An Efficient Hybrid Model for 3D Complex Fractured Vuggy Reservoir Simulation
- Lijun Liu (China University of Petroleum (East China)) | Zhaoqin Huang (China University of Petroleum (East China)) | Jun Yao (China University of Petroleum (East China)) | Yuan Di (Peking University) | Yu-Shu Wu (Colorado School of Mines)
- Document ID
- Society of Petroleum Engineers
- SPE Journal
- Publication Date
- April 2020
- Document Type
- Journal Paper
- 907 - 924
- 2020.Society of Petroleum Engineers
- fractured vuggy reservoir, 3D complex fracture-vug network, vug model, modified embedded discrete fracture model
- 13 in the last 30 days
- 152 since 2007
- Show more detail
- View rights & permissions
|SPE Member Price:||USD 5.00|
|SPE Non-Member Price:||USD 35.00|
Fractured vuggy reservoir is a typical type of carbonate reservoir. The 3D complex fracture networks and Stokes flow inside vugs make fractured vuggy reservoir simulation remain a challenging problem. Most of the proposed models in previous studies are computation consuming, which cannot meet with the demand of field application. In this paper, a novel and efficient hybrid model, consisting of a modified embedded discrete fracture model (EDFM) and a vug model, is proposed to simulate multiphase flow in 3D complex fractured vuggy reservoirs. The modified EDFM improves the fracture-discretization process by using two sets of independent grids for matrix and fracture systems, which promotes the modeling of 3D complex fractures in real geological structures. Meanwhile, the vug model simplifies the coupled porous-free flow with the assumption of multiphase instantaneous gravity differentiation. The accuracy of the modified EDFM and the vug model is demonstrated by comparing the results with those of the conventional EDFM and volume of fluid (VOF) method. After that, a series of case studies, including three conceptual fracture-vug unit models and a real field model, have been conducted to test the proposed hybrid model. The results of the three fracture-vug unit models indicate the significant effect of a local fracture-vug structure on the flow characteristics and production performance. Finally, the application with a real field model with 3D complex fracture and vug geometries further verifies the practicability of our proposed model in real fractured vuggy reservoirs.
|File Size||13 MB||Number of Pages||18|
Aziz, K. and Settari, A. 1979. Petroleum Reservoir Simulation. London, England, UK: Applied Science Publishers.
Beavers, G. S. and Joseph, D. D. 1967. Boundary Conditions at a Naturally Permeable Wall. J Fluid Mech 30 (1): 197–207. https://doi.org/10.1017/S0022112067001375.
Camacho-Velazquez, R., Vasquez-Cruz, M., Castrejon-Aivar, R. et al. 2002. Pressure Transient and Decline Curve Behaviors in Naturally Fractured Vuggy Carbonate Reservoirs. Paper presented at the SPE Annual Technical Conference and Exhibition, San Antonio, Texas, USA, 29 September–2 October. SPE-77689-MS. https://doi.org/10.2118/77689-MS.
Chen, Z. X. 1989. Transient Flow of Slightly Compressible Fluids through Double-Porosity, Double-Permeability Systems—A State-of-the-Art Review. Trans Porous Media 4 (2): 147–184. https://doi.org/10.1007/BF00134995.
Fumagalli, A., Pasquale, L., Zonca, S. et al. 2016. An Upscaling Procedure for Fractured Reservoirs with Embedded Grids. Water Resour Res 52 (8): 6506–6525. https://doi.org/10.1002/2015WR017729.
Guo, J. C., Nie, R. S., and Jia, Y. L. 2012. Dual Permeability Flow Behavior for Modeling Horizontal Well Production in Fractured-Vuggy Carbonate Reservoirs. J Hydrol 464: 281–293. https://doi.org/10.1016/j.jhydrol.2012.07.021.
Huang, Z., Gao, B., Zhang, X. et al. 2016. On the Coupling of Two-Phase Free Flow and Porous Flow. Paper presented at the ECMOR XV-15th European Conference on the Mathematics of Oil Recovery, Amsterdam, The Netherlands, 29 August. https://doi.org/10.3997/2214-4609.201601774.
