PUMP CAPACITY DETERMINATION FOR TWO-PHASE VERTICAL FLUID FLOW
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- 1-5 Chapters
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- Table of Content: Available
- Reference Style: APA
- Recommended for : Student Researchers
- NGN 5000
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.
Objectives
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.
Scope of The Work
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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