Abstract
This paper presents a novel methodology to model semi-steady state horizontal well flow performance in an anisotropic reservoir taking into account flow in the near-well region for an arbitrary well trajectory. It is based on an analytical productivity model describing coupled axial reservoir flow and radial well inflow. In order to apply this model in an anisotropic reservoir, the permeability field relative to the radial direction perpendicular to the well trajectory and the axial direction along the well trajectory must first be determined. A classical space transformation is used in concert with rotational transforms to obtain a virtual isotropic model. The transformation preserves the volumes and pressures. It is not a novel concept, but different from previous approaches in the sense that it is only applied in the near-well domain to formulate an equally isotropic media. As a result, the use of this virtual isotropic model requires the Dietz shape factor for an ellipse, transformed from the original cylindrical near-well domain. The Dietz shape factors are determined numerically in this research. The semi-steady state well/near-well model is implemented in a numerical simulator incorporating formation anisotropy and wellbore hydraulics. The specific productivity index along the well trajectory is generated using the virtual configuration. Numerical results for different anisotropy ratios and also incorporating frictional losses in the well are presented. Furthermore, the well/near-well model is applied in coupling with streamline reservoir model for a water flooding case. This appears to be the first coupling of a well hydraulics model and a streamline simulator. It presents the application of the well/near-well model in integrated reservoir simulation in an efficient and accurate manner. The results demonstrate that the coupling approach with a streamline reservoir model and the well/near-well is of great potential for advanced well simulation efficiently.
Similar content being viewed by others
References
Aavatsmark, I., Klausen, R.A.: Well index in reservoir simulation for slanted and slightly curved wells in 3D grids. SPE J. 8(01), 41–48 (2003)
Aziz, K., Settari, A.: Petroleum Reservoir Simulation, vol. 476. Applied Science Publishers, London (1979)
Babu, D.K., Odeh, A.: Productivity of a horizontal well. SPE Reserv. Eng. 4(4), 417–421 (1989)
Besson, J.: Performance of slanted and horizontal wells on an anisotropic medium. SPE 20965 presented at European Petroleum Conference, The Hague, Netherlands, October 21-24 (1990)
Borisov, J.P.: Oil production using horizontal and multiple deviation wells, Nedra, Moscow, 1964. Translated into English by Strauss J, Edited by Joshi S D. Philips (1984)
Brand, C.W., Heinemann, J.E., Aziz, K: The grid orientation effect in reservoir simulation. SPE symposium on reservoir simulation, Anaheim, California, February 17–20 (1991)
Brekke, K., Johansen, T.E., Olufsen, R.: A new modular approach to comprehensive simulation of horizontal wells. In: SPE Annual Technical Conference and Exhibition. Society of Petroleum Engineers (1993)
Cao, J., James, L.A., Johansen, T.E.: A new coupled axial-radial productivity model with application to high order numerical well modeling. Presented at SPE reservoir characterisation and simulation conference and exhibition, Abu Dhabi, UAE September (2015)
Cao, J.: Horizontal well and near-well region simulation using coupled axial-radial productivity models. Doctoral dissertation, Memorial University of Newfoundland, St. John’s, Canada (2017)
Cinco-Ley, H., Ramey, H.J., Miller, F.G.: Pseudo-skin factors for partially-penetrating directionally drilled wells, paper SPE 5589, Presented at 50th Annual Fall Meeting, Dallas, September 28 - October 1 (1957)
Dietz, D.N.: Determination of average reservoir pressure from build-up surveys. J. Petrol. Tech. 17(8), 955–959 (1965)
Dikken, B.: Pressure drop in horizontal wells and its effect on production performance. J. Petrol. Tech. 42 (11), 1426–1433 (1990)
Economides, M., Deimbachor, F.X., Brand, C.W., Heinemann, Z.E.: Comprehensive-simulation of horizontal-well performance. SPE Form. Eval. 6(04), 418–426 (1991)
Economides, M.J., Brand, C.W., Frick, T.P.: Well configurations in anisotropic reservoirs. SPE Form. Eval. 11(04), 257–262 (1996)
Fanchi, J.R.: Directional permeability. SPE Reserv. Eval. Eng. 11(3), 565 (2008)
Fokker, P.A., Verga, F., Egberts, P.: New semi-analytic technique to determine horizontal well PI in fractured reservoirs society of petroleum engineers (2005)
Furui, K., Zhu, D., Hill, A.D.: A new skin factor model for perforated horizontal wells. In SPE Annual Technical Conference and Exhibition, 29 September-2 October, San Antonio, Texas (2002)
Furui, K., Zhu, D., Hill, A.D.: A new skin factor model for gravel-packed completions, the SPE Annual Technical Conference and Exhibition held in Houston Texas (2004)
