A New Model for Reservoirs With a Discrete-Fracture System
- Fanhua Bill Zeng (University of Regina) | Gang Zhao (University of Regina) | Hong Liu (Chongqing University of Science and Technolog)
- Document ID
- Society of Petroleum Engineers
- Journal of Canadian Petroleum Technology
- Publication Date
- March 2012
- Document Type
- Journal Paper
- 127 - 136
- 2012. Society of Petroleum Engineers
- 4.1.5 Processing Equipment, 5.8.6 Naturally Fractured Reservoir, 4.1.2 Separation and Treating
- naturally fractured reservoir, tight gas, discrete fracture systems, fluid flow in porous medium, well testing
- 3 in the last 30 days
- 868 since 2007
- Show more detail
- View rights & permissions
|SPE Member Price:||USD 10.00|
|SPE Non-Member Price:||USD 30.00|
Dual-porosity and dual-permeability models for naturally fractured reservoirs assume that the fractures in the reservoir are connected with each other and uniformly distributed. However, in some cases, the reservoir characteristics exhibit a discrete-fracture system, which means that the fractures might be unconnected and their distribution is not uniform. In this paper, a new computational model is developed to compute the transient-pressure behaviour for reservoirs with a discrete-fracture system. This computational model is based on Laplace transforms. The fluid flow in the fracture system and reservoir are computed separately, and flux and pressure equivalent conditions in Laplace space are applied in the fracture wall to couple the fluid flow in both systems.
The results suggest that the pressure response in a reservoir with a discrete-fracture system has three flow regions: fluid flow near the wellbore, fracture-dominated fluid flow, and fluid flow in the matrix away from the fracture. The distance between the fracture and the well, fracture parameters (fracture conductivity and non-Darcy effects), and fracture distribution are the main factors affecting the pressure response. In some particular situations, the fracture-dominated fluid-flow region in the pressure-derivative curve may present two valleys, which has been observed in some field cases (Clarkson 2009). The transient-pressure behaviour of a discrete-fracture system is also compared with that for a composite model. It is suggested that in these two scenarios, the early- and middle-time transient-pressure behaviour may be similar and latetime behaviours are quite different. The model provides a tool for identifying the fracture pattern in a specific reservoir.
|File Size||1 MB||Number of Pages||10|
Clarkson, C.R. 2009. Case Study: Production Data and PressureTransient Analysis of Horseshoe Canyon CBM Wells. J Can Pet Technol 48 (10): 27-38. SPE-114485-PA. http://dx.doi.org/10.2118/114485-PA.
Forchheimer, P.F. 1901. Wasserbewegung durch Boden.Zeitschrift des Vereines deutscher Ingenieure 45 (5):1781-1788.
Gao, G., Evans, R.D. and Chang, M. 1994. Pressure-TransientBehavoir for a Horizontal Well Intersecting Multiple Random Discrete Fractures.Prepared for presentation at the SPE Annual Technical Conference andExhibition, New Orleans, 25-28 September.
Karimi-Fard, M., Durlofsky, L.J., and Aziz, K. 2003. AnEfficient Discrete Fracture Model Applicable for General Purpose ReservoirSimulators. Paper SPE 79699 presented at the SPE Reservoir SimulationSymposium, Houston, 3-5 February. http://dx.doi.org/10.2118/79699-MS.
Stehfest, H. 1970. Algorithm 368: Numerical inversion of Laplace transforms.Commun. ACM 13 (1): 47-49. http://dx.doi.org/10.1145/361953.361969.
van Kruijsdijk, C.P.J.W. 1988. Semianalytical Modeling ofPressure Transients in Fractured Reservoirs. Paper SPE 18169 presented at theSPE Annual Technical Conference and Exhibition, Houston, 2-5 October. http://dx.doi.org/10.2118/18169-MS.
Warren, J.E. and Root, P.J. 1963. The Behavior of NaturallyFractured Reservoirs. SPE J. 3 (3): 245-255. SPE-426-PA. http://dx.doi.org/10.2118/426-PA.
Zeng, F. and Zhao, G. 2007. Well Testing Analysis for VariablePermeability Reservoirs. J Can Pet Technol 46 (2).
Zeng, F. and Zhao, G. 2008a. Semianalytical Model forReservoirs With Forchheimer's Non-Darcy Flow. SPE Res Eval & Eng 11 (2): 280-291. SPE-100540-PA. http://dx.doi.org/10.2118/100540-PA.
Zeng, F. and Zhao, G. 2008b. The Optimal Hydraulic FractureGeometry Under Non-Darcy Flow Effects. Paper SPE 114285 presented at theCIPC/SPE Gas Technology Symposium 2008 Joint Conference, Calgary, 16-19 June.http://dx.doi.org/10.2118/114285-MS.