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Using Distributed Volumetric Sources To Predict Production From Multiple-Fractured Horizontal Wells Under Non-Darcy-Flow Conditions
- Shahram Amini (Texas A&M University) | Peter P. Valkó (Texas A&M University)
- Document ID
- Society of Petroleum Engineers
- SPE Journal
- Publication Date
- March 2010
- Document Type
- Journal Paper
- 105 - 115
- 2010. Society of Petroleum Engineers
- 5.5 Reservoir Simulation, 5.3.2 Multiphase Flow, 5.8.1 Tight Gas, 5.8.3 Coal Seam Gas, 2 Well Completion, 2.5.2 Fracturing Materials (Fluids, Proppant), 5.8.2 Shale Gas, 3.2.3 Hydraulic Fracturing Design, Implementation and Optimisation, 5.6.3 Pressure Transient Testing, 5.6.4 Drillstem/Well Testing
- tight gas; horizontal well intersected by transverse fracture; non-Darcy flow; method of distributed volumetric sources; optimum fracture dimensions
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- 1,381 since 2007
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The method of distributed volumetric sources (DVS) has been applied to predict gas production from a horizontal well with multiple transverse fractures in a bounded reservoir. Combining the quasianalytical DVS method, which provides us with the opportunity to predict pressure and production behavior of complex well/fracture configurations, with non-Darcy flow in the fracture enables us to calculate the optimum configuration in terms of the number and dimensions of fractures per well for a certain amount of proppant of a given type. The method is applied to an example case of a tight gas reservoir to maximize the production performance of this complex well/fracture configuration. Comparing results with and without inclusion of the non-Darcy effect in the fracture shows that a decrease in production occurs because of non-Darcy flow in all cases. However, a systematic screening of a realistic set of well/fracture configurations reveals that the detrimental effect of non-Darcy flow can be substantially compensated for by selecting the right number of fractures and shifting the fracture dimensions in favor of thicker fractures. While a simultaneous decrease in optimum lateral (and vertical) extension is necessary, it has limited effect on productivity. The simplicity, robustness, and small computational demand of the model allow seamless integration with external economic and operational constraints, providing a tool to screen and optimize a large set of possible configurations most suited for the development of economically marginal fields.
Modern drilling and completion technologies have now provided us the opportunity to design and implement complex well fracture configurations. These complex configurations are used mainly in development of economically marginal reserves, where nonfractured vertical wells would be uneconomical. Among the complex completion schemes of particular importance is the horizontal well completed with multiple transverse fractures. This completion scheme is now widely used in offshore and tight gas development projects.
The main goal of this paper is to provide a practical tool for prediction of the pressure and productivity behavior of such completions. Development of the method of DVS and the formulation of the problem for the case of a horizontal well with multiple fractures are discussed.
Because one of the main applications of this type of completion is in tight gas and the inertial effect for high-velocity gas flow is significant, in this work, the DVS method is implemented, taking into account the non-Darcy-flow effect in the fracture. A simple optimum search procedure is presented to achieve maximum production performance from a given amount of resources. The procedure is then applied to a tight-gas-field case, and it is demonstrated that, by selecting the right configuration, the detrimental effect of non-Darcy flow can be largely compensated for.
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