Assignment 3,4,5,6
10
Example 3 – PanSystem
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Transcript of Assignment 3,4,5,6
Example 3 – PanSystem
Near Well bore effects: Infinite conductivity Vertical Fracture (half-unit slope, wellbore storage effects not significant in comparison)
Stabilisation
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
2250
2450
2650
Pre
ssur
e [p
sia]
0 200 400 600 800
Time [hr]
0
250
Liqu
id ra
te [S
TB/D
]
History plot (Pressure [psia], Liquid rate [STB/D] vs Time [hr])
1E-4 1E-3 0.01 0.1 1 10 100Time [hr]
1
10
100
Pre
ssur
e [p
si]
Log-Log plot: p-p@dt=0 and derivative [psi] vs dt [hr]
0 1 2 3 4 5 6
Superposition Time Function
2250
2350
2450
2550
2650
2750
Pre
ssur
e [p
si]
Horner plot: p [psi] vs log(tp+dt)-log(dt)
Stabilisation
Near Well bore effects: Wellbore storage (unit slope signifies wellbore storage effects)
Reservoir Behaviour: Psuedo-double-porosity system (significant change in slope after initial stabilisation leading to a large dip, before hump rising up again to reach radial flow)
Boundary Effects: Infinite lateral extent (curve begins to stabilise after 2nd porosity reached)
Example 5 - Interpret
10
100
1000
0.1 1 10 100 1000
Pre
ssur
e C
hang
e an
d D
eriv
ativ
e (p
si)
Elapsed time (hrs)
Log-Log Diagnostic - Flow Period 2
10
100
1000
0.1 1 10 100 1000
Pre
ssur
e C
hang
e an
d D
eriv
ativ
e (p
si)
Elapsed time (hrs)
Log-Log Match - Flow Period 2
240
260
280
300
320
340
360
380
400
420
440
460
480
500
520
0 100 200 300 400 500 600
Pre
ssur
e (p
sia)
Superposition Function (STB/D)
Horner Analysis - Flow Period 2
240
260
280
300
320
340
360
380
400
420
440
460
480
500
520
0 100 200 300 400 500 600
Pre
ssur
e (p
sia)
Superposition Function (STB/D)
Horner Match - Flow Period 2
-400
-300
-200
-100
0
100
200
300
400
500
600
700
800
1000 1100 1200 1300 1400
Pre
ssur
e (p
sia)
Elapsed time (hrs)
0
100
200
300
400
Tota
l Rat
e (S
TB/D
)
Simulation (Constant Skin) - Flow Period 2
Model Infinite Conductivity Vertical Frac. with C and S 2 Porosity, Restricted Interporosity Flow Infinite Lateral Extent
Results (pav)i 769.354 psia pwf 246.800 psia kh 27.95 mD.ft k 0.5590 mD C 0.1049 bbl/psi xf 481.991 ft S(w) 0.02 S(t) -6.85 Omega 0.1860 Lambda 0.00041672 ri 218 ft PI 0.2871 B/D/psi FE 0.9649 fraction Dp(S) 18.36 psi
10
100
1000
0.1 1 10 100 1000
Pre
ssur
e C
hang
e an
d D
eriv
ativ
e (p
si)
Elapsed time (hrs)
Log-Log Diagnostic - Flow Period 2
Stabilisation
Stabilisation
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 2nd porosity reached)
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)
Log-Log diagnostic
Log-Log match Gringarten 6 OPC
10-2 10-1 100 101
10-2
10-1
Delta-T (hr)
DP &
DER
IVAT
IVE
(PSI
/STB
/D)
ENDWBS
2015/11/20-0000 : OIL
Gringarten 6 OPC
10-2 10-1 100 101
10-2
10-1
Delta-T (hr)
DP &
DER
IVAT
IVE
(PSI
/STB
/D)
UNIT SLP
ENDWBS
STABILFAULT
2015/11/20-0000 : OIL
Stabilisation
Stabilisation
Horner Plot
Horner Match
Gringarten 6 OPC
100 101 102 103 104
3300
.34
00.
3500
.36
00.
(Tp + dT)/dT
P PS
IENDWBS
SLOPE
2015/11/20-0000 : OIL
Gringarten 6 OPC
100 101 102 103 104
3300
.34
00.
3500
.36
00.
3700
.
(Tp + dT)/dT
P PS
I
ENDWBS
2015/11/20-0000 : OIL
Pressure History Match & Analysis Parameters
Gringarten 6 OPC
-150. -100. -50. 0. 50.
3200
.33
00.
3400
.35
00.
3600
.37
00.
Time (hours)
pres
sure
s (PS
I)
2015/11/20-0000 : OIL
Homogeneous Reservoir** Simulation Data ** well. storage = 0.0098263 BBLS/PSI skin = -3.7527 permeability = 5.4006 MD Areal Ky/Kx = 1.0000 Perm-Thickness = 1350.1 MD-FEET +x Distance = 118. FEET (1.00) Initial Press. = 3756.39 PSI
Static-Data and ConstantsVolume-Factor = 1.000 vol/volThickness = 250.0 FEETViscosity = 1.000 CPTotal Compress = .1610E-05 1/PSIRate = 700.0 STB/DStorivity = .8050E-04 FEET/PSIDiffusivity = 4423. FEET^2/HRGauge Depth = N/A FEETPerf. Depth = N/A FEETDatum Depth = N/A FEETAnalysis-Data ID: GAU002Based on Gauge ID: GAU002PFA Starts: 2015-11-14 00:00:00PFA Ends : 2015-11-24 00:00:00
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