Page 292 - Fundamentals of Reservoir Engineering

OILWELL TESTING
228
SHUT-IN TIME - ∆t MINUTES
7
6
5
4
3
4
2
9
100
3
5
9
6
7
4
2
2
10
3
5
6
7
10
2
3
4
5
6
7
T/F = 500,000
9
T/F = 250,000
3
4
T/F = 100,000
5
6
7
9
T/F = 50,000
10
-2
2
T/F = 25,000
3
4
5
6
7
9
10
-1
∆
∆
V
∆
A
F
q
∆t
G
T
c W
2
=
=
∆p = p ws
µ
kh
PRESSURE BUILDUP GROUP - ∆ p f / q
A
G
3
- p wf

5.6 c W
4
5
6
7
= Shut-in time, minutes
= Wellbore volume, bbls
T/F = 500
9
pressure, psi
10
0
Wellbore Transmissibility,
= Wellbore liquid gradient, psi/ft
cp
; For partially liquid filled wells
= Wellbore cross-sectional, area, sq ft
mD - ft
= Wellbore fluid compressibility, (psi) -1
2
T/F = 100
= Production rate, reservoir barrels per day
V; For completely fluid-filled wells
= Pressure change from flowing
3
4
5
6
7
9
10
1
21
Fig. 7.40 10 -3 2 -4 McKinley type curves for 1 min <∆ ∆∆ ∆t < 1000 min. (After McKinley ) T/F = 250 9 1000
(Reproduced by courtesy of the SPE of the AIME)