A2 - Solutions
-
Upload
hirensurat -
Category
Documents
-
view
29 -
download
1
description
Transcript of A2 - Solutions
Solutions 1
NExT April 2000
Introduction to Well Testing
Solutions 2
NExT April 2000
Exercise 3
Introduction to Well Testing
Calculate Compressibility for Undersaturated Oil Reservoir
Solution
ct = cf + So co + Sw cw + Sg cg
cf = 3.6 x 10-6 psi-1
Sw = 0.17
Sg = 0
So = 1 - Sw - Sg = 1 - 0.17 - 0.0 = 0.83
From fluid properties correlations,
pb = 2803 psi
co = 1.158 x 10-5 psi-1
cw = 2.277 x 10-6 psi-1
ct = cf + So co + Sw cw + Sg cg
= 3.6 x 10-6 + (0.83) (1.158 x 10-5)
+ (0.17) (2.277 x 10-6) + (0) (?)
= 1.36 x 10-5 psi-1
Solutions 3
NExT April 2000
Exercise 4
Introduction to Well Testing
Calculate Compressibility for Saturated Oil Reservoir
Solution
ct = cf + So co + Sw cw + Sg cg
cf = 3.6 x 10-6 psi-1
Sw = 0.17
Sg = 0.05
So = 1 - 0.17 - 0.05 = 0.78
From fluid properties correlations,
pb = 2803 psi
co = 1.429 x 10-4 psi-1
cg = 5.251 x 10-4 psi-1
cw = 4.995 x 10-6 psi-1
ct = cf + So co + Sw cw + Sg cg
= 3.6 x 10-6 + (0.78) (1.429 x 10-4) + (0.17) (4.995 x 10-6)
+ (0.05) (5.251 x 10-4 )
= 1.42 x 10-4 psi-1
Solutions 4
NExT April 2000
Exercise 5Introduction to Well Testing
Calculate Compressibility for Low-Pressure, High-Permeability Gas Reservoir
Solution
ct = cf + So co + Sg cg + Sw cw
cf = 3.6 x 10-6 psi-1
Sw = 0.2
Sg = 0
Sg = 1 - Sw - So = 1 - 0.2 - 0 = 0.8
From fluid properties correlations,
cg = 8.144 x 10-3 psi-1
cw = 4 x 10-6 psi-1
ct = cf + So co + Sg cg + Sw cw
= 3.6 x 10-6 + (0) ( ? ) + (0.8) (8.144 x 10-3)
+ (0.2) (4 x 10-6)
= 6.52 x 10-3 psi-1
Solutions 5
NExT April 2000
Exercise 6
Introduction to Well Testing
Calculate Compressibility for High-Pressure, Low-Permeability Gas Reservoir
Solution
ct = cf + So co + Sg cg + Sw cw
cf = 2.0 x 10-5 psi-1
So = 0
Sw = 0.35
Sg = 1 - So - Sw = 1 - 0 - 0.35 = 0.65
From fluid properties correlations,
cg = 1.447 x 10-4 psi-1
cw = 3.512 x 10-6 psi-1
ct = cf + So co + Sg cg + Sw cw
= 2.0 x 10-5 + (0) ( ? ) + (0.65) (1.447 x 10-4)
+(0.35) (3.512 x 10-6)
= 1.15 x 10-4 psi-1
Solutions 6
NExT April 2000
Radial Flow and Radius of Investigation
Solutions 7
NExT April 2000
Exercise 1
Radial Flow and Radius of Investigation
Factors That Affect Radius of Investigation
Solution
Without looking at the notes, choose the correct response to complete each statement. Check your answers by referring to the radius of investigation equation.
