Influence of reservoir mineralogy on oil recovery during polymer flooding

UDK: 622.276.64
DOI: 10.24887/0028-2448-2022-4-44-48
Key words: enhanced oil recovery (EOR), polymer flooding, wettability alteration, reservoir mineralogy, carbonate content, core filtration study
Authors: D. Popic (NTC NIS-Naftagas, Serbia, Novi Sad), J. Pantic (NTC NIS-Naftagas, Serbia, Novi Sad), M. Tripkovic (NTC NIS-Naftagas, Serbia, Novi Sad), A.P. Losev (RTE Nedra-Test LLC, RF, Moscow; Gubkin University, RF, Moscow)

As a part of a preparation for field application of polymer flooding with HPAM at 20 mPa·c viscosity, series of core flood tests were carried out to determine resistance modification, residual resistance factor and retention factor. Tests were performed with actual core samples taken from reservoir, which is a fine to medium sandstone. In terms of permeability, the reservoir is highly heterogeneous so the samples were divided in 3 groups – high, medium and low permeability. It was expected that values of measured parameters would be more or less dependent on permeability, however, some of the results obtained did not correspond to this trend. When mineral composition of core samples was analyzed it was noticed that some samples have carbonate content up to 70%, while having values of porosity and permeability in the same range as other sandstone samples with low carbonate content. General dependence of experimental results on permeability and carbonate content was established. Further, since carbonates have different wettability characteristic than silicates, a concept of combining Smart Water technology and polymer flooding was tested on samples with high carbonate content. Combined treatment resulted in additional 5% of oil recovery when compared with proper polymer flooding.

References

1. Ferreira V.H.S., Moreno R.B.Z.L., Rheology-based method for calculating polymer inaccessible pore volume in core flooding experiments, Proceedings of E3S Web Conf. Vol. 89 (The 2018 International Symposium of the Society of Core Analysts – SCA 2018), 2019, DOI:10.1051/e3sconf/20198904001

2. Thomas A., Essentials of polymer flooding technique,  John Wiley and sons Ltd., 328 p.

3. Sameer A.H., Syed M.M., Hesham A., Saeed A., An overview on polymer retention in porous media, Energies, 2018, V. 11, no. 10, p. 2751, DOI: 10.3390/en11102751

4. Seright R., How much polymer should be injected during a polymer flood? Review of previous and current practices, Conference Proceedings. IOR 2017 – 19th European Symposium on Improved Oil Recovery, April 2017, DOI:10.2118/179543-MS

5. Sorbie K.S., Polymer-improved oil recovery, Dordrecht (Netherlands): Springer, 1991, 359 p.

6. Austard T., Water-based EOR in carbonates and sandstones: New Chemical understanding of the EOR potential using “Smart Water”, Chapter 13 in book: Enhanced oil recovery field cases, edited by Sheng J., Houston (TX, USA): Gulf Professional Publishing, 2013, 712 r., DOI:10.1016/B978-0-12-386545-8.00013-0

7. Ethington E.F., Interfacial contact angle measurements of water, mercury, and 20 organic liquids on quartz, calcite, biotite, and Ca-montmorillonite substrates, Golden (CO, USA): U.S. Geological Survey, 1990, 18 p.

8. Broseta D., Medjahed F., Lecourtier J., Robin M., Polymer adsorption/Retention in porous media: Effects of core wettability on residual oil, SPE 24149-PA, 1995, DOI:10.2118/24149-PA

9. Rezaei Gomari K.A., Hamouda A.A., Effect of fatty acids, water composition and pH on the wettability alteration of calcite surface, Journal of Petroleum Science and Engineering, 2006, V. 50, pp. 140–150.

10. Ahmadi S., Hosseini M., Tangestani E., Mousavi S.E., Niazi M., Wettability alteration and oil recovery by spontaneous imbibition of smart water and surfactants into carbonates, Petroleum Science, 2020, V. 17, pp. 712–721, DOI: 10.1007/s12182-019-00412-1

11. Evdokimov I.N., Nanozhidkosti i “umnye zhidkosti” v tekhnologiyakh razrabotki neftegazovykh mestorozhdeniy (Nanofluids and “smart fluids” in oil and gas field development technologies), Moscow: Nedra Publ., 2016, 247 p.

12. Fathi S.J., Austad T., Strand S., Water-based enchanced oil recovery (EOR) by “smart water”: Optimal ionic composition for EOR in carbonates, Energy and Fuels, 2011, no. 25(11), pp. 5173–5179, DOI:10.1021/ef201019k

13. Antoniadi D.G., Savenok O.V., Bukov N.N. et al., The possibility of using low-salinity water for increasing oil fields in Krasnodar region (In Russ.), Gornyy informatsionno-analiticheskiy byulleten', 2014, no. 8, pp. 331–339.

