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Example 2: Solution Isolate The Reservoir Performance To Visualize The Effect of Changing Reservoir Pressure. The

The document investigates the effects of reservoir depletion on an oil well by analyzing its inflow and outflow performance curves under different reservoir pressures. At an initial reservoir pressure of 2,500 psia, the curves intersect at a production rate of 380 STB/D and bottomhole pressure of 1,650 psia. However, when the reservoir pressure declines to 2,000 psia, the curves do not intersect, indicating the well will stop flowing under these conditions. Options to consider include lowering the wellhead pressure, reducing the tubing size, or installing artificial lift.

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Jitendra Kumar
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68 views1 page

Example 2: Solution Isolate The Reservoir Performance To Visualize The Effect of Changing Reservoir Pressure. The

The document investigates the effects of reservoir depletion on an oil well by analyzing its inflow and outflow performance curves under different reservoir pressures. At an initial reservoir pressure of 2,500 psia, the curves intersect at a production rate of 380 STB/D and bottomhole pressure of 1,650 psia. However, when the reservoir pressure declines to 2,000 psia, the curves do not intersect, indicating the well will stop flowing under these conditions. Options to consider include lowering the wellhead pressure, reducing the tubing size, or installing artificial lift.

Uploaded by

Jitendra Kumar
Copyright
© © All Rights Reserved
We take content rights seriously. If you suspect this is your content, claim it here.
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Download as DOCX, PDF, TXT or read online on Scribd
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Example 2

Investigate the effects of reservoir depletion of an oil well to estimate producing conditions and consider the
need for artificial lift. The well under consideration is producing with a constant wellhead pressure of 250
psia and is controlled by the choke.
Solution Isolate the reservoir performance to visualize the effect of changing reservoir pressure. The
flowing bottomhole pressure at mid-perforations is selected as the node and, as the well is producing under
critical flow conditions, the wellhead will serve as the terminal end of the system.
The inflow and outflow rate-pressure data is generated with Eqs. 5 and 6. Table 3 provides the inflow
performance data for average reservoir pressures of 2,500 psia and 2,000 psia. Table 4 shows the tubingintake data or outflow performance data for a flowing wellhead pressure of 250 psia with 2 7/8-in.
tubing. Fig. 5 plots this information, which is used to determine the producing conditions at the two
reservoir pressures. At an average reservoir pressure of 2,500 psia, the curves intersect at an oil
production rate of 380 STB/D and a flowing bottomhole pressure of 1,650 psia. However, there is no
intersection or point of continuity between the inflow and outflow performance curves when the reservoir
pressure declines to 2,000 psia. This indicates that the well will not flow under these reservoir conditions.
On the basis of this analysis, the effects of lowering the wellhead pressure, reducing the tubing size, or
installing artificial lift early in the life of the well to enhance its deliverability should be investigated

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