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WELL TESTING
( 1 ) PRODUCTI VI TY TESTS( 1 ) PRODUCTI VI TY TESTSto determine the performance of a well, i.e. the flow rates that can beproduced under an imposed pressure drop
Oil=>Productivity Index (PI ) Gas=>W ell de l i verab i l i t y
( 2 ) DRAW DOW N TESTS
early transient stateearly transient state (k , S)
transient statetransient state -- single rate (k , S or S)- two rates (k , S, D)
pseudopseudo--steady statesteady state (k , Vp )
(RESERVOI R LI MI T TESTRESERVOI R LI MI T TEST)
to evaluate the average parameters of the reservoir rock, and to assessthe degree of damage or stimulation in the vicinity of the wellbore
FLOW REGI ME
(3) BUILDUP TESTSto evaluate the average permeability of the reservoir rock, and averagereservoir pressure (k , )p
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Deliverability Tests for Gas Wells
Back pressure test
qsc
p
SPURGO
tT TTT
qsc1
qsc2
qsc3
qsc4
pwf1
pwf2
pwf3
pwf4
T > ts
p
CLEAN-UP
qSC
q SC1
q SC2
q SC3
q SC4
T TTT
T>ts
t
p
pp w f1
p w f2
p w f3
p w f4
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Empirical relationship ofEmpirical relationship ofRowlinsRowlins-- SchellardtSchellardt
0.5
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+
= 'S2
rc
A25.2ln
T
p
kh2
Tq)p(m)p(m
2wAsc
scscw
Rigorous equation for gas flow under pseudopseudo--steady statesteady stateconditions:
a
b
SCq
)p(m
SCq
sc
sc
w bqaq
)p(m)p(m+=
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Deliverability Tests for Gas Wells
Isochronal test
qsc
p
SPURGO
tT2T TT
qsc1
qsc2
qsc3qsc4
pwf1
pwf2
pwf3
pwf4
2T 2T
EXTENDED FLOW
p
CLEAN-UP
qSC
qSC1
qSC4
qSC3
qSC2
T T T2T2T 2T
EXTENDEDFLOW
p
p
pw f 1
pw f 4
pw f3
pw f2
t
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Empirical relationship ofEmpirical relationship ofRowlinsRowlins-- SchellardtSchellardt
2h4h8hpseudopseudo--steady statesteady state
)pplog(2wf
2
scqlog
n2wf
p2
pCscq
=
1/n
1/n
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Deliverability Tests for Gas Wells
Modified isochronal test
n2w f
2
sc ppCq
====For the first producing rate:For the first producing rate:
(((( ))))n2w f2w ssc ppCq ====For the rates following the first:For the rates following the first:
qsc
p
SPURGO
tT TT
qsc1qsc2
qsc3qsc4
pwf1
pwf2
pwf3pwf4
EXTENDED FLOW
T T T
pws4
pws3pws2p
t
CLEAN-UP
qSC
qSC1
qSC4qSC3
qSC2
T
EXTENDEDFLOW
p
ppw f1
pw f4
pw f3
pw f 2
T T T T T
pw s2 pw s3
pw s4
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Productivity tests for oil wells
qoST
p
SPURGO
t
qoST
pwf
T > ts
p
T
CLEAN-UP
qOSTq OST
T
T>ts
tp
p
p w f
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wf
STo
pp
qPI
=
Stabilized Productivity Index (for single phase flow only)Stabilized Productivity Index (for single phase flow only)
PI
Flusso bifase
qoST
pwf
p
Flusso monofase
psat
Single phase flowSingle phase flow
psat
pw f
p
qost
PI
Two phase flowTwo phase flow
Productivity tests for oil wells
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Drawdown tests for oil wells
qoST
p
t
p(rw,t)
p
q
p
qOSTq
pp(rw,t)
t
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The reservoir is assumed as an infinite acting system(radial geometry)
Hy po th esi s o f cons tan t f l ow ra t e q Hy po th esi s o f cons tan t f l ow ra t e q
=
= D
w
iw t,1r
rP
kh2
qp)t,r(p
=
=
=
trc
kt
pq
kh2t,1rrP
2w
D
D
w
Early transient stateEarly transient state:
1 0 0t D
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+
=
+
=
=
tlogrc
klogtlog
plogq
kh2logt,1
r
rPlog
2w
D
Dw
On a l og - l og g raph )t(ft,1
r
rP)t(fp DD
w
=
==
Match point
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tD
= D
w
t,1
r
rP
t
p
Match point
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t
p
tD
= D
w t,1r
r
P
* M* M
Match point
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Any point M chosen in the superposition area of the two diagramshas two coordinate sets, one for each graph. The coordinatevalues, read on the corresponding axes, allow the calculation ofthe constants by which the two curves are translated and,
therefore, the evaluation of the parameters of the reservoir rockparameters of the reservoir rock:
MD
M2w
M
M
D
w
tt
rkc
p
t,1rrP
2
qk h
====
====
====
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Wellbore Storage
surface flowrate
sandface flowrate
drawdown
q
time
qwh
qsf< qwh
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Wellbore Storage
wcVpVC =
=
tqV = tC
qp =
The w e l lbo re st o rage coe f f i c ien t depends on The w e l lbo re st o rage coe f f i c ien t depends on ::
! fluid compressibility
! wellbore dimension
and
! formation permeability: low permeability formations induce morerelevant wellbore storage effects
p is a linear function of t, and it will be demonstrated that on a
dimensionless log-log graph the slope is equal to unity.
