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RESERVOI RPROPERTI ES
REAL SYSTEMREAL SYSTEM
Q
t
FI ELD I NPUTFI ELD I NPUT
Q
t
MODEL I NPUTMODEL I NPUT
p
t
MODEL OUTPUTMODEL OUTPUT
p
t
RESERVOI RRESERVOI R
RESPONSERESPONSE
MODELPARAMETERS
MATHEMATI CAL MODELMATHEMATI CAL MODEL
MMAA
TT
CC
HH
CALIBRATION OF MODEL PARAMETERSCALIBRATION OF MODEL PARAMETERS
Interpretation
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Model
MODEL: simplified version of the real system, by which the behaviorof the real system can be approximately but yet representativelysimulated
• MASS BALAN CE EQUATI ONS:MASS BALAN CE EQUATI ONS:for the considered extensive quantities
• FLOW EQUATI ONS:FLOW EQUATI ONS: relate theextensive quantities to the significant statevariables of the problem
• STATE EQUATI ONS:STATE EQUATI ONS: define thebehavior of the components of the system
• I N I TI AL AND BOUNDARYI NI TI AL AND BOUNDARY
CONDI TI ONS:CONDI TI ONS: must be defined after thedomain geometry has been established
MATHEMATI CAL M ODELMATHEMATI CAL M ODEL
THEORETI CAL MODELTHEORETI CAL MODEL Set of simplifyingSet of simplifyingassumptionsassumptions
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REALREALSYSTEMSYSTEM MATHEMATI CALMATHEMATI CAL
MODELMODEL
SOLUTI ONS OFSOLUTI ONS OF
MATHEMATI CAL MODELMATHEMATI CAL MODEL
NUM ERI CAL M ETHODNUM ERI CAL M ETHODNecessary in the case of:• non linearity of the equations
which constitute the model• complexity of the boundary
conditions, etc.
ANALYTI CAL METHODANALYTI CAL METHODPreferable for the ease of applicability of the solutions
MODEL COEFFI CI ENTSMODEL COEFFI CI ENTS:the transport coefficients of theconsidered extensive quantities
Model solutions
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Flow Problem
Number of phasesNumber of phases•single phase (kass)•multiphase (krel)
Nature of fluidsNature of fluids•compressible (liquid)•very compressible (gas)
GeometryGeometry•monodimensional•bidimensional (radial flow)•tridimentional
Hydraulic regimeHydraulic regime
•steady state flow•pseudo-steady state flow•transient flow
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t
)()v(
∂
φρ∂−=ρ∇
CONTI NUI TY EQUATI ONCONTI NUI TY EQUATI ON
STATESTATE EQUATI ONSEQUATI ONS
zRT
Mp=ρ
)pp(c
00e −−−−==== ρρLiquid
Real Gas
FLOW EQUATI ONSFLOW EQUATI ONS(gravity effects are neglected)
Turbulent flow (Turbulent flow (ForchheimerForchheimer))
pkv ∇µ
−=
Laminar flow (Darcy)Laminar flow (Darcy)
2vvk
p βρ+µ
=∇−
Basic equations
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Diffusivity Equation
MONOPHASI C FLOW OF A SLI GHTLY COMPRESSI BLE FLUI D ( LI QUI D)THROUGH A HOMOGENEOUS AND I SOTROPI C POROUS MEDI UM.PRESSURE GRADI ENTS ARE SMALL AN D DA RCY’S LAW APPLI ES
ηη DIFFUSIVITY CONSTANTDIFFUSIVITY CONSTANT
t
p1
t
p
k
cp t2
∂
∂
η=
∂
∂φµ=∇
φµ
=η
tc
k
MONOPHASIC FLOW MONOPHASIC FLOW : in the case of oil flow the water saturation is
equal to the irreducible value Swi, and the pressure is always greaterthan the bubble point pressure; in the case of water flow the oilsaturation is equal to the residual value Sor
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Pressure Profile
! Each time the well production is modified (rate change) apressure disturbance starts to propagate in the reservoir
!The DIFFUSIVITY EQUATION DIFFUSIVITY EQUATION describes how the pressuredisturbance evolves within the reservoir
Q
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Infinite Acting Radial Flow
(I.A.R.F.)HYPOTESIS: constant thickness of the producing formation,
and wellbore open to production across the entire formation
thickness.Therefore, the fluid flow is horizontal.
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Radial Flow Equations
t
p
k
c
r
p
r
1
r
p t
2
2
∂
∂φµ=
∂
∂+
∂
∂
!transient flow
!pseudo-steady state flow
dt
dp
k
c
dr
dp
r
1
dr
pd t2
2 φµ=+
!steady state flow
0drdp
r1
drpd2
2=+
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Average Pressure
MEASUREMENT OF AVERAGE PRESSUREMEASUREMENT OF AVERAGE PRESSURE
•• TheoreticallyTheoretically: the average pressure could be measured in the wellbore
under static conditions if the well (or the field) had been shut in for an
infinitely long time so as to allow the reservoir pressure to reach
equilibrium.
