Numerical Simulation of Natural Gas Flow in Shale Reservoirs with Thermodynamic Equation of State: A Comparative Study
- Ardiansyah Negara (Baker Hughes Inc.) | Mokhtar Elgassier (Baker Hughes Inc.) | Bilal Saad (Baker Hughes Inc.)
- Document ID
- Society of Petroleum Engineers
- SPE Europec featured at 78th EAGE Conference and Exhibition, 30 May-2 June, Vienna, Austria
- Publication Date
- Document Type
- Conference Paper
- 2016. Society of Petroleum Engineers
- 2.4 Hydraulic Fracturing, 3 Production and Well Operations, 5 Reservoir Desciption & Dynamics, 5.5 Reservoir Simulation, 5.8.2 Shale Gas, 5.8 Unconventional and Complex Reservoirs, 2 Well completion, 5.2.2 Fluid Modeling, Equations of State, 5.2 Fluid Characterization, 1.6.6 Directional Drilling, 4.6 Natural Gas
- Experimenting pressure field, Thermodynamic equation of state, Dual-porosity dual-permeability, Shale gas, Unconventional reservoirs
- 0 in the last 30 days
- 161 since 2007
- Show more detail
- View rights & permissions
|SPE Member Price:||USD 5.00|
|SPE Non-Member Price:||USD 28.00|
Production from unconventional reservoirs like shale gas has increased considerably in the past few years due to the advancement in twofold, i.e., horizontal drilling and hydraulic fracturing technologies. Although there has been some success in increasing gas production from shale reservoirs, unfortunately, the physicochemical processes that take place in the shale formations remain challenging and are not completely understood. Unlike conventional reservoirs, shale reservoirs are characterized by very small porosity and extremely low-permeability. Gas flow in this tight formation involves complex flow processes such as Knudsen diffusion, Klinkenberg effect, adsorption and desorption, strong rock-fluid interaction, rock deformation, etc. Furthermore, because of high pressure and high temperature reservoir conditions the gas behaves as real gas. In this work, our shale gas mathematical model is built based on the dual-porosity dual-permeability model that incorporates the complex flow processes mentioned above as well as the thermodynamic calculations. Peng-Robinson equation of state (PR-EOS) was used to calculate the gas density and compressibility factor by solving the cubic equation. In the numerical method implementation we combine the finite difference method with the experimenting pressure field approach to solve the pressure equations for the matrix and fracture systems in the dual-porosity dual-permeability model. This combination greatly reduces the computational cost when solving the large systems of pressure equations of the matrix and fracture. In this approach, a set of predefined pressure fields is generated in the solution domain such that the undetermined coefficients are calculated from these pressure fields. In the numerical example, we considered a shale reservoir with single production well. Comparison between real gas and ideal gas is studied and the result shows that considering the real gas behavior generates higher cumulative production, which implies that the gas transport capacity is higher than the ideal gas case. The result also indicates that considering real gas behavior in the model would increase the production and retard the decline curve. Therefore, it is very important to incorporate the real gas behavior into the model in order to be able to forecast the production accurately.
|File Size||1 MB||Number of Pages||14|
Azom, P.N. and Javadpour, F. 2012. Dual Continuum Modeling of Shale and Tight Gas Reservoirs. Presented at the SPE Annual Technical Conference and Exhibition, San Antonio, Texas, USA, 8-10 October 2012. SPE-159584-MS. http://dx.doi.org/10.2118/159584-MS.
Ertekin, T., King, G.A., and Schwerer, F.C. 1986. Dynamic Gas Slippage: A Unique Dual-Mechanism Approach to the Flow of Gas in Tight Formations. SPE Formation Evaluation 1: 43–52. SPE-12045-PA. http://dx.doi.org/10.2118/12045-PA.
Florence, F.A., Rushing, J.A., Newsham, K.E. 2007. Improved Permeability Prediction Relations for Low Permeability Sands. Presented at the SPE Rocky Mountation Oil & Gas Technology Symposium, Denver, Colorado, USA, 16-18 April. SPE-107954-MS. http://dx.doi.org/10.2118/107954-MS.