Huang, Z., Yan, X., and Yao, J. 2014. A Two-Phase Flow Simulation of Discrete-Fractured Media Using Mimetic Finite Difference Method. Commun Comput Phy 16 (3): 799–816. https://doi.org/10.4208/cicp.050413.170314a.
Huang, Z., Yao, J., Li, Y. et al. 2011. Numerical Calculation of Equivalent Permeability Tensor for Fractured Vuggy Porous Media Based on Homogenization Theory. Commun Comput Phys 9 (1): 180–204. https://doi.org/10.4208/cicp.150709.130410a.
Kang, Z., Wu, Y. S., Li, J. et al. 2006. Modeling Multiphase Flow in Naturally Fractured Vuggy Petroleum Reservoirs. Paper presented at the SPE Annual Technical Conference and Exhibition, San Antonio, Texas, USA, 24–27 September. SPE-102356-MS. https://doi.org/10.2118/102356-MS.
Karimi-Fard, M., Durlofsky, L. J., and Aziz, K. 2004. An Efficient Discrete-Fracture Model Applicable for General-Purpose Reservoir Simulators. SPE J. 9 (2): 227–236. SPE-88812-PA. https://doi.org/10.2118/88812-PA.
Lee, S. H., Jensen, C. L., and Lough, M. F. 1999. An Efficient Finite Difference Model for Flow in a Reservoir with Multiple Length-Scale Fractures. SPE J. 5 (3): 268–275. SPE-56752-MS. https://doi.org/10.2118/56752-MS.
Lee, S. H., Lough, M. F., and Jensen, C. L. 2001. Hierarchical Modeling of Flow in Naturally Fractured Formations with Multiple Length Scales. Water Resour Res 37 (3): 443–455. https://doi.org/10.1029/2000WR900340.
Li, L. and Lee, S. H. 2008. Efficient Field-Scale Simulation of Black Oil in a Naturally Fractured Reservoir through Discrete Fracture Networks and Homogenized Media. SPE Res Eval & Eng 11 (4): 750–758. SPE-103901-PA. https://doi.org/10.2118/103901-PA.
Lie, K. A. 2014. An Introduction to Reservoir Simulation Using MATLAB: User Guide for the Matlab Reservoir Simulation Toolbox (MRST). Oslo, Norway: SINTEF ICT. https://www.sintef.no/contentassets/8af8db2e42614f7fb94fb0c68f5bc256/mrst-book-2016.pdf.
Liu, J., Bodvarsson, G. S., and Wu, Y. S. 2003. Analysis of Flow Behavior in Fractured Lithophysal Reservoirs. J Contam Hydrol 62 (1): 189–211. https://doi.org/10.1016/S0169-7722(02)00169-9.
Loucks, R. G. 1999. Paleocave Carbonate Reservoirs: Origins, Burial-Depth Modifications, Spatial Complexity, and Reservoir Implications. AAPG Bull 83 (11): 1795–1834. https://doi.org/10.1306/E4FD426F-1732-11D7-8645000102C1865D.
Lyu, X., Liu, Z., Hou, J. et al. 2017. Mechanism and Influencing Factors of EOR by N2 Injection in Fractured-Vuggy Carbonate Reservoirs. J Nat Gas Sci Eng 40: 226–235. https://doi.org/10.1016/j.jngse.2017.02.022.
Moinfar, A., Varavei, A., Sepehrnoori, K. et al. 2014. Development of an Efficient Embedded Discrete Fracture Model for 3D Compositional Reservoir Simulation in Fractured Reservoirs. SPE J. 19 (2): 289–303. SPE-154246-PA. https://doi.org/10.2118/154246-PA.
Panfili, P. and Cominelli, A. 2014. Simulation of Miscible Gas Injection in a Fractured Carbonate Reservoir Using an Embedded Discrete Fracture Model. Paper presented at the Abu Dhabi International Petroleum Exhibition and Conference, Abu Dhabi, UAE, 10–13 November. SPE-171830-MS. https://doi.org/10.2118/171830-MS.
