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Context 1
... history matching involved adjustment of gravel pack size and permeability and addition of impermeable grids between the two completion intervals. Moreover, a considerable adjustment of the relative permeability and capillary pressure curves, shown in Figures 10 and 11, had to be made to match the production history after the well's re-completion -particularly within the aquifer zone. Since the T-1 sand is unconsolidated, the flow properties -permeability, relative permeability and capillary pressure, may change during production due to the change of fluid saturation and pressure. ...
Context 2
... DWS well simulation model is used to demonstrate physical mechanism of rapid water cut increase and watering out the DWS well after bottom completion shut-in a) b) at 57.5 months. As depicted in Figure 12, there is a very prompt and severe water invasion into the oil pay zone around the well. It follows that a conventional single -completed well in this reservoir would not produce any oil but water. ...
Context 3
... Moreover, potential restoration the well's oil productivity might require a resting time period after the shut-in of the oil leg -so no more water is produced. During the resting time period, gravity forces could reduce the water saturation around the top completion due to the re-balanced distribution of oil and water in the water coning area. Fig. 12. Water invasion at DWS well after shutdown of sink completion (57.5 ...
Context 4
... production forecasts for the weak (Fig. 13) and strong ( Fig. 14) cases clearly demonstrate inability to produce this reservoir with conventional wells that practically become water wells. The DWS well does restore oil production but would produce about 10 percent less oil due to accidental shutdown of the sink completion (case b) comparing to operation without the accident ...
Context 5
... production forecasts for the weak (Fig. 13) and strong ( Fig. 14) cases clearly demonstrate inability to produce this reservoir with conventional wells that practically become water wells. The DWS well does restore oil production but would produce about 10 percent less oil due to accidental shutdown of the sink completion (case b) comparing to operation without the accident (case c). Moreover, when ...
Context 6
... DWS well does restore oil production but would produce about 10 percent less oil due to accidental shutdown of the sink completion (case b) comparing to operation without the accident (case c). Moreover, when aquifer is small and water drive is weak oil production rate cannot be maintained over the project life, as shown in Figure 13, since the average reservoir pressure drops steadily due to the high water drainage rate and aquifer depletion. Also, when reservoir pressure drops below the bubble point, oil viscosity increases quickly, so less oil could be produced with the same pressure drawdown. ...
Context 7
... when reservoir pressure drops below the bubble point, oil viscosity increases quickly, so less oil could be produced with the same pressure drawdown. In contrast, pressure support from the aquifer would be enough to maintain the oil production rate when the aquifer is large (strong) as shown in Figure 14, therefore higher oil recovery factor could be possible as shown in Figure 15. The reason why constant oil rate value is maintained with large aquifer case is that water drainage from the bottom (sink) completion generates enough pressure drawdown to control water coning around the top completion as shown in Figure 16. ...
Context 8
... when reservoir pressure drops below the bubble point, oil viscosity increases quickly, so less oil could be produced with the same pressure drawdown. In contrast, pressure support from the aquifer would be enough to maintain the oil production rate when the aquifer is large (strong) as shown in Figure 14, therefore higher oil recovery factor could be possible as shown in Figure 15. The reason why constant oil rate value is maintained with large aquifer case is that water drainage from the bottom (sink) completion generates enough pressure drawdown to control water coning around the top completion as shown in Figure 16. ...
Context 9
... contrast, pressure support from the aquifer would be enough to maintain the oil production rate when the aquifer is large (strong) as shown in Figure 14, therefore higher oil recovery factor could be possible as shown in Figure 15. The reason why constant oil rate value is maintained with large aquifer case is that water drainage from the bottom (sink) completion generates enough pressure drawdown to control water coning around the top completion as shown in Figure 16. Comparison of the water saturation maps in Figure 16 and Figure 14 clearly demonstrates effective removal of water saturation beneath the well pumping water at the sink completion. ...
Context 10
... reason why constant oil rate value is maintained with large aquifer case is that water drainage from the bottom (sink) completion generates enough pressure drawdown to control water coning around the top completion as shown in Figure 16. Comparison of the water saturation maps in Figure 16 and Figure 14 clearly demonstrates effective removal of water saturation beneath the well pumping water at the sink completion. Water saturation in the coning area could be somewhat reduced due gravity by shutting down the oil leg and letting the well rest for some time with no production. ...
Context 11
... reason why constant oil rate value is maintained with large aquifer case is that water drainage from the bottom (sink) completion generates enough pressure drawdown to control water coning around the top completion as shown in Figure 16. Comparison of the water saturation maps in Figure 16 and Figure 14 clearly demonstrates effective removal of water saturation beneath the well pumping water at the sink completion. Water saturation in the coning area could be somewhat reduced due gravity by shutting down the oil leg and letting the well rest for some time with no production. ...
