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When the injected fluid reaches the wellbore, the flowing bottom hole pressure increases quickly.
In these methods, production rate and flowing bottom hole pressure must be known.
However, tubing too small for the production rate can cause excess friction and require a larger flowing bottom hole pressure.
The additional gas augments the formation gas and reduces the flowing bottom hole pressure, thereby increasing the inflow of produced fluids.
Controlling the annulus pressure to regulate the tubing flow rate to minimize flowing bottom hole pressure and increase production can be an effective method.
Based on the data provided, we assume that during the data gathering, the change in flowing bottom hole pressure (FBHP) is negligible.
Similar(44)
BHP is denoted by pwf (flowing bottom-hole pressure) or pws (shut in pressure).
As the result, it does not need iteration in each reservoir pressure step to compute the relevant flowing bottom-hole pressure during the constant gas production period.
The lower flowing bottom-hole pressure is, the shorter tef is, because the larger producing pressure drop enhances the fluid flow in formation.
Fig. 3 represents the actual data compared with calculated production rate from modified five-region model [setting the flowing bottom-hole pressure (FBHP) to 4 MPa].
The modeling results confirm the experimental results, and both methods indicate that significant productivity loss can occur in retrograde gas condensate reservoirs when the flowing bottom-hole pressure falls below dew point pressure.
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