1887

Abstract

Summary

This paper aims to synthesize theoretical insights and field experiences concerning water injection efficiency following polymer flooding. The objective is to summarize fluid and reservoir dynamics during this critical transition to guide the design of cost-effective and technically robust enhanced oil recovery (EOR) projects. Key discussions focus on the integrity of the polymer slug when injection is resumed, the diversion (or lack thereof) of water into previously unswept zones due to polymer-induced resistance, and potential tailing strategies to mitigate premature water breakthrough.

Our methodology involves an extensive review of historical and contemporary case studies, complemented by a series of laboratory tests guided by reservoir engineering principles. Initially, we analyze fluid dynamics relevant to this phase of the project, followed by an evaluation of existing laboratory experiments and the investigation of strategies designed to conclude injection while minimizing water breakthrough. Drawing insights from projects across Kazakhstan, China, the Middle East, and the Americas, we develop guidelines and strategies aimed at extending the operational lifespan of existing projects.

Analyses of several enhanced oil recovery projects reveal a rapid decline in recovery efficiency upon switching from polymer to water flooding, predominantly driven by unfavorable mobility ratios. Notably, water channels swiftly through higher permeability zones where polymer-induced resistance remains the lowest compared to less permeable areas. The ineffective displacement of the polymer slug by water often signals the premature conclusion of the project. These findings underscore the need to reduce mobility ratios to preserve polymer bank integrity and, consequently, the efficiency of the flood. These statements are substantiated by examining field cases in Kazakhstan, China, the Middle East, and the Americas.

The recommendations provide a pragmatic approach to extending the polymer injection phase, significantly deviating from traditional EOR practices. They present a robust strategy for future polymer flooding projects. By emphasizing the importance of maintaining polymer slug integrity and optimizing injection strategies, the guidelines aim to enhance overall recovery efficiency and extend the productive life of oil fields. This comprehensive analysis integrates theoretical principles with practical insights, offering valuable guidance for the successful implementation of polymer flooding and subsequent water injection in diverse reservoir conditions. The findings and recommendations are expected to contribute significantly to the advancement of EOR methodologies, promoting more sustainable and efficient oil recovery practices.

© EAGE Publications BV
Loading

Article metrics loading...

/content/papers/10.3997/2214-4609.202531004
2025-04-02
2026-02-19

  • From This Site

    /content/papers/10.3997/2214-4609.202531004
    dcterms_title,dcterms_subject,pub_keyword
    -contentType:Journal -contentType:Contributor -contentType:Concept -contentType:Institution
    10
    5
Loading full text...

Full text loading...