•• I n p r a ct i c e:I n p r a ct i c e: the average pressure can be determined from buildup tests.
AVERAGE PRESSURE AVERAGE PRESSURE : the representative reservoir pressureat which the pressure dependent parameters in the materialbalance equations should be evaluated.
∫=VpdV
V
1p
VOLUME AVERAGEDVOLUME AVERAGED
RESERVOI R PRESSURERESERVOI R PRESSURE
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Steady State Flow
w
e
we
rrln
ppkh2q
−
µ
π=
MUSKAT EQUATION
eerrconstpp
t,rtp
===
∀∀=∂∂ 0
Initial and boundary conditions:
The pressure p(r) at a distance r from the well can be evaluated as follows:
w
wr
rln
kh2
qp)r(p
π
µ+=
0dr
dp
r
1
dr
pd2
2
=+Radial Flow Equations
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rw re
h
p
r
k
pe
p w
If there is a damaged zone in the vicinity of the wellbore characterizedby a reduced permeability k’ with respect to the formation permeabilityk - due, for instance, to invasion of drilling or completion mud into theformation - an additional pressure drop is observed at the wellbore.
Skin Effect
SKI N EFFECT SKI N EFFECT : permeability damage in the vicinity of thewellbore.
r'
r’=0.5 - 1 m
k'p ’w
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Skin Factor
ww'r
r 'r ln
kh2qppπ
µ+=k ’ = k
w
w'r
r
'r ln
h'k2
q'pp
π
µ+=k ’ < k
wSww
r
'r ln1'k
k
kh2
qp'pp
−π
µ=∆=−
Additional pressure drop in the wellboreAdditional pressure drop in the wellbore: :
k ’ < k S > 0 permeability reduction (damage)
k ’ = k S = 0 no change in permeability
k ’ > k S < 0 permeability enhancement (stimulation)
SKI N FACTORSKI N FACTOR:wr
'rln1
'k
kS
−−−−====
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Sw
w pr
r ln
kh2
qp)r (p ∆+
π
µ+=
+
π
µ+= S
r
r ln
kh2
qp)r (p
ww
S
Additional pressure drop
wS
r
'r ln1
'k
k
kh2
qp
−π
µ=∆
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COMPLETI ON FACTORCOMPLETI ON FACTOR
)0S(PI
)0S(PICF
ltheoretica
real
=
≠=
real
S
real
Sreal
real
ltheoretica
pp1
ppp
ppCF
∆∆−=
∆∆−∆=
∆∆=
PRODUCTI VI TY I NDEXPRODUCTI VI TY I NDEX
p
qPI STo
∆
=
Sr
r
ln
1
B
kh2PI
w
eo
+
µ
π=
Productivity Index
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Partial Penetration and Partial Perforation
If the wellbore is partially penetrating in the reservoir, or the wellbore is open toproduction over a restricted interval of the reservoir, there is a distortion of theradial flow pattern close to the well (the flow lines are not parallel in the vicinity of the wellbore) giving rise to an ADDITIONAL PRESSURE DRAWDOWN.ADDITIONAL PRESSURE DRAWDOWN.
This pressure drop is generally accounted for by including the effect of partial
penetration as an additional skin factor. It can not be measured, but it can bequantitatively evaluated by numerical models that take the wellbore completioncharacteristics into account.
