user's guide 12-02-2009 tlsd
TRANSCRIPT
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The use of the software is restricted to participants to
Imperial College JIP on Deconvolution.
If you are a participant, click I agree
Your Company
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TLSD is a pre-processor that converts a variable rate pressure history into a unit
rate drawdown with a duration equal to the total duration of the pressure history.
TLDS
* von Schroeter, T., Hoellander, F. and Gringarten, A. C.:
Deconvolution of Well test Data as a Non-linear Total Least Square Problem, SPEJ
(Dec. 2004) 375-390
TLSD uses a deconvolution algorithm
based on the Total Least Squaremethod*, which provides stable results.
The algorithm estimates both rates
(called adapted rates herein) and
normalised derivative by minimising an
error measure, E, which is a weightedcombination of pressure match, rate
match, and a penalty term based on
the overall curvature of the graphed
derivative and whose purpose is to
enforce smoothness of the resultingdeconvolved derivative.
Data: p, q
Curvature operator: matrix D, vectork
Parameters:
: relative weight : regularization parameter
4342132144 344 21
curvaturematchratematchpressure
222
kzDqygyppE i ++=
Guess g , discretize into D(z), minimize E over pi , y, z
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The weight of the pressure match is normalized to one and the estimate
depends on two weights, for the rate match, and for the roughness penalty.
is usually set at a default value and only the regularisation parameter is
varied.
Regularisation introduces bias, however, and thus the user must choose a level
of that imposes just enough smoothness to eliminate small-scale oscillations
on the derivative while preserving genuine reservoir features.
The methodology for well test analysis using deconvolution is summarised in the
schematic in the following page:
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Deconvolved mn(p) derivative Adapted rates
Convolved pseudo-pressure with adapted rates
Pressure data p
Unit rate convolved pseudo-pressure drawdown
Interpretation
model
Pressure data
Adapted rates
END
Pseudo-pressure mn(p)
Rates
mn(p) vs. p
NO
YES
Deconvolve
Compare
Convolve
Convolve
Analyse ConvolveRefine
match
Unit rate
p vs. mn(p)Unit rate convolved
pressure drawdown
Well test analysis using deconvolution
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1. Deconvolution with various levels of regularisation is applied to pressure andrate data (for gas, pressures are first converted to normalised pseudo-
pressure in order to approximate a linear system).
2. Once a satisfactory derivative has been obtained, a convolved pressure
history is calculated with that derivative, the adapted rates and the initialpressure obtained from deconvolution, and compared with the measured
pressures.
3. If the match is acceptable, a unit-rate pseudo-pressure drawdown is
generated for a duration equal to that of the test, using the deconvolvedderivative.
4. This unit-rate drawdown is analysed in the conventional way.
5. The resulting model is then used applied to the measured pressure datausing the adapted rates and the model parameters are refined until an
acceptable match is obtained.
Well test analysis using deconvolution
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Maureen A2
Test 1 (Exploration)
FP06
Test 2 (Product ion)
FP35
The procedure is illustrated with Well A2 from the Maureen reservoir
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Maureen A2
Test 2 (Build-up)
Test 1 (Bui ld-up)
Test 2 (Drawdown)
RADIAL FLOW
SPHERICAL FLOW
WELLB
ORE
STOR
AGE
Changing
Wellbore
Storage
No boundaries are apparent on a Log-log plot
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Maureen A2 Test 1 (Exploration)Yet, an interpretation model of infinite extent applied to one of the tests fails to match the other test
Exploration test
Production testExploration
test
Exploration test
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Production
test
10-3 10-1 10 103
Elapsed time, t ( hours)
PressureChan
geand
Derivative(psi)
104
103
102
10
1
10-1
10-2
Maureen A2 Test 2 (Production)
Decreasing wellbore storage(gas goingback into solution)
Exploration test
Production test Production test
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Test 1 (build-up)
Test 2 (build-up)
Maureen A2: Evidence of depletionThe only suggestion of boundaries comes from the superposition plot
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Time from the start of the test (hours)
0 4000 8000 12000 16000
Pressure
(psia)
3600
3400
3200
3000
2800
2600
2400
2200
Maureen A2 : Closed rectangle model
Test 1 Test 2
(pav)i psia
(pav)f at the
end of the test psiakh mD.ft
k(xy) mD
k(z) mD
C1 bbl/psi
C2 bbl/psi hrs
hw/h
hw ftS(w)
S(c)
S(t)
Zw ft
d1 ft
d2 ft
d3 ft
d4 ftA
3471.1
346989170
442
4
0.44
0.35
70-3.3
12.8
3.3
166.5
15900
8120
16000
29093.52E+08 ft
2
3478.6
256584090
416
6
0.37
0.06
