A Novel Model of Productivity Analysis and Forecasting for Oil-gas Well We calculate the fluid productivity index firstly and then calculate the unknown set of T. Christopher and O. Uche, Evaluating productivity index in a gas well using K. Aziz, Calculation of well index for nonconventional wells on arbitrary grids,, calculate the productivity of multi-fractured horizontal well. For a fractured For a gas well, the dimensionless productivity index in the wellbore is. 2. 2 w gsc gsc. This paper also gives formulas for calculating the pseudo-skin factor due to partial If the reservoir has a gas cap or bottom water, the effects of the radius and Well productivity is often evaluated using the productivity index, which is defined Keywords: Productivity index; horizontal well; pseudo-skin factor; shape factor group; wellbore eccentricity. INTRODUCTION. Productivity index of oil and gas Function, Description. 1, GasFlowRatePSS, Gas well flow rate for pseudosteady state condition using Darcy flow approximation, [mscf/d].
This paper also gives formulas for calculating the pseudo-skin factor due to partial If the reservoir has a gas cap or bottom water, the effects of the radius and Well productivity is often evaluated using the productivity index, which is defined
The well's productivity index (PI or J is common) is: Under pseudo-steady state (pss), a calculated PI is: The effective permeability-thickness in md-ft () and skin (s) are estimated based on well test analyses. The external radius, , is the radius in feet to the no-flow boundary, based on the approximate drainage area of the well. The Productivity Index trend of the gas well is evaluated from the test data. Regression Analysis is used to develop a correlation, which is then used to evaluate andforecast future Productivity Index trend. The back pressure equation of the Simplified Analysis method is also used to examine the test data. The well is off-center in the y-direction (d y = 1,000 ft; D y = 2,000 ft), centered in the x-direction (d x = D x = 1,000 ft), and off-center in the z-direction (d z = 50 ft; D z = 150 ft). Permeabilities are k x = k y =100 md and k z = 20 md. Wellbore radius is 0.25 ft, B o = 1.25 RB/STB, μ = 1 cp, and s d = 0. Find the productivity index, J. Solution. From Eq. AOF is a common indicator of well productivity and refers to the maximum rate at which a well could flow against a theoretical atmospheric backpressure at the reservoir. The productivity of a gas well is determined with deliverability testing. The constant productivity index concept is only appropriate for oil wells producing under single-phase flow conditions, pressures above the reservoir fluid’s bubblepoint pressure. For reservoir pressures less than the bubblepoint pressure, the reservoir fluid exists as two phases, vapor and liquid, and techniques other than the productivity index must be applied to predict oilwell performance.
The well is off-center in the y-direction (d y = 1,000 ft; D y = 2,000 ft), centered in the x-direction (d x = D x = 1,000 ft), and off-center in the z-direction (d z = 50 ft; D z = 150 ft). Permeabilities are k x = k y =100 md and k z = 20 md. Wellbore radius is 0.25 ft, B o = 1.25 RB/STB, μ = 1 cp, and s d = 0. Find the productivity index, J. Solution. From Eq.
Estimating Productivity Index is one of the necessary and very important steps once the production from an oil or gas well starts. Productivity index tells the
Productivity index (J) The productivity index is a measure of the well potential or ability to produce and is a commonly measured well property 1 . The symbol J is commonly used to express the productivity index; as well as, being the preferred symbol by the Society of Petroleum Engineers.
A discussion of the various measures of the relative ability of a well to produce shows the productivity index to be superior. Although it is felt by some that the productivity index is not a constant with rate of production, data presented indicate that if the tests are properly conducted, the productivity index is constant. Using this method, the Productivity Index (PI) and the Injectivity Index (II) (ie, production/injection rate divided by the driving pressure gradient) can be enhanced by up to 100–180%, with fracture lengths ranging from 25 to 100 m, respectively. The technologies of massive water injection and hydraulic-proppant treatments are well known and One procedure which has been found useful in a number of projects where existing wells were to be used for injection purposes involves the use of a mass productivity index. In this measure of well productivity per pound square inch drawdown, production is expressed in terms of pounds of hydrocarbon material produced, instead of the conventional Productivity Index IPR is well described in this video. To get more familiar with the Inflow / Outflow performance, please refer to our website http://produc Productivity index in horizontal wells Charles Ibelegbu Department of Petroleum & Gas Engineering, University of Port Harcourt, Nigeria Received 19 September 2003; accepted o4 November 2004 The study investigates the effect of reservoir and well parameters on the Productivity Index (PI) of a well. It analyses The productivity index can be a useful indicator of well productivity and wellbore condition during the life of a well. PI will generally decrease over time due to declining reservoir pressure, changes in producing conditions, and/or production problems. for Petroleum Engineering Productivity indexes and flow equations for oil and gas, vertical and horizontal wells, steady state, pseudosteady state and transient flow conditions. Unit conversion in Petroleum Office is based on UnitConverter() Excel function which is part on add-in function library.
The well's productivity index (PI or J is common) is: Under pseudo-steady state (pss), a calculated PI is: The effective permeability-thickness in md-ft () and skin (s) are estimated based on well test analyses. The external radius, , is the radius in feet to the no-flow boundary, based on the approximate drainage area of the well.
AOF is a common indicator of well productivity and refers to the maximum rate at which a well could flow against a theoretical atmospheric backpressure at the reservoir. The productivity of a gas well is determined with deliverability testing. The constant productivity index concept is only appropriate for oil wells producing under single-phase flow conditions, pressures above the reservoir fluid’s bubblepoint pressure. For reservoir pressures less than the bubblepoint pressure, the reservoir fluid exists as two phases, vapor and liquid, and techniques other than the productivity index must be applied to predict oilwell performance. In this study, a new approach is introduced to augment existing correlations for the analysis of Productivity Index of a gas well. The Modified Isochronal test method is used in this analysis. The Productivity Index trend of the gas well is evaluated Horizontal well productivity index under steady state flow. The Giger-Reiss-Jourdan method for well in an anisotropic reservoir, [STB/(d.psi)] 7 ProdIndexHorWellJoshi: Horizontal well productivity index under steady state flow. The Joshi method for well in an anisotropic reservoir, [STB/(d.psi)]