Comparison of Chemical-Component Transport in Naturally Fractured Reservoirs Using Dual-Porosity and Multiple-Interacting-Continua Models
- Ali Al-Rudaini (Heriot-Watt University) | Sebastian Geiger (Heriot-Watt University) | Eric Mackay (Heriot-Watt University) | Christine Maier (Heriot-Watt University) | Jackson Pola (Heriot-Watt University)
- Document ID
- Society of Petroleum Engineers
- SPE Journal
- Publication Date
- February 2020
- Document Type
- Journal Paper
- 2020.Society of Petroleum Engineers
- dual-porosity models, multiple interacting continua, MINC, chemical component transport
- 11 in the last 30 days
- 92 since 2007
- Show more detail
- View rights & permissions
|SPE Member Price:||USD 5.00|
|SPE Non-Member Price:||USD 35.00|
We propose a workflow to optimize the configuration of multiple-interacting-continua (MINC) models and overcome the limitations of the classical dual-porosity (DP) model when simulating chemical-component-transport processes during two-phase flow. Our new approach captures the evolution of the saturation and concentration fronts inside the matrix, which is key to design more effective chemical enhanced-oil-recovery (CEOR) projects in naturally fractured reservoirs. Our workflow is intuitive and derived from the simple concept that fine-scale single-porosity (SP) models capture fracture/matrix interaction accurately; it can hence be easily applied in any reservoir simulator with MINC capabilities. Results from the fine-scale SP model are translated into an equivalent MINC model that yields more accurate results compared with a classical DP model for oil recovery by spontaneous imbibition; for example, in a water-wet (WW) case, the root-mean-square error (RMSE) improves from 0.123 to 0.034. In general, improved simulation results can be obtained when selecting five or fewer shells in the MINC model. However, the actual number of shells is case specific. The largest improvement in accuracy is observed for cases where the matrix permeability is low and fracture/matrix transfer remains in a transient state for a prolonged time. The novelty of our approach is the simplicity of defining shells for a MINC model such that the chemical-component-transport process in naturally fractured reservoirs can be predicted more accurately, especially in cases where the matrix has low permeability. Hence, the improved MINC model is particularly suitable to model chemical-component transport, key to many CEOR processes, in (tight) fractured carbonates.
|File Size||1 MB||Number of Pages||17|
Abushaikha, A. S. and Gosselin, O. R. 2008. Matrix-Fracture Transfer Function in Dual-Media Flow Simulation: Review, Comparison and Validation. Paper presented at the Europec/EAGE Conference and Exhibition, Rome, Italy, 9–12 June. SPE-113890-MS. https://doi.org/10.2118/113890-MS.
Abushaikha, A. S. and Gosselin, O. R. 2009. SubFace Matrix-Fracture Transfer Function: Improved Model of Gravity Drainage/Imbibition. Paper presented at the EUROPEC/EAGE Conference and Exhibition, Amsterdam, The Netherlands, 8–11 June. SPE-121244-MS. https://doi.org/10.2118/121244-MS.
Adibhatia, B. and Mohanty, K. K. 2007. Simulation of Surfactant-Aided Gravity Drainage in Fractured Carbonates. Paper presented at the SPE Reservoir Simulation Symposium, Houston, Texas, USA, 26–28 February. SPE-106161-MS. https://doi.org/10.2118/106161-MS.
Ahmed Elfeel, M., Al-Dhahli, A., Geiger, S. et al. 2016. Fracture-Matrix Interactions During Immiscible Three-Phase Flow. J Pet Sci Eng 143 (July): 171–186. https://doi.org/10.1016/j.petrol.2016.02.012.
Ahr, W. M. 2008. Geology of Carbonate Reservoirs: The Identification, Description, and Characterization of Hydrocarbon Reservoirs in Carbonate Rocks. Hoboken, New Jersey, USA: John Wiley & Sons.
Akbar, M. I., Agenet, N., Kamp, A. M. et al. 2018. Evaluation and Optimisation of Smart Water Injection for Fractured Reservoir. Paper presented at the SPE Europec featured at 80th EAGE Conference and Exhibition, Copenhagen, Denmark, 11–14 June. SPE-190854-MS. https://doi.org/10.2118/190854-MS.
