Long term stability of ATBS type polymers for enhanced oil recovery

Sandengen, Kristian; Meldahl, M.M.; Gjersvold, Berit; Molesworth, Peter P.; Gaillard, Nicolas; Braun, Olivier; Antignard, S.

doi:10.1016/j.petrol.2018.06.001

Cited by 37 publications

(12 citation statements)

References 8 publications

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“…Figures 1 and 2 show the 13 C‐NMR spectra of the AN 125 and FP 5115 samples. The percentage of each group in the polymer chain was calculated via integration to find the area under the peaks in the carbonyl region of the acrylate group (AA) at 185 ppm, of the amide group (AM) at 182 ppm, and of the AMPS group at 178 ppm 16,19 …”

Section: Resultsmentioning

confidence: 99%

“…In view of this, there is a need to develop new polymers that can maintain their viscosifying power over long periods (often several years) in oil reservoirs. In this respect, other studies have investigated the substitution of some acrylamide groups in the molecules by other monomers, which are able to slow the hydrolysis of the acrylamide by protecting it with larger groups, such as n‐vinylpyrrolidone (NVP) or 2‐acrylamido‐2‐methylpropane sulfonic acid (AMPS) 17–21 …”

Section: Introductionmentioning

confidence: 99%

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Thermal stability of polymers based on acrylamide and 2‐acrylamido‐2‐methylpropane sulfonic acid in different temperature and salinity conditions

Vieira

Oliveira

Costa

et al. 2021

J of Applied Polymer Sci

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Partially hydrolyzed polyacrylamide (PHPA) is the most widely used polymer in enhanced oil recovery (EOR) applications. However, under conditions of high temperature and salinity, the PHPA molecules become hydrolyzed, causing a drastic reduction of the viscosity of the polymer solution due to the presence of negative charges, making the molecules more susceptible to interactions with cations. In this sense, in order to increase the stability of these polymers, an anionic monomer more resistant to cations such as 2‐acrylamido‐2‐methylpropane sulfonic acid (AMPS) has been incorporated into the HPAM molecules. This work evaluated the thermal stability of a copolymer (acrylamide and AMPS ‐ AN125) and a terpolymer (acrylamide, acrylate, and AMPS‐FP5115) in the time course of 360 days. The tests were carried out in typical conditions of Brazilian offshore reservoirs, such as absence of oxygen, high temperature, and high salt concentration. The test method involved measurements of intrinsic viscosity in function of time and determination of the hydrolysis degree of the polymers by elemental analysis. The copolymer AN125 was more stable under the test conditions than the terpolymer FP 5115 due to the presence of a higher concentration of AMPS in the copolymer. The AMPS group was hydrolyzed to AA at a temperature of 100 °C, however, the increase in salt concentration delayed the onset of this degradation. The tests indicated that the presence of a higher AMPS content in the copolymer does not prevent the polymer from undergoing hydrolysis, but delays the polymer precipitation step in the solution.

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Section: Resultsmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

Thermal stability of polymers based on acrylamide and 2‐acrylamido‐2‐methylpropane sulfonic acid in different temperature and salinity conditions

Vieira

Oliveira

Costa

et al. 2021

J of Applied Polymer Sci

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“…Gaillard [253,254] synthesized polymers based on acrylamide (AM), sodium acrylate (AA-Na), sodium acrylamide-tertiary-butyl sulfonate (ATBS) and N-vinyl pyrrolidone (NVP), testing their thermal stability at temperatures up to 120°C and TDS up to 70,000 ppm with high hardness content, finding that both NVP and ATBS improved thermal and salt stability, withstanding these conditions with minor loss of viscosity during at least 1 year. A disadvantage regarding these copolymers of NVP is its higher cost as compared with HPAM polymers [255].…”

Section: New Products and Techniques For Polymer Eormentioning

confidence: 99%

Chemical enhanced oil recovery and the role of chemical product design

2019

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“…Therefore, PF is not a simple process of adding polymer to water [ 6 , 7 ]. To obtain a better PF performance, many experimental investigations have been comprehensively studied [ 8 , 9 ], and most of these studies have focused on polymer static degradation [ 10 , 11 ]. However, the study of polymer dynamic degradation in porous media is relatively rare and requires more research.…”

Section: Introductionmentioning

confidence: 99%

Polymer Flooding in Heterogeneous Heavy Oil Reservoirs: Experimental and Simulation Studies

Xin

et al. 2021

Polymers

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Polymer flooding (PF) in heterogeneous heavy oil reservoirs is not only closely related to polymer degradation, but also to non-Newtonian flow. In this paper, both experimental and simulation methods are combined to investigate this type of flooding. Through experiments, the degradation of polymer, rheological properties of fluids, and flow of fluids in porous media were determined. Based on the experimental results, a novel mathematical model was established, and a new PF simulator was designed, validated, and further applied to study the effects of polymer degradation, polymer solution shear thinning, and non-Newtonian flow on PF in heterogeneous heavy oil reservoirs. These experimental results demonstrated that the polymer first-order static degradation rate constant was lower than the polymer first-order dynamic degradation rate constant; the polymer solution and heavy oil were non-Newtonian fluids, with shear thinning and Bingham fluid properties, respectively; and the heavy oil threshold pressure gradient (TPG) in low-permeability porous media was higher than that in high-permeability porous media. All comparison results showed that the designed simulator was highly accurate and reliable, and could well describe both polymer degradation and non-Newtonian flow, with special emphasis on the distinction between polymer static and dynamic degradation and heavy oil TPG. Furthermore, the simulation results verified that polymer degradation, polymer solution shear thinning, and heavy oil TPG all had negative effects on the efficiency of PF in heterogeneous heavy oil reservoirs.

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Long term stability of ATBS type polymers for enhanced oil recovery

Cited by 37 publications

References 8 publications

Thermal stability of polymers based on acrylamide and 2‐acrylamido‐2‐methylpropane sulfonic acid in different temperature and salinity conditions

Thermal stability of polymers based on acrylamide and 2‐acrylamido‐2‐methylpropane sulfonic acid in different temperature and salinity conditions

Chemical enhanced oil recovery and the role of chemical product design

Polymer Flooding in Heterogeneous Heavy Oil Reservoirs: Experimental and Simulation Studies

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