Popov, P., Efendiev, Y., and Qin, G. 2009. Multiscale Modeling and Simulations of Flows in Naturally Fractured Karst Reservoirs. Commun Comput Phys 6 (1): 162–184. https://doi.org/10.4208/cicp.2009.v6.p162.
Quandalle, P. and Sabathier, J. C. 1989. Typical Features of a Multipurpose Reservoir Simulator. SPE J. 4 (4): 475–480. SPE-16007-PA. https://doi.org/10.2118/16007-PA.
Saffman, P. G. 1971. On the Boundary Condition at the Surface of a Porous Medium. Stud Appl Math 50 (2): 93–101. https://doi.org/10.1002/sapm197150293.
Smosna, R., Bruner, K. R., and Riley, R. A. 2005. Paleokarst and Reservoir Porosity in the Ordovician Beekmantown Dolomite of the Central Appalachian Basin. Carbonates Evaporites 20 (1): 50–63. https://doi.org/10.1007/BF03175448.
Warren, J. E. and Root, P. J. 1963. The Behavior of Naturally Fractured Reservoirs. SPE J. 3 (3): 245–255. SPE-426-PA. https://doi.org/10.2118/426-PA.
Wu, Y. S., Di, Y., Kang, Z. et al. 2011. A Multiple-Continuum Model for Simulating Single-Phase and Multiphase Flow in Naturally Fractured Vuggy Reservoirs. J Pet Sci Eng 78 (1): 13–22. https://doi.org/10.1016/j.petrol.2011.05.004.
Xie, H., Li, A., Huang, Z. et al. 2017. Coupling of Two-Phase Flow in Fractured-Vuggy Reservoir with Filling Medium. Open Phy 15 (1): 12–17. https://doi.org/10.1515/phys-2017-0002.
Xu, Y., Cavalcante Filho, J., Yu, W. et al. 2017. Discrete-Fracture Modeling of Complex Hydraulic-Fracture Geometries in Reservoir Simulators. SPE Res Eval & Eng 20 (2): 403–422. SPE-183647-PA. https://doi.org/10.2118/183647-PA.
Xu, Y., Fernandes, B. R. B., Marcondes, F. et al. 2019. Embedded Discrete Fracture Modeling for Compositional Reservoir Simulation Using Corner-Point Grids. J Pet Sci Eng 177 (2019): 41–52. https://doi.org/10.1016/j.petrol.2019.02.024.
Xu, Y. and Sepehrnoori, K. 2019. Development of an Embedded Discrete Fracture Model for Field-Scale Reservoir Simulation with Complex Corner-Point Grids. SPE J. 24 (4): 1552–1575. SPE-195572-PA. https://doi.org/10.2118/195572-PA.
Yan, X., Huang, Z., Yao, J. et al. 2018. An Efficient Numerical Hybrid Model for Multiphase Flow in Deformable Fractured-Shale Reservoirs. SPE J. 23 (4): 1412–1437. SPE-191122-PA. https://doi.org/10.2118/191122-PA.
Yan, X., Huang, Z., Yao, J. et al. 2019. Numerical Simulation of Hydro-Mechanical Coupling in Fractured Vuggy Porous Media Using the Equivalent Continuum Model and Embedded Discrete Fracture Model. Adv Water Resour 126: 137–154. https://doi.org/10.1016/j.advwatres.2019.02.013.
Yao, J., Huang, Z., Li, Y. et al. 2010. Discrete Fracture-Vug Network Model for Modeling Fluid Flow in Fractured Vuggy Porous Media. Paper presented at the International Oil and Gas Conference and Exhibition, Beijing, China, 8–10 June. SPE-130287-MS. https://doi.org/10.2118/130287-MS.
Zhang, Q., Huang, Z., Yao, J. et al. 2017. Multiscale Mimetic Method for Two-Phase Flow in Fractured Media Using Embedded Discrete Fracture Model. Adv Water Resour 107: 180–190. https://doi.org/10.1016/j.advwatres.2017.06.020.