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Determination of porosity and permeability of a porous medium as a result of polymer structuring of disintegrated quartz sand using the IPNG-PLAST 2 technology

UDK: 622.276.031.011:53.09
DOI: 10.24887/0028-2448-2018-8-52-54
Key words: semi consolidated sand, chemical conglomeration, polymeric composition, x-ray micro computed tomography, porosity and permeability calculations
Authors: A.A. Pachezhertsev (Moscow Institute of Physics and Technology, RF, Dolgoprudny), A.A. Erofeev (Moscow Institute of Physics and Technology, RF, Dolgoprudny), D.A. Mitrushkin (Moscow Institute of Physics and Technology, RF, Dolgoprudny), A.I. Tsitsorin (Oil and Gas Research Institute of RAS, RF, Moscow), D.A. Kaushansky (Oil and Gas Research Institute of RAS, RF, Moscow), V.B. Demianovskiy (Oil and Gas Research Institute of RAS, RF, Moscow), A.N. Dmitrievsky (Oil and Gas Research Institute of RAS, RF, Moscow)

High filtration rates and pressure gradients in the bottomhole formation zone affect the mechanical properties of the reservoir, causing additional rock deformations. In this regard, long-term exploitation of oil wells leads to destruction of the bottomhole formation zone and removal of mechanical impurities into the wellbore. That leads to problems in the work of downhole and ground equipment, reduction of time between overhaul period and increase in downtime of wells. To consolidate the rock and prevent the removal of mechanical impurities from the bottomhole formation zone, the polymer-based composition IPNG-Plast 2 was developed. An important factor in the effectiveness of this composition is the preservation of the reservoir properties of the bottomhole formation zone after well treatment.

This article presents the results of a study of the influence of the polymer composition of IPNG-Plast 2 on the characteristics of porous space of artificial core samples. To study the internal structure and structure of pore space, the method of computer microtomography was applied. This method allows to investigate the internal structure of objects with high accuracy and without destroying the samples. Based on the results obtained, digital models of pore space were constructed; the total porosity and absolute permeability were calculated by solving the simplified Navier – Stokes equations by the finite volume method. As a result, insignificant changes were observed in the absolute values of the total porosity and the structure of the pore space. Calculation of permeability showed more significant changes after injection of the composition both in absolute values and in spatial distribution in the bulk of the sample. In general, a slight change in reservoir properties of artificial cores as a result of structuring using the IPNG-Plast 2 technology was revealed.

References

1. Tsitsorin A.I., Dem'yanovskiy V.B., Kaushanskiy D.A., Chemical methods of reduction of sand ingress in oil and gas wells (In Russ.), Georesursy. Geoenergetika. Geopolitika, 2014, no. 10.

2. Rumyantseva E.A., Kozupitsa L.M., Akimov N.I., Chemical methods for incompetent rock stabilizing (In Russ.), Interval, 2008, no. 4, pp. 27–31.

3. Suvernev S.P., Chemical binding of weakly cemented formation for control sand (In Russ.), Inzhenernaya praktika, 2011, no. 2, pp. 101–103.

4. Yakimov S.B., Specific features of underground equipment operation after carrying out some activities, limiting sand removal from a bottomhole area (In Russ.), Oborudovanie i tekhnologii dlya neftegazovogo kompleksa, 2014, no. 1, pp. 51–55.

5. Patent no. 2558831 RF, Hydrocarbon production intensification method by limitation of sand production in oil and gas wells, Inventors: Kaushanskiy D.A., Tsitsorin A.I., Dem'yanovskiy V.B., Dmitrievskiy A.N.

6. Kaushanskiy D.A., Tsitsorin A.I., Dmitrievskiy A.N. et al., Study of strength and filtration properties of core samples structured by urethane pre-polymer (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2016, no. 3, pp. 105–107.

7. Kaushanskiy D.A., Dmitrievskiy A.N., Tsitsorin A.I., Dem'yanovskiy V.B., Physicochemical and rheological properties of IPNG-PLAST 2 composition for limiting the mechanical impurities washing over in the oil wells (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2015, no. 4, pp. 84–87.

8. Yazynina I.V., Shelyago E.V., Abrosimov A.A. et al., Novel approach to core sample MCT research for practical petrophysics problems solution (In Russ.) Neftyanoe khozyaystvo = Oil Industry, 2017, no. 1, pp. 19–23.

9. Krivoshchekov S.N., Kochnev A.A., Application experience of computed tomography to study the properties of rocks (In Russ.), Vestnik Permskogo natsional'nogo issledovatel'skogo politekhnicheskogo universiteta. Geologiya.Neftegazovoe i gornoe delo = Perm Journal of Petroleum and Mining Engineering, 2013, no. 6, pp. 32–42.