7.551E-03
0.35
70-3.7
12.2
1.4
166.5
5233
25923
7947
17343.65E+08
Based on this suggestion, in conventional analysis, a closed reservoir model is used
and the distances to the boundaries are adjusted by regression. The distances to
boundaries are highly non-unique, but the area is reasonably constrained
Boundaries can be made to appear
by deconvolution
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Click TLSD
to start
Then click Deconvolution & Convolution
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Input: Variable rate pressure file
Input: Rate history file
Select rate history range from rate history file (default: all rates are used)
Select of flow periods to deconvolve from pressure file
Select initial pressure
input or calculation
STEPS
1
2
3
4
Get default
parameters
Start deconvolution
Deconvolved derivative
Unit rate drawdown with total duration of test calculated from deconvolved derivative
Adapted rates, corrected for errors as determined by deconvolution
Not implemented yet
Input: pseudo-pressure vs. pressure file for gas data deconvolution
Verification
11
Final analysis
12
Advanced options: do not modi fy
Select Excel file to display deconvolution results or ignore for default7
9
Convolved pressure history, calculated from deconvolved derivative, to be compared with input data
Data derivative plot 10
5 Number of points calculated forthe deconvolved derivative (does
not converge if too many points)
8
6
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STEP 1: Input variable rate pressure history file
Format:
1st line: text
1st column: time from start
2nd column: pressure
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STEP 2: Input rate history file
Format:
1st line: text
1st column: duration
2
nd
column: rate
To avoid resolution
problems, choose unitsso that rate values are
small (e.g., MMscf/Dinstead of Mscf/D)
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Additional STEP if gas: Input pseudo-pressure file
2
1
Format:
1st line: text
1st column: pressure
2nd column: pseudo-pressure
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STEP 3: Select rate to be included in deconvolution (default: ALL)
2
43
1
This STEP 3 can be skipped if all rates are to be included in deconvolution
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STEP 4: Select flow periods to be included in deconvolution
2
2
43
1
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STEP 5: Impose a value for the initial pressure
Enter initial pressure
Default: highest
pressure value2
1
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STEP 5: Alternatively, let deconvolution calculate the initial pressure
Only if an initial DST is included in the pressure history
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STEP 6: Initialise to obtain default weights and
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STEP 7: Select an existing output Excel file (or accept the default name)
This Excel fi le is
automaticallycreated to display
the deconvolved
derivative
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STEP 7: Rename the output Excel file (or accept the default name)
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STEP 8: Start deconvolution
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STEP 8 (contd): Deconvolution proceeds
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STEP 9 Deconvolved derivative plotted in Project Excel File
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STEP 9 (contd): Increase and redo deconvolution from STEP 8
Repeat with different values of until satisfactory pressure
match, rate match and deconvolved derivative are obtained
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BETTER DECONVOLVED DERIVATIVE
(i.e., converging to the most likely behaviour)
Increasing
Successive deconvolved derivatives are plotted together
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Successive deconvolved derivatives are compared in the Project Excel
File which is automatically generated by the software in Step 8
Deconvolved derivative files, *.pd , for various deconvolutions
Number of deconvolutions
STEP 10: Successive deconvolved derivatives can be compared with
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1
2
STEP 10: Successive deconvolved derivatives can be compared with
actual data by adding Data Derivative (rate-normalised)
Ratio of derivative window length to total
length of data on a superposition plot
3 4
STEP 10: Data derivatives
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STEP 10: Data derivatives
STEP 10: Data derivatives can be imported if the derivative calculated in
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Rate for flow period 34
Column G is
derivative
divided by rate
Column E is
Elapsed time
Number of points plotted
Number of data derivatives plotted
STEP 10: Data derivatives can be imported if the derivative calculated in
The Project excel file is too noisy
