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Well Test Analysis
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7/18/2014
1
Pressure Drawdown Test
1
Lecture Outline
Brief overview of PDD
Test Procedure
Test Types
Information obtained
Mathematical Model
Interpretation
Semi-log analysis
Cartesian and log-log analysis
Ideal versus Actual Test
ETR, MTR & LTR
Practice Problems
Common mistakes
Summary
2
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Lecture Outcomes
At the end of this class, a student should be able to do the following:
Describe how a pressure drawdown test is conducted
Synthesize the various data and information to interpret a pressure draw down test
Make qualitative judgment on the data and choose appropriate interpretation method
Isolate the correct data for interpretation
Draw conclusions from results
Make suggestions on the improvement of the test
3
Test Procedure
A well that is static, stable, and shut in, is opened to flow. Ideally, the flow rate should be constant. Flow rate is usually measured as surface rate
recording the pressure (usually down hole) in the wellbore as a function of time
4
Ra
te,
qP
ress
ure
, P
Time, t
drawdown
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Types of Flow Tests
PDD is also known as Flow Test. Actually, Flow Test is a more generalized term.
There may me several types of Flow Tests, as follows:
Single or Constant Rate Test (q = constant)
variable Rate Test [q = f(t)]
Rate changing smoothly
Rate changing abruptly (Multi-Rate Tests)
5
Ra
te,
q
time
q1
q2
q3
q4
q5
q6
qn-1
qn
t1 t2 t3 t4 t5 tn-1
Test Outcomes
Information gathered/required
Pressure versus time recording (pwf – vs – t)
Flow rate (q)
Fluid properties- B, µ
Formation and well parameters –Ø, ct, h, rw
Test interpretation results Formation permeability (k)
Initial pressure (pi)
Wellbore condition - damage or stimulation- skin (s)
Reservoir heterogeneities or boundaries
Hydrocarbon Volume
6
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Mathematical Model
The basis for flow-test analysis techniques is the line source solution to the diffusivity equation:
7
kt
rc
kh
qBPP wt
wfi
2688,1ln
6.70
If natural logarithm is changed to base-10 logarithm and
rearranged
s
rc
kt
kh
qBPP
wt
iwf 869.023.3loglog6.162
2
s
kt
rc
kh
qBPP wt
iwf 2688,1
ln6.70 2
8Mathematical Model
This equation is similar to XmBY log
and suggest a semi-log plot of vs wfP tlog
s
rc
kt
kh
qBPP
wt
iwf 869.023.3loglog6.162
2
should be a straight line
pwf = pressure at the wellbore any time during flow
pi = initial pressure
t = elapsed time after production begins
Ø = pororsity
µ = viscosity
ct = total compressibility; s = skin factor
with a slope of kh
qB6.162
this equation is the main mathematical model for the PBU
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Pwf
t
100 101 102 103 104 105
Pwf1
Pwf2
One log cycle
Slope = Pwf2 – Pwf1
Semi-log Plot9
Analysis Method (Estimate k, s)
Draw the best fit straight line through the MTR data points
Obtain the slope of the straight line
kh
qBmslope
6.162
10
The absolute value of the slope is used to estimate the effective
permeability to the fluid flowing in the drainage area of the well
mh
qBk
6.162
23.3log151.1
2
1
wt
hri
rc
k
m
PPs
And the skin factor is (absolute value of m must be used here as well)
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Analysis Method (Estimate Pore Volume)
dt
dPc
qBV
wf
t
p
234.0
dt
dPwf
11
For a well centered in a cylindrical drainage area the pore volume
of the drainage area can be estimated by:
where
is the slope
of the
straight line
of the
Cartesian
plot of Pwf
versus t
Pw
f, p
si
t, hours
slope=dPwf/d
t
Here we use a Cartesian Plot- Pseudo-Steady State MUST be reached
Actual Drawdown DataBecause many of the assumptions made during the derivation and solution of the diffusivity equation, in actual life instead of obtaining a straight line for all times, we obtain a curve which can be divided into three region:
1. An early time region in which well bore unloading effects are dominant,
2. A middle time region during which the transient flow regime is applicable and the diffusivity equation is purely valid, and
