PCB3013 HW#7 Solutions
Transcript of PCB3013 HW#7 Solutions
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Tablo 2. RLT Pressure and Pressure-Derivative Data
Time, hour Delta pressure,
p, psi
Pressure-Derivative,
p, psi
1.00E-03 8.74E+00 7.71E+00
1.58E-03 1.29E+01 9.95E+00
2.00E-03 1.53E+01 1.15E+01
2.51E-03 1.82E+01 1.29E+01
3.16E-03 2.12E+01 1.43E+01
3.98E-03 2.48E+01 1.52E+01
5.01E-03 2.82E+01 1.56E+01
6.31E-03 3.20E+01 1.48E+01
7.94E-03 3.50E+01 1.43E+01
1.00E-02 3.86E+01 1.41E+01
1.26E-02 4.15E+01 1.29E+01
1.58E-02 4.45E+01 1.18E+01
2.00E-02 4.69E+01 9.26E+00
2.51E-02 4.88E+01 9.39E+00
3.16E-02 5.12E+01 5.22E+00
3.98E-02 5.12E+01 6.31E+00
5.01E-02 5.41E+01 8.69E+00
6.31E-02 5.52E+01 4.78E+00
7.94E-02 5.63E+01 5.64E+00
1.00E-01 5.78E+01 6.50E+00
1.26E-01 5.93E+01 5.00E+00
1.58E-01 6.01E+01 3.67E+00
2.00E-01 6.10E+01 7.25E+00
3.16E-01 6.36E+01 4.77E+00
3.98E-01 6.56E+01 5.42E+00
5.01E-01 6.61E+01 3.69E+00
6.31E-01 6.73E+01 3.25E+00
7.94E-01 6.76E+01 4.33E+00
1.00E+00 6.93E+01 7.58E+00
1.58E+00 7.28E+01 2.79E+00
2.51E+00 7.32E+01 5.44E+00
3.16E+00 7.48E+01 4.13E+00
3.98E+00 7.51E+01 7.17E+00
5.01E+00 7.81E+01 5.88E+00
6.31E+00 7.78E+01 6.11E+00
7.94E+00 8.09E+01 1.45E+01
1.00E+01 8.45E+01 1.39E+01
1.26E+01 8.73E+01 1.25E+01
1.58E+01 9.02E+01 1.84E+01
2.00E+01 9.59E+01 2.78E+01
2.51E+01 1.03E+02 3.30E+01
3.16E+01 1.11E+02 3.69E+01
3.98E+01 1.20E+02 4.56E+01
5.01E+01 1.32E+02 6.07E+01
6.31E+01 1.48E+02 7.60E+01
7.94E+01 1.67E+02 1.04E+02
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APPENDIX I
In Table C.1, CA represents the Dietz shape factor, the column with `Exact for tDA`
represents tDA,pss, and the last column `Use infinite system` represents tDA,esl. The
equations for tDA,pss and tDA,esl are given by
esl
t
eslDA thAc
kht
4
,
10637.2 = (I-1)
pss
t
pssDA thAc
kht
4
,
10637.2
= (I-2)
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SOLUTIONS
(a)Figure S.1 shows the log-log plot of the drawdown pressure change and its Bourdet
derivative data. As can be see from derivative data, there is a short period of unit-slope
indicating wellbore storage effect. We observe a hump in derivative data in the time
interval from 0.003 to 0.03 hr, possibly due to a positive skin factor. The wellbore
storage effect ends at about 0.003 hr. Although the derivative data are scattered due tonoise, an infinite acting-radial flow period can be identified as a zero-slope line in the
time interval from 0.03 to 6.0 hr. After about 6.5 hr, we observe a unit-slope line which
is indicative of the pseudo-steady state flow regime, when the no-flow boundaries of
the reservoir influence the well respons.
Figure S.1 Log-Log plot of pressure change and derivative
(b)Figure S.2 showns the semi-log plot based on p not pressure. The slope m is
calculated as:
( ) ( ) ( ) ( )./06.12
1.0log1log
48.5754.69
1log2log
12hrpsi
yy
yym =
=
= (1)
From this slope value, the permeability k is calculated as:
.9.8906.12*30
8.0*25.1*2006.1626.162 md
hm
qBk ===
(2)
1E-3 1E-2 1E-1 1E+0 1E+1 1E+2
Zaman, saat
1E+0
1E+1
1E+2
1E+3
De
lta-pveDelta-p'ninlogaritmikt
revi,psi
Delta-p
Delta-p'nin Trevi Birim Egimli Dogru(Kuyuici Depolanma Etkileri)
evrel Akis(Radyal Akis)
Birim Egimli Dogru(Dis Sinir Etkileri)
Unit-slope line (WBS)
Unit-slope line (PSS Flow)
IARF
Time, h
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The skin is computed from the following equation:
52.023.3328.0*8.0*55.1*2.0
9.89
log06.12
54.69
151.1
23.3log151.1
2
2
1
=
+
=
+
=
e
rc
k
m
pS
wt
hr
(3)
As shown in Fig. S.2, the pressure change (p) data deviate from the semi-log line at about
6 hr so so tesl= 6 hr. Note that p1hr is equal to 4930.46 psi.
Figure S.2: Semi-log plot for IARF analysis.
(c)Figure S.3 shows a Cartesian plot of flowing bottom-hole pressure vs. time. As can be
seen, a well defined straight line with a slope equal to m*=1.202 psi/hr and a intercept
at t = 0 as p0hr= 4972.82 psi was fitted through the data after tpss= 6.5 hr. From the
slope, the pore volume is determined as:
3
5*6.3244014
202.1*105.1*24
25.1*200*615.5
24
615.5ft
mc
qBV
t
p =
==
(4)
The drainage area of the well can be computed as:
1E-3 1E-2 1E-1 1E+0 1E+1 1E+2
Zaman, saat
0.0
40.0
80.0
120.0
160.0
200.0
Delta-p,psi
Yapilan FitY=B*Ln(X)+AY = 5.24586 * Ln(X) + 69.5406
tesl=6 hr
Time, h
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2
5*4.540765
202.1*30*105.1*2.0
25.1*200*234.0234.0ft
hmc
qBA
t
=
==
(5)
(d)Using the equation given for the average pressure and evaluating it at the last test time
of t=79.4 hr
psie
tcV
qBt
Ahc
qBpp
tpt
i 456.954.7955.1*6.3244014
25.1*200*234.0234.0234.0=
===
(6)
psip 5.4904= olarak bulunur.
(e)The Dietz shape factor CAis computed as:
( )
( ) 07.3382.497246.493006.12303.2
exp202.1
06.12
456.5
303.2exp456.5 01*
=
=
=
hrhr
r
r
A pp
mm
mC
(7)
Figure S.3 Cartesian plot of pwf vs. time.
The values of tDA,eslve tDA,pss are computed from
0 5 10 15 20 25 30 35 40 45 50 55 60 65 70 75 80
Zaman, saat
4800.0
4840.0
4880.0
4920.0
4960.0
5000.0
Kuyudibiakisba
sinci,psi
Linear, Y=B*X+ADenklem:Y = -1.20219 * X + 4927.82
pwf
Time, h
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1096.068.0*4.540765*30*105.1*2.0
30*9.89*10637.210637.25
44
, =
=
=
esl
t
eslDA thAc
kht
(8)
1187.05.68.0*4.540765*30*105.1*2.0
30*9.89*10637.210637.25
44
, =
=
=
pss
t
pssDA thAc
kht
(9)
Using these time values together with the value of CA=33.06, I determined a square or
hexagonal type reservoir with the well at the center could be plausible models for the test
data.