Effects of Partial Completion on Productivity Index

Description

– Effects of Partial Completion on Productivity Index –

Download Effects of Partial Completion on Productivity Index. Petroleum Engineering students who are writing their projects can get this material to aid their research work.

Abstract

A new method for analyzing productivity index (PI) on vertical wells is the main objective of this study. Well, performance is often measured in terms of the well’s productivity which is dependent on a number of factors such as the reservoir’s configuration,

the type of completion, petrophysical and fluid properties, formation damage, etc. The effect of partial completion is the main focus of making the productivity index analysis since almost all vertical wells are partially completed due to the reasons of water coning or gas cap issue, etc.

It is also very expensive to fully complete a well, especially when the formation thickness is so large. Pressure behavior solutions for both closed boundary and constant pressure boundary have been obtained, taking into consideration the effect of partial completion.

Introduction

Well, productivity is one of the major concerns in oil field development and provides the means for oil field development strategy. Sometimes, well performance is measured in terms of productivity index.

In order to arrive at the economic feasibility of drilling a well, petroleum engineers require proven and reliable methods to estimate the expected productivity of that well. Well, productivity is often evaluated using the productivity index, defined as the production rate per unit pressure draw-down.

Petroleum engineers often relate the good productivity evaluation to the long-time performance behavior of a well, that is, the behavior during pseudo-steady-state or/and steady-state flow of a closed system or/and constant pressure system respectively.

The long-term productivity of oil wells is influenced by many factors. Among these factors are petrophysical properties, fluid properties, degree of formation damage and/or stimulation, well geometry, well completions, number of fluid phases, and flow-velocity type (Darcy, non-Darcy) (Yildiz, 2003).

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