2w
Dhrc2
CC
=
Dimensionless wellbore storage coefficientDimensionless wellbore storage coefficient
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Type-Curves of Agarwal et al.(1970)
The t y pe The t y pe --cu r ves ob t a ined by cu r ves ob t a ined by A g a r w a l A g a r w a l e t a l.e t a l.
== DD
w
D C,S,t,1r
rPfP
describe the pressure decline at the wellbore in dimensionless terms asa function of wellbore storage and skin factor.
Again, the match point method allows the evaluation of kh (and c):
MD
M
2
w
M
MD
t
t
r
kc
p
P
2
qkh
=
=
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Type-Curves of Agarwal et al.(1970)
PD
tD
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Transient stateTransient state:
DD
D
C)S5.36 0(t
1 0 0t
++++
Pressure data can be assumed free from wellbore storage effects
( )S2t25.2lnkh4
qp)t,r(p Diw +
=
++
+
= S281.0
rc
klntln
kh4
qp)t,r(p
2wt
iw
Transient state
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m
ln t
p(rw,t)
Transient State
p
ln t
p
p(rw, t)
m
k h4
qm
====
( )S2t25.2lnkh4
qp)t,r(p Diw +
=
S
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Transient State
== 0.9
rc
kln
m
p)h1t,r(p
2
1S
2wt
iw
At t= 1 hour
++
== S20.9
rc
kln
kh4
qp)h1t,r(p
2
wt
iw
Determination of the skin factor SDetermination of the skin factor S
R i Li it T t
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Reservoir Limit Test
PseudoPseudo--steady state conditionssteady state conditions
++
= S2t4
rc
A25.2ln
kh4
qp)t,r(p
AD2wA
iw
*mc
qAhV
t
p ==Pore volume drained by the well:Pore volume drained by the well:
m*
t
p(rw,t)p(rw,t)
t
tAhc
qS2rc
A25.2lnkh4
qp)t,r(pt
2wA
iw
+
=
Ahcq*m
t ====
Di t Sh F t
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===
m
)0t,r(p)h1t,r(pexp
*m
m
3600
4c wwA
Dietz Shape Factor cA
It is obtained by combination of the analysis of the drowdown test rununder both transient conditions [from which m and p(rw,t) at t=1h areknown] and pseudo-steady conditions [from which m* and p(rw,t) att=0 are known].
+
==
++
==
S2rc
A25.2ln
kh4
qp)0t,r(p
S20.9rc
klnkh4
qp)h1t,r(p
2
wA
iw
2wt
iw
The calculated value for cA can then be compared with the Dietz shapefactors presented for a variety of different geometrical configurations
to infer the shape of the drainage area and the well location within thedrainage area.
D d T t f G W ll
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Drawdown Tests for Gas Wells
In the case of gas wells single rate drawdown tests can be performed toevaluate the parameters of the producing formationparameters of the producing formationjust as for oil wellsprovided that the appropriate gas flow equations are used forinterpretation.
)'S281.0rc
klnt(ln
T
p
kh2
Tq)p(m)p(m
2wtsc
scsciw ++
+
=
Transient state flow equationTransient state flow equation
PseudoPseudo--steady state flow equationsteady state flow equation
+
+
= 'S2t
Ac
k4
rc
A25.2ln
T
p
kh2
Tq)p(m)p(m
t2wAsc
scsciw
However, t w o sing le ra t e i soch r ona l tests are usually performed ingas well testing. In fact, interpretation of the late transient pressure
data allows the determination of the apparent skin factor only, but twoflow rates are needed to determine both S and D .
