An Analytical Solution for Water Coning in Vertical Wells
- Mohammad Tabatabaei (Texas A&M University) | Ali Ghalambor (University of Louisiana at Lafayette) | Boyun Guo (University of Louisiana at Lafayette)
- Document ID
- Society of Petroleum Engineers
- SPE Production & Operations
- Publication Date
- May 2012
- Document Type
- Journal Paper
- 195 - 204
- 2012. Society of Petroleum Engineers
- 5.5 Reservoir Simulation
- production and operations
- 5 in the last 30 days
- 1,304 since 2007
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Optimizing the completion interval to minimize water coning has been long recognized as a challenge in the industry. After reviewing the mechanism of water coning, a simple analytical model is presented in this study for water-coning systems in high-conductivity reservoirs (reservoirs with low pressure gradient). This model is applicable to predict the critical rate and to determine the optimum wellbore penetration for achieving maximum water-free production rate of vertical oil wells.
The developed model predicts the critical rate on the basis of a radial/spherical/combined (RSC) 3D flow field assumption that takes into account the effect of permeability anisotropy, density difference between water and oil, and limited wellbore penetration. Moreover, optimum wellbore penetration into the oil zone has been determined by maximizing the critical rate. This analytical model reveals the optimum wellbore penetration in high-conductivity reservoirs to be almost half of the pay-zone thickness, depending on the radius of wellbore and drainage area, pay-zone thickness, and the permeability anisotropy of the reservoir.
|File Size||1 MB||Number of Pages||10|
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