References

  1. Abdul Hamid, S.A., Muggeridge, A.H., (2018). Analytical solution of polymer slug injection with viscous fingering: Computational Geosciences, 22, 711–723. https://doi.org/10.1007/s10596-018-9721-0.
     [Google Scholar]
  2. Al Sawafi, M. M., & Aljabri, A. (2024). South Oman Polymer Project: A decade of operational excellence and comprehensive reservoir monitoring and surveillance. SPE Improved Oil Recovery Conference, Tulsa, Oklahoma, USA, 22–25 April 2024. https://doi.org/10.2118/218201-MS.
     [Google Scholar]
  3. Al-Sulaimani, H., Al-Rawahi, Z., Velazco Quesada, C, Anand, A., Hemink, G., Frumau, M., Al-Hussaini, A., Syed, M., Al-Zadjali, R., Mahajan, S., Al-Yahyai, A., Al-Mahrooqi, M., & Ajmi, J. (2022). Successful polymer flood pilot application in lower permeability heterogeneous sandstone reservoir in the south of the Sultanate of Oman. SPE Conference at Oman Petroleum & Energy Show. https://doi.org/10.2118/200051-MS.
     [Google Scholar]
  4. An, B., Solorzano, D., Yuan, Q., (2022). Viscous fingering dynamics and flow regimes of miscible displacements in a sealed Hele-Shaw cell: Energies, 15, 5798. https://doi.org/10.3390/en15165798.
     [Google Scholar]
  5. Anand, A., & Riyami, O. (2022). Optimizing ongoing field-scale polymer flood in south of Oman through detailed simulation. SPE Journal. https://doi.org/10.2118/200207-MS.
     [Google Scholar]
  6. Bakharev, F., Enin, A., Kalinin, K., Petrova, Y., Rastegaev, N., Tikhomirov, S., (2020). Optimal polymer slugs injection profiles: arXiv preprint, arXiv:2012.03114. https://doi.org/10.48550/arXiv.2012.03114
     [Google Scholar]
  7. Blunt, M.J., Barker, J.W., Rubin, B., Mansfield, M., Culverwell, I.D., Christie, M.A., (1994). Predictive theory for viscous fingering in compositional displacement: SPE Reservoir Engineering, 9(1), 73–80. https://doi.org/10.2118/24807-PA.
     [Google Scholar]
  8. Chang, S. H. and Slattery, J.C, (1986). A linear stability analysis for miscible displacements, Transport in Porous Media1, 179.
     [Google Scholar]
  9. Chen, J.D., (1987). Radial viscous fingering patterns in Hele-Shaw cells: Experimental Fluids, 5, 363–371.
     [Google Scholar]
  10. Claridge, E. L., (1972). Discussion of the use of capillary tube networks in reservoir performance studies, Soc. Petrol Eng. J., 12, 352.
     [Google Scholar]
  11. Claridge, E.L., (1978). A method for designing graded viscosity banks: Society of Petroleum Engineers Journal, 18(5), 315–324. https://doi.org/10.2118/6752-PA.
     [Google Scholar]
  12. Cyr, T.J., De La Cruz, V., & Spanos, T.J.T. (1988). An analysis of the viability of polymer flooding as an enhanced oil recovery technology. Transport in Porous Media, 3(6), 591–618. https://doi.org/10.1007/BF00959104.
     [Google Scholar]
  13. Delamaide, E. (2016). Comparison of Primary, Secondary and Tertiary Polymer Flood in Heavy Oil -Field Results. Paper SPE 180852 presented at the SPE Trinidad and Tobago Section Energy Resources Conference, Port of Spain, Trinidad and Tobago, 13–15 June.
     [Google Scholar]
  14. Dupuis, G., Ould Metidji, M. (2023). Better Understanding of Polymer Behaviour in Porous Media Allowing Reducing OPEX of EOR Projects. EAGE IOR+ Conference & Exhibition. https://doi.org/10.3997/2214-4609.202331071.
     [Google Scholar]
  15. Giordano, R. M. and Salter, S. J., (1984). The effects of dispersion and phase behavior of unfavourable mobility ratio displacements, S.P.E. 13165, Soc. Petr. Eng., P.O. Box 833836, Richardson, Texas.
     [Google Scholar]
  16. Hatton, T. A. and Lightfoot, E. N., (1982) On the significance of the dispersion coefficient in two-phase flow, Chern. Eng. Sci. 37, 1289.
     [Google Scholar]
  17. Homsy, G. M., (1987). Viscous Fingering in Porous Media: Annual Review of Fluid Mechanics, 19, 271–311.
     [Google Scholar]
  18. Imanbayev, B., Kushekov, R., Sagyndikov, M., & Shyrakbayev, D. (2022). Feasibility study of a polymer flood for the Uzen Brownfield conditions. SPE Annual Caspian Technical Conference. https://doi.org/10.2118/212091-MS
     [Google Scholar]
  19. Kargozarfard, Z., Riazi, M., Ayatollahi, S., (2019). Viscous fingering and its effect on areal sweep efficiency during waterflooding: An experimental study: Petroleum Science, 16, 105–116.
