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Evaluation of filtration-capacitive properties of complex reservoir rocks using the results of core microtomography

UDK: 552.546 : 622.276.1
DOI: 10.24887/0028-2448-2019-8-86-88
Key words: computerized microtomography of core, reservoir rocks, relative permeability, reservoir properties, pore-scale modeling
Authors: S.R. Bembel (Tyumen Branch of SurgutNIPIneft, RF, Tyumen), V.M. Aleksandrov (Tyumen Industrial University, RF, Tyumen), A.A. Ponomarev (Tyumen Industrial University, RF, Tyumen), P.V. Markov (MicroModel LLC, RF, Moscow), S.P. Rodionov (Tymen Branch of Khristianovich Institute of Theoretical and Applied Mechanics, Siberian Branch of RAS, RF, Tyumen)

The article is devoted to the problems of determining and evaluating the filtration and capacitive properties of complex reservoir rocks using the results of core microtomography. Various processes were simulated directly for the three-dimensional pore space images of the samples (pore-scale modeling) to evaluate their effective properties and to obtain a more detailed understanding of the processes under study Ц one- and two-phase flow in porous media. The results of mathematical processing and interpretation of core computed microtomography data (ќЉCT) allowed us to obtain relative permeabilities which can be used for three-dimensional reservoir simulation models. In comparison with experimental studies, the methods of computer microtomography together with pore-scale modeling make it possible to estimate filtration-capacitive properties with significantly lower costs and to conduct calculations for core samples, for which it is impossible to conduct experiments, as well as to rescale the results for the use in reservoir simulation models. Taking into account in a more complete way the microscale factors using the techniques of microtomography expands opportunities of reservoir simulation models for complex reservoirs, which have hard-to-recover reserves, and, as a consequence, allows more reasonable and less costly ways to solve the management problems of oil and gas field development.

References

1. Shpurov I.V., Pisarnitskiy A.D., Purtova I.P., Varichenko A.I., Trudnoizvlekaemye zapasy nefti Rossiyskoy Federatsii. Struktura, sostoyanie, perspektivy osvoeniya (Hard to recover oil reserves of the Russian Federation. Structure, status and prospects of development), Tyumen': Publ. of FGUP ZapSibNIIGG, 2012, 256 p.

2. Blunt M.J., Flow in porous media - pore-network models and multiphase flow, Current Opinion in Colloid & Interface Science, 2001, V. 6, pp. 197Ц207.

3. Xiong Q., Baychev T.G., Jivkov A.P., Review of pore network modelling of porous media: Experimental characterisations, network constructions and applications to reactive transport, Journal of Contaminant Hydrology, 2016, V. 192, pp. 101Ц117.

4. Markov P.V., Rodionov S.P., Application of porous media microstructure models when calculating filtration characteristics for hydrodynamic models (In Russ.), Neftepromyslovoe delo. Ц 2015. Ц є 11. Ц S. 64Ц75.

5. Shabarov A.B., Shatalov A.V., Markov P.V., Shatalova N.V., Relative permeability calculation methods in multiphase filtration problems (In Russ.), Vestnik Tyumenskogo gosudarstvennogo universiteta. Fiziko-matematicheskoe modelirovanie. Neft', gaz, energetika, 2018, V. 4, no. 1, pp. 79Ц101.

6. Ryazanov A.V., Pore-scale network modelling of residual oil saturation in mixed-wet systems, Edinburgh: Heriot-Watt University, Institute of Petroleum Engineering, 2012.

7. Valvatne P.H., Predictive pore-scale modelling of multiphase flow, London: Imperial College, 2003, 146 р.

8. √Шren P.E., Bakke S., Arntzen O.J., Extending predictive capabilities to network models, SPE 52052-PA, 1998.

9. Zeyun Jiang, Kejian Wu et al., Efficient extraction of networks from three-dimensional porous media, Water Resources Research, 2007, V. 43, no. 12, рр. 1Ц17, DOI: 10.1029/2006WR005780.

10. Markov P.V, Rodionov S.P., Method of stochastic generation of pore network models from their parameter distribution (In Russ.), Vestnik kibernetiki, 2016, no. 3 (23), pp. 18Ц25.

