1887

Abstract

Summary

Multi-scale fractured reservoirs can be modelled effectively using hybrid methods that partition fractures into two subsets: one where fractures are upscaled and another one where fractures are represented explicitly. Existing partitioning methods are qualitative or empirical.

In this paper, we present a novel and quantitative partitioning approach based on a single-porosity hybrid modelling workflow that uses numerical (Embedded Discrete Fracture Methods – EDFM) and semi-analytical (Effective Medium Theory – EMT) methods for fracture subset upscaling. We demonstrate this workflow using synthetic fracture data and realistic data sourced from outcrops of the Jandaira Carbonate Formation in the Potiguar Basin, Brazil.

Fracture subset upscaling with EDFM and EMT using three datasets (two real, one synthetic) shows that the smallest, most numerous fractures are poorly connected. The ability of fracture subset upscaling to identify these fractures is essential to the hybrid modelling workflow. EDFM and EMT methods give nearly identical results, but EMT enables us to greatly accelerate the calculations.

To validate our workflow, hybrid models were created with different partitioning sizes and compared against EDFM simulations where all fractures are represented explicitly. A single-phase pressure drawdown was used a test problem. The simulation results show that once the upscaled fractures begin to connect, deviations in flow response start to grow because single-porosity representations are inadequate to capture the separation of timescales between flow in a well-connected fracture subset and flow in the matrix. In some cases, the flow regime in the model were observed to change entirely.

Overall, the results justify the proposed workflow as a means for systematic and quantitative construction of hybrid models.

Loading

Article metrics loading...

/content/papers/10.3997/2214-4609.201802221
2018-09-03
2024-04-19
Loading full text...

Full text loading...

References

  1. Abushaikha, A. S., & Gosselin, O. R.
    (2013). Matrix-Fracture Transfer Function in Dual-Media Flow Simulation: Review, Comparison and Validation. In Europec/EAGE Conference and Exhibition. Society of Petroleum Engineers. https://doi.org/10.2118/113890-MS
    [Google Scholar]
  2. Ahmed Elfeel, M., & Geiger, S.
    (2012). Static and Dynamic Assessment of DFN Permeability Upscaling. Proceedings of SPE Europec/EAGE Annual Conference, (June), 4–7. https://doi.org/10.2118/154369-MS
    [Google Scholar]
  3. Berkowitz, B.
    (2002). Characterizing flow and transport in fractured geological media: A review. Advances in Water Resources, 25(8–12), 861–884. https://doi.org/10.1016/S0309-1708(02)00042-8
    [Google Scholar]
  4. Bisdom, K., Bertotti, G., Bezerra, H., Van Eijk, M., Van Der Voet, E., & Reijmer, J.
    (2017). Deterministic fracture network models from the Potiguar basin, Brazil. TU Delft. https://doi.org/10.4121/uuid:988152da-3ac3-44cb-9d87-c7365e3707b6
  5. Bisdom, K., Bertotti, G., & Nick, H.
    (2015). The impact of different aperture distribution models and critical stress criteria on equivalent permeability in fractured rocks. Journal of Geophysical Research: Solid Earth. https://doi.org/10.1002/2015JB012657
    [Google Scholar]
  6. Bonnet, E., Bour, O., Odling, N. E., Davy, P., Main, I., Cowie, P., & Berkowitz, B.
    (2001). Scaling of Fracture Systems in Geological Media, (1999), 347–383.
    [Google Scholar]
  7. Bourbiaux, B.
    (2010). Fractured Reservoir Simulation: a Challenging and Rewarding Issue. Oil & Gas Science and Technology – Revue de l’Institut Français Du Pétrole, 65(2), 227–238. https://doi.org/10.2516/ogst/2009063
    [Google Scholar]
  8. Bourbiaux, B., Basquet, R., Cacas, M.-C., Daniel, J.-M., & Sarda, S.
    (2002). An Integrated Workflow to Account for Multi-Scale Fractures in Reservoir Simulation Models: Implementation and Benefits. In Abu Dhabi International Petroleum Exhibition and Conference. Society of Petroleum Engineers. https://doi.org/10.2118/78489-MS
    [Google Scholar]
  9. Cominelli, A., Panfili, P., Scotti, A., & Milano
    . (2013). Using Embedded Discrete Fracture Models (EDFMs) to Simulate Realistic Fluid Flow Problems. Second Workshop on Naturally Fractured Reservoirs, (August 2016). https://doi.org/10.3997/2214-4609.20132026
    [Google Scholar]
  10. Cosentino, L., Coury, Y., Daniel, J. M., Manceau, E., Ravenne, C., Van Lingen, P., … Sengul, M.
    (2001). Integrated Study of a Fractured Middle East Reservoir with Stratiform Super-K Intervals - Part 2: Upscaling and Dual Media Simulation. 2001 SPE Middle East Oil Show, (SPE 68184), 654–666. https://doi.org/10.2523/68184-MS
    [Google Scholar]
  11. Dershowitz, W. S., & Herda, H. H.
    (1992). Interpretation of fracture spacing and intensity, 757–766.
    [Google Scholar]
  12. Ebigbo, A., Lang, P. S., Paluszny, A., & Zimmerman, R. W.
    (2016). Inclusion-Based Effective Medium Models for the Permeability of a 3D Fractured Rock Mass. Transport in Porous Media, 113(1), 137–158. https://doi.org/10.1007/s11242-016-0685-z
    [Google Scholar]
  13. Firoozabadi, A.
    (2000). Recovery mechanisms in fractured reservoirs and field performance. Journal of Canadian Petroleum Technology, 39(11), 13–17. https://doi.org/10.2118/00-11-DAS
    [Google Scholar]
  14. Flemisch, B., Berre, I., Boon, W., Fumagalli, A., Schwenck, N., Scotti, A., … Tatomir, A.
    (2017). Benchmarks for single-phase flow in fractured porous media. Advances in Water Resources, 111(October 2017), 239–258. https://doi.org/10.1016/j.advwatres.2017.10.036
    [Google Scholar]
  15. Karimi-Fard, M., Gong, B., & Durlofsky, L. J.
    (2006). Generation of coarse-scale continuum flow models from detailed fracture characterizations. Water Resources Research, 42(10), 1–13. https://doi.org/10.1029/2006WR005015
    [Google Scholar]
  16. Kazemi, H., & Gilman, J. R.
    (1993). Multiphase Flow in Fractured Petroleum Reservoirs. Flow and Contaminant Transport in Fractured Rock. Woodhead Publishing Limited. https://doi.org/10.1016/B978-0-12-083980-3.50010-3
    [Google Scholar]
  17. Lee, S. H., Lough, M. F., & Jensen, C. L.
    (2001). Hierarchical modeling of flow in naturally fractured formations with multiple length scales. Water Resources Research, 37(3), 443–455. https://doi.org/10.1029/2000WR900340
    [Google Scholar]
  18. Lemonnier, P., & Bourbiaux, B.
    (2010a). Simulation of Naturally Fractured Reservoirs. State of the Art. Oil & Gas Science and Technology – Revue de l’Institut Français Du Pétrole, 65(2), 239–262. https://doi.org/10.2516/ogst/2009066
    [Google Scholar]
  19. (2010b). Simulation of Naturally Fractured Reservoirs. State of the Art. Oil & Gas Science and Technology – Revue de l’Institut Français Du Pétrole, 65(2), 263–286. https://doi.org/10.2516/ogst/2009067
    [Google Scholar]
  20. Makel, G. H.
    (2007). The modelling of fractured reservoirs: constraints and potential for fracture network geometry and hydraulics analysis. Geological Society, London, Special Publications, 292, 375–403. https://doi.org/10.1144/SP292.21
    [Google Scholar]
  21. March, R., Doster, F., & Geiger, S.
    (2018). Assessment of CO 2 storage potential in Naturally Fracture Reservoirs with dual-porosity models, 1–23. https://doi.org/10.1002/2017WR022159
  22. Matthai, S. K., & Belayneh, M.
    (2004). Fluid flow partitioning between fractures and a permeable rock matrix. Geophysical Research Letters, 31(7), 1–5. https://doi.org/10.1029/2003GL019027
    [Google Scholar]
  23. Moinfar, A., Varavei, A., Sepehrnoori, K., & Johns, R. T.
    (2014). Development of an Efficient Embedded Discrete Fracture Model for 3D Compositional Reservoir Simulation in Fractured Reservoirs. Spe, (April), 289–303. https://doi.org/10.2118/163666-MS
    [Google Scholar]
  24. Nelson, R. A.
    (2001). Geologic analysis of naturally fractured reservoirs. Gulf Professional Pub. Retrieved from http://www.sciencedirect.com.ezproxy1.hw.ac.uk/science/book/9780884153177
    [Google Scholar]
  25. Oda, M.
    (1985). Permeability tensor for discontinuous rock masses. Géotechnique, 35(4), 483–495. https://doi.org/10.1680/geot.1985.35.4.483
    [Google Scholar]
  26. Priest, S.
    (1993). Discontinuity Analysis for Rock Engineering. Journal of Chemical Information and Modeling (Vol. 53). https://doi.org/10.1017/CBO9781107415324.004
    [Google Scholar]
  27. Sævik, P. N.
    (2015). Analytical Methods for Upscaling of Fractured Geological Reservoirs, PhD Thesis. University of Bergen.
    [Google Scholar]
  28. Sævik, P. N., Berre, I., Jakobsen, M., & Lien, M.
    (2013). A 3D Computational Study of Effective Medium Methods Applied to Fractured Media. Transport in Porous Media, 100(1), 115–142. https://doi.org/10.1007/s11242-013-0208-0
    [Google Scholar]
  29. Sævik, P. N., Jakobsen, M., Lien, M., & Berre, I.
    (2014). Anisotropic effective conductivity in fractured rocks by explicit effective medium methods. Geophysical Prospecting, 62(6), 1297–1314. https://doi.org/10.1111/1365-2478.12173
    [Google Scholar]
  30. Tene, M., Bosma, S. B. M., Al Kobaisi, M. S., & Hajibeygi, H.
    (2017). Projection-based Embedded Discrete Fracture Model (pEDFM). Advances in Water Resources, 105, 205–216. https://doi.org/10.1016/j.advwatres.2017.05.009
    [Google Scholar]
  31. Wang, X.
    (2016). Fluid flow in multi-scale fractured networks : from field observation to numerical modelling.
    [Google Scholar]
  32. Warren, J. E., & Root, P. J.
    (1963). The behavior of naturally fractured reservoirs. Society of Petroleum Engineers Journal, 3(3), 245–255.
    [Google Scholar]
  33. Witherspoon, P. A., Wang, J. S. Y., Iwai, K., & Gale, J. E.
    (1980). Validity of Cubic Law for fluid flow in a deformable rock fracture. Water Resources Research, 16(6), 1016–1024. https://doi.org/ 10.1029/WR016i006p01016
    [Google Scholar]
http://instance.metastore.ingenta.com/content/papers/10.3997/2214-4609.201802221
Loading
/content/papers/10.3997/2214-4609.201802221
Loading

Data & Media loading...

This is a required field
Please enter a valid email address
Approval was a Success
Invalid data
An Error Occurred
Approval was partially successful, following selected items could not be processed due to error