14. Shokoufeh A., Behzad R., An investigation of polymer adsorption in porous media using pore network modeling, Transport in Porous Media, 2016, V. 115, pp. 169–187, DOI:10.1007/s11242-016-0760-5

As a part of a preparation for field application of polymer flooding with HPAM at 20 mPa·c viscosity, series of core flood tests were carried out to determine resistance modification, residual resistance factor and retention factor. Tests were performed with actual core samples taken from reservoir, which is a fine to medium sandstone. In terms of permeability, the reservoir is highly heterogeneous so the samples were divided in 3 groups – high, medium and low permeability. It was expected that values of measured parameters would be more or less dependent on permeability, however, some of the results obtained did not correspond to this trend. When mineral composition of core samples was analyzed it was noticed that some samples have carbonate content up to 70%, while having values of porosity and permeability in the same range as other sandstone samples with low carbonate content. General dependence of experimental results on permeability and carbonate content was established. Further, since carbonates have different wettability characteristic than silicates, a concept of combining Smart Water technology and polymer flooding was tested on samples with high carbonate content. Combined treatment resulted in additional 5% of oil recovery when compared with proper polymer flooding.

References

1. Ferreira V.H.S., Moreno R.B.Z.L., Rheology-based method for calculating polymer inaccessible pore volume in core flooding experiments, Proceedings of E3S Web Conf. Vol. 89 (The 2018 International Symposium of the Society of Core Analysts – SCA 2018), 2019, DOI:10.1051/e3sconf/20198904001

2. Thomas A., Essentials of polymer flooding technique,  John Wiley and sons Ltd., 328 p.

3. Sameer A.H., Syed M.M., Hesham A., Saeed A., An overview on polymer retention in porous media, Energies, 2018, V. 11, no. 10, p. 2751, DOI: 10.3390/en11102751

4. Seright R., How much polymer should be injected during a polymer flood? Review of previous and current practices, Conference Proceedings. IOR 2017 – 19th European Symposium on Improved Oil Recovery, April 2017, DOI:10.2118/179543-MS

5. Sorbie K.S., Polymer-improved oil recovery, Dordrecht (Netherlands): Springer, 1991, 359 p.

6. Austard T., Water-based EOR in carbonates and sandstones: New Chemical understanding of the EOR potential using “Smart Water”, Chapter 13 in book: Enhanced oil recovery field cases, edited by Sheng J., Houston (TX, USA): Gulf Professional Publishing, 2013, 712 r., DOI:10.1016/B978-0-12-386545-8.00013-0

7. Ethington E.F., Interfacial contact angle measurements of water, mercury, and 20 organic liquids on quartz, calcite, biotite, and Ca-montmorillonite substrates, Golden (CO, USA): U.S. Geological Survey, 1990, 18 p.

8. Broseta D., Medjahed F., Lecourtier J., Robin M., Polymer adsorption/Retention in porous media: Effects of core wettability on residual oil, SPE 24149-PA, 1995, DOI:10.2118/24149-PA

9. Rezaei Gomari K.A., Hamouda A.A., Effect of fatty acids, water composition and pH on the wettability alteration of calcite surface, Journal of Petroleum Science and Engineering, 2006, V. 50, pp. 140–150.

10. Ahmadi S., Hosseini M., Tangestani E., Mousavi S.E., Niazi M., Wettability alteration and oil recovery by spontaneous imbibition of smart water and surfactants into carbonates, Petroleum Science, 2020, V. 17, pp. 712–721, DOI: 10.1007/s12182-019-00412-1

11. Evdokimov I.N., Nanozhidkosti i “umnye zhidkosti” v tekhnologiyakh razrabotki neftegazovykh mestorozhdeniy (Nanofluids and “smart fluids” in oil and gas field development technologies), Moscow: Nedra Publ., 2016, 247 p.

12. Fathi S.J., Austad T., Strand S., Water-based enchanced oil recovery (EOR) by “smart water”: Optimal ionic composition for EOR in carbonates, Energy and Fuels, 2011, no. 25(11), pp. 5173–5179, DOI:10.1021/ef201019k

13. Antoniadi D.G., Savenok O.V., Bukov N.N. et al., The possibility of using low-salinity water for increasing oil fields in Krasnodar region (In Russ.), Gornyy informatsionno-analiticheskiy byulleten', 2014, no. 8, pp. 331–339.

14. Shokoufeh A., Behzad R., An investigation of polymer adsorption in porous media using pore network modeling, Transport in Porous Media, 2016, V. 115, pp. 169–187, DOI:10.1007/s11242-016-0760-5


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