10. Van Geet M., Swennen R., Wevers M., Quantitative analysis of reservoir rocks by microfocus X-ray computerised tomography, Sedimentary Geology, 2000, V. 132, P. 25-36.

11. Taud H. et al., Porosity estimation method by X-ray computed tomography, Journal of Petroleum Science and Engineering, 2005, V. 47, pp. 209–217.

12. Vandersteen K. et al., Quantitative characterization of fracture apertures using microfocus computed tomography, Geological Society, 2003, V. 215, pp. 61–68.

High filtration rates and pressure gradients in the bottomhole formation zone affect the mechanical properties of the reservoir, causing additional rock deformations. In this regard, long-term exploitation of oil wells leads to destruction of the bottomhole formation zone and removal of mechanical impurities into the wellbore. That leads to problems in the work of downhole and ground equipment, reduction of time between overhaul period and increase in downtime of wells. To consolidate the rock and prevent the removal of mechanical impurities from the bottomhole formation zone, the polymer-based composition IPNG-Plast 2 was developed. An important factor in the effectiveness of this composition is the preservation of the reservoir properties of the bottomhole formation zone after well treatment.

This article presents the results of a study of the influence of the polymer composition of IPNG-Plast 2 on the characteristics of porous space of artificial core samples. To study the internal structure and structure of pore space, the method of computer microtomography was applied. This method allows to investigate the internal structure of objects with high accuracy and without destroying the samples. Based on the results obtained, digital models of pore space were constructed; the total porosity and absolute permeability were calculated by solving the simplified Navier – Stokes equations by the finite volume method. As a result, insignificant changes were observed in the absolute values of the total porosity and the structure of the pore space. Calculation of permeability showed more significant changes after injection of the composition both in absolute values and in spatial distribution in the bulk of the sample. In general, a slight change in reservoir properties of artificial cores as a result of structuring using the IPNG-Plast 2 technology was revealed.

References

1. Tsitsorin A.I., Dem'yanovskiy V.B., Kaushanskiy D.A., Chemical methods of reduction of sand ingress in oil and gas wells (In Russ.), Georesursy. Geoenergetika. Geopolitika, 2014, no. 10.

2. Rumyantseva E.A., Kozupitsa L.M., Akimov N.I., Chemical methods for incompetent rock stabilizing (In Russ.), Interval, 2008, no. 4, pp. 27–31.

3. Suvernev S.P., Chemical binding of weakly cemented formation for control sand (In Russ.), Inzhenernaya praktika, 2011, no. 2, pp. 101–103.

4. Yakimov S.B., Specific features of underground equipment operation after carrying out some activities, limiting sand removal from a bottomhole area (In Russ.), Oborudovanie i tekhnologii dlya neftegazovogo kompleksa, 2014, no. 1, pp. 51–55.

5. Patent no. 2558831 RF, Hydrocarbon production intensification method by limitation of sand production in oil and gas wells, Inventors: Kaushanskiy D.A., Tsitsorin A.I., Dem'yanovskiy V.B., Dmitrievskiy A.N.

6. Kaushanskiy D.A., Tsitsorin A.I., Dmitrievskiy A.N. et al., Study of strength and filtration properties of core samples structured by urethane pre-polymer (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2016, no. 3, pp. 105–107.

7. Kaushanskiy D.A., Dmitrievskiy A.N., Tsitsorin A.I., Dem'yanovskiy V.B., Physicochemical and rheological properties of IPNG-PLAST 2 composition for limiting the mechanical impurities washing over in the oil wells (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2015, no. 4, pp. 84–87.

8. Yazynina I.V., Shelyago E.V., Abrosimov A.A. et al., Novel approach to core sample MCT research for practical petrophysics problems solution (In Russ.) Neftyanoe khozyaystvo = Oil Industry, 2017, no. 1, pp. 19–23.

9. Krivoshchekov S.N., Kochnev A.A., Application experience of computed tomography to study the properties of rocks (In Russ.), Vestnik Permskogo natsional'nogo issledovatel'skogo politekhnicheskogo universiteta. Geologiya.Neftegazovoe i gornoe delo = Perm Journal of Petroleum and Mining Engineering, 2013, no. 6, pp. 32–42.

10. Van Geet M., Swennen R., Wevers M., Quantitative analysis of reservoir rocks by microfocus X-ray computerised tomography, Sedimentary Geology, 2000, V. 132, P. 25-36.

11. Taud H. et al., Porosity estimation method by X-ray computed tomography, Journal of Petroleum Science and Engineering, 2005, V. 47, pp. 209–217.

12. Vandersteen K. et al., Quantitative characterization of fracture apertures using microfocus computed tomography, Geological Society, 2003, V. 215, pp. 61–68.


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