Production Performance of a Constant-Pressure Well in an Orthogogonally Fractured Reservoir
- Jacques Hagoort (Hagoort and Associates BV)
- Document ID
- Society of Petroleum Engineers
- SPE Reservoir Evaluation & Engineering
- Publication Date
- June 2010
- Document Type
- Journal Paper
- 523 - 537
- 2010. Society of Petroleum Engineers
- 4.3.4 Scale, 5.1.1 Exploration, Development, Structural Geology, 4.1.5 Processing Equipment, 4.1.2 Separation and Treating, 5.8.6 Naturally Fractured Reservoir, 4.6 Natural Gas, 5.6.9 Production Forecasting, 5.6.4 Drillstem/Well Testing, 5.8.8 Gas-condensate reservoirs
- Fractured reservoirs
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We have analyzed the production performance of a constant-pressure well in a naturally fractured reservoir made up of orthogonal matrix blocks. The fractured reservoir is modeled as a double porosity reservoir, in which interporosity flow is represented by an exact analytical transient influx function. Three distinct production modes can be recognized: Modes I, II, and III. In Mode I, the reservoir boundary is seen after flow in the matrix blocks has stabilized. In Mode II, this occurs while flow in the matrix blocks is still in the infinite-acting stage. In Mode III, the reservoir boundary is already seen before the influx from the matrix blocks has effectively set off. The effect of the natural fractures becomes increasingly evident with increasing mode number: from almost absent in Mode I, to significant in Mode II, and to dominant in Mode III. Mode I shows the best production performance, Mode III the worst. Each production mode can be subdivided into a number of distinct flow regimes. The production profiles in each of these regimes and the regime boundaries can be approximated by simple analytical formulas. These formulas may be used for production forecasting and for analyzing historical production decline.
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