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Capillary pressure
§
Drainage Process: 
ú
Non Wetting phase 
displacing Wetting 
phase
§
ImbibitionProcess:
ú
Wetting phase 
displacing Non wetting 
phase
•Determination
o
f
Connate
w
ater
•Establish
Saturation
–height
relation
•Rock
Typing
Mar-
2010
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Wettability
§
‘The tendency of a fluid to spread or adhere to a solid surface in 
presence of another immiscible fluid ‘
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2010
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Relative Permeability
§
Wh
e
n two or mor
e
pha
ses
flow 
s
imultan
e
ou
s
ly th
e
ratio of 
e
ff
ec
tiv
e
to ab
s
olut
e
p
e
rm
e
ability i
s
t
e
rm
e
‘R
e
lativ
e
p
e
rm
e
ability’
Kro
ko/k
Kre
k
w
/k
Krg
kg/k
Soc
S
w
c
N
w
P
WP
Mar-
2010
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Relative Permeability-Rock typing
§
The variation in Rock 
Texture imparts 
significant changes in 
Relperm estimates in 
core plugs of same 
formation
Mar-
2010
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Relative Permeability-Core Condition
§
Comparison of Rel-
perms of cores with 
natural reservoir 
wettabilitypreserved 
against a plug 
cleaned, dried and 
resaturated.
§
Relative Permeability
Mar-
2010
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Relative Permeability-wettability
0.8-1.0
1.5-3
6-8
Oil Wet
0.5-0.9
2-4
3-5
Mixed 
Wet
0.1-0.4
4-6
2-3
Water 
Wet
Krw
Nw
No
Type
Mar-
2010
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Reservoir Pressure
§
Reservoir Pressure
§
The fluids confined in the pores of the reservoir rock occur 
under certain degree of pressure, generally called reservoir 
pressure
ú
The maximum pressure is called the static bottom hole 
pressure, the shut in pressure or static formation pressure
Mar-
2010
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Well testing
§
Th
e
r
es
pon
se
of th
e
r
ese
rvoir to 
c
hang
e
in produ
c
tion/ 
inj
ec
tion rat
es
in a w
e
ll i
s
monitor
e
d
§
Th
e
r
ese
rvoir r
es
pon
se
i
s
m
e
a
s
ur
e
d in t
e
rm
s
of ‘pr
ess
ur
e
r
es
pon
se
& i
s
u
s
ually d
e
p
e
nd
e
nt on K, Skin, W
e
ll bor
e
s
torag
e
, boundari
es
, fra
c
tur
es
, dual poro
s
ity 
e
t.
c
ú
Evaluation:     D
e
liv
e
rability, Prop
e
rti
es
, Siz
e
ú
Manag
e
m
e
nt: R
e
fining for
ec
a
s
t, Front  mov
e
m
e
nt
ú
D
esc
ription:   Fault
s
, barri
e
r
s
Res
K,s,C
Model
K,s,C
qo
t
P
P
T
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Mar-20
1
0
Radial Flow in a porou
s
m
e
dia :
For a 
s
ingl
e
pha
se
fluid flow (radial)  in a 
c
on
s
tant 
p
e
rm
e
ability and poro
s
ity for a fluid of 
s
mall and 
c
on
s
tant 
c
ompr
ess
ibility, th
e
e
auation i
s
:
Pws= Pi-162.6q
µB/kh*log((T+∆t)/ ∆t)
K= 162.6qµB
mh
S= 1.151[ P1hr-Pwf
] –log (K / ФuCtrw2 )+3.23]
m
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Pressure Build-up analysis
§
Log-log Plot(Diagno
s
ti
c
plot): 
Log ▲t V
s
Log ▲P
§
Horn
e
r Plot or MDH Plot : 
Log [(tp+ ▲t)/ ▲t] V
s
Pwf
P
s
kin
= 0.87mS
J
a
c
tual
      q       . 
P
*
-Pwf
J
id
e
al
=         q                 . 
P
*
-Pwf-▲
P
s
kin
Flow Effi
c
i
e
n
c
y = J
a
c
tual
/ J
id
e
al
D(di
s
tan
ce
of fault)=
(0.00105K ▲t/ ФuCt)
1/2 
Wh
e
r
e
▲t = point at th
e
tim
e
of int
e
r
sec
tion 
b
e
tw
ee
n two        
s
traight lin
es
Horn
e
r Plot
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