The skin factor S determined by well tests comprises both the component due to a
change in permeability Sk, and the component due to partial penetration SB:
S =S = SSkk ++ SSBB
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Pseudo-Steady State Flow
Radial Flow Equations
Initial and boundary conditions:
e
ei
rrr
p
rconstdt
dpt
rrppt
==
∂
∂
∀=>
===
0
0
0
Solution in terms of average pressure:
S4
3
r
rln
ppkh2q
w
e
w
+−
−
µ
π=
w
e
w
e
r
r472.0ln
4
3
r
rln =−
Pseudo-steady state drainage radius: 0.472 re=rds
dt
dp
k
c
dr
dp
r
1
dr
pd t2
2 φµ=+
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Transient Flow
Radial Flow Equations
π
µ−= D
wi t,
r
r P
kh2
qp)t,r (p
Solution:
c
Dt
tt =Dimensionless time
k
rct
2wt
c
φµ=Characteristic time
Initial and boundary conditions:
==
∂
∂
==
>
∀==
w
ei
i
rrconstr
p
rrpp
t
rppt
0
0
CONSTANT TERMINAL RATECONSTANT TERMINAL RATE
t
p
k
c
r
p
r
1
r
p t2
2
∂
∂φµ=
∂
∂+
∂
∂
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Function P(r/rw,tD)
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η−−=
t4
rE
2
1t,
r
rP
2
iD
w
At very short times, for :20r
r
w
≥
At the well radius rw, if :100tD ≥
≥=
= D
w
D
w
t,20rrPt,1
rrP
Therefore, if k
rc25t
2t φµ
≥
kt25.2
rclnt4
rE
2t
2
i
φµ=
η−
Also, when x ≤ 0.01 )x781.1ln()x(Ei =−
η
−−=
=
t4
r E
2
1t,1
r
r P
2
iD
w
Now some developments…
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)t25.2(lnkh4
qp)t,r (p Diw
π
µ−=
φµπ
µ−=
2wt
iwr c
kt25.2ln
kh4
qp)t,r (p
Solution at the well radius rw , for tD>100
2wtc
Dr c
kt
t
tt
φµ==Dimensionless time
…and here’s the solution
φµ−
π
µ−=
kt25.2
r cln
2
1
kh2
qp)t,r (p
2wt
iw
)S2t25.2(lnkh4
q
p)t,r (p Diw +π
µ
−=
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Tim e to reach pseud oTim e to reach pseud o -- st eady st a test eady s ta t e tt ss
i2et
sise p
rc
kt25.2ln
kh4
qp)t,r(p =
φµπ
µ−=
krc
25.21t
2
ets φµ=
Dra inage o r i n vest i ga t i on r ad ius rD ra inage o r i n vest i ga t i on r ad ius r dd
φµ=
2wtw
d
r c
kt25.2ln
2
1
r
r ln
t5.1tc
k5.1r
td η=
φµ=
Investigation radius
W h
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Water encroachment
t
p
k
c
r
p
r
1
r
p t
2
2
∂
∂φµ
=∂
∂
+∂
∂
Tr ansien t f l owTr ansien t f l ow
VanVan Everd ingenEverd ingen --
Hurs t Mode lHurs t Mode l
Car terCar ter -- TracyTracy
Mode lMode l
rw rw
V E di H t l ti
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Van Everdingen-Hurst solution
∞≠=
∂∂
∞==
=
=∆−==
>
∀==
w
e
w
eie
e
wiww
i
rr0
rp
r
rp)t,r(p
rr
tcospp)t,r(prr
0t
rpp0t
Initial and boundary conditions:
Van Everdingen-HurstSOLUTI ONSSOLUTI ONS
to diffusivity equation
CONSTANT TERMINAL RATE :Rate of water influx=const for ∆t
" calculation of pressure drop
CONSTANT TERMINAL PRESSURE:boundary pressure drop=const for ∆t
" calculation of water influx rate
V E di H t if
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Van Everdingen-Hurst aquifer
Dimensionless water influxDimensionless water influx
w
eD
rr,tQ
Dimensionless timeDimensionless time 2wtw
D r c
kt
t φµ=
Dimensionless radiusDimensionless radius
=
w
eD
r
r r
Cumulative Water influxCumulative Water influx
∆=
w
eDwe
rr,tQpBW
where B: water influx constantB: water influx constant hr cB wt
2
2 πφ=hf rcB wt
22 πφ=360
θ=f
F ti Q( / t )
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Dim ens ion less Tim e, t D
W a t e r I
n f l u x ,
Q
Function Q(re /rw,tD)
Carter Tracy aquifer
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Carter-Tracy aquifer
The CarterThe Carter--Tracy solution is not an exact solution to theTracy solution is not an exact solution to thediffusivity equation, it is an approximationdiffusivity equation, it is an approximation
( ) ( ) ( ) ( )[ ]( ) ( )
( ) ( ) ( )
−
−∆−+=
−
−−−
nD1nDnD
nD1nen1nDnD1nene
'ptp
'pWpBttWW
Where : B=Van Everdingen-Hurst water influx constant
n=current time stepn-1=previous time step
∆pn=total pressure drop, pi-pn
pD=dimensionless pressurep’ D=dimensionless pressure derivative
CONSTANT W ATER I NFLUX RATE
ove r each f i n i t e t im e in t e r va l .
Condition: Condition:
Gas Flow
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Gas Flow
Therefore, the Forchheimer equation should be used instead of the Darcy
equation. However, if a quadratic expression for the fluid velocity is substitutedinto the continuity equation a non linear, partial differential equation is obtained,which can not be solved analytically.