Andersen, P. Ø., Brattekås, B., Walrond, K. et al. 2017. Numerical Interpretation of Laboratory Spontaneous Imbibition—Incorporation of the Capillary Back Pressure and How it Affects SCAL. Paper presented at the SPE Abu Dhabi International Petroleum Exhibition & Conference, Abu Dhabi, UAE, 13–16 November. SPE-188625-MS. https://doi.org/10.2118/188625-MS.
Austria, J. J. C. Jr. and O’Sullivan, M. J. 2015. Dual Porosity Models of a Two-Phase Geothermal Reservoir. Oral presentation given at the World Geothermal Congress 2015, Melbourne, Australia, 19–25 April.
Babadagli, T. 2005. Mature Field Development—A Review. Paper presented at the SPE Europec/EAGE Annual Conference, Madrid, Spain, 13–16 June. SPE-93884-MS. https://doi.org/10.2118/93884-MS.
Barenblatt, G., Zheltov, I., and Kochina, I. 1960. Basic Concepts in the Theory of Seepage of Homogeneous Liquids in Fissured Rocks [Strata]. J. Appl. Math. Mech. 24 (5): 1286–1303. https://doi.org/10.1016/0021-8928(60)90107-6.
Bourbiaux, B. J. and Kalaydjian, F. J. 1990. Experimental Study of Cocurrent and Countercurrent Flows in Natural Porous Media. SPE Res Eval & Eng 5 (3): 361–368. SPE-18283-PA. https://doi.org/10.2118/18283-PA.
Burchette, T. P. 2012. Carbonate Rocks and Petroleum Reservoirs: A Geological Perspective from the Industry. Geol Soc Spec Publ 370 (1): 17–37. https://doi.org/10.1144/SP370.14.
Computer Modelling Group (CMG). 2018. STARS Advanced Processes and Thermal Reservoir Simulator, Version 2018 User Guide. Calgary, Canada: Computer Modelling Group.
de Dreuzy, J.-R., Rapaport, A., Babey, T. et al. 2013. Influence of Porosity Structures on Mixing-Induced Reactivity at Chemical Equilibrium in Mobile/Immobile Multi-Rate Mass Transfer (MRMT) and Multiple INteracting Continua (MINC) Models. Water Resour Res 49 (12): 8511–8530. https://doi.org/10.1002/2013WR013808.
Delshad, M., Najafabadi, N. F., Anderson, G. A. et al. 2009. Modeling Wettability Alteration by Surfactants in Naturally Fractured Reservoirs. SPE Res Eval & Eng 12 (3): 361–370. SPE-100081-PA. https://doi.org/10.2118/100081-PA.
Di Donato, G., Lu, H., Tavassoli, Z. et al. 2007. Multirate-Transfer Dual-Porosity Modeling of Gravity Drainage and Imbibition. SPE J. 12 (1): 77–88. SPE-93144-PA. https://doi.org/10.2118/93144-PA.
Ding, Y. D., Wu, Y.-S., Farah, N. et al. 2014. Numerical Simulation of Low Permeability Unconventional Gas Reservoirs. Paper presented at the SPE/EAGE European Unconventional Resources Conference and Exhibition, Vienna, Austria, 25–27 February. SPE-167711-MS. https://doi.org/10.2118/167711-MS.
Egya, D. O., Geiger, S., Corbett, P. W. M. et al. 2018. Analysing the Limitations of the Dual-Porosity Response During Well Tests in Naturally Fractured Reservoirs. Pet. Geosci. 25 (1): 30. https://doi.org/10.1144/petgeo2017-053.
Famy, C., Bourbiaux, B., and Quintard, M. 2005. Accurate Modeling of Matrix-Fracture Transfers in Dual-Porosity Models: Optimal Subgridding of Matrix Blocks. Paper presented at the SPE Reservoir Simulation Symposium, The Woodlands, Texas, USA, 31 January–2 February. SPE-93115-MS. https://doi.org/10.2118/93115-MS.