     [Google Scholar]
  20. Koval, E.J., (1963). A method for predicting the performance of unstable miscible displacement in heterogeneous media: Society of Petroleum Engineers Journal, 3(2), 145–154. https://doi.org/10.2118/4503-PA.
     [Google Scholar]
  21. Ligthelm, D.J., (1989). Reservoir engineering approach to viscosity grading in polymer drives. Journal of Petroleum Science and Engineering, 8(2–3), 159–166. https://doi.org/10.1016/0920-4105(89)90062-4.
     [Google Scholar]
  22. Lu, X. G., Li, W., Wei, Y. N., & Xu, J. (2023). A systematical review of the largest polymer flood project in the world: from laboratory to pilots and field application. SPE Reservoir Evaluation & Engineering, 26(03), 708–721. https://doi.org/10.2118/210298-pa.
     [Google Scholar]
  23. Melo, M.A., Silva, I.P.G., Mezzomoe, R.F., Lima, J.C., Aguiar, A.A. (2010). Sustainability Evaluation of Polymer Pilots for Petroleum Recovery in Brazil. Rio Oil & Gas Expo and Conference 2010.
     [Google Scholar]
  24. Melo, M.A., Lins, A.G., Silva, I.P.G. (2017). Lessons Learned From Polymer Flooding Pilots in Brazil. SPE Latin America and Caribbean Mature Fields Symposium, https://doi.org/10.2118/184941-MS.
     [Google Scholar]
  25. Mezzomo, R.F., Luvizotto, J.M., Palagi, C.L. (2001). Improved Oil Recovery in Carmopolis Field: R&D and Field Implementations. SPE Reservoir Evaluation & Engineering. February 2001 https://doi.org/10.2118/69811-PA.
     [Google Scholar]
  26. Peaceman, D. W. and Rachford, H. H., (1962), Numerical calculation of multi-dimensional miscible displacement,Soc. Petrol. Eng. J.2, 327.
     [Google Scholar]
  27. Prasad, D., Pandey, A., Kumar, M.S. et al. (2014). Pilot to Full-Field Polymer Application in One of the Largest Onshore Field in India. Presented at the SPE Improved Oil Recovery Symposium. Tulsa, Oklahoma, USA, 12–16 April. SPE-169146-MS. http://dx.doi.org/10.2118/169146-MS.
     [Google Scholar]
  28. Qi, Z., Wilton, R.R, Fan, X., Serediak, O., Ghosh, P. and Abedini, A.2022. Paper presented at the 2nd EAGE Workshop on EOR in the Americas, Bogota, Colombia. 12–14 October.
     [Google Scholar]
  29. Qi, C, Haroun, M., Al Kobaisi, M., & Rahman, M.M. (2024). Dynamic characterization of viscous fingering during grading viscosity polymer flooding (GVPF) in heterogeneous sandstone by core-scale simulation. SPE Journal. https://doi.org/10.2118/219128-MS.
     [Google Scholar]
  30. Raffa, D. and Abedini, A. (2023). Learnings from the Planning and Execution of a Heavy Oil Polymer Flood Pilot in North Saskatchewan, Canada. Paper SPE 212760 presented at the Canadian Energy Technology Conference and Exhibition, 15–16 March. Calgary, Alberta. https://doi.org/10.2118/212760-MS
     [Google Scholar]
  31. Sagyndikov, M., Mukhambetov, B., Orynbasar, Y., Nurbulatov, A., Aidarbayev, S. (2018). Evaluation of Polymer Flooding Efficiency at brownfield development stage of giant Kalamkas oilfield, Western Kazakhstan. Paper presented at the SPE Annual Caspian Technical Conference and Exhibition held in Astana, Kazakhstan, 31st October - 2nd November 2018. SPE-192555-MS. https://doi.org/10.2118/192555-MS
     [Google Scholar]
  32. Sagyndikov, M., Seright, R.S., Kudaibergenov, S., and Ogay, E. (2022a). Field Demonstration of the Impact of Fractures on Hydolyzed Polyacrilamide Injectivity, Propagation and Degradation. SPE Journal27 (02): 999–1016. SPE-208611-PA. https://doi:10.2118/208611-PA
     [Google Scholar]
  33. Sagyndikov, M., Seright, R.S., Tuyakov, N. (2022b). An unconventional approach to model a polymer flood in the Kalamkas oilfield. Paper presented at the SPE Virtual Improved Oil Recovery Conference to be held 25–29 April 2022. SPE-209355-MS. https://doi.org/10.2118/209355-MS
     [Google Scholar]
  34. Kushekov, R. M., Sagyndikov, M. S., Ispanbetov, T. I., Pourafshary, P., & Shyrakbayev, D. A. (2024). Full-Field Polymer Flooding Project - Principles and challenges at the Kalamkas Oilfield. SPE Improved Oil Recovery Conference. https://doi.org/10.2118/218213-MS
     [Google Scholar]
  35. Seright, R.S., Fan, T., Wavrik, K., and Balaban, R.C.2011. New Insights into Polymer Rheology in Porous Media. SPE J.16 (1): 35–42. SPE-129200-PA. https://doi.org/10.2118/129200-PA