In general t u r b u l e n t f l o w c o n d i t i o n st u r b u l e n t f l o w c o n d i t i o n s have to be assumed near thewellbore when the reservoir fluid is gas due to its low viscosity
Lam ina r f l owLam ina r f l ow for Qg<50000 Sm3 /d approximately
Tur bu len t f l owTu r bu len t f l ow for Qg>100000 Sm3 /d
11 ST ST APPROACH APPROACH : Da rcy equa t i on fo r l am ina r f l ow
An equation is obtained, the solution of which can not be applied in the vicinity of thewellbore without restrictions.
2 2 n d n d APPROACH: APPROACH: Fo r c h h ei m e r e q u at i o n f o r t u r b u l e n t f l o w
The Forchheimer equation is integrated to obtain an equation valid under steady state
conditions only. The assumption of steady state flow can be removed if the drainageradius is inserted in place of the reservoir external radius, and the appropriatepressure is used .
Pseudo Pressure Function m(p)
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Pseudo-Pressure Function m(p)
∫ µ= p
p 0
dpzp2)p(m
m(p) is a function of: • pressure
• temperature• gas composition
m(p)
p
1st Approach
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1st Approach
Flow Equation: LAMINAR flow assumption
1)z
p
µ
tp1
tp
kcp t2
∂∂
η=
∂∂φµ=∇
= CONSTANT= CONSTANT (p > 3000(p > 3000 psipsi))
2) zµ
t
p1
t
p
k
cp
22t22
∂
∂
η=
∂
∂φµ=∇
= CONSTANT= CONSTANT (p < 2000(p < 2000 psipsi))
RIGOROUS SOLUTIONRIGOROUS SOLUTION
(no simplifying assumptions)(no simplifying assumptions)
t)p(m1
t)p(m
kc)p(m t2
∂∂
η=
∂∂φµ=∇
3)
SOLVI NG EQUATI ONSOLVI NG EQUATI ON
tpzpkcrprzprr1t
∂∂φ=
∂∂µ∂∂
2nd Approach
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2nd Approach
Flow Equation: TURBULENT flow assumption2vv
kdr
dpβρ+
µ=
++
π=−
scw
e
scsc
sc
weDqS
r
rlnq
T
p
kh
T)p(m)p(m
),k( φβ=β
Turbulence factorφ
k
β
It is assumed that there exists a damaged zone in the vicinity of the
wellbore characterized by k’ and β’ different from the formation values.Furthermore, an average viscosity value is assumed.
Apparent Skin
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S’
qSC
S
D
−β+
−β
µπ=
ewsc
sc
r
1
'r
1
'r
1
r
1
T
p
Rh2
kMD
DD “ n o n“ n o n -- Dar cy f l ow coe f f i ci en t ”Dar cy f l ow coe f f i ci en t ”
APPARENT SKI N S’APPARENT SKI N S’
S’=S+DqSC
Apparent Skin
Flow Equations
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Flow Equations
PSEUDOPSEUDO-- STEADY STATE FLOW EQUATI ONSTEADY STATE FLOW EQUATI ON
++
π=− sc
w
esc
sc
scw DqS
r
r472.0lnq
T
p
kh
T)p(m)p(m
sde r r 472.0 =
pp e →
TRAN SI ENT FLOW EQUATI ONTRAN SI ENT FLOW EQUATI ON
Under transient conditions D=f(tD) but a constant value is attained when rd>> r’
)Dq2S2t25.2(lnqT
p
kh2
T)p(m)p(m scDsc
sc
scwi ++
π=−
φµ=
2wtw
d
rc
kt25.2ln
2
1
r
rln
ie pp →
Flow Equations for Reservoir Engineering
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If a well is asymmetrically located in a bounded, irregularly shapeddrainage area the flow equations derived in the case of a porous mediumof infinite extent can still be applied provided that the effects of thepermeability limits which bound the drainage area are taken into account.
Flow Equations for Reservoir Engineering
METHOD OF I MAGE W ELLSMETHOD OF I MAGE W ELLSA virtual, hydraulically equivalent situation is assumed to simulate theadditional pressure drops due to the reflection of the pressuredisturbances on the permeability limits (no-flow boundaries).
