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The Mystery of The Mystery of Capillary PressureCapillary Pressure
April 2005April 2005
Presentation SummaryPresentation Summary What is capillary pressure and what causes it?What is capillary pressure and what causes it? Why is understanding capillary pressure Why is understanding capillary pressure
important to reservoir optimization?important to reservoir optimization? Situation of capillary equilibrium and non-Situation of capillary equilibrium and non-
equilibriumequilibrium How capillary pressure can work for or against How capillary pressure can work for or against
us in oil and gas production operationsus in oil and gas production operations How to we measure and understand capillary How to we measure and understand capillary
pressurepressure
WHAT IS WHAT IS CAPILLARY CAPILLARY PRESSURE?PRESSURE?
Pc = 2 * Pc = 2 * σσ * cos * cos θθ / r / r
The strength of the Interface The strength of the Interface between two fluids is Measured by between two fluids is Measured by
the ‘Interfacial Tension’the ‘Interfacial Tension’
Typical Interfacial Tension ValuesTypical Interfacial Tension Values
Air – Water = 70 dyne/cm (mN.m)Air – Water = 70 dyne/cm (mN.m)Air – mineral oil = 25-30 dyne/cmAir – mineral oil = 25-30 dyne/cmAir – mercury = 470 dyne/cmAir – mercury = 470 dyne/cmThe The lowerlower the IFT – the closer the two the IFT – the closer the two
phases are to phases are to ‘miscibly’‘miscibly’ blending blendingLow IFT considered to be <0.01 dyne/cmLow IFT considered to be <0.01 dyne/cm
Typical Reservoir Fluid Interfacial Typical Reservoir Fluid Interfacial Tension ValuesTension Values
Water – Gas (2000 psi, 100 C, 85% C1) – Water – Gas (2000 psi, 100 C, 85% C1) – 30-40 dyne/cm30-40 dyne/cm
Water – CO2 Gas (2000 psi, 100 C) - < 2 Water – CO2 Gas (2000 psi, 100 C) - < 2 dyne/cmdyne/cm
Water – Live Oil - typically 5-25 dyne/cmWater – Live Oil - typically 5-25 dyne/cmGas – Oil – typically 1-30 dyne/cmGas – Oil – typically 1-30 dyne/cmAdditional of surfactants or miscible Additional of surfactants or miscible
solvents can radically lower IFTsolvents can radically lower IFT
Common Methods of Interfacial Common Methods of Interfacial Tension MeasurementTension Measurement
Drop PendantDrop PendantSpinning dropSpinning dropDunoue RingDunoue Ring
The Interaction of the Interface Will The Interaction of the Interface Will be Controlled by the Preferential be Controlled by the Preferential
Surface WettabilitySurface Wettability
The Interaction of the Interface Will The Interaction of the Interface Will be Controlled by the Preferential be Controlled by the Preferential
Surface WettabilitySurface Wettability
The Interaction of the Interface Will The Interaction of the Interface Will be Controlled by the Preferential be Controlled by the Preferential
Surface WettabilitySurface Wettability
The Concept of ‘Capillary The Concept of ‘Capillary Curvature’Curvature’
cRPc 1
Capillary Pressure Effects in a Capillary Pressure Effects in a Capillary TubeCapillary Tube
The Size of the Characteristic The Size of the Characteristic Radius Will be a Function ofRadius Will be a Function of
The size of the capillary (the smaller the The size of the capillary (the smaller the capillary, the smaller the size of the capillary, the smaller the size of the characteristic radius)characteristic radius)
The interfacial tension between the two The interfacial tension between the two fluids (the higher the IFT, the stiffer the fluids (the higher the IFT, the stiffer the interface and the smaller the amount of interface and the smaller the amount of the characteristic radius)the characteristic radius)
ThereforeThereforeAs the size of the capillary decreases, the As the size of the capillary decreases, the
radius of curvature decreases and hence radius of curvature decreases and hence the value of the capillary pressure the value of the capillary pressure increasesincreases
As the IFT between the fluids increases As the IFT between the fluids increases the stiffness of the interface increases and the stiffness of the interface increases and hence the capillary pressure increaseshence the capillary pressure increases
In Nature, the ‘Suction’ Effect of Capillary In Nature, the ‘Suction’ Effect of Capillary Pressure is Exactly Balanced by Gravity in Pressure is Exactly Balanced by Gravity in an Equilibrium Situation With no Imposed an Equilibrium Situation With no Imposed
External Pressure GradientsExternal Pressure Gradients
ghP cHydrostati
Thus in Capillaries of Differing Thus in Capillaries of Differing sizessizes
How do we Translate How do we Translate These Principles to These Principles to
a Oil or Gas a Oil or Gas Reservoir Situation?Reservoir Situation?