A) increases
B) decreases
C) does not affect
1. Increasing viscosity __________________ the radius of investigation.
2. Increasing permeability __________________ the radius of investigation.
3. Increasing formation volume factor __________________ the radius ofinvestigation.
4. Increasing test time __________________ the radius of investigation.
5. Increasing production rate __________________ the radius ofinvestigation.
6. Increasing net pay thickness __________________ the radius ofinvestigation.
7. Increasing porosity __________________ the radius of investigation.
8. Increasing total compressibility __________________ the radius ofinvestigation.
decreases
increases
does not affect
increases
does not affect
does not affect
decreases
decreases
Solutions 8
NExT April 2000
Exercise 2
Radial Flow and Radius of Investigation
Calculate Radius of Investigation for an Undersaturated Oil Reservoir
Solution
φ = 0.17
µ = 1.06 cp
ct = 1.36 x 10-5 psi-1 (from Ex. 3, previous section)
ri = 745 ft
k = 250 md
krc948
t2itµφ=
( ) ( ) ( ) ( ) ( )
hrs1.5
25074510x36.106.117.0948
krc948
t
25
2it
=
=
µφ=
−
Solutions 9
NExT April 2000
Exercise 3
Radial Flow and Radius of Investigation
Calculate Radius of Investigation for aSaturated Oil Reservoir
Solution
φ = 0.17
µ = 1.185 cp
ct = 1.42 x 10-4, from Ex. 4, previous section
ri = 745 ft
kro = 0.8
k = 250 md
ko = k kro = (250) (0.8) = 200 md
krc948
t2itµφ=
( ) ( ) ( ) ( ) ( )
hrs75200
74510x42.1185.117.0948
krc948
t
24
2it
=
=
µφ=
−
Solutions 10
NExT April 2000
Exercise 4
Radial Flow and Radius of Investigation
Calculate Radius of Investigation for a Low-Pressure, High-Permeability Gas Reservoir
Solution
φ = 0.12
µ = 0.01151 cp
ct = 6.52 x 10-3 psi-1, from Ex. 5, previous section
ri = 745 ft
k = 100 md
krc948
t2itµφ=
( ) ( ) ( ) ( ) ( )
hrs
x
k
rct it
47100
7451052.601151.012.0948
948
23
2
=
=
µφ=
−
Solutions 11
NExT April 2000
Exercise 5
Radial Flow and Radius of Investigation
Calculate Radius of Investigation for a High-Pressure, Low-Permeability Gas Reservoir
Solution
φ = 0.04
µ = 0.02514 cp
ct = 1.151 x 10-4 psi-1, from Ex. 6, previous section
ri = 745 ft
k = 0.08 md
krc948
t2itµφ=
( ) ( ) ( ) ( ) ( )
hrs76108.0
74510x151.102514.004.0948
krc948
t
24
2it
=
=
µφ=
−
Solutions 12
NExT April 2000
CharacterizingDamage and Stimulation
Solutions 13
NExT April 2000
Exercise 1
Skin Factor and Wellbore Storage
Damage and Skin Factor Calculations
Solution
1.
2.
3.
4.
( ) ( ) ( ) ( )( ) ( ) ( )
psi8.66
111755400
1907.120002.141
khBq2.141
ps
=
=
µ=∆
%6.66
160018008.6616001800
ppppp
Ewf
swff
=
−−−=
−∆−−=
ft10x6.5
e124
err
6
11
swwa
−
−
−
=
=
=
5
2/10012/4
ln
2/Lr
ln
rr
lns
f
w
wa
w
−=
=
=
=
Solutions 14
NExT April 2000
Semilog Analysis for Oil Wells
Solutions 15
NExT April 2000
Exercise 1Semilog Analysis for Oil Wells
Solution
1. First, we plot flowing bottomhole pressure, pwf, as a function of time on semilog paper. The slope, m, of the resulting straight line is the difference between values of pwf one log cycle apart, or
where by convention we use the absolute value of the slope.
2. Effective permeability to oil is estimated using the absolute value of the slope, m, of the line,
( ) ( ) ( ) ( ) cyclepsi1001log100logpsia340,3psia540,3
tlogtlogpp
m12
1wf2wf =−
−=−−=
( )( )( )( )( )( ) md0.8
461008.0136.12506.162
mhBq6.162
k ==µ=
Solutions 16
NExT April 2000
Exercise 1Semilog Analysis for Oil Wells
Solution
3300
3350
3400
3450
3500
3550
3600
1 10 100
Time, hrs
Pre
ssu
re, p
si
p1hr = 3540
p100hr = 3340
m = 100 psi/cycle
3. Noting that p1hr = 3,540 psi, we calculate the skin factor.
As we shall discuss later, a positive value of skin factor indicates a flow restriction (i.e., damage) around the wellbore.