d/2
P P'
k,φ
d/2
k,φ
Liquid Flow Equations
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Liquid Flow Equations
For 20rd
w
≥
η−−=
t4dE
21t,
rdP
2
iD
w
η−−π
µ
−= t4
d
Et25.2lnkh4
q
p)t,r(p
2
iDiw
+
π
µ−= D
w
Diw t,r
dPt25.2ln
2
1
kh2
qp)t,r(pLinear boundary:
For an asymmetrically well located in a bounded, irregularly shaped drainage area aninfinite number of images has to be accounted for, and the influence of each of the
images depends on the distance from the producing well:
η−−
π
µ−= ∑
∞
=1 j
2 j
iDiwt4
dEt25.2ln
kh4
qp)t,r(p
0t
dif 0
t4
dE
2
i→
∞→→
η−
Superposition in space
F function
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Dimensionless time with respect to the drainage area:
A
rt
Ac
ktt
2w
D
t
AD =φµ
=
FF fun ct i on o r MBHMBH f u n ct i on ( Mat t h e w s, Br o ns, Hazeb r oek )
∑∞
=
η−+π=
1 j
2 j
iADt4
dEt4F
F depends on:
•Time (tDA)•Shape of the drainage area
•Well location within the drainage area
F function
F function or MBH function
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F function or MBH function
Late transient conditions
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)Ft4t25.2(lnkh4
q
p)t,r(p ADDiw −π+π
µ
−=
)Ft4(kh4
qpp
ADi* −π
π
µ−=
The influence of the boundaries of the drainage area is felt
D*
w t25.2lnkh4
qp)t,r(p
π
µ−=
An equivalent pressure value p*
, which has no physical meaning,is defined:
Late transient conditions
Pseudo-steady state conditions
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At the time ts when the pseudo-steady state is reached, the FF functionstabilizes and becomes linear. In dimensionless terms:
ADA tclnF =sADAD tt >when
DI ETZ SHAPE FACTORDI ETZ SHAPE FACTOR ccAA: depends on the shape of the drainage
area, and on the well location within the drainage area
π+
π
µ−=
AD2wA
iw t4
rc
A25.2ln
kh4
qp)t,r(p
kh4
qt4pp
ADiπ
µπ=− 2
wA
wrc
A25.2ln
kh4
qp)t,r(p
π
µ−=
Furthermore: Fkh4
qpp *
π
µ+=
In the case of pseudo-steady state the average pressure is used:
p
V
V
1
c ∆
∆
= φ=− cAh
qtpp i
Pseudo steady state conditions
Dietz shape factor cA
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Dietz shape factor cA
Pressure decline at the wellbore in time
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LATE TRANSIENT CONDI TIONS LATE TRANSIENT CONDI TIONS (one or more boundaries are felt)
EARLY TRANSIENT CONDI TIONS EARLY TRANSIENT CONDI TIONS (radial flow)
PSEUDO PSEUDO - - STEADY STATE CONDITIONS STEADY STATE CONDI TIONS (all boundaries are felt)
t
P(rw, t)
( 1 )( 3 )
( 2 )
Liquid Flow Equations
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( 1 ) General equation
)S2Ft4t25.2(lnkh4
qp)t,r(p
ADDiw +−π+π
µ−=
+
π
µ−= S2
rc
A25.2ln
kh4
qp)t,r(p
2wA
w
( 3 ) Equation valid under pseudopseudo--steady state conditionssteady state conditions
)S2t25.2(lnkh4
qp)t,r(p Diw +π
µ−=
( 2 ) Equation valid under early transient conditionsearly transient conditions only, when noboundaries are felt, also called infinite acting state (radial flow)
q q
Gas Flow Equations
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t)p(m1)p(m2
∂∂
η=∇tp1p2
∂∂η=∇Liquids Liquids Gas Gas
Analogy with the liquid flow: the solutions to the two equationsin dimensionless terms are the same, only the proportionality
groups are different.
ADtP
kh4
qp
π
µ=∆
ADsc
scsc
tP
Tp
kh2Tq)p(m
π=∆
Ft4t25.2lnt
PADD
AD−π+=
2wA
AD rc
A25.2ln
tP =
DAD
t25.2lnt
P =
Always validAlways valid
PseudoPseudo--steady state conditionssteady state conditions
Early transient conditionsEarly transient conditions
Pressure decline at the wellbore in time
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PSEUDO PSEUDO - - STEADY STATE CONDITIONS STEADY STATE CONDI TIONS (all boundaries are felt)
LATE TRANSIENT CONDI TIONS LATE TRANSIENT CONDI TIONS (one or more boundaries are felt)
EARLY TRANSIENT CONDI TIONS EARLY TRANSIENT CONDI TIONS (radial flow)
t
m(pw)
( 1 )( 3 )
( 2 )
Gas Flow Equations
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)'S2t25.2(lnT
p
kh2
Tq)p(m)p(m D
sc
scscwi +
π=−
)'S2Ft4t25.2(lnT
p
kh2
Tq)p(m)p(m
ADD
sc
scscwi +−π+
π=−
+
π=− 'S2
rc
A25.2ln
T
p
kh2
Tq)p(m)p(m
2wAsc
scscw
( 1 ) General equation
( 2 ) Equation valid under early transient conditionsearly transient conditions only, when noboundaries are felt, also called infinite acting state (radial flow)
( 3 ) Equation valid under pseudopseudo--steady state conditionssteady state conditions
WELL TESTING
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( 1 ) PRODUCTI VI TY TESTS( 1 ) PRODUCTI VI TY TESTS
to 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 (RESERVOI R LI MI T TESTRESERVOI R LI MI T TEST)
- k , Vp
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
Deliverability Tests for Gas Wells
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Back pressure test
qsc
p
SPURGO
tT TTT
qsc1
qsc2
qsc3
qsc4
pwf 1
pwf 2
pwf 3
pwf 4
T > ts
p
CLEAN-UP
qSC
q SC1
q SC2
qSC3
