High Resolution Hydraulic Fracture Network Modeling Using Flexible Dual Porosity Dual Permeability Framework
- D. Yang (Chevron Energy Technology Company) | X. Xue (Chevron Energy Technology Company) | J. Chen (Chevron Energy Technology Company)
- Document ID
- Society of Petroleum Engineers
- SPE Western Regional Meeting, 22-26 April, Garden Grove, California, USA
- Publication Date
- Document Type
- Conference Paper
- 2018. Society of Petroleum Engineers
- 5.5 Reservoir Simulation, 5.5.8 History Matching, 2 Well completion, 5.6 Formation Evaluation & Management, 5 Reservoir Desciption & Dynamics, 5.6.9 Production Forecasting, 2.4 Hydraulic Fracturing, 3 Production and Well Operations
- High Resolution Hydraulic Fracture Network, Flexible Dual Porosity Dual Permeability Framework
- 3 in the last 30 days
- 194 since 2007
- Show more detail
- View rights & permissions
|SPE Member Price:||USD 9.50|
|SPE Non-Member Price:||USD 28.00|
Advancement of multistage hydraulic fracturing technology made unconventional reservoirs (UCR) development economically very attractive. Accurate and efficient production forecasts from UCR are challenging because of the complexity of the fracture network. Abstractions inherent in the traditional dual porosity dual permeability (DPDK) model makes it inadequate to simulate UCR. Discrete Fracture Model (DFM) provides better resolution of fracture geometry but it is not widely used in the industry because it is computationally expensive and history matching is difficult to perform.
This paper presents a new option which utilizes the dual medium framework from traditional DPDK modeling and incorporates effects of each fracture explicitly as it is done in the DFM approach. Single medium is used to model the matrix where there is no fracture present, and dual medium is used to model the fracture network and matrix. This method takes advantage of the optimized DPDK feature in existing commercial simulators. In the near wellbore areas where fractures exist, matrix-fracture coupling is calculated using the same equation as the Embedded Discrete Fracture Model (EDFM). Additionally, to increase accuracy, high resolution local grid refinements (LGRs) are adopted at fracture locations. The new option is benchmarked with the existing EDFM tool using synthetic and field cases.
The results of the benchmark studies indicate that high resolution LGR can minimize sensitivity to the resolution of matrix grid. Flexible DPDK framework allow us to utilize existing reservoir simulation workflow for grid property modification with clear and detailed 3D visualization of matrix and fracture through comerically available visualization packages.
The new option provides a precise and efficient method to simulate complex fracture networks. Implementation and integration with other simulation workflows are straightforward since it makes use of existing functionalities and frameworks in a commercial simulator. Potential applications to improve the efficiency of UCR factory operations include automatic probabilistic forecasting, history matching, and optimization.
|File Size||1 MB||Number of Pages||14|
Kazemi, H., Merill, L.S., Porterfield, K.L. and Zeman, P.R. 1976. Numerical Simulation of Water-Oil Flow in Naturally Fractured Reservoirs. SPE Journal 16 (6): 317–326. http://dx.doi.org/10.2118/5719-PA.
Cipolla, C. L., Lolon, E. P., Erdle, J. C., & Rubin, B. 2010. Reservoir Modeling in Shale-Gas Reservoirs. SPE Res Eval & Eng 13 (4): 638–653, SPE-125530-PA. http://dx.doi.org/10.2118/125530-PA.
Baca, R.G., Arnett, R.C., and Langford, D.W. 1984. Modeling fluid flow in fractured porous rock masses by finite element techniques, Int. J. Num. Meth. Fluids 4:337–348. http://dx.doi.org/10.1002/fld.1650040404.
Kim, J.-G. and Deo, M. D. 2000. Finite element, discrete-fracture model for multiphase flow in porous media. AIChE J. 46: 1120–1130. http://dx.doi.org/10.1002/aic.690460604.
Karimi-Fard, M., & Firoozabadi, A. 2003. Numerical Simulation of Water Injection in Fractured Media Using the Discrete-Fracture Model and the Galerkin Method. SPE Res Eval & Eng 6 (2): 117–126. http://dx.doi.org/10.2118/83633-PA.
Karimi-Fard, M., Durlofsky, L. J., and Aziz, K. 2004. An Efficient Discrete-Fracture Model Applicable for General-Purpose Reservoir Simulators. SPE Journal 9 (2): 227–269. http://dx.doi.org/10.2118/88812-PA.