D a do n Tests fo Gas Wells
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Drawdown Tests for Gas Wells
qsc1
p
t
p(rw,t)
p
q
qsc2
T T2T
q
p
p
qSC1
qSC2
p(rw,t)
T T2T
t
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ln t
m(pw)
m1m2
m p( )
ln t
m(pw)
m(p)
=
sc
sc2sc2
Tp
kh2Tqm
=
sc
sc1sc1
T
p
kh2
Tqm
Fort = 1 h
=+
=+
=
=
0.9
rc
kln
m
)p(m)p(m
2
1DqS
0.9rc
klnm
)p(m)p(m21DqS
2
wt2
i2h1tw
2sc
2wt1
i1h1tw
1sc
Buildup Tests for Oil Wells
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Buildup Tests for Oil Wells
The well is shut in, i.e. q=0, after producing at a constant flow rate for a certain time.Pressure variations occur under transient conditions.
p(rw,t)
qOST
tp+ttp
p
If the well has been produced at a constant flow rate then t is the production timeprior to shut-in. If the well has been produced at different flow rates then theeffective production time t eq is to be used
STo
p
eqqNt ====
t=0
cumulative volume of oil since beginning of production
final flow rate
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)S2t25.2(lnkh4
qp)t,r(p D
*w +
=
Flow equation which extend the flow equation derived for an infinite acting system(radial geometry) to the case of a finite, irregularly-shaped drainage area:
i* pp =
If the well is new:
Fkh4
qpp *
+=
If the well has been produced:
The equation applies when the flow rate q is constant. The superposition theoremis applied:
+q
-q
tp+ttp
++++
= S281.0)ttln(
rc
kln
kh4
qp)t,r(p p2
wt
*w
+++
+ S281.0tln
rc
kln
kh4
q2wt
Horner Plot
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t
ttln
kh4
qp)t,r(p
p*w
+
=
"" Horne r p lo t Ho rne r p lo t
k h4
qm
====
pw
t
ttln
p
+
m
p*
"" Bu i l dup equa t i on o r Ho rne r equa t i on Bu i l dup equa t i on o r Ho rne r equa t i on
Horner Plot
mFpp * =
The pressure p*, from which the volume averaged reservoir pressure p can be
determined, is evaluated at an infinite shut-in time t :
Afterflow
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surface flowrate
sandface flowrate
build-up
q
time
qwh=0
qsf>0
Afterflow
Horner Plot
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The solution is derived with respect to an ideal well, and in addition S does not appearin the buildup equation. However, the skin effects as well as the after flow effects dueto shutting the well in at the surface rather than downhole have to be taken intoaccount.
HORNER PLOTHORNER PLOT
t
ttln
p
+
pw
m
After flowAfter flow
Skin effectSkin effect
*
p
Horner Plot
Determination of the Skin Factor
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Determination of the Skin Factor
atat t=0, i.e.at the production time tt=0, i.e.at the production time t
)S2t25.2(lnkh4
qp)0t,r(p D
*w +
==
+++
== S281.0rc
klntlnkh4
qp)0t,r(p 2
wt
iw
atat t=1 hourt=1 hour
)3600lnt(lnkh4qp)h1t,r(p*w
==
h1tifttt =+
+++
=
==3600lnS281.0
rc
kln
kh4
qpp
2
wt
h1tw0tw
= == 9rc
kln
m
pp
2
1S
2
wt
0twh1tw
Oil Well
Buildup Tests for Gas Wells
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Buildup Tests for Gas Wells
)'S2t25.2(lnTp
kh2Tq)p(m)p(m D
sc
scsc*w +
=
+
=
t
ttlnT
p
kh2
Tq)p(m)p(m p
sc
scsc*w
"" Bu i l dup equa t i on o r Ho rne r equa t i on Bu i l dup equa t i on o r Ho rne r equa t i on
t
ttln
p
+
"" Horn er Plo t Horn er Plo t
m(pw)
m
sc
scsc
T
p
k h2
Tqm
====m(p*)
Determination of the Skin Factor
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Determination of the Skin Factor
= == 0.9
rckln
m)p(m)p(m
21'S
2wt
0twh1tw
Gas Well
Type-Curves of Agarwal et al.(1970)
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Type Curves of Agarwal et al.(1970)
The typeThe type--curves obtained bycurves obtained by AgarwalAgarwalet alet al..
== DD
w
D C,S,t,1r
rPfP
represent solutions to the drawdown equation to describe the pressure decline at thewellbore, expressed in dimensionless terms, as a function of wellbore storage effectsand skin factor.
However, the use of the type-curves to interpret also buildup tests could be justifiedprovided that the producing time prior to well shut-in was sufficiently large so that
the rate of pressure decline could be assumed negligible during the shut-in period. Ifthis assumption was satisfied the buildup curve would be a mirror image of thedrawdown curve, and as such analyzed.