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 of Empirical relationship of
Rowlins Rowlins
- -
Schellardt Schellardt
0.5<n<1
Turbu len tf low
Lamina rf low
AOFAOF ( Abso l u te Open Fl ow ) :( Abso l u te Open Fl ow ) : maximum producing rate which
could be theoretically obtained for ∆pmax,i.e. when pwf is zero
n2wf
2sc ppCq
−=
logqscAOFAOF
logp2
)pplog(2
wf
2
−
logC
1/n
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+
π=− 'S2
rc
A25.2ln
T
p
kh2
Tq)p(m)p(m
2wAsc
scscw
Rigorous equation for gas flow under pseudopseudo--steady statesteady state
conditions:
a
b
SCq)p(m∆
SCq
sc
sc
w bqaq
)p(m)p(m+=
−
Deliverability Tests for Gas Wells
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Isochronal test
qsc
p
SPURGO
tT2T TT
qsc1
qsc2
qsc3
qsc4
pwf 1
pwf 2
pwf 3
pwf 4
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 of Empirical relationship of Rowlins Rowlins - - Schellardt Schellardt
2h4h8hpseudopseudo--steady statesteady state)pplog(
2wf
2−
scqlog
n2wf
p2
pCscq
−=
1/n
1/n
Deliverability Tests for Gas Wells
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Modified isochronal test
n2w f
2
sc ppCq
−−−−====For the first producing rate:For the first producing rate:
(((( ))))n2w f
2w ssc ppCq −−−−====For the rates following the first:For the rates following the first:
qsc
p
SPURGO
tT TT
qsc1
qsc2
qsc3
qsc4
pwf 1
pwf 2
pwf 3
pwf 4
EXTENDED FLOW
T T T
pws4pws3
pws2p
t
CLEAN-
UP
qSC
qSC1
qSC4
qSC3
qSC2
T
EXTENDED
FLOW
p
ppw f1
pw f4
pw f3
pw f 2
T T T T T
pw s2 pw s3
pw s4
Productivity tests for oil wells
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qoST
p
SPURGO
t
qoST
pwf
T > ts
p
T
CLEAN-UP
qOST
qOST
T
T>ts
t
p
p
p w f
Productivity tests for oil wells
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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
pFlusso monofase
psat
Single phase flowSingle phase flow
psat
pw f
p
qost
PI
Two phase flowTwo phase flow
Drawdown tests for oil wells
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qoST
p
t
p(rw,t)
p
q
p
qOSTq
p
p(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
=
πµ−= D
w
iw t,1rrP
kh2qp)t,r(p
φµ=
∆µ
π
=
=
trc
kt
pq
kh2
t,1r
r
P
2w
D
Dw
Early transient stateEarly transient state:
1 0 0t D <<<<
Match point
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+φµ
=
∆+µ
π=
=
tlogr c
klogtlog
plogq
kh2logt,1r r Plog
2w
D
Dw
On a l og - l og g raph )t(f t,1r
rP)t(f p DD
w
=
=⇔=∆
Match point
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tD
= D
w
t,1r
rP
t
∆p
Match point
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t
∆p
tD
= D
w
t,1r
rP
* M* M
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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 of the constants by which the two curves are translated and,
therefore, the evaluation of the parameters of the reservoir rock parameters of the reservoir rock :
MD
M
2w
M
MD
w
t
t
r
k
c
p
t,1r
r
P
2
qk h
µµµµ====φφφφ
∆∆∆∆
====
ππππ
µµµµ====
Wellbore Storage
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surface flowrate
sandface flowrate
drawdown
q
time
qwh
qsf < qwh
Wellbore Storage
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wcVp
V
C =∆
∆
=
tqV ∆=∆ tCqp ∆=∆
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 dimensionand
# 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
D hrc2
C
C φπ=
Dimensionless wellbore storage coefficient Dimensionless wellbore storage coefficient
Type-Curves of Agarwal et al.(1970)
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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
rPf P
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 cφ):
MD
M
2w
M
MD
t
t
r
kc
p
P
2
qkh
µ=φ
∆π
µ=
Type-Curves of Agarwal et al.(1970)
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PD
tD
Transient state
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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 +
π
µ−=
++
φµ+
π
µ−= S281.0
rc
klntln
kh4
qp)t,r(p
2wt
iw
Transient State
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m
ln t
p(rw,t)
p
ln t
p
p(rw, t)
m
k h4
qm
ππππ
µµµµ−−−−====
( )S2t25.2lnkh4
qp)t,r(p Diw +
π
µ−=
Transient State
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−
φµ−
−== 0.9
rc
kln
m
p)h1t,r(p
2
1S
2wt
iw
At ∆t= 1 hour
++
φµπ
µ−== S20.9
rc
kln
kh4
qp)h1t,r(p
2wt
iw
Determination of the skin factor S Determination of the skin factor S
Reservoir Limit Test
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PseudoPseudo--steady state conditionssteady state conditions
+π+
π
µ−= S2t4
rc
A25.2ln
kh4
qp)t,r(p
AD2wA
iw
*mc
qAhV
t
p −=φ=Pore volume drained by the well:Pore volume drained by the well:
m*
t
p(rw,t)p(rw,t)
t
m *
tAhc qS2rcA25.2lnkh4qp)t,r(pt
2wA
iwφ−
+πµ−=
Ahc
q*m
t φφφφ−−−−====
Dietz Shape Factor cA
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=−=π=
m
)0t,r(p)h1t,r(pexp
*m
m
3600
4c ww
A
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].