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STEP 10: Deconvolved derivative can also be plotted from TLSD
1
2
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PLOTS: Deconvolved derivative
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PLOTS: Input pressure and rate histories
1
2
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PLOTS: Input pressure and rate histories
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STEP 11: rate match (adapted rates vs. input rates)
1
2
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STEP 11 : rate match (adapted rates vs. input rates)
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STEP 11 : Pressure match
(convolved pressure history vs. input pressure history)
1
2
This plot must be made to verify the quality of the deconvolution
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STEP 11 : Pressure match
(convolved pressure history vs. input pressure history)
Match shown only for the flow periods used for deconvolution
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STEP 11 : Pressure match- zoomed
(convolved pressure history vs. input pressure history)
Match shown only for
the flow periods used
for deconvolution
STEP 12: Select the unit rate drawdown corresponding
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3470.58
3470.60
3470.62
3470.64
3470.66
3470.68
3470.70
3470.72
3470.74
-2000 0 2000 4000 6000 8000 10000 12000 14000 16000 18000
Pressur
e(psia)
Elapsed time (hrs)
0.0
0.2
0.4
0.6
0.8
1.0
1.2
1.4
1.6
1.8
2.0
TotalRate(STB/D)
STEP 12: Select the unit rate drawdown corresponding
to the best deconvolved derivative (*.up)
STEP 12 (contd): Analyse the unit rate drawdown corresponding
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0.0001
0.001
0.01
0.1
0.0001 0.01 1 100 10000 1000000
PressureChangeandDerivative(psi)
Elapsed time (hrs)
Log-Log Diagnostic - Flow Period 2
0.00001
0.0001
0.001
0.01
0.1
1
0.0001 0.01 1 100 10000 1000000
Pres
sureChangeandDerivative(psi)
Elapsed time (hrs)
Log-Log Match - Flow Period 2
3470.59
3470.60
3470.61
3470.62
3470.63
3470.64
3470.65
3470.66
3470.67
3470.68
3470.69
-4 -3 -2 -1 0 1 2 3 4 5
Pressure(psia)
Superposition Function (STB/D)
Horner Analysis - Flow Period 2
3470.61
3470.62
3470.63
3470.64
3470.65
3470.66
3470.67
3470.68
3470.69
3470.70
3470.71
-3 -2 -1 0 1 2 3 4
Pressure(psia)
Superposition Function ( STB/D)
Horner Match - Flow Period 2
3470.58
3470.60
3470.62
3470.64
3470.66
3470.68
0 2000 4000 6000 8000 10000 12000 14000 16000 18000
Pressure(psia)
Elapsed time (hrs)
Simulation (Constant Skin) - Flow Period 2
3470.56
3470.58
3470.60
3470.62
3470.64
3470.66
3470.68
3470.70
3470.72
3470.74
-5000 0 5000 10000 15000 20000
Pressure(psia)
Elapsed time (hrs)
0.0
0.2
0.4
0.6
0.8
1.0
1.2
1.4
1.6
1.8
2.0
TotalRate(STB/D)
Pressure History Model
Partially Penetrating Well with C and SHomogeneousRectangle
Results
(pav)i 3470.690 ps ia(pav) f 3470.611 ps iapwf 3470.595 psiakh 94881 mD.ft
k(xy) 469.7 mDk(z) 46.47 mDC 0.2573 bbl/psihw/h 0.3276Hw 66.17 ftS(w) -1.78S(c) 10.88S(t) 5.46Zw 56.24 ftType top No FlowType bot No Flow
d1 5548.55 ftd2 9851.6 ftd3 6218.37 ftd4 20754.1 ftA 3.6013E+008 ft2Type d1 No FlowType d2 No FlowType d3 No FlowType d4 No FlowPI 65.02 B/D/psiPI-SS 45.21 B/D/psiFE 1.340 fraction
Dp(S) -0.007519 ps i
STEP 12 (cont d): Analyse the unit rate drawdown corresponding
to the best deconvolved derivative
STEP 13: Use the unit rate drawdown interpretation model to analyse
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p y
the measured pressures with the adapted rates (*.ar)
1
10
100
1000
0.0001 0.001 0.01 0.1 1 10 100
PressureChangeandDe
rivative(psi)
Elapsed time (hrs)
Log-Log Diagnostic - Flow Period 34
0.1
1
10
100
1000
0.0001 0.001 0.01 0.1 1 10 100 1000 10000
Pres
sureChangeandDerivative(psi)
Elapsed time (hrs)
Log-Log Match - Flow Period 34
2250
2300
2350
2400
2450
2500
30000 40000 50000 60000 70000 80000 90000 100000
Pressure(psia)
Superposition Function (STB/D)
Horner Analysis - Flow Period 34
2200
2300
2400
2500
2600
0 20000 40000 60000 80000 100000
Pressure(ps
ia)
Superposition Function (STB/D)
Horner Match - Flow Period 34
2200
2400
2600
2800
3000
3200
3400
3600
-2000 0 2000 4000 6000 8000 10000 12000 14000 16000 18000
Pressure(psia)
Elapsed time (hrs)
Simulation (Constant Skin) - Flow Period 34
-4000
-3000
-2000
-1000
0
1000
2000
3000
4000
5000
6000
-5000 0 5000 10000 15000 20000
Pressure(psia)
Elapsed time (hrs)
0
10000
20000
30000
40000
50000
60000
70000
80000
OilRate(STB/D)
Pressure History Model
Partially Penetrating Well with C and SHomogeneousRectangle
Results
(pav)i 3470.690 ps ia(pav) f 2545.409 ps iapwf 2277.907 psiakh 60681 mD.ft
k(xy) 300.4 mDk(z) 30.00 mDC 0.08331 bbl/psihw/h 0.3416Hw 69.00 ftS(w) -3.86S(c) 10.39S(t) -0.92Zw 101.00 ftType top No FlowType bot No Flow
d1 5548.55 ftd2 9851.6 ftd3 6218.37 ftd4 20754.1 ftA 3.6013E+008 ft2Type d1 No FlowType d2 No FlowType d3 No FlowType d4 No FlowPI 52.34 B/D/psiPI-SS 48.30 B/D/psiFE 2.185 fraction
Dp(S) -343.5 psi
THE END