     [Google Scholar]
  36. Seright, R. S. (2017). How Much Polymer Should Be Injected During a Polymer Flood? Review of Previous and Current Practices. SPE Journal22(01): 1–18. SPE- 179543-PA. https://doi.org/10.2118/179543-PA.
     [Google Scholar]
  37. Seright, R. S., & Wang, D. (2023). Literature review and experimental observations of the effects of salinity, hardness, lithology, and ATBS content on HPAM polymer retention for the Milne Point polymer flood. SPE Journal28(05), 2300–2312. https://doi.org/10.2118/212946-PA.
     [Google Scholar]
  38. Seright, R. S., & Wang, D. (2023). Polymer flooding: Current status and future directions. Petroleum Science, S1995822623000171. https://doi.org/10.1016/j.petsci.2023.02.002
     [Google Scholar]
  39. Shankar, V., Shekhar, S., Gupta, A. K., Brown, A., Veerbhadrappa, S., & Nakutnyy, P. (2022). Mangala Polymer Flood performance: Connecting the dots through In-Situ polymer sampling. SPE Reservoir Evaluation & Engineering, 25(04), 655–666. https://doi.org/10.2118/206146-pa.
     [Google Scholar]
  40. Silva, C, Beteta, A., Mclver, K., Sorbie, K., Johnson, G., Hesampour, M. (2024). Adsorption Kinetics of Copolymers and Sulfonated Polymers for Enhanced Oil Recovery. SPE Improved Oil Recovery Conference, https://doi.org/10.2118/218215-MS.
     [Google Scholar]
  41. Su, S., Giddins, M. A., Naccache, P., Clarke, A., & M Howe, A. (2015). Accurate Modeling of Polymer Enhanced Oil Recovery Corefloods by Reservoir Simulation. Day 1 Mon, September 14, 2015, D011S002R002. https://doi.org/10.2118/175555-MS.
     [Google Scholar]
  42. Takaqi, S., Pope, G.A., Sepehrnoori, K., Putz, A.G., and BenDakhlia, H. (1992). Simulation of a Successful Polymer Flood in the Chateaurenard Field. SPE 24931, presented at the 67th Annual Technical Conference and Exhibition of the Society of Petroleum Engineers, Washington, DC, 4–7 October.
     [Google Scholar]
  43. Tikhomirov, S., Bakharev, F., Groman, A., Kalyuzhnyuk, A., Petrova, Y., Enin, A., Kalinin, K., & Rastegaev, N. (2021). Calculation of graded viscosity banks profile on the rear end of the polymer slug. SPE Russian Petroleum Technology Conference. https://doi.org/10.2118/206426-MS.
     [Google Scholar]
  44. Thomas, A., Giddins, M. A., & Wilton, R. (2019). Why is it so Difficult to Predict Polymer Injectivity in Chemical Oil Recovery Processes?IOR 2019 – 20th European Symposium on Improved Oil Recovery, 1–25. https://doi.org/10.3997/2214-4609.201900114
     [Google Scholar]
  45. Thomas, A. (2023). Revisiting polymer selection workflows for chemical enhanced oil recovery. IOR+ 2023, European Association of Geoscientists & Engineers, 2023, 1–32. https://doi.org/10.3997/2214-4609.202331012.
     [Google Scholar]
  46. Todd, M., Longstaff, W. (1972). The development, testing and application of a numerical simulator for predicting miscible flood performance. J. Petrol. Tech.24, 874–882.
     [Google Scholar]
  47. Ulovich, I., Imqam, A., Martinez, J., Aljubori, A., and Rathod, R. (2023). Case Study of Sucessful Pilot Polymer Flooding to Improve the Recovery of Lloydminster Heavy Oil Reservoir - West Central Saskatchewan. SPE paper 215041 presented at the SPE Annual Technical Conference and Exhibition. San Antonio, TX, October. https://doi.org/10.2118/215041-MS
     [Google Scholar]
  48. Wilton, R.R. (2015). Rheology and Flow Behaviour of Non-Newtonian, Polymeric Fluids in Capillaric and Porous Media: Aspects Related to Polymer Flooding for Enhanced Recovery of Heavy Oil. PhD Dissertation. University of Regina. https://ourspace.uregina.ca/items/5943234b-6e7d-4b96-8e5e-2be7d5bc86e0.
     [Google Scholar]
/content/papers/10.3997/2214-4609.202531004
Loading
Revisiting Water Injection Post-Polymer Flooding: A Global Perspective on Project Performance
Conference Proceedings 2025, 1 (2025); https://doi.org/10.3997/2214-4609.202531004
/content/papers/10.3997/2214-4609.202531004
/content/papers/10.3997/2214-4609.202531004
Loading

Data & Media loading...

Most Cited This Month Most Cited RSS feed

This is a required field
Please enter a valid email address
Approval was a Success
Invalid data
An Error Occurred
Approval was partially successful, following selected items could not be processed due to error