+
π
µ−==
++
φµπµ−==
S2rc
A25.2ln
kh4
qp)0t,r(p
S20.9rc
klnkh4
qp)h1t,r(p
2wA
iw
2wt
iw
The calculated value for cA can then be compared with the Dietz shapefactors presented for a variety of different geometrical configurationsto infer the shape of the drainage area and the well location within the
drainage area.
Drawdown Tests for Gas Wells
I th f ll i l t d d t t b f d t
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In the case of gas wells single rate drawdown tests can be performed toevaluate the parameters of the producing formation parameters of the producing formation just 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 ++
φµ+
π−=
Transient state flow equationTransient state flow equation
PseudoPseudo--steady state flow equationsteady state flow equation
+
φµπ+
π−= '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 pressuredata allows the determination of the apparent skin factor only, but two
flow rates are needed to determine both S and D .
Drawdown Tests for Gas Wells
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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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m2
ln t
m(pw)
m1
m p( )
ln t
m(pw)
m(p)
π−=sc
sc2sc
2 T
p
kh2
Tq
m
π−=
sc
sc1sc1
Tp
kh2Tqm
For ∆t = 1 h
−
φµ−
−=+
−φµ−
−=+
=
=
0.9rc
kln
m
)p(m)p(m
2
1DqS
0.9rc
klnm
)p(m)p(m
2
1DqS
2wt2
i2h1tw
2sc
2wt1
i1h1t
w
1sc
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.
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u , q 0, a p odu g a a o a o a o a a
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
eqq
N
t ====
∆t=0
cumulative volume of oil since beginning of production
final flow rate
Flow equation which extend the flow equation derived for an infinite acting system
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)S2t25.2(lnkh4
qp)t,r(p D
*w +
π
µ−=
q q g y
(radial geometry) to the case of a finite, irregularly-shaped drainage area:
i* pp =
If the well is new:F
kh4
qpp *
π
µ+=
If the well has been produced:
The equation applies when the flow rate q is constant. The superposition theoremis applied:+q
-q
tp+∆t
tp
++∆++
φµπµ−= S281.0)ttln(
rckln
kh4qp)t,r(p p2
wt
*w
++∆+
φµπµ+ S281.0tln
rckln
kh4q
2wt
Horner Plot
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t
ttln
kh4
qp)t,r(p
p*w
∆
∆+
π
µ−=
!! Horne r p lo t Ho rne r p lo t
k h4
qm
ππππ
µµµµ====
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
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
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 PLOT HORNER PLOT
t
ttln
p
∆
∆+
pw
m
After flowAfter flow
Skin effectSkin effect
*p
Determination of the Skin Factor
••atat ∆∆t=0, i.e.at the production time tt=0, i.e.at the production time t Oil Well
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)S2t25.2(lnkh4
qp)0t,r(p D
*w +
π
µ−==∆
++
φµ+
π
µ−==∆ S281.0
rc
klntln
kh4
qp)0t,r(p
2wtiw
••atat ∆∆t=1 hourt=1 hour
)3600lnt(lnkh4
qp)h1t,r(p *
w−
π
µ−==∆
h1tif ttt =∆≈+∆
+++
φµπ
µ−=−
=∆=∆3600lnS281.0
rc
kln
kh4
qpp
2
wt
h1tw0tw
−
φµ−−= =∆=∆ 9
rckln
mpp
21S
2
wt
0twh1tw
Buildup Tests for Gas Wells
pTq scsc*
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)'S2t25.2(lnT
p
kh2
q
)p(m)p(m D
sc
scscw +π−=
∆∆+
π−=
tttln
Tp
kh2Tq)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
ttlnp
∆
∆+
!! Horn er Plo t Horn er Plo t
m(pw)
m
sc
scsc
T
p
k h2
Tqm
ππππ====m(p*)
Determination of the Skin Factor
Gas Well
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−
φµ
−−
= =∆=∆ 0.9
rc
kln
m
)p(m)p(m
2
1'S
2
wt
0twh1tw
Type-Curves of Agarwal et al.(1970)
The type The type - - curves obtained by curves obtained by Agarwal Agarwal et al et al ..
