Inflow Performance Relationship (IPR) - Paper Example

IPR, the inflow performance relationship, is defined as the relationship between well flow rate and the pressure drawdown or flowing bottom-hole pressure.

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The Inflow Performance Relationship (IPR) for a well is the relationship between the flow rate of the well q and the flowing pressure of the well Pwf. In single phase flow this is a straight line but when gas is moving in the reservoir, at a pressure below the bubble point, this in not a linear relationship.

Put the below equation that has qo and Pwf together

qoqo, min = 1 0.2 (Pwf p*R) 0.8 (Pwf p*R)2Write how to generate IPR curve, use the below equation.

J=qoPres-Pwf q= 2000 STB/DAY

pres= 1822.6 psi

Pwf=1360.5 psi

Since the Pwf > Pb this equation should be applied

qo=J(Pres-Pwf )Pwf qo

1822.647 0

1500 1396.295984

1000 3560.109662

500 5723.92334

0 7887.737019

Using Pwf and qo, the IPR is generated

Write a little more about IPR and how it useful in determining how many wells are required depending on the drainage area of the field

Inflow performance relationship (IPR) is defined as the relationship between well flow rate and the pressure drawdown (or flowing bottom-hole pressure FBHP). If the FBHP is below the bubble-point pressure or if inertial effects become significant at high rates, IPR becomes curvilinear rather than linear.

In order to generate IPR for wells with different drainages, flow rate, FBHP and average reservoir pressure are used in determining the IPR corresponding to the reservoirs pressure through a single stabilized test (single-point test). Chengs Model applies to the cases where the well penetrates the producing interval at an angle. The angle ranges from zero (vertical well) to 90 degrees (horizontal well). The model is a semi-analytical one, wherein the coefficients of the polynomial equations vary with the inclination angle. For example, the correlations for the 30 and 75 degrees scenarios are respectively:

Majority of the pressure drop caused by production is near the wellbore. This is confirmed by the radial flow equation. In this situation even if the average reservoir pressure is above the bubble point, the area around the wellbore is not, which causes the gas to come out of solution in this area causing the relative permeability (which is based on fluid saturation) of the liquids to change. As the pwf is lower for a greater flow rate the greater this effect has on the well which causes the IPR Curve to bend down.

[qo/qomax]300 = 0.9959 0.1254[pwf/pr] 0.8682[pwf/pr]2[qo/qomax]750 = 0.9915 + 0.1002[pwf/pr] 1.0829[pwf/pr]2

Where;qo = oil flow rate, bbl/dayqomax = oil flow rate at FBHP = 0, bbl/daypwf = FBHP = flowing bottom hole pressure, psipr = reservoir pressure, psith = slant or deviation angle, degrees

In generating the IPRs for horizontal wells, their IPR method is based on estimates of reservoir/well architecture and fluid properties, rather than stabilized flow tests. The central task is to evaluate the maximum oil flow rate (absolute open flow potential).

2.0 Numbers of wells

Put the Ae equation, which is the drainage area of the field

Ae=0.234qBohCtmParameters of the drainage area of the field

Slope of the trend(m) 4.3276

Production rate (q) 2000bbl/day

Formation Thickness (h) 212ft

Formation Volume factor (Bo) 1.116

Rack compressibility factor (Ct) 0.00000746

Porosity () 0.259

Get the Ae in should be in ft^2

Put the asthmatic of a drainage area of horizontal well (2000ft)

And then

Calculate the following

A1= LW = 2000 ft 2(0.5 )

0.5 is the radius in ft

A2 = p 0.5 2/ 2

A3= LW = (rL/c ) (2r ) = ((0.5 )(2000) / 70 )(2(0.5) = 14.28 ft^2

At= 2000+0.39269+14.2858 = 2014.67839 ft^2

#wells= Drainage Area (Ae)Drainage of each wells =292261.702014.67839= 146.24 = 146 wells