Temperature-dependent viscosity model of HPAM polymer through high-temperature reservoirs

Choi, ByungIn; Jeong, Moon Sik; Lee, Kun Sang

doi:10.1016/j.polymdegradstab.2014.09.006

Cited by 63 publications

(30 citation statements)

References 5 publications

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“…Choi et al successfully developed an in-situ rheological model for high temperature porous media [30]. Through this model, it may minimize potential problems resulting from underestimation of laboratory calculations compared to in-situ observations.…”

Section: Temperaturementioning

confidence: 99%

Polyhydroxybutyrate for Improved Oil Recovery: A Literature Review

2016

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In this study the role of polymer flooding as one of the most efficient processes to enhance oil recovery (EOR) is discussed. Polyhydroxybutyrate (PHB) is a bio-based polymer that has potential application for use in polymer flooding. This polymer is reviewed with particular emphasis on the effect of concentration, shear rate, salinity, hardness and temperature on polymer viscosity. Initial findings showed that PHB owned higher resistant as compared to mechanical degradation and thermal stability of HPAM as well as XG.

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Section: Temperaturementioning

confidence: 99%

Polyhydroxybutyrate for Improved Oil Recovery: A Literature Review

2016

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“…The hydrolysis in HPAM, however, significantly increases at temperatures above 70 °C. As the degree of hydrolysis reaches the critical value of 40%, polymer precipitation (due to bridging effect) occurs in the presence of high concentrations of divalent cations [5,[7][8][9][10][11]. The degree of hydrolysis is defined here as the fraction of the carboxyl residue replacing acrylamide units over the total number of the polymer macromolecule.…”

Section: Introductionmentioning

confidence: 99%

Assessment of Polyacrylamide Based Co-Polymers Enhanced by Functional Group Modifications with Regards to Salinity and Hardness

et al. 2017

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Abstract:This research aims to test four new polymers for their stability under high salinity/high hardness conditions for their possible use in polymer flooding to improve oil recovery from hydrocarbon reservoirs. The four sulfonated based polyacrylamide co-polymers were FLOCOMB C7035; SUPERPUSHER SAV55; THERMOASSOCIATIF; and AN132 VHM which are basically sulfonated polyacrylamide copolymers of AM (acrylamide) with AMPS (2-Acrylamido-2-Methylpropane Sulfonate). AN132 VHM has a molecular weight of 9-11 million Daltons with 32 mol % degree of sulfonation. SUPERPUSHER SAV55 mainly has about 35 mol % sulfonation degree and a molecular weight of 9-11 million Daltons. FLOCOMB C7035, in addition, has undergone post-hydrolysis step to increase polydispersity and molecular weight above 18 million Daltons but it has a sulfonation degree much lower than 32 mol %. THERMOASSOCIATIF has a molecular weight lower than 12 million Daltons and a medium sulfonation degree of around 32 mol %, and also contains LCST (lower critical solution temperature) type block, which is responsible for its thermoassociative characteristics. This paper discusses the rheological behavior of these polymers in aqueous solutions (100-4500 ppm) with NaCl (0.1-10 wt %) measured at 25 • C. The effect of hardness was investigated by preparing a CaCl 2 -NaCl solution of same ionic strength as the 5 wt % of NaCl. In summary, it can be concluded that the rheological behavior of the newly modified co-polymers was in general agreement to the existing polymers, except that THERMOASSOCIATIF polymers showed unique behavior, which could possibly make them a better candidate for enhanced oil recovery (EOR) application in high salinity conditions. The other three polymers, on the other hand, are better candidates for EOR applications in reservoirs containing high divalent ions. These results are expected to be helpful in selecting and screening the polymers for an EOR application.

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“…Formation of low interfacial tension is a key factor of chemical flooding to enhance oil recovery. Ultra-low interfacial tension makes oil droplets that are attached to the cores and moved easily, so that resistance to flow through the pores throat is reduced [18]. These are all in favor of enhanced oil recovery.…”

Section: Oil-water Interfacial Tensionmentioning

confidence: 99%

Laboratory Evaluation and Field Application of a Type of Surface–Active Polymer Oil Displacement Agent

Wei¹,

Li²,

Wang³

et al. 2014

TOPEJ

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Aiming to obtain a type of oil displacement with both surface activity and polymer performances, this paper, basing on mixing initiators at low temperatures, proposed a type of anion-nonionic surface-active polymer oil displacement agent (ANSP-1) by introducing polymerizable anion-nonionic surfmer (ANS-1), acrylamide (AM) and acrylic acid (AA). Structure of ANSP-1 was measured by FTIR. Laboratory studies show that: ANS-1 graft copolymerization occurs with AM, it avoids chromatographic separation, and it has better performances on molecular properties, such as tackifying performance, salt resistance, shear resistance and thermal stability. Oil-water interfacial tension can reach 1×10 -1 mN/m. Field application shows that average recovery ratio of the test wells which used ANSP-1 is 11%, which is 6.2% higher than the whole area.

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Temperature-dependent viscosity model of HPAM polymer through high-temperature reservoirs

Cited by 63 publications

References 5 publications

Polyhydroxybutyrate for Improved Oil Recovery: A Literature Review

Polyhydroxybutyrate for Improved Oil Recovery: A Literature Review

Assessment of Polyacrylamide Based Co-Polymers Enhanced by Functional Group Modifications with Regards to Salinity and Hardness

Laboratory Evaluation and Field Application of a Type of Surface–Active Polymer Oil Displacement Agent

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