A Reservoir Pore System Can be Considered to A Reservoir Pore System Can be Considered to be a Network of ‘Capillary’ Tubes of Varying Sizes be a Network of ‘Capillary’ Tubes of Varying Sizes
and Degrees of Interconnectivenessand Degrees of Interconnectiveness
A Reservoir Pore System Can be Considered to A Reservoir Pore System Can be Considered to be a Network of ‘Capillary’ Tubes of Varying Sizes be a Network of ‘Capillary’ Tubes of Varying Sizes
and Degrees of Interconnectivenessand Degrees of Interconnectiveness
The Hydrostatic Portion of any Two The Hydrostatic Portion of any Two (or more) Phase Portion of a (or more) Phase Portion of a
Reservoir Can be Expressed AsReservoir Can be Expressed As
ghP cHydrostati
Therefore we can Also Say ThatTherefore we can Also Say That
chcap RghP 1)(
Thus in a Static Capillary Thus in a Static Capillary Equilibrium Situation, Equilibrium Situation,
Hydrostatic Gravitational Hydrostatic Gravitational Forces Always Exactly Forces Always Exactly Balance the Capillary Balance the Capillary
Pressure ForcesPressure Forces
This is too SayThis is too Say
CA
PILLAR
Y FOR
CES
GR
AVI
TY F
OR
CES
The Concept of a Capillary The Concept of a Capillary Transition ZoneTransition Zone
The Concept of a Capillary The Concept of a Capillary Transition ZoneTransition Zone
Water Contact – Location in the Reservoir Where aFinite Free Gas or Oil Saturation Begins to be Apparent
The Concept of a Capillary The Concept of a Capillary Transition ZoneTransition Zone
The Concept of a Capillary The Concept of a Capillary Transition ZoneTransition Zone
In a Low Permeability Reservoir the In a Low Permeability Reservoir the Pores/Pore Throats Are SmallPores/Pore Throats Are Small
This Equates to a Network of Very Fine This Equates to a Network of Very Fine Capillaries and Hence ‘High’ Capillary Capillaries and Hence ‘High’ Capillary
PressurePressure
In a High Permeability Reservoir In a High Permeability Reservoir the Pores/Pore Throats Are Largerthe Pores/Pore Throats Are Larger
This Equates to a Network of Larger Capillaries This Equates to a Network of Larger Capillaries and Hence ‘Lower’ Capillary Pressure at a Given and Hence ‘Lower’ Capillary Pressure at a Given
Height Above the Free Water ContactHeight Above the Free Water Contact
In a Reservoir, The Capillary Pressure is In a Reservoir, The Capillary Pressure is Controlled by the Characteristic Curvature. Controlled by the Characteristic Curvature.
Unlike a Capillary Tube Both Phases Exist at the Unlike a Capillary Tube Both Phases Exist at the Same Time in a Given Pore LocationSame Time in a Given Pore Location
In a Reservoir, The Capillary Pressure is In a Reservoir, The Capillary Pressure is Controlled by the Characteristic Curvature as Controlled by the Characteristic Curvature as
Unlike a Capillary Tube Both Phases Exist at the Unlike a Capillary Tube Both Phases Exist at the Same Time in a Given Pore LocationSame Time in a Given Pore Location
In a Reservoir, The Capillary Pressure is In a Reservoir, The Capillary Pressure is Controlled by the Characteristic Curvature as Controlled by the Characteristic Curvature as
Unlike a Capillary Tube Both Phases Exist at the Unlike a Capillary Tube Both Phases Exist at the Same Time in a Given Pore LocationSame Time in a Given Pore Location
The Concept of a Capillary The Concept of a Capillary Transition ZoneTransition Zone
The Concept of a Capillary The Concept of a Capillary Transition ZoneTransition Zone
The Concept of a ‘Capillary The Concept of a ‘Capillary Pressure Curve’Pressure Curve’
A graphical relationship that relates the A graphical relationship that relates the apparent capillary pressure to the average apparent capillary pressure to the average water saturation in a given (assumed to be water saturation in a given (assumed to be homogeneous) pore systemhomogeneous) pore system
Typical Water-Gas Capillary Typical Water-Gas Capillary Pressure CurvePressure Curve
Typical Water-Gas Capillary Typical Water-Gas Capillary Pressure CurvePressure Curve
Typical Water-Gas Capillary Typical Water-Gas Capillary Pressure CurvePressure Curve
COMMON CAPILLARY COMMON CAPILLARY PRESSURE PRESSURE
DETERMINATION METHODSDETERMINATION METHODS
Common Capillary Pressure Common Capillary Pressure Determination MethodsDetermination Methods