3. A late time region in which the radius of investigation has reached the well’s drainage boundaries.
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Pwf
100 101 102 103104
Late Time
Region
(LTR)
Early Time
Region
(ETR) Middle
Time
Region
(MTR)
t
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PBU versus PDD
PDD
Pressure-Time data when the well is producing
Involves 1 rate only (ideal)
Difficult to maintain constant flow rate
No revenue loss due to shut in
PBU
Pressure-Time data when the well is shut in
Involves at least 2 rates, the last rate MUST be zero
Constant flow rate is easily obtained (shut in period)
Difficult to obtain constant rate prior to shut in
Revenue loss
13
PBU versus PDD
PDD- semi-log analysis
pwf vs t
no transformation of t
wellbore & boundary effects may be present to distort data
PBU- semi-log analysis
pws vs Horner Time Ratio
time is transformed as (tp + Δt)/ Δt
wellbore & boundary effects may be present to distort data
14
Cartesian (useful- Early time and Late time)Log-log – Type curves (very useful)Semi log –Plot (very useful- if MTR straight line can be located)Semi-log plot may vary depending on the test type, as illustrated below:
Pwf
t100
101
102
103
104
105
Pw
f1Pw
f2
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8
15
PDD Test Example
Estimate formation permeability, skin factor and the reservoir pore
volume in the drainage area from the drawdown test data given
the following formation and fluid properties:
q = 90 STB/D
Pi = 2140 psia
h = 5 ft
= 21.7 %
rw = 0.49 ft
B = 1.091 RB/STB
ct = 7.8 x 10-6 psi-1
= 2.44 cp
PDD Test Example
Drawdown Test Data:
16
Time
(minutes)
Pressure
(psi)
Time
(minutes)
Pressure
(psi)
15 538.8 195 411.6
30 499.2 210 408.3
45 479.1 225 405.2
60 465.4 240 402.4
75 455.0 255 399.7
90 446.6 270 397.1
105 439.6 285 394.7
120 433.5 300 392.4
135 428.1 315 390.3
150 423.4 330 388.2
165 419.1 345 386.2
180 415.2 360 384.3
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PDD Test Example
Time must be in hours.
17
Time (minutes) Time
(hours)
Pressure
(psi)
Time (minutes) Time
(hours)
Pressure
(psi)
15 0.25 538.8 195 3.25 411.630 0.50 499.2 210 3.50 408.345 0.75 479.1 225 3.75 405.260 1.00 465.4 240 4.00 402.475 1.25 455.0 255 4.25 399.790 1.50 446.6 270 4.50 397.1
105 1.75 439.6 285 4.75 394.7120 2.00 433.5 300 5.00 392.4135 2.25 428.1 315 5.25 390.3150 2.50 423.4 330 5.50 388.2165 2.75 419.1 345 5.75 386.2180 3.00 415.2 360 6.00 384.3
350
400
450
500
530
10-1 100 101 102 103
t
Pwf,
psi
PDD Test Example- Semi-log Plot
cyclepsim /100462362
18
462
362
4621 hrP
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PDD Test Example
mh
qBk
6.162
19
1005
44.2091.1906.162k
mdk 9.77
Formation permeability:
cyclepsim /100462362
from the semi-log plot, we got
putting in the equation
PDD Test Example
23.3
49.0108.744.2217.0
9.77log
100
4622140151.1
26xs
20
23.3log151.1
2
1
wt
hri
rc
k
m
PPs
4621 hrP
94.13s
Skin factor:
from the semi-log plot, we got
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PDD Test Example21
350.0
370.0
390.0
410.0
430.0
450.0
470.0
490.0
510.0
530.0
550.0
0.00 1.00 2.00 3.00 4.00 5.00 6.00 7.00
= - 12
x1 = 5y1 = 394
x2 = 6y2 = 382
m = -12
dt
dPwf
dt
dPc
qBV
wf
t
p
234.0
Vp = 0.234 X 90 X 1.091/(7.8X10-6X12) = 245,475 cu.ft.