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== DD
w
D C,S,t,1r
rPf P
represent solutions to the drawdown equation to describe the pressure decline at the
wellbore, 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 thatthe rate of pressure decline could be assumed negligible during the shut-in period. If
this 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(pww
=∆−
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
r
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== DDw
D C,S,t,1rPf PThe Agarwal type curves:
can be written as a function of: t
C
kh2
C
t
D
D
µ
π=
trc
kt
2wt
Dφµ
=
2wt
Dhrc2
CC
φπ=
Infinite acting radial flow equation for fluid flux occurring in a homogeneous porous
medium under transient conditions:
( )S2t25.2lnkh4
qp)t,r(p Diw +
π
µ−=
( )S2t25.2ln2
1P DD +=
obtained from
( )
++=
S2
D
D
DD eCln81.0C
t
ln2
1
P
By substitution:
Type-Curves Plot
100
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D
DD
C
tP =
(i.e., unit slope)
0.1
1
10
0.1 1 10 100 1000 10000t
CD
D
PD C eDS2 10000
0. 1
PD CDe2S10000
0. 1
tD
CD
When pure wellbore storage flow occurs:
Pressure Derivative Method
According to this method, which is largely based on the solutions obtained byAgarwal et al., the type-curves are redrawn in terms of the derivative of the
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g , ypdimensionless 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 datap(rw,t), expressed in terms of pressure derivative:
dt
)pp(d'p wf i −
=∆
)t(f t'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(f t
ttt'p ∆=∆+∆∆
Type-Curve Derivatives
D' dP
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=
D
DD
C
td
P
PURE W ELLBORE STORAGE PURE W ELLBORE STORAGE
1
C
t
d
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 UM FOR A H OMOGENEOUS POROUS MEDI UM
=
=
D
D
D
D
D'D
C
t
5.0
C
td
dPP
Type-Curves and Type-Curve Derivatives
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10-210-3 10-1 1 10
∆∆∆∆t (hr)
103
102
101
104
∆ ∆∆ ∆ p ( p s
i a ) &
∆ ∆∆ ∆ p ’
WellboreStorage
Radial Flow
CDe2S
1030
1012
106
10-1
102
104
Real data vs type-curves
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∆∆∆∆t (hr)
∆ ∆∆ ∆ p ( p s i a ) &
∆ ∆∆ ∆ 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
Superposition real data & type-curves
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103
102
101
10-210-3 10-1 1 10 101
104
∆∆∆∆t (hr)
∆ ∆∆ ∆ p ( p s i
a ) &
∆ ∆∆ ∆ p ’
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Interpretation Result
Pr ess r e Mat chPr ess r e Mat ch k hk hB
kh4
PD ∆
π
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• C C g ives 2wt
Dhrc2
CC πφ=
•• Cu r ve Mat ch Cu r ve Mat ch
S2
DeC
•• Skin Skin
= D
S2D
C
eC
ln2
1
S
• Pr essur e Mat ch Pr essur e Mat ch k h k h pqBPo
D ∆µ=
••Tim e Mat ch Tim e Mat ch C C tC
kh2
Ct
D
D
∆µ
π
=
Drawdown Test Analysis
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Pressure
L o g ∆ ∆∆ ∆ 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
Pr e ssu r e v s Ho r n er t i m e
Buildup Test Analysis
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Log t
P r e s s u
r e
L o g ∆ ∆∆ ∆ 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
The derivatives of the type-curves exhibit a linear dependency on time of
pressure data points Linearity can occur according to different yet
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pressure data points. Linearity can occur according to different yetcharacteristic slopes which are a function of flow geometry:
FLOW TYPE FLOW TYPE PRESSURE PRESSURE SLOPE SLOPE
linear linear
bilinear bilinear
radial radial
spherical spherical
(hemispherical)(hemispherical)
)t(f p =
)t(f p 4=
)t(lnf p =
=
t
1f p
1/ 2 1/ 2
1/ 4 1/ 4
- - 1/ 2 1/ 2
horizontal horizontal
straight line straight line