shear rate becomes more evident (see Figure 11 ) on the decline in viscosity of the solution, as observed with the case of 5000 ppm concentration.…”

Section: Physical and Chemical Characteristics Of Green Polymers Omentioning

confidence: 99%

“…However, this field of application is largely based on the condition of the reservoir and many unforeseen circumstances could arise during production. To this effect, we have presented summarized data for field conditions in polymer application, specifically related to XG and HPAM ( Table 5 ), based on the study by [ 64 , 65 ] with recent modifications from [ 32 ]. In addition to this, a summary of some key parameters for field cases where XG and HPAM have been implemented especially in sandstone reservoir is presented in Table 6 .…”

Section: Conditions For Polymer Applicationsmentioning

confidence: 99%

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Comparative Study of Green and Synthetic Polymers for Enhanced Oil Recovery

et al. 2020

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Several publications by authors in the field of petrochemical engineering have examined the use of chemically enhanced oil recovery (CEOR) technology, with a specific interest in polymer flooding. Most observations thus far in this field have been based on the application of certain chemicals and/or physical properties within this technique regarding the production of 50–60% trapped (residual) oil in a reservoir. However, there is limited information within the literature about the combined effects of this process on whole properties (physical and chemical). Accordingly, in this work, we present a clear distinction between the use of xanthan gum (XG) and hydrolyzed polyacrylamide (HPAM) as a polymer flood, serving as a background for future studies. XG and HPAM have been chosen for this study because of their wide acceptance in relation to EOR processes. To this degree, the combined effect of a polymer’s rheological properties, retention, inaccessible pore volume (PV), permeability reduction, polymer mobility, the effects of salinity and temperature, and costs are all investigated in this study. Further, the generic screening and design criteria for a polymer flood with emphasis on XG and HPAM are explained. Finally, a comparative study on the conditions for laboratory (experimental), pilot-scale, and field-scale application is presented.

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Section: Summary Of Comparisonmentioning

confidence: 97%

Section: Polyacrylamides and Polysaccharidesmentioning

confidence: 99%

Section: Physical and Chemical Characteristics Of Green Polymers Omentioning

confidence: 99%

Section: Conditions For Polymer Applicationsmentioning

confidence: 99%

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Comparative Study of Green and Synthetic Polymers for Enhanced Oil Recovery

et al. 2020

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“…Also, it is well‐known that reservoirs at high temperatures can promote fast, severe thermal degradation of polymer molecules. [ 75 ]…”

Section: Case Studies: Demonstrating the Design Frameworkmentioning

confidence: 99%

Design of polymeric materials: Experiences and prescriptions

Scott

Penlidis

2020

Can J Chem Eng

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As process engineering has matured, research interest has shifted towards polymer product quality. In the past 20 years or so, the shift has progressed even further, as interest in polymer product quality has morphed into polymer product design. Product design is intended to be a targeted pursuit of optimal conditions that will yield polymers with desirable properties for a specific application. This can be achieved by following a systematic design framework that employs sequential, iterative steps informed by prior knowledge and experience. This overview provides some background information regarding the

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Behavior study of a thermo‐responsive hydrophobically associative water‐soluble terpolymer in laboratory test with heavy crude oil

Torres‐Martínez

Pérez-Álvarez²,

Jiménez‐Regalado³

et al. 2022

J of Applied Polymer Sci

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In this work, a thermo‐responsive hydrophobically associative water‐soluble terpolymer was prepared and evaluated as polymer flooding in laboratory tests versus a heavy crude oil from a carbonated reservoir in southern Mexico. Terpolymer of acrylamide, N‐isopropylacrylamide and N,N′‐dihexylacrylamide were synthesized via micellar free radical polymerization. Reaction was carried out at 50°C using sodium dodecyl sulfonate as surfactant and 4‐(4′‐azobis)cyanovaleric acid as initiator. The terpolymer was characterized by nuclear magnetic resonance. Steady shear viscosity of polymer solutions at different concentrations was determined in the presence of NaCl (from 1 to 5 wt%) at different temperatures (from 25 to 120°C). Heavy crude oil sample was characterized and revealed a viscosity of 2. 26 Pa s, 10.21° API with a content of Saturates, Aromatics, Resins, Asphaltenes of 26.4, 38.5, 22.3, and 12.8, respectively. The crude oil recovery of polymer at 2 and 3 wt% revealed a surface tensions of 49.6 and 48.2 mN × m and adsorption capacities of 1.33 and 1.77 wt%. Finally, polymer solutions at 2 and 3 wt% showed a contact angle between 29.6 and 26.5° and a crude oil recovery of 68.3 and 75.3%, respectively.

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Evaluation of Polymeric Materials for Chemical Enhanced Oil Recovery

Cited by 75 publications

References 142 publications

Comparative Study of Green and Synthetic Polymers for Enhanced Oil Recovery

Comparative Study of Green and Synthetic Polymers for Enhanced Oil Recovery

Design of polymeric materials: Experiences and prescriptions

Behavior study of a thermo‐responsive hydrophobically associative water‐soluble terpolymer in laboratory test with heavy crude oil

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