Difference between revisions of "3 Phase IPR"

Revision as of 07:38, 17 April 2019

Three-phase Inflow Performance Relationship

3 Phase IPR Curve ^[1]

3 Phase IPR is an IPR curve calculated on the basis of total barrels of produced fluid, including gas.

3 Phase IPR curve is used in Pump Design software for pump sizing.

Math and Physics

The volume of 1 stb of liquid plus associated gas at any pressure and temperature is given by^[1]:

VF=WCUT\ B_w + (1-WCUT)\ B_o + (GLR\ - (1-WCUT)R_s - WCUT\ R_{sw})B_g

^[1]

The total volume of produced fluid rate (liquid plus gas) at any conditions of pressure and temperature:

V=q_{t_{sc}} \times VF

^[1]

$q_{t_{sc}}$ is calculated as usual using:

Vogel's IPR equation
Composite IPR equation

3 Phase IPR calculation example

Figure.1 3 Phase IPR calculation example

Following the well #1 example given by Brown^[1]on Figure 5.8, page 191:

Given:

P_r

= 2550 psi

P_b

= 2100 psi

Test data:

P_{wf}

= 2300 psi

q_t

= 500 b/d

Calculate:

Determine the 3 Phase IPR curves for F_w=0, 0.25, 0.5, 0.75, and 1.

Solution:

The problem was run through PQplot software for different values of watercut.

Result 3 Phase IPR curves are shown on Fig.1. Points indicate results obtained by Brown ^[1].

The PQplot model from this example is available online by the following link: 3 Phase IPR calculation example

Nomenclature

VF

= volume factor, bbl/stb

WCUT

= water cut, fraction

B

= volume factor, dimensionless

GLR

= gas liquid ratio, ? scf / stb

R

= solution gas ration, scf / stb

V

= total volume of produced fluid rate (inducing gas), bbl/d

q

= flowing rate, stb/d

Subscripts

w = water

o = oil

sc = standard conditions

t = total

References

↑ ^1.0 ^1.1 ^1.2 ^1.3 ^1.4 ^1.5 Brown, Kermit (1984). The Technology of Artificial Lift Methods. Volume 4. Production Optimization of Oil and Gas Wells by Nodal System Analysis. Tulsa, Oklahoma: PennWellBookss.

@@ Line 40: / Line 40: @@
 == Nomenclature  ==
-:<math> A, B, C, D, tan(\beta), CD, CG </math> = calculation variables
+:<math> VF </math> = volume factor, bbl/stb
-:<math> F_o </math> = oil fraction, fraction
+:<math> WCUT</math> = water cut, fraction
-:<math> F_w </math> = water fraction, fraction
+:<math> B</math> = volume factor, dimensionless
-:<math> J </math> = productivity index, stb/d/psia
+:<math> GLR</math> = gas liquid ratio, ? scf / stb
-:<math> P </math> = pressure, psia
+:<math> R</math> = solution gas ration, scf / stb
-:<math> q </math> = flowing rate, stb/d
+:<math> V </math> = total volume of produced fluid rate (inducing gas), bbl/d
+:<math> q </math> = flowing rate, stb/d
 ===Subscripts===
-:b = at bubble point<BR/>
+:w = water<BR/>
-:max = maximum<BR/>
 :o = oil<BR/>
-:r = reservoir<BR/>
+:sc = standard conditions
 :t = total<BR/>
-:wf = well flowing bottomhole pressure<BR/>
-:wfG = well flowing bottomhole pressure at point G<BR/>
 == References ==

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