Giger, F.M., Reiss, L.H., Jourdan, A.P.: The reservoir engineering aspect of horizontal drilling, SP 13024 presented at the SPE 59th Annual Technical Conference and Exhibition, Houston, Texas, Sept. 16-19 (1984)
Gupta, A., Penuela, G., Avila, R.: An integrated approach to the determination of permeability tensors for naturally fractured reservoirs. J. Canad. Petroleum Technol. 40(12), 281–295 (2001)
Guyaguler, B., Zapata, V.J., Cao, H., Stamati, H.F., Holmes, J.A.: Near-well-subdomain simulations for accurate inflow-performance-relationship calculation to improve stability of reservoir/network coupling, SPE Canadian unconventional resources and international petroleum conference, Calgary, Alberta, Canada 19-21 October (2010)
Greenkorn, R., Johnson, C., Shallenberger, L.: Directional permeability of heterogeneous anisotropic porous media. SPE J. 2(4), 124–132 (1964). SPE-788-pa
Haaland, S.E.: Simple and explicit formulas for the friction factor in turbulent pipe flow. J. Fluids Eng. 105 (1), 89–90 (1983)
Holmes, J.A., Barkve, T., Lund, O.: Application of a multisegment well model to simulate flow in advanced wells Paper SPE 50646 Presented at the European Petroleum Conference 20-22 October, The Hague, Netherlands (1998)
Kuchuk, F., Brigham, W.E.: Transient flow in elliptical systems. SPE J. 19(06), 401–410 (1979)
Matthews, C.S., Brons, F., Hazebroek, P.: A method for determination of average pressure in a bounded reservoir. Trans., AIME 201, 182–191 (1954)
Medeiros, F., Ozkan, E., Kazemi, H.: A semianalytical, pressure-transient model for horizontal and multilateral wells in composite, layered, and compartmentalized reservoirs. In: SPE Annual Technical Conference and Exhibition. Society of Petroleum Engineers (2006)
Muskat, M.: The flow of homogeneous fluids through porous media. Soil Sci. 46(2), 169 (1937)
Novy, R.A.: Pressure drop in horizontal wells: when can they be ignored?. SPE Reservoir Eng. 10(01), 29–35 (1996)
Penmatcha, V., Aziz, K.: Comprehensive reservoir/wellbore model for horizontal wells. SPE J. 4(3), 224–234 (1999)
Peaceman, D.W.: Interpretation of well-block pressures in numerical reservoir simulation with nonsquare grid blocks and anisotropic permeability. SPE J. 23.03, 531–543 (1983)
Peaceman, D.W.: Recalculation of dietz shape factor for rectangles. Unsolicited Paper SPE, 21256 (1990)
Pedrosa, O.A. Jr., Aziz, K.: Use of a hybrid grid in reservoir simulation. SPE Reservoir Eng. 1(06), 611–621 (1986)
Pollock, D.W.: Semianalytical computation of path lines for finite-difference models. Groundwater 26(6), 743–750 (1988)
Johansen, T.E., Khoriakov, V.: Iterative techniques in modeling of multi-phase flow in advanced wells and the near well region. J. Pet. Sci. Eng. 58(1), 49–67 (2007)
Johansen, T.E., James, L.A., Cao, J.: Analytical coupled axial-radial productivity model for steady-state flow in horizontal wells International Journal of Petroleum Engineering (2015)
Johansen, T.E., Cao, J., James, L.A.: Coupled axial and radial semi-steady state productivity model for horizontal wells accepted by International Journal of Petroleum Engineering (2016)
Johansen, T.E., Hender, D.G., James, L.A.: Productivity index for arbitrary well trajectories in laterally isotropic, spatially anisotropic porous media SPE J. (2017). https://doi.org/10.2118/184408-PA
Joshi, S.D.: Augmentation of well productivity with slant and horizontal wells (includes associated papers 24547 and 25308). J. Petroleum Technol. 40.06, 729–739 (1988)
Skinner, J.H., Johansen, T.E.: Near wellbore streamline modeling: its novelty, application, and potential use. In: SPE International Symposium and Exhibition on Formation Damage Control, 15-17 February, Lafayette, Louisiana, USA (2012)
Tang, Y., Ozkan, E., Kelkar, M., Sarica, C., Yildiz, T.: Performance of horizontal wells completed with slotted liners and perforations. In: SPE/CIM International Conference on Horizontal Well Technology. Society of Petroleum Engineers (2000)
Wolfsteiner, C., Durlofsky, L.J.: Near-well radial upscaling for the accurate modeling of nonconventional wells. SPE Western regional/AAPG Pacific Section Joint Meeting, Anchorage, Alaska 20-22 May (2002)
Wolfsteiner, C., Durlofsky, L.J., Aziz, K.: Calculation of well index for nonconventional wells on arbitrary grids. Comput. Geosci. 7, 61–28 (2003)
Zhang, N.: A New Semi-analytical streamline simulator and its applications to modelling waterflooding experiments. Doctoral disertation, Memorial University of Newfoundland, St. John’s, Canada (2017)
Acknowledgements
The authors thank the Hibernia Management and Development Company (HMDC), Natural Sciences and Engineering Research Council of Canada (NSERC), Chevron Canada and Research and Development Corporation (RDC) for the support without which this work could not have been performed.