Firoozabadi, A. 2000. Recovery Mechanisms in Fractured Reservoirs and Field Performance. J Can Pet Technol 39 (11): 13–17. PETSOC-00-11-DAS. https://doi.org/10.2118/00-11-DAS.
Geiger, S., Dentz, M., and Neuweiler, I. 2013. A Novel Multi-Rate Dual-Porosity Model for Improved Simulation of Fractured and Multiporosity Reservoirs. SPE J. 18 (4): 670–684. SPE-148130-PA. https://doi.org/10.2118/148130-PA.
Gilman, J. R. and Kazemi, H. 1983. Improvements in Simulation of Naturally Fractured Reservoirs. SPE J. 23 (4): 695–707. SPE-10511-PA. https://doi.org/10.2118/10511-PA.
Gong, B., Karimi-Fard, M., and Durlofsky, L. J. 2008. Upscaling Discrete Fracture Characterizations to Dual-Porosity, Dual-Permeability Models for Efficient Simulation of Flow With Strong Gravitational Effects. SPE J. 13 (1): 58–67. SPE-102491-PA. https://doi.org/10.2118/102491-PA.
Gurpinar, O. and Kossack, C. A. 2000. Realistic Numerical Models for Fractured Reservoirs. SPE J. 5 (4): 485–491. SPE-68268-PA. https://doi.org/10.2118/68268-PA.
Haggerty, R. and Gorelick, S. M. 1995. Multiple-Rate Mass Transfer for Modeling Diffusion and Surface Reactions in Media with Pore-Scale Heterogeneity. Water Resour Res 31 (10): 2383–2400. https://doi.org/10.1029/95WR10583.
Haggerty, R., Fleming, S. W., Meigs, L. C. et al. 2001. Tracer Tests in a Fractured Dolomite: 2. Analysis of Mass Transfer in Single-Well Injection-Withdrawal Tests. Water Resour Res 37 (5): 1129–1142. https://doi.org/10.1029/2000WR900334.
Hamon, G. 1990. Simulation Study of a Naturally Fractured, Oil-Wet, Water Drive Reservoir. Paper presented at the European Petroleum Conference, The Hague, The Netherlands, 21–24 October. SPE-20892-MS. https://doi.org/10.2523/20892-MS.
Hamon, G. and Vidal, J. 1986. Scaling-Up the Capillary Imbibition Process from Laboratory Experiments on Homogeneous and Heterogeneous Samples. Paper presented at the European Petroleum Conference, London, UK, 20–22 October. SPE-15852-MS. https://doi.org/10.2118/15852-MS.
Iraola, A., Trinchero, P., Karra, S. et al. 2019. Assessing Dual Continuum Method for Multicomponent Reactive Transport. Comput Geosci 130 (May): 11–19. https://doi.org/10.1016/j.cageo.2019.05.007.
Khan, A. S., Siddiqui, A. R., Abd, A. S. et al. 2018. Guidelines for Numerically Modeling Co- and Counter-Current Spontaneous Imbibition. Transp Porous Media 124 (3): 743–766. https://doi.org/10.1007/s11242-018-1093-3.
Kiani, M., Kazemi, H., Ozkan, E. et al. 2011. Pilot Testing Issues of Chemical EOR in Large Fractured Carbonate Reservoirs. Paper presented at the SPE Annual Technical Conference and Exhibition, Denver, Colorado, USA, 30 October–2 November. SPE-146840-MS. https://doi.org/10.2118/146840-MS.
Lemonnier, P. and Bourbiaux, B. 2010. Simulation of Naturally Fractured Reservoirs. State of the Art. Oil Gas Sci. Technol.–Rev. IFP 65 (2): 239–262. https://doi.org/10.2516/ogst/2009066.
Lu, H., Di Donato, G., and Blunt, M. J. 2008. General Transfer Functions for Multiphase Flow in Fractured Reservoirs. SPE J. 13 (3): 289–297. SPE-102542-PA. https://doi.org/10.2118/102542-PA.