Porous PlatePorous PlateClean StateClean StateNative StateNative State
CentrifugeCentrifugeClean StateClean StateNative StateNative State
Mercury InjectionMercury Injection
Porous Plate MethodPorous Plate MethodUses a ceramic wetted plate Uses a ceramic wetted plate Plate is permeable to only the wetting Plate is permeable to only the wetting
phase in the porous media being phase in the porous media being evaluated up to a certain ‘breakdown’ evaluated up to a certain ‘breakdown’ pressure level (typically 1000-1500 kPa)pressure level (typically 1000-1500 kPa)
Two methods, single plate (capable of full Two methods, single plate (capable of full reservoir conditions) and bulk porous plate reservoir conditions) and bulk porous plate (non reservoir conditions)(non reservoir conditions)
SINGLE POROUS PLATE SINGLE POROUS PLATE METHODMETHOD
Porous Plate
Core Sample atMaximum
WettingPhase
Saturation
Injection Head
NonWetPhs
Constant P Drive
SINGLE POROUS PLATE SINGLE POROUS PLATE METHODMETHOD
Porous Plate
Core Sample atMaximum
WettingPhase
Saturation
Injection Head
NonWetPhs
Constant P Drive
SINGLE POROUS PLATE SINGLE POROUS PLATE METHODMETHOD
Porous Plate
Core Sample atMaximum
WettingPhase
Saturation
Injection Head
NonWetPhs
Constant P Drive
SINGLE POROUS PLATE SINGLE POROUS PLATE METHODMETHOD
Porous Plate
Core Sample atMaximum
WettingPhase
Saturation
Injection Head
NonWetPhs
Constant P Drive
SINGLE POROUS PLATE SINGLE POROUS PLATE METHODMETHOD
Porous Plate
Core Sample atMaximum
WettingPhase
Saturation
Injection Head
NonWetPhs
Constant P Drive
SINGLE POROUS PLATE SINGLE POROUS PLATE METHODMETHOD
Porous Plate
Core Sample atMaximum
WettingPhase
Saturation
Injection Head
NonWetPhs
Constant P Drive
Data AnalysisData Analysis
Advantages and Disadvantages of Advantages and Disadvantages of the Single Plug Porous Plate the Single Plug Porous Plate
MethodMethod
PROSPROS Can stress samplesCan stress samples Can use native state Can use native state
core materialcore material Can be conducted in Can be conducted in
conjunction with conjunction with electrical property electrical property measurementsmeasurements
ConsCons Slow for low perm Slow for low perm
samplessamples Increased expenseIncreased expense Maximum 1000-1500 Maximum 1000-1500
kPa capillary pressure kPa capillary pressure possiblepossible
Not suitable for Not suitable for samples less than 1-5 samples less than 1-5 mDmD
SINGLE POROUS PLATE SINGLE POROUS PLATE SYSTEMSYSTEM
BULK POROUS PLATE METHODBULK POROUS PLATE METHOD
BULK POROUS PLATE
QUICK RELEASE PRESSURE SEAL COVER
BULK POROUS PLATE METHODBULK POROUS PLATE METHOD
BULK POROUS PLATE
QUICK RELEASE PRESSURE SEAL COVER
BULK POROUS PLATE METHODBULK POROUS PLATE METHOD
BULK POROUS PLATE
QUICK RELEASE PRESSURE SEAL COVER
BULK POROUS PLATE METHODBULK POROUS PLATE METHOD
BULK POROUS PLATE
QUICK RELEASE PRESSURE SEAL COVER
BULK POROUS PLATE CELLBULK POROUS PLATE CELL
Advantages and Disadvantages of Advantages and Disadvantages of the Bulk Porous Plate Methodthe Bulk Porous Plate Method
PROSPROS Can use native state core Can use native state core
materialmaterial Can be conducted in Can be conducted in
conjunction with electrical conjunction with electrical property measurementsproperty measurements
Relatively inexpensiveRelatively inexpensive
ConsCons Slow for low perm Slow for low perm
samplessamples Maximum 1000-1500 kPa Maximum 1000-1500 kPa
capillary pressure capillary pressure possiblepossible
Not suitable for samples Not suitable for samples less than 1-5 mDless than 1-5 mD
Test proceeds at the rate Test proceeds at the rate of the lowest permeability of the lowest permeability samplesample
MODIFIED BULK POROUS PLATE MODIFIED BULK POROUS PLATE METHODMETHOD
BULK POROUS PLATE
QUICK RELEASE PRESSURE SEAL COVER
MODIFIED BULK POROUS PLATE MODIFIED BULK POROUS PLATE CELLCELL
Advantages and Disadvantages of Advantages and Disadvantages of the Bulk Porous Plate Methodthe Bulk Porous Plate Method
PROSPROS Can use native state core Can use native state core
materialmaterial Can be conducted in Can be conducted in
conjunction with electrical conjunction with electrical property measurementsproperty measurements
Relatively inexpensiveRelatively inexpensive No need to remove No need to remove