Author information
Authors and Affiliations
Corresponding author
Appendix
Appendix
The Dietz shape factor for ellipses with different major to minor axes ratios and with the well in the center is determined numerically in this Section. Previous research, [11, 26, 32], calculated the Dietz shape factor for triangular and rectangular configurations.
Consider a well producing a single-phase, slightly compressible fluid from the center of an elliptical reservoir, which is homogeneous and isotropic. The well is producing at a constant flow rate and the outer boundary of the reservoir is a no flow boundary. Using the above assumptions and boundary conditions, the conservation equation is
An implicit discretization [2] of Eq. (21) is
using a fixed point source well rate, where \(T_{x}= \frac {K}{\phi \mu c_{t}} \frac {\Delta t}{\Delta x^{2}}\) and \(T_{y}=\frac {K}{\phi \mu c_{t}} \frac {\Delta t}{\Delta y^{2}}\). The reservoir is defined by an ellipse with a unique major to minor axes ratio b/a. The equivalent wellbore radius (Peaceman, 1983) in the square grid blocks is given by
where, \(G=\frac {1}{4} e^{-\gamma } \approx 0.1404\). Matching the productivity equation, the Dietz shape factor can be determined by
A calculation example with b/a = 2 is given below using parameters from Table 3. The odd number of grid blocks is convenient in order to locate the well in the center. The pressure distribution after 30 hours is shown in Fig. 25. The red grid blocks are inactive, with no communication to the elliptic reservoir. The average reservoir pressure and the wellbore pressure vs. time are plotted in Fig. 26. The semi-steady state flow period can be determined by observing linearly decreasing pressure everywhere. It is observed that the flow is stabilized after approximately three hours, which means the flow after that is semi-steady state. After that point, the average reservoir pressure curve is parallel to the wellbore pressure, i.e., the difference between them is a constant. Substituting this constant pressure difference into Eq. 24, the Dietz shape factor of this major to minor axes ratio (b/a = 1/2) can be determined. Repeating the same simulation process for different major to minor axes ratios will finally results in the Dietz shape factor function for an elliptical reservoir. This function is plotted in Fig. 28.
The grid orientation effect is also tested in this research to confirm that it does not affect the results we achieved using a finite difference method. Reservoir simulators using finite difference methods are affected by grid orientation effects [6], i.e., fluid tends to flow in the direction of the grid axes rather than diagonal to them. To verify the previous results, the elliptic reservoir is rotated by π/4 from the original one. The shape factor calculation process is repeated again for the rotated elliptical reservoir. An example of pressure distribution for the rotated elliptical reservoir is shown in Fig. 27. The Dietz shape factor results, using both the original elliptic reservoir and the rotated one are plotted in Fig. 28, which indicates the grid orientation effect is insignificant.
Rights and permissions
About this article
Cite this article
Cao, J., Zhang, N., James, L.A. et al. Modeling semi-steady state near-well flow performance for horizontal wells in anisotropic reservoirs. Comput Geosci 22, 725–744 (2018). https://doi.org/10.1007/s10596-018-9722-z
Received:
Accepted:
Published:
Issue Date:
DOI: https://doi.org/10.1007/s10596-018-9722-z