( )( )( )( )05.5
23.3365.010178.012.0
8log
100540,3412,4
151.1
23.3rc
klog
mpp
151.1s
26
2wt
hr1i
=
+
×−−=
+
µφ−−=
−
Solutions 17
NExT April 2000
Exercise 2Semilog Analysis for Oil Wells
Solution
1. First, construct a semilog plot of shut-in pressure, pws, as a function of the Horner time ratio, (tp + ∆t)/∆t. The calculated Horner time ratios are given in the table below, while the semilog plot is shown on the next slide. The absolute value of the slope of the semilog straight line.
t HTR pws t HTR pws
2 500.5 2615.1 18 56.5 2662.5
3 334 2623.9 24 42.625 2668.6
4 250.75 2630.1 30 34.3 2673.3
6 167.5 2638.9 36 28.75 2677.1
8 125.875 2645.1 48 21.8125 2683.1
10 100.9 2649.9 60 17.65 2687.7
12 84.25 2653.8 72 14.875 2691.4
15 67.6 2658.6
( ) ( )cyclepsi50
1log10log750,2700,2
t
ttlog
t
ttlog
ppm
1
1p
2
2p
1ws2ws
=
−−=
∆∆+
−
∆∆+
−=
Solutions 18
NExT April 2000
2500
2550
2600
2650
2700
2750
2800
1101001000
Horner Time Ratio
Pre
ssu
re, p
si
p1hr = 2600
p* = 2750
m = 50 psi/cycle
Exercise 2Semilog Analysis for Oil Wells
Solution
2. Next, we calculate the effective permeability to oil using the slope of the straight line.
3. The original reservoir pressure is found by extrapolating the semilog straight line to infinite shut-in time, i.e., (tp + ∆t)/ ∆t = 1. The pressure at this point is pi = 2,750 psia. At ∆t = 1 hour, the Horner time ratio is (tp + ∆t)/ ∆t = (999 + 1)/1 = 1000. From the extrapolated semilog straight line, p1hr = 2,600 psia at this value.
4. The skin factor is
( )( )( )( )( ) md30
325095.225.1806.162
mhBq6.162
k ==µ=
( )
( )( )( )( )( )
12
23.325.0101595.215.0
30log
508.1847600,2
151.1
23.3rc
klog
mpp
151.1s
26
2wt
wfhr1
=
+
×−−=
+
µφ−−=
−
Solutions 19
NExT April 2000
Wellbore Storage
Solutions 20
NExT April 2000
Exercise 2
Skin Factor and Wellbore Storage
Calculate WBS Coefficient For Single-Phase Liquid
Solution
First, calculate the wellbore volume, using the equation for thevolume of a right circular cylinder:
Next, calculate the WBS coefficient.
( )( ) ( )
bbl5.88
bbl/ft615.5
ft497
ft497
2600122
921.5
hrV
3
3
3
2
2
=
=
=
π=
π=
( ) ( )psi/bbl10X54.3
10X45.88
cVc
4
6
wbwb
−
−
=
=
=
Solutions 21
NExT April 2000
Exercise 3
Skin Factor and Wellbore Storage
Calculate WBS Coefficient For Rising Liquid Level
Solution
First, calculate the cross-sectional area of the wellbore, using the equation for the area of a circle:
Next, calculate the WBS coefficient:
2
2
ft191.0
12.2921.5
rA
=
π=
π=
( ) ( )
psi/bbl10x56.7
cm/g
ft/lbm4.62xcm/g04.1
191.065.25
A65.25c
2
3
33
wb
wb
−=
=
ρ=
Solutions 22
NExT April 2000
Exercise 4
Skin Factor and Wellbore Storage
Calculate WBS Coefficient for Single-Phase Gas
Solution
First, calculate the wellbore volume using the equation for the volume of a right circular cylinder:
Next, use FLPROP to calculate the gas compressibility
cg = 3.21 x 10-4 psi-1
Finally, calculate the WBS coefficient:
C = Vwb cwb
= (54) (3.21 x 10-4) = 0.017 bbl/psi
( ) ( ) ( ) ( ) ( ) ( )
bbls54
ft306
375122
921.57200
122441.2
hrhr
VVV
3
22
csg2csgtbg
2tbg
csgtbgwb
=
=
+
π=
π+π
+=
Solutions 23
NExT April 2000
Flow Regimes and the Diagnostic Plot
Solutions 24
NExT April 2000
FLOWREGM.WTD (Diagnostic Plot)
0.01
0.1
1
10
100
1000
0.0001 0.001 0.01 0.1 1 10 100 1000 10000
Wellbore storage Linear flow
Adj
uste
d pr
essu
re c
hang
e, p
si
Radial equivalent adjusted time, hr
Exercise 1 Flow Regimes and the Diagnostic Plot
Solution