Guo, C., Bai, B., Wei, M. 2013. Study on Gas Permeability in Nano Pores of Shale Gas Reservoirs. Presented at the SPE Unconventional Resources Conference-Canada, Calgary, Alberta, Canada, 5-7 November. SPE-167179-MS. http://dx.doi.org/10.2118/167179-MS.
Javadpour, F. 2009. Nanopores and Apparent Permeability of Gas Flow in Mudrocks. Journal of Canadian Petroleum Technology 48 (8): 16–21. http://dx.doi.org/10.2118/09-08-16-DA.
Michel, G.G., Sigal, R.F., Civan, F. 2011. Parametric Investigation of Shale Gas Production Considering Nano-Scale Pore Size Distribution, Formation Factore, and Non-Darcy Flow Mechanisms. Presented at the SPE Annual Technical Conference and Exhibition, Denver, Colorado, USA, 30 October-2 November. SPE-147438-MS. http://dx.doi.org/10.2118/147438-MS.
Negara, A., Salama, A., and Sun, S. 2013. 3-D Numerical Investigation of Subsurface Flow in Anisotropic Porous Media using Multipoint Flux Approximation Method. Presented at the SPE Reservoir Characterisation and Simulation Conference and Exhibition, Abu Dhabi, UAE, 16-18 September. SPE-165960-MS. http://dx.doi.org/10.2118/165960-MS.
Negara, A., Salama, A., and Sun, S. 2014. Density-Driven Flow in Anisotropic Porous Media: Application to CO2 Geological Sequestration. Presented at the SPE Saudi Arabia Section Annual Technical Symposium and Exhibition, Al-Khobar, Saudi Arabia, 21-24 April. SPE-172232-MS. http://dx.doi.org/10.2118/172232-MS.
Negara, A., Salama, A., Sun, S. 2015b. Numerical Simulation of Natural Gas Flow in Anisotropic Shale Reservoirs. Presented at the SPE Abu Dhabi International Petroleum Exhibition and Conference, Abu Dhabi, UAE, 9-12 November. SPE-177481-MS. http://dx.doi.org/10.2118/177481-MS.
Sakhaee-Pour, A. and Bryant, S.L. 2012. Gas Permeability of Shale. SPE Reservoir Evaluation and Engineering 15: 401–409. SPE-146944-PA. http://dx.doi.org/10.2118/146944-PA.
Singh, H., Javadpour, F., Ettehadtavakkol, A. 2014. Nonempirial Apparent Permeability of Shale. SPE Journal 17: 414–424. SPE-170243-PA. http://dx.doi.org/10.2118/170243-PA.
Wang, H. and Marongiu-Porcu, M. 2015. A Unified Model of Matrix Permeability in Shale Gas Formations. Presented at the SPE Reservoir Simulation Symposium, Houston, Texas, 23-25 February. SPE-173196-MS. http://dx.doi.org/10.2118/173196-MS.
Warren, J.E. and Root, P.J. 1963. The Behavior of Naturally Fractured Reservoirs. SPE Journal 3 (3): 245–255. SPE-426-PA. http://dx.doi.org/10.2118/426-PA.
Wasaki, A. and Akkutlu, I.Y. 2014. Permeability of Organic-Rich Shale. Presented at the SPE Annual Technical Conference and Exhibition, Amsterdam, The Netherlands, 27-29 October. SPE-170830-MS. http://dx.doi.org/10.2118/170830-MS.
Wu, Y.S., Li, J., Ding, D.Y. 2014. A Generalized Framework Model for the Simulation of Gas Production in Unconventional Gas Reservoirs. SPE Journal 19 (5): 845–857. SPE-163609-PA. http://dx.doi.org/10.2118/163609-PA.
Wu, K., Chen, Z., Wang, H. 2015a. A Model for Real Gas Transfer in Nanopores of Shale Gas Reservoirs. Presented at the SPE Europec, Madrid, Spain, 1-5 June. SPE-174293-MS. http://dx.doi.org/10.2118/174293-MS.
Xiong, X., Devegowda, D., Michel, G.G. 2012. A Fully-Coupled Free and Adsorptive Phase Transport Model for Shale Gas Reservoirs including Non-Darcy Flow Effects. Presented at the SPE Annual Technical Conference and Exhibition, San Antonio, Texas, USA, 8-10 October. SPE-159758-MS. http://dx.doi.org/10.2118/159758-MS.