Furthermore, Agarwal has empirically found that by plotting the buildup pressuredata:
)0t,r(p)t,r(p ww =
on a log-log graph versus an equivalent expression of time, defined as follows:
tt
ttt
p
p
e
+
=
the type-curve analysis can be made without the requirement of a long drawdownperiod.
Type-Curves
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Type Curves
== DD
w
D C,S,t,1rrPfPThe Agarwal type curves:
can be written as a function of: tC
kh2
C
t
D
D
=
trc
kt
2wt
D
=
2wt
Dhrc2
CC
=
Infinite acting radial flow equation for fluid flux occurring in a homogeneous porousmedium under transient conditions:
( )S2t25.2lnkh4
qp)t,r(p Diw +
=
( )S2t25.2ln21P DD +=
obtained from
( )
++= S2D
D
DD eCln81.0
Ctln
21P
By substitution:
Type-Curves Plot
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Type Curves Plot
D
D
D C
t
P =
(i.e., unit slope)
0.1
1
10
100
0.1 1 10 100 1000 10000
tC
D
D
PD C eDS2 10000
0.1
PD CDe2S
10000
0.1
tD
CD
When pure wellbore storage flow occurs:
Pressure Derivative Method
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According to this method, which is largely based on the solutions obtained by
Agarwal et al., the type-curves are redrawn in terms of the derivative of thedimensionless pressure PD:
)C/t(d
dP'P
DD
DD =
The dimensionless pressure values are plotted on a log-log graph as follows:
)C/t(f)C/t('P DDDDD =
The drawdown test interpretation is carried out by matching the field pressure data
p(rw,t), expressed in terms of pressure derivative:
dt
)pp(d'p wfi
=
)t(ft'p =and plotted on a log-log graph as follows:
with the type-curves of the derivative of the dimensionless pressure.
In the case of a buildup test the field time-pressure data p(rw,t) are plotted on a log-log graph as follows:
)t(ft
ttt'p =
+
Type-Curve Derivatives
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yp
=
D
D
D'D
C
td
dPP
PURE W ELLBORE STORAGEPURE W ELLBORE STORAGE
1
Ctd
dPP
D
D
D'D =
=
I NFI NI TE ACTI NG RADI AL FLOW ( I .A.R.F. )I NFI NI TE ACTI NG RADI AL FLOW ( I .A.R.F. )FOR A H OMOGENEOUS POROUS MEDI UMFOR A H OMOGENEOUS POROUS MEDI UM
=
=
D
D
D
D
D'D
Ct
5.0
Ctd
dPP
Type-Curves and Type-Curve Derivatives
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yp yp
10-210-3 10-1 1 10
t (hr)
103
102
101
104
p(psia)&
p
WellboreStorage
Radial Flow
CDe2S
1030
1012
106
10-1
102
Real data vs type-curves
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t (hr)
p(psia)&
p
103
102
101
100
10-1
10-2 10-1 1 10 102 103 104103
LogLog pp
D er i va t i veD er i va t i ve
104
yp
Superposition real data & type-curves
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103
102
101
10-210-3 10-1 1 10 101
104
t (hr)
p(psia
)&
p
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Interpretation Result
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CCg ives 2wt
Dhrc2
CC
=
Cu r ve Mat chCu r ve Mat ch S2DeC
SkinSkin
=
D
S2
DC
eCln2
1S
Pr essur e Mat chPr essur e Mat ch k hk hpqB
kh4Po
D
=
Tim e Mat ch Tim e Mat ch CCtCkh2Ct DD
=
Drawdown Test Analysis
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Pressure
L
og
p
Log t
Pr essu r e vs t im e
Pressu r e de r i va t i ve vs t im e
Log t
Buildup Test Analysis
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Log t
Pressur
e
Log
p
Pr e ssu r e v s Ho r n er t i m e
Pr essu r e de r i va t i ve vs t im e
Interpretation with the Pressure Derivative Method
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The derivatives of the type-curves exhibit a linear dependency on time ofpressure data points. Linearity can occur according to different yet
characteristic slopes which are a function of flow geometry:
FLOW TYPEFLOW TYPE PRESSUREPRESSURE SLOPESLOPE
linearlinear
bilinearbilinear
radialradial
sphericalspherical
(hemispherical)(hemispherical)
)t(fp =
)t(fp 4=
)t(lnfp =
=
t
1fp
1/ 21/ 2
1/ 41/ 4
--1/ 21/ 2
horizontalhorizontal
straight linestraight line