Monteagudo, J. E. P. and Firoozabadi, A. 2004. Control-volume method for numerical simulation of two-phase immiscible flow in two- and three-dimensional discrete-fractured media. Water Resour. Res. 40 (7): 1–20. http://dx.doi.org/10.1029/2003WR002996.
Matthäi, S. K., Mezentsev, A., & Belayneh, M. 2005. Control-Volume Finite-Element Two-Phase Flow Experiments with Fractured Rock Represented by Unstructured 3D Hybrid Meshes. Presented at the SPE Reservoir Simulation Symposium, The Woodlands, Texas, 31 January-2 February. http://dx.doi.org/110.2118/93341-MS.
Olorode, O., Freeman, C. M., Moridis, G., and Blasingame, T. A. 2013. High-Resolution Numerical Modeling of Complex and Irregular Fracture Patterns in Shale-Gas Reservoirs and Tight Gas Reservoirs. SPE Res Eval & Eng 16 (4): 443–455. http://dx.doi.org/10.2118/152482-PA.
Monteagudo, J.E.P., Rodriguez, A.A., and Florez, H. 2011. Simulation of Flow in Deformable Fractured Porous Media. Paper SPE 141267 presented at the 2011 SPE Reservoir Simulation Symposium, The Woodlands, Texas, 21-23 February. http://dx.doi.org/10.2118/141267-MS.
Yang, D., Moridis, G.J., and Blasingame, T. 2014. A fully coupled multiphase flow and geomechanics solver for highly heterogeneous porous media. Journal of Computational and Applied Mathematics 270: 417–432. https://doi.org/10.1016/j.cam.2013.12.029.
Li, L. and Lee, S. H. 2018. 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. http://dx.doi.org/10.2118/103901-PA.
Hajibeygi, H., Karvounis. D., and Jenny, P. A hierarchical fracture model for the iterative multiscale finite volume method. J. Comput. Phys. 230 (3): 628–643. https://doi.org/10.1016/j.jcp.2011.08.021.
Moinfar, A., Varavei, A., Sepehrnoori, K., and Johns, R. T. 2013. Development of a Coupled Dual Continuum and Discrete Fracture Model for the Simulation of Unconventional Reservoirs. Paper SPE 163647 presented at the 2013 SPE Reservoir Simulation Symposium, The Woodlands, Texas, 18-20 February. https://doi.org/10.2118/163647-MS.
Moinfar, A., Varavei, A., Sepehrnoori, K., and Johns, R. T. 2014. Development of an Efficient Embedded Discrete Fracture Model for 3D Compositional Reservoir Simulation in Fractured Reservoirs. SPE Journal 19 (2): 289–303. https://doi.org/10.2118/154246-PA.
Jiang, J. and Younis, R. M. 2016. Hybrid Coupled Discrete-Fracture/Matrix and Multicontinuum Models for Unconventional-Reservoir Simulation. SPE Journal 21 (3): 1009–1027. https://doi.org/10.2118/178430-PA.
Xu, Y., Cavalcante Filho, J. S. A., Yu, W., and Sepehrnoori, K. 2017. Discrete-Fracture Modeling of Complex Hydraulic-Fracture Geometries in Reservoir Simulators. SPE Res Eval & Eng 20 (2): 403–422. https://doi.org/10.2118/183647-PA.
Du, S., Liang, B., and Yuanbo, L. 2017. Field Study: Embedded Discrete Fracture Modeling with Artificial Intelligence in Permian Basin for Shale Formation. Paper SPE 187202 presented at the 2017 SPE Annual Technical Conference and Exhibition, San Antonio, Texas, 9-11 October. https://doi.org/10.2118/187202-MS.
Nasvik, H., Dombrowsky, T. P., Cheng, N., Bowen, G., and Edwards, D. A. 2013. Representing Hydraulic Fractures Using a Multilateral, Multisegment Well in Simulation Models. Paper SPE 163644 presented at the 2013 SPE Reservoir Simulation Symposium, 18-20 February, The Woodlands, Texas, USA. http://dx.doi.org/10.2118/163644-MS.
Du, S., Yoshida, N., Liang, B., and Chen, J. 2016. Application of multi-segment well approach: Dynamic modeling of hydraulic fractures. Journal of Natural Gas Science and Engineering 34: 886–897. https://doi.org/10.1016/j.jngse.2016.07.028.