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Pump Capacity Determination For Two-phase Vertical Fluid Flow
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1.2 STATEMENT OF THE PROBLEM
It is important to accurately predict
the pressure drop accross a production system. This has been a difficult
task in the oil and gas industry as the production system in real life
is not homogenous (single phase) as assumed in most theories. The reason
for this is that the two-phase flow is complex and difficult to
analyze. Ideally, gas moves at a much higher velocity than the liquid.
As a result, the down hole flowing pressure of the liquid-gas mixture is
greater than the corresponding pressure corrected for down hole
temperature and pressure and this could be calculated from the produced
gas-liquid ratio.
This pressure drop in a flowing (production) system
could be identified using different existing correlations. Some of
these correlations are empirical, mechanistic or numerical. Hagedorn and
Brown is the most widely used correlation for vertical wells (Schoham,
2006). In planning well completion the tubing diameter that will give
less pressure drop hence much liquid production can be selected by the
use of multiphase correlation.
It is also very necessary to plan for
pumps in tubing size selection should need arise on future production
for pumping of the reservoir fluid to optimize production.
1.3 OBJECTIVE OF THE STUDY
Determine the Hydraulic Horse Power Requirement needed to maintain production of reservoir fluid within economic limit.
The
above objective can be achieved by using two-phase pressure drop
correlations to determine pressure drop in selected production tubing
used in the Niger Delta.
1.4 SCOPE OF THE STUDY
The determination
of pressure drop using the selected two-phase correlations using
production tubings used most often in the Niger Delta.
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