Common Mistakes Incorrect Reading of plot
slope
p1hr
pi, pwf
Units
log term calculation
Scaling of the plot- choose scale such that paper usage is maximum, and covers the entire data range
22
dt
dPwf
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12
Lecture Summary Remember the axes of the plots- what goes along which axis
for semi log plot, we have pwf along Y-axis (Cartesian), and t along X-axis (log)
Semi log plot is most useful for interpretation of PDD
Cartesian plot is also used for PDD, to obtain Reservoir Pore Volume. Only late time data is used for this purpose, assuming Pseudo-Steady Stae is reached
Not all data will fall on the straight line
MTR straight line is most important- but locating it is a challenge
plots must be nice, clean, and informative
Be careful about the common mistakes
practice, practice, practice
23
Lecture Outline Discussions on WBS
Estimating WBS & twbs
Application of various plots
Lecture Outcomes: Students should be able to
Apply graphical techniques and equations in a comprehensive manner for PDD test interpretation:
locate the correct data set appropriate for analysis
estimate Cs & twbs
evaluate k, s, Vp
Comment and discuss on the relative merits/applicability of the techniques
24
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Estimating Wellbore Storage
During a pressure transient test (such as PBU, PDD etc) the early data usually gets distorted by Near Wellbore Effects
Skin, Wellbore Storage, Fractures
Quantifying skin from test data was covered before
Need to address Wellbore Storage
Define the term Cs = Wellbore storage coefficient
Cs is defined as : bbl/psi
Awb = cross sectional area of wellbore, ft2
ρ = density of the fluid in wellbore, lb/ft3
25
Estimating Wellbore Storage
Once s and Cs are estimated, the end of WBS can be estimated from the equation:
Thus, the 2 contributors to the early time data distortion are quantified
Graphical Technique for Cs
early time data is plotted on CARTESIAN graph paper
slope is obtained in terms of psi/hr
using the formula:
twbs can be estimated from the equation, using this value of Cs
Finally- twbs is verified from the log-log & semi-log plots
26
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PDD Analysis- Application of Different Plots27
2500
3000
3500
4000
4500
5000
5500
6000
6500
0.01 0.1 1 10 100
100
1000
10000
0.01 0.1 1 10 100
q = 2500 STB/Dpi = 6009 psiρ = 55 lb/ft3Bo =1.21 RB/STBµ = 0.92 CPct = 8.72E-06 /psirw = 0.401 ftØ = 0.21h = 23 ft
From log-log & Semi-log plotsend of wbs ≈ 2.5 hrs
From Semi-log plotm = 250 psi/cycle
k = 78.7 mDs = +6.7
Estimating Cs, twbs & Vp28
y = -8238x + 6006.8
R² = 0.9988
5700
5750
5800
5850
5900
5950
6000
6050
0 0.005 0.01 0.015 0.02 0.025 0.03 0.035
2900
3000
3100
3200
3300
3400
3500
0 5 10 15 20 25
From Early Time Cartesian Plot:mwbs = 8238 psi/hrCs = 0.0153 RB/psikh/µ = 1967.46 (previous results)twbs = 2.2 hrs (close to log-log & semi-log estimates)
if we use Cs from formula:Awb = 0.5054 ft2
Cs = 0.2446 RB/psitwbs = 34.8 hrs (NOT close!)
From Late-Time Cartesian Plotdp/dt = -6 psi/hrVp = 1.35E+07 ft3 = 2.41E+06 Bbl