11. Markov P.V., The relative permeability regions assignment on the basis of pore network models parameters distributions, Proceedings of Saint Petersburg 2016 International Conference & Exhibition, 11Ц14 April 2016. Ц St. Petersburg, 2016, рр. 31Ц35.

12. Markov P.V., Rodionov S.P., Rock typing on the basis of pore-scale models and complex well log interpretation parameters, Proceedings of International Conference & Exhibition "Tyumen 2017", EAGE, 11Ц14 April 2017, Tyumen, 2017, 14 р.

The article is devoted to the problems of determining and evaluating the filtration and capacitive properties of complex reservoir rocks using the results of core microtomography. Various processes were simulated directly for the three-dimensional pore space images of the samples (pore-scale modeling) to evaluate their effective properties and to obtain a more detailed understanding of the processes under study Ц one- and two-phase flow in porous media. The results of mathematical processing and interpretation of core computed microtomography data (ќЉCT) allowed us to obtain relative permeabilities which can be used for three-dimensional reservoir simulation models. In comparison with experimental studies, the methods of computer microtomography together with pore-scale modeling make it possible to estimate filtration-capacitive properties with significantly lower costs and to conduct calculations for core samples, for which it is impossible to conduct experiments, as well as to rescale the results for the use in reservoir simulation models. Taking into account in a more complete way the microscale factors using the techniques of microtomography expands opportunities of reservoir simulation models for complex reservoirs, which have hard-to-recover reserves, and, as a consequence, allows more reasonable and less costly ways to solve the management problems of oil and gas field development.

References

1. Shpurov I.V., Pisarnitskiy A.D., Purtova I.P., Varichenko A.I., Trudnoizvlekaemye zapasy nefti Rossiyskoy Federatsii. Struktura, sostoyanie, perspektivy osvoeniya (Hard to recover oil reserves of the Russian Federation. Structure, status and prospects of development), Tyumen': Publ. of FGUP ZapSibNIIGG, 2012, 256 p.

2. Blunt M.J., Flow in porous media - pore-network models and multiphase flow, Current Opinion in Colloid & Interface Science, 2001, V. 6, pp. 197Ц207.

3. Xiong Q., Baychev T.G., Jivkov A.P., Review of pore network modelling of porous media: Experimental characterisations, network constructions and applications to reactive transport, Journal of Contaminant Hydrology, 2016, V. 192, pp. 101Ц117.

4. Markov P.V., Rodionov S.P., Application of porous media microstructure models when calculating filtration characteristics for hydrodynamic models (In Russ.), Neftepromyslovoe delo. Ц 2015. Ц є 11. Ц S. 64Ц75.

5. Shabarov A.B., Shatalov A.V., Markov P.V., Shatalova N.V., Relative permeability calculation methods in multiphase filtration problems (In Russ.), Vestnik Tyumenskogo gosudarstvennogo universiteta. Fiziko-matematicheskoe modelirovanie. Neft', gaz, energetika, 2018, V. 4, no. 1, pp. 79Ц101.

6. Ryazanov A.V., Pore-scale network modelling of residual oil saturation in mixed-wet systems, Edinburgh: Heriot-Watt University, Institute of Petroleum Engineering, 2012.

7. Valvatne P.H., Predictive pore-scale modelling of multiphase flow, London: Imperial College, 2003, 146 р.

8. √Шren P.E., Bakke S., Arntzen O.J., Extending predictive capabilities to network models, SPE 52052-PA, 1998.

9. Zeyun Jiang, Kejian Wu et al., Efficient extraction of networks from three-dimensional porous media, Water Resources Research, 2007, V. 43, no. 12, рр. 1Ц17, DOI: 10.1029/2006WR005780.

10. Markov P.V, Rodionov S.P., Method of stochastic generation of pore network models from their parameter distribution (In Russ.), Vestnik kibernetiki, 2016, no. 3 (23), pp. 18Ц25.

11. Markov P.V., The relative permeability regions assignment on the basis of pore network models parameters distributions, Proceedings of Saint Petersburg 2016 International Conference & Exhibition, 11Ц14 April 2016. Ц St. Petersburg, 2016, рр. 31Ц35.

12. Markov P.V., Rodionov S.P., Rock typing on the basis of pore-scale models and complex well log interpretation parameters, Proceedings of International Conference & Exhibition "Tyumen 2017", EAGE, 11Ц14 April 2017, Tyumen, 2017, 14 р.


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