Recommended polymer workflow: Interpretation and parameter identification

Authors

Arild Lohne; Arne Stavland; Siv Marie Åsen; Olav Aursjø; Aksel Hiorth

Keywords:

The National IOR Centre of Norway, polymer workflows, polymer flooding

Synopsis

Injecting a polymer solution into a porous medium significantly increases the modeling complexity, compared to model a polymer bulk solution. Even if the polymer solution is injected at a constant rate into the porous medium, the polymers experience different flow regimes in each pore and pore throat. The main challenge is to assign a macroscopic porous media “viscosity” to the fluid which can be used in Darcy law to get the correct relationship between the injection rate and pressure drop. One can achieve this by simply tabulating experimental results (e.g., injection rate vs pressure drop). The challenge with the tabulated approach is that it requires a huge experimental database to tabulate all kind of possible situations that might occur in a reservoir (e.g., changing temperature, salinity, flooding history, permeability, porosity, wettability etc.). The approach presented in this report is to model the mechanisms and describe them in terms of mathematical models. The mathematical model contains a limited number of parameters that needs to be determined experimentally. Once these parameters are determined, there is in principle no need to perform additional experiments.

Author Biographies

Arild Lohne

Senior researcher
NORCE
arlo@norceresearch.no

Arne Stavland

Chief researcher
NORCE
arst@norceresearch.no

Siv Marie Åsen

Researcher
Faculty of Science and Technology
University of Stavanger
siv.m.asen@uis.no

Olav Aursjø

Senior researcher
NORCE
olau@norceresearch.no

Aksel Hiorth

Professor
Faculty of Science and Technology
Department of Energy Resources
University of Stavanger
aksel.hiorth@uis.no

References

1. Lohne, A., Nødland, O., Stavland, A., and Hiorth, A., "A model for non-Newtonian flow in porous media at different flow regimes," Computational Geosciences, vol. 21 (December), 2017.
https://doi.org/10.3997/2214-4609.201601771

2. Stavland, A., Jonsbråten, H.C., Lohne, A., Moen, A., and Giske, N.H., "Polymer Flooding - Flow Properties in Porous Media Versus Rheological Parameters," SPE 131103-MS presented at SPE EUROPEC/EAGE Annual Conference and Exhibition, Barcelona, Spain, 14-17 June 2010.
https://doi.org/10.2118/131103-MS

3. Jouenne, S. and Levache, B., "Universal viscosifying behavior of acrylamide-based polymers used in enhanced oil recovery," Journal of Rheology, vol. 64 (5), pp. 1295-1313, 2020.
https://doi.org/10.1122/8.0000063

4. Lohne, A., Stavland, A., and Reichenbach-Klinke, R., "Modeling of Associative Polymer Flow in Porous Medium," Tu B 08 presented at IOR 2019 - 20th European Symposium on Improved Oil Recovery, Pau, France, 8-11 April 2019.
https://doi.org/10.3997/2214-4609.201900117

5. Chauveteau, G., "Fundamental Criteria in Polymer Flow Through Porous Media," in Water-Soluble Polymers, Adv. in Chem. Ser., J. E. Glass, Ed., 1986.
https://doi.org/10.1021/ba-1986-0213.ch014

6. Howe, A.M., Clarke, A., and Giernalczyk, D., "Flow of concentrated viscoelastic polymer solutions in porous media: effect of Mw and concentration on elastic turbulence onset in various geometries," Soft Matter, vol. 11 (32), pp. 6419-6431, 2015.
https://doi.org/10.1039/C5SM01042J

7. Lohne, A., Han, L., van der Zwaag, C., van Velzen, H., Mathisen, A.-M., Twynam, A., Hendriks, W., Bulgachev, R., and Hatzignatiou, D.G., "Formation Damage and Well Productivity Simulation," SPE Journal, vol. 15 (3), pp. 751-769, 2010.
https://doi.org/10.2118/122241-PA

8. Dupuis, G., Al-Khoury, P., Nieuwerf, J., and Favero, C., "Using Polymer EOR to Reduce Carbon Intensity While Increasing Oil Recovery," IOR 2021, 2021.
https://doi.org/10.3997/2214-4609.202133048

Downloads

Published

June 27, 2022

Online ISSN

2387-6662