Wells performance is
evaluated by IPR curves that show the relationship between bottomhole pressure
and inflow rate. This curve and its outcome equation can be applied for production schedule and maintenance management
of well and reservoir. But, the measuring of bottomhole pressure to approach
these curves needs much time and high expenses and also running special tools
in wells. In these operations, the probability of catastrophic failure such as
well damage or well complete lost may exist. However, these difficulties in
offshore wells like production platform in the South Pars gas field that are
installed tens kilometers far from lands are harder than any places. Therefore,
nowadays by considering these difficulties, there is a high tendency for using
wellhead test data that are very inexpensive as well as these data are less
accurate than in well data. Moreover, pressure drop due to the existence of gas
condensate in well fluid causes the flow regime to be more complicated. Wide
researches have been applied to two-phase flow pressure drop in the wellbore
and a lot of equations are considered. Anyhow, these equations and their
accuracy should be studied in each special case. In this study that is on the
south Pars gas condensate
field wells, widespread of equations are utilized for calculation of pressure
drop in the tubing and they are applied for tubing performance curve as well.
In the south pars field wells, the well data of bottomhole pressure are not
being measured during production. In this paper, we try to calculate bottomhole
pressure by using PIPESIM software and simulating reservoir fluid and wellbore.
For calculating this pressure, with the combination of effective conditions,
the best equation of flow regime in that well will be selected. Eventually, by
simulation of the reservoir fluid, different parameters like in well
performance and proper tubing size is calculated.
Cite this paper
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