Example 3 PanSystem
Stabilisati
on
Near Well bore effects: Infinite conductivity Vertical Fracture (half-unit slope,
wellbore storage effects not significant in comparison)
Reservoir Behaviour: Homogenous radial flow (curve stabilises to 0 gradient,
no double porosity behaviour observed)
Boundary Effects: Infinite lateral extent (No subsequent change in gradient is
observed)
Example 4 - Saphir
Liquid rate [STB/D]
Pressure [psia]
2650
2450
2250
250
0
0
200
400
600
800
Time [hr]
History plot (Pressure [psia], Liquid rate [STB/D] vs Time [hr])
Stabilisati
on
Pressure [psi]
100
10
1
1E-4
1E-3
0.01
0.1
10
Time [hr]
Log-Log plot: p-p@dt=0 and derivative [psi] vs dt [hr]
100
2750
Pressure [psi]
2650
2550
2450
Near Well bore
effects: Wellbore
storage (unit slope
signifies wellbore
storage effects)
2350
2250
Reservoir
Behaviour: PsuedoSuperposition Time Function
double-porosity system
Horner plot: p [psi] vs log(tp+dt)-log(dt) (significant change in slope
after
initial stabilisation leading to
a large dip, before hump rising up again to reach radial flow)
0
Boundary Effects: Infinite lateral extent (curve begins to stabilise after 2 nd
porosity reached)
Example 5 - Interpret
PressureC
hangeandD
erivative(psi)
1000
Log-LogD
iagnostic-FlowP
eriod2
100
10
0.1
Elapsed1t0
im
e(hrs)
100
1000
Stabilisati
on
Stabilisati
on
Log-LogDiagnostic-FlowPeriod2
Log-LogMatch-FlowPeriod2
100
10
0.1
10
Elapsedtime(hrs)
100
100
10
0.1
1000
100
200
10
Elapsedtime(hrs)
100
1000
HornerMatch-FlowPeriod2
Pressure(psia)
Pressure(psia)
HornerAnalysis-FlowPeriod2
520
500
480
460
440
420
400
380
360
340
320
300
280
260
2400
Model
Infinite Conductivity Vertical Frac. with C and S
2 Porosity, Restricted Interporosity Flow
Infinite Lateral Extent
1000
PressureChangeandDerivative(psi)
PressureChangeandDerivative(psi)
1000
300
400
SuperpositionFunction(STB/D)
500
600
520
500
480
460
440
420
400
380
360
340
320
300
280
260
2400
100
200
300
400
SuperpositionFunction(STB/D)
500
(pav)i
pwf
kh
k
C
xf
S(w)
S(t)
Omega
Lambda
ri
PI
FE
Dp(S)
Results
769.354
246.800
27.95
0.5590
0.1049
481.991
0.02
-6.85
0.1860
0.00041672
218
0.2871
0.9649
18.36
600
400
300
TotalRate(STB/D)
Pressure(psia)
Simulation(ConstantSkin)-FlowPeriod2
800
700
600
500
400
300
200
100
0
-100
-200
-300
-4010000
200
100
1100
1200
Elapsedtime(hrs)
1300
14000
Near Well bore effects: Infinite conductivity Vertical Fracture (half-unit slope,
wellbore storage effects not significant in comparison)
Reservoir Behaviour: Transient 2-porosity system (significant change in slope
after initial stabilisation)
Boundary Effects: Infinite lateral extent (curve begins to stabilise after 2 nd
porosity reached)
psia
psia
mD.ft
mD
bbl/psi
ft
ft
B/D/psi
fraction
psi
Example 6 - PIE
Near Well bore effects: Wellbore storage (unit slope signifies wellbore storage
effects)
Reservoir Behaviour: Radial flow (Derivative curve stabilises)
Boundary Effects: Single linear sealing fault (derivative curve destabilises and
destabilises in the late times, indicating single sealing fault)
2015/11/20-0000 : OIL
10 -1
Stabilisati
on
10 -2
Stabilisati
on
DP & DERIVATIVE (PSI/STB/D)
Log-Log diagnostic
10 -2
10 -1
10 0
10 1
Delta-T (hr)
Gringarten 6 OPC
10 -1
10 -2
DP & DERIVATIVE (PSI/STB/D)
Log-Log match
10 -2
10 -1
10 0
Delta-T (hr)
Gringarten 6 OPC
Horner Plot
10 1
2015/11/20-0000 : OIL
2015/11/20-0000 : OIL
3500.
P PSI
3600.
ENDWBS
3300.
3400.
SLOPE
10 0
10 1
10 2
10 3
10 4
(Tp +dT)/dT
Horner Match
Gringarten 6 OPC
2015/11/20-0000 : OIL
3500.
3400.
3300.
P PSI
3600.
3700.
ENDWBS
10 0
10 1
10 2
10 3
(Tp +dT)/dT
Gringarten 6 OPC
10 4
Pressure History Match & Analysis Parameters
3500.
3400.
3200.
3300.
pressures (PSI)
3600.
3700.
2015/11/20-0000 : OIL
-150.
-100.
-50.
0.
50.
Time (hours)
Gringarten 6 OPC
Homogeneous Reservoir
** Simulation Data **
well. storage = 0.0098263
skin
=
-3.7527
permeability
=
5.4006
Areal Ky/Kx
=
1.0000
Perm-Thickness =
1350.1
+x Distance
=
118.
Initial Press. =
3756.39
BBLS/PSI
MD
MD-FEET
FEET (1.00)
PSI
Static-Data and Constants
Volume-Factor = 1.000 vol/vol
Thickness
= 250.0 FEET
Viscosity
= 1.000 CP
Total Compress = .1610E-05 1/PSI
Rate
= 700.0 STB/D
Storivity
= .8050E-04 FEET/PSI
Diffusivity
= 4423. FEET^2/HR
Gauge Depth
= N/A FEET
Perf. Depth
= N/A FEET
Datum Depth
= N/A FEET
Analysis-Data ID: GAU002
Based on Gauge ID: GAU002
PFA Starts: 2015-11-14 00:00:00
PFA Ends : 2015-11-24 00:00:00