Ma, S., Morrow, N. R., and Zhang, X. 1997. Generalized Scaling of Spontaneous Imbibition Data for Strongly Water-Wet Systems. J Pet Sci Eng 18 (3–4): 165–178. https://doi.org/10.1016/S0920-4105(97)00020-X.
Maier, C., Schmid, K. S., Ahmed, M. et al. 2013. Multi-Rate Mass-Transfer Dual-Porosity Modelling Using the Exact Analytical Solution for Spontaneous Imbibition. Paper presented at the EAGE Annual Conference & Exhibition incorporating SPE Europec, London, UK, 10–13 June. SPE-164926-MS. https://doi.org/10.2118/164926-MS.
March, R., Doster, F., and Geiger, S. 2016. Accurate Early-Time and Late-Time Modeling of Countercurrent Spontaneous Imbibition. Water Resour Res 52 (8): 6263–6276. https://doi.org/10.1002/2015WR018456.
Mason, G. and Morrow, N. R. 2013. Developments in Spontaneous Imbibition and Possibilities for Future Work. J Pet Sci Eng 110 (October): 268–293. https://doi.org/10.1016/j.petrol.2013.08.018.
Montaron, B. 2008. Carbonate Evolution. Oil and Gas Middle East, 13 August, https://www.oilandgasmiddleeast.com/article-4852-carbonate-evolution.
Nooruddin, H. A. and Blunt, M. J. 2016. Analytical and Numerical Investigations of Spontaneous Imbibition in Porous Media. Water Resour Res 52 (9): 7284–7310. https://doi.org/10.1002/2015WR018451.
O’Sullivan, M. J. and O’Sullivan, J. P. 2016. Reservoir Modeling and Simulation for Geothermal Resource Characterization and Evaluation. In Geothermal Power Generation: Developments and Innovation, ed. R. DiPippo, Chap. 7, 165–199. Duxford, UK: Woodhead Publishing.
O’Sullivan, M. J., Pruess, K., and Lippmann, M. J. 2001. State of the Art of Geothermal Reservoir Simulation. Geothermics 30 (4): 395–429. https://doi.org/10.1016/S0375-6505(01)00005-0.
Pirker, B. and Heinemann, Z. E. 2008. Method to Preliminary Estimation of the Reserves and Production Forecast for Dual Porosity Fractured Reservoirs. Paper presented at the Europe/EAGE Annual Conference and Exhibition, Rome, Italy, 9–12 June. SPE-113378-MS. https://doi.org/10.2118/113378-MS.
Pruess, K. and Narasimhan, T. N. 1985. A Practical Method for Modeling Fluid and Heat Flow in Fractured Porous Media. SPE J. 25 (1): 14–26. SPE-10509-PA. https://doi.org/10.2118/10509-PA.
Rubin, B. 2007. Simulating Gravity Drainage and Reinfiltration with a Subdomain-Dual-Permeability Hybrid Fracture Model. Paper presented at the SPE Reservoir Simulation Symposium, Houston, Texas, USA, 26–28 February. SPE-106191-MS. https://doi.org/10.2118/106191-MS.
Rubin, B. 2010. Accurate Simulation of Non Darcy Flow in Stimulated Fractured Shale Reservoirs. Paper presented at the SPE Western Regional Meeting, Anaheim, California, USA, 27–29 May. SPE-132093-MS. https://doi.org/10.2118/132093-MS.
Schlumberger. 2017. ECLIPSESM Industry - Reference Reservoir Simulator Technical Description and Reference Manual. Sugar Land, Texas, USA: Schlumberger.
Schmid, K. S. and Geiger, S. 2012. Universal Scaling of Spontaneous Imbibition for Water-Wet Systems. Water Resour Res 48 (3): 1–13. https://doi.org/10.1029/2011WR011566.
Schmid, K. S., Geiger, S., and Sorbie, K. S. 2011. Semianalytical Solutions for Cocurrent and Countercurrent Imbibition and Dispersion of Solutes in Immiscible Two-Phase Flow. Water Resour Res 47 (2): 1–16. https://doi.org/10.1029/2010WR009686.