Context 12
... history matching involved adjustment of gravel pack size and permeability and addition of impermeable grids between the two completion intervals. Moreover, a considerable adjustment of the relative permeability and capillary pressure curves, shown in Figures 10 and 11, had to be made to match the production history after the well's re-completion -particularly within the aquifer zone. Since the T-1 sand is unconsolidated, the flow properties -permeability, relative permeability and capillary pressure, may change during production due to the change of fluid saturation and pressure. ...
Context 13
... DWS well simulation model is used to demonstrate physical mechanism of rapid water cut increase and watering out the DWS well after bottom completion shut-in a) b) at 57.5 months. As depicted in Figure 12, there is a very prompt and severe water invasion into the oil pay zone around the well. It follows that a conventional single -completed well in this reservoir would not produce any oil but water. ...
Context 14
... Moreover, potential restoration the well's oil productivity might require a resting time period after the shut-in of the oil leg -so no more water is produced. During the resting time period, gravity forces could reduce the water saturation around the top completion due to the re-balanced distribution of oil and water in the water coning area. Fig. 12. Water invasion at DWS well after shutdown of sink completion (57.5 ...
Context 15
... production forecasts for the weak (Fig. 13) and strong ( Fig. 14) cases clearly demonstrate inability to produce this reservoir with conventional wells that practically become water wells. The DWS well does restore oil production but would produce about 10 percent less oil due to accidental shutdown of the sink completion (case b) comparing to operation without the accident ...
Context 16
... production forecasts for the weak (Fig. 13) and strong ( Fig. 14) cases clearly demonstrate inability to produce this reservoir with conventional wells that practically become water wells. The DWS well does restore oil production but would produce about 10 percent less oil due to accidental shutdown of the sink completion (case b) comparing to operation without the accident (case c). Moreover, when ...
Context 17
... DWS well does restore oil production but would produce about 10 percent less oil due to accidental shutdown of the sink completion (case b) comparing to operation without the accident (case c). Moreover, when aquifer is small and water drive is weak oil production rate cannot be maintained over the project life, as shown in Figure 13, since the average reservoir pressure drops steadily due to the high water drainage rate and aquifer depletion. Also, when reservoir pressure drops below the bubble point, oil viscosity increases quickly, so less oil could be produced with the same pressure drawdown. ...
Context 18
... when reservoir pressure drops below the bubble point, oil viscosity increases quickly, so less oil could be produced with the same pressure drawdown. In contrast, pressure support from the aquifer would be enough to maintain the oil production rate when the aquifer is large (strong) as shown in Figure 14, therefore higher oil recovery factor could be possible as shown in Figure 15. The reason why constant oil rate value is maintained with large aquifer case is that water drainage from the bottom (sink) completion generates enough pressure drawdown to control water coning around the top completion as shown in Figure 16. ...
Context 19
... when reservoir pressure drops below the bubble point, oil viscosity increases quickly, so less oil could be produced with the same pressure drawdown. In contrast, pressure support from the aquifer would be enough to maintain the oil production rate when the aquifer is large (strong) as shown in Figure 14, therefore higher oil recovery factor could be possible as shown in Figure 15. The reason why constant oil rate value is maintained with large aquifer case is that water drainage from the bottom (sink) completion generates enough pressure drawdown to control water coning around the top completion as shown in Figure 16. ...
Context 20
... contrast, pressure support from the aquifer would be enough to maintain the oil production rate when the aquifer is large (strong) as shown in Figure 14, therefore higher oil recovery factor could be possible as shown in Figure 15. The reason why constant oil rate value is maintained with large aquifer case is that water drainage from the bottom (sink) completion generates enough pressure drawdown to control water coning around the top completion as shown in Figure 16. Comparison of the water saturation maps in Figure 16 and Figure 14 clearly demonstrates effective removal of water saturation beneath the well pumping water at the sink completion. ...
Context 21
... reason why constant oil rate value is maintained with large aquifer case is that water drainage from the bottom (sink) completion generates enough pressure drawdown to control water coning around the top completion as shown in Figure 16. Comparison of the water saturation maps in Figure 16 and Figure 14 clearly demonstrates effective removal of water saturation beneath the well pumping water at the sink completion. Water saturation in the coning area could be somewhat reduced due gravity by shutting down the oil leg and letting the well rest for some time with no production. ...
Context 22
... reason why constant oil rate value is maintained with large aquifer case is that water drainage from the bottom (sink) completion generates enough pressure drawdown to control water coning around the top completion as shown in Figure 16. Comparison of the water saturation maps in Figure 16 and Figure 14 clearly demonstrates effective removal of water saturation beneath the well pumping water at the sink completion. Water saturation in the coning area could be somewhat reduced due gravity by shutting down the oil leg and letting the well rest for some time with no production. ...