samples from system samples from system resulting in less sample resulting in less sample disturbance and grain disturbance and grain lossloss
ConsCons Slow for low perm Slow for low perm
samplessamples Maximum 1000-1500 kPa Maximum 1000-1500 kPa
capillary pressure capillary pressure possiblepossible
Not suitable for samples Not suitable for samples less than 1-5 mDless than 1-5 mD
Test proceeds at the rate Test proceeds at the rate of the lowest permeability of the lowest permeability samplesample
CENTRIFUGE METHODSCENTRIFUGE METHODS
Centrifuge MethodsCentrifuge MethodsUse applied centrifugal force induced by Use applied centrifugal force induced by
rapid rotation of the core sample to rapid rotation of the core sample to generate the capillary pressure forcegenerate the capillary pressure force
Non linear capillary pressure and Non linear capillary pressure and saturation profile is generated using this saturation profile is generated using this methodmethod
Centrifuge SystemCentrifuge System
Capillary Pressure Induced by Capillary Pressure Induced by RotationRotation
),,,( 2 SRcap LLfP
Core Sample
Invading Fluid
Base PrecisionCollection Pipette
Top PrecisionCollection Pipette
Core Sample
Invading Fluid
Core Sample
Invading Fluid
Core Sample
Invading Fluid
Core Sample
Invading Fluid
Generation of the Capillary Generation of the Capillary Pressure CurvePressure Curve
Initial Conditions100% Water Saturation
Generation of the Capillary Generation of the Capillary Pressure CurvePressure Curve
Endface Pcap
‘Average’ Sw
Endface Sw
Generation of the Capillary Generation of the Capillary Pressure CurvePressure Curve
Endface Pcap‘A
verage’ Sw
Endface Sw
Core Sample
Invading Fluid
Core Sample
Invading Fluid
Core Sample
Invading Fluid
Core Sample
Invading Fluid
Generation of the Capillary Pressure Curve Generation of the Capillary Pressure Curve – Restored State Secondary Drainage– Restored State Secondary DrainageInitial ConditionsAt Initial Reservoir Water Saturation
Generation of the Capillary Pressure Curve Generation of the Capillary Pressure Curve – Restored State Secondary Drainage– Restored State Secondary Drainage
Generation of the Capillary Pressure Curve Generation of the Capillary Pressure Curve – Restored State Secondary Drainage– Restored State Secondary Drainage
Core Sample
Invading Fluid
Core Sample
Invading Fluid
Core Sample
Invading Fluid
Core Sample
Invading Fluid
Generation of the Capillary Pressure Curve Generation of the Capillary Pressure Curve – Restored State Imbibition Drainage– Restored State Imbibition Drainage
Generation of the Capillary Pressure Curve Generation of the Capillary Pressure Curve – Restored State Imbibition Drainage– Restored State Imbibition Drainage
The Combined Amott/USBM The Combined Amott/USBM Wettability TestWettability Test
Most common and accurate method of Most common and accurate method of reservoir wettability determinationreservoir wettability determination
Can use dead oil & brine Can use dead oil & brine Useful for distinguishing type and degree Useful for distinguishing type and degree
of wettability preferenceof wettability preferenceUses the principle of Uses the principle of capillarycapillary
thermodynamics to infer thermodynamics to infer wettabilitywettability
Basis of the MethodBasis of the MethodArea under a capillary pressure – water Area under a capillary pressure – water
saturation curve provides a representation saturation curve provides a representation of the relative amount of ‘work’ required to of the relative amount of ‘work’ required to displace a fluid into a porous mediadisplace a fluid into a porous media
Example – strongly water wet rocks will Example – strongly water wet rocks will readily spontaneously imbibe water and readily spontaneously imbibe water and absorb water under applied capillary absorb water under applied capillary pressure much easier than the oil phasepressure much easier than the oil phase
Combined Amott/USBM MethodCombined Amott/USBM Method
BRINE STATICIMBIBITION
OIL STATICIMBIBITION
Amott Wettability IndexAmott Wettability Index
Total
eousSpon
Water
Water
VV
Water tan
Total
eousSpon
Oil
Oil
VV
Oil tan
Amott Wettability IndicesAmott Wettability IndicesWaterWater
Near Zero – oil/neutral wet or tightNear Zero – oil/neutral wet or tightNear 1 – strongly water wