pcb3013 hw#5 solution
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8/13/2019 PCB3013 HW#5 Solution
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PCB3013-Well Test Analysis
HW# 5
Prof. Dr. Mustafa Onur, UTP, September 2013
SOLUTIONS
Given Date: October 29, 2013Due Data: November 07, 2013
Subject: Analysis of a buildup test with wellbore storage and skin effects by using type-curve
matching and semi-log techniques.
Table 1 gives reservoir/well/fluid data for a vertical well known to be producing at the center
of a closed reservoir. Table 2 presents the pressure data obtained from a buildup testconducted in that well.
(a) (10 pts)Estimate producing time using total production and rate prior to shut-in.
(b) (20 pts)Make a log-log diagnostic plot of delta shut-in pressure change and its derivative
versus elapsed time, and identify flow regimes exhibited by the buildup data and their timeintervals. Also calculate wellbore storage coefficient from unit-slope line if it exists and kh
from radial flow derivative (i.e., from zero-slope line) if it exists.
(c) (30 pts) Perform Horner Analysis to determine permeability, skin, and initial staticpressure. Note that to determine which time interval you will fit your radial flow straight lineon Horner graph, you should look at log-log diagnostic plots of delta pressure and its
derivative.
(d) (40 pts) Analyze the same data using type curve matching to estimate k, s, wellborestorage coefficient. Please tabulate your results for comparison.
Table 1. Reservoir/well/fluid property data.
Reservoir Thickness, h, 30 ft
Well radius, rw,, 0.3 ft
Viscosity, , 1.0 cp
Formation Volume Factor,Bo, 1.0 RB/STB
Porosity 0.1Total compressibility, ct 1x10
-51/psi
Flow rate before shut-in 300 STB/D
Total production prior to shut-in 150000 STB
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Table 2. Buildup Test Pressure Data
Shut-in Time
t, h.
Shut-in
Pressures
pws, psi
Delta Pressure
p=pwf,s-pws
psi
Delta
pressure-
derivative
(based on
Equivalent
time)psi
0.0 3961.98 0.0 -
0.01 3965.16 2.40 2.27
0.06 3977.23 15.25 15.84
0.14 3997.14 35.16 33.79
0.2 4011.03 49.05 48.55
0.32 4037.89 75.91 74.83
0.57 4091.54 129.56 113.62
1.01 4175.46 213.48 174.77
1.43 4244.22 282.24 222.47
2.01 4326.49 364.51 253.54
4.02 4515.62 553.64 271.05
6.37 4631.6 669.62 217.87
8.02 4678.39 716.41 182.83
10.1 4715.24 753.26 142.92
12.71 4743.4 781.42 105.56
16 4764.25 802.27 77.89
20.15 4780.28 818.3 58.99
25.37 4792 830.02 46.92
31.93 4801.62 839.64 39.37
35.83 4806.51 844.53 39.64
40.2 4810.72 848.74 36.25
50.61 4819.51 857.53 36.63
56.79 4823.23 861.25 35.65
71.49 4831.93 869.95 33.68
80.21 4835.39 873.41 34.1
127.13 4851.33 889.35 33.45
a-) The total production is given as 150000STB and the flow rate prior to shut in is
given as 300STB/D. From the above we can approximate the production time as:
Total Production 150000500 12000
300p p pt t Days t hrs
q= = = =
b-) The log-log plot is given below:
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It is clear from the points that fall on the unit slope line that a wellbore storage
dominated flow period exists. Using the point at t=0.14 hrs.
05.016.3524
14.01300
24=
=
=
p
tBqC osc bbl/psi
From the radial flow period we have:
70.6 70.6
ln
ln
sc o sc od p q B q Bkhd pd t kh
d t
= =
If we use the point at t=71.49 hrs. Then we have:
9.62868.33
10.13006.70
ln/
6.70=
=
=
tdpd
Bqkh osc
md-ft
c-) Since we have taken tpas 12000hrs, we can say tp>>t. The horner plot of the data
is given below:
0.01 0.1 1 10 100 1000t, hrs
1
10
100
1000
pwf,s
-pws,psi
Unit slope line
Flat line
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The equation for the semi-log straight line of the Horner plot is given as follows:
81.7log 5013.48pt t
pt
+ = +
Hence from the slope of the semilog straightline we can estimate the kh product:
1.5977.81
10.13006.162ln/
6.162 ==
=tdpd
Bqkh osc md-ft
From the semilog equation we can compute the pressure at t =1hr.
( )12000 1
( 1) 81.7log 5013.48 1 4680.21
p t p t psi+
= = + = =
We can solve for skin using the below equation
23.4
23.33.011011.0
9.19log
7.81
98.39612.4680151.1
23.3log151.1
25
2
,1
=
+
=
+
=
s
s
rc
k
m
pps
wt
swfhr
Estimate of initial static pressure can be found from extrapolation of the straight line
to Horner ratio of 1 aspi= 5013 psia.
1 10 100 1000 10000 100000 1000000 10000000
(tp+t)/t
3800
4000
4200
4400
4600
4800
5000
Shutin
pressure,psi
p=-81.7log((tp+t)/t)+5013.48
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d-) Data have been analyzed using type curve matching. The following values of kh,
C and S are obtained.
kh, md-ft 661
s 5.55
C, bbl/psi 0.0495
All values determined from all analysis methods are given below:
Unit Slope line
and log-log
derivative plot,
part-b
Horner part-c Type-Curve Matching
kh, md-ft 628.9 597.1 661
S 4.23 5.55
C, bbl/psi 0.05 0.0495
pi, psi 5013 -