Shah, D. O. and Schechter, R. S. ed. 1977. Improved Oil Recovery by Surfactant and Polymer Flooding. New York City, New York, USA: Academic Press.
Sivon, A. G., Moridis, G. J., and Blasingame, T. A. 2018. Developing Guidelines for Selection of Appropriate Fracture Models in the Numerical Simulation of Well Performance Behavior for Liquid Rich Ultra-Low Permeability ULP Reservoirs. Paper presented at the SPE Hydraulic Fracturing Technology Conference and Exhibition, The Woodlands, Texas, USA, 23–25 January. SPE-189862-MS. https://doi.org/10.2118/189862-MS.
Su, S., Gosselin, O., Parvizi, H. et al. 2013. Dynamic Matrix-Fracture Transfer Behavior in Dual-Porosity Models. Paper presented at the EAGE Annual Conference & Exhibition incorporating SPE Europec, London, UK, 10–13 June. SPE-164855-MS. https://doi.org/10.2118/164855-MS.
Szymkiewicz, A. 2013. Modelling Water Flow in Unsaturated Porous Media: Accounting for Nonlinear Permeability and Material Heterogeneity: Accounting for Nonlinear Permeability and Material Heterogeneity, Vol. 9. Berlin, Heidelberg: GeoPlanet: Earth and Planetary Sciences, Springer Berlin Heidelberg. https://doi.org/10.1007/978-3-642-23559-7.
Tatomir, A. B., Szymkiewicz, A., Class, H. et al. 2011. Modeling Two Phase Flow in Large Scale Fractured Porous Media with an Extended Multiple Interacting Continua Method. Comput Model Eng Sci 77 (2): 81–111. https://doi.org/10.3970/cmes.2011.077.081.
Torcuk, M. A., Kurtoglu, B., Fakcharoenphol, P. et al. 2013. Theory and Application of Pressure and Rate Transient Analysis in Unconventional Reservoirs. Paper presented at the SPE Annual Technical Conference and Exhibition, New Orleans, Louisiana, USA, 30 September–2 October. SPE-166147-MS. https://doi.org/10.2118/166147-MS.
Treiber, L. E. and Owens, W. W. 1972. A Laboratory Evaluation of the Wettability of Fifty Oil-Producing Reservoirs. SPE J. 12 (6): 531–540. SPE-3526-PA. https://doi.org/10.2118/3526-PA.
Wang, Z., Rutqvist, J., Wang, Y. et al. 2014. The Effect of Stress on Flow and Transport in Fractured Rock Masses Using an Extended Multiple Interacting Continua Method with Crack Tensor Theory. Nucl Technol 187 (2): 158–168. https://doi.org/10.13182/NT13-76.
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.
Yan, B., Alfi, M., An, C. et al. 2016. General Multi-Porosity Simulation for Fractured Reservoir Modeling. J Nat Gas Sci Eng 33 (July): 777–791. https://doi.org/10.1016/j.jngse.2016.06.016.
Zhang, X., Morrow, N. R., and Ma, S. 1996. Experimental Verification of a Modified Scaling Group for Spontaneous Imbibition. SPE Res Eng 11 (4): 280–285. SPE-30762-PA. https://doi.org/10.2118/30762-PA.
Zhou, D., Jia, L., Kamath, J. et al. 2002. Scaling of Counter-Current Imbibition Processes in Low-Permeability Porous Media. J Pet Sci Eng 33 (1–3): 61–74. https://doi.org/10.1016/S0920-4105(01)00176-0.
Zhou, X., Morrow, N. R., and Ma, S. 2000. Interrelationship of Wettability, Initial Water Saturation, Aging Time, and Oil Recovery by Spontaneous Imbibition and Waterflooding. SPE J. 5 (2): 199–207. SPE-62507-PA. https://doi.org/10.2118/62507-PA.
Zimmerman, R. W., Hadgu, T., and Bodvarsson, G. S. 1996. A New Lumped-Parameter Model for Flow in Unsaturated Dual-Porosity Media. Advances in Water Resources 19 (5): 317–327. https://doi.org/10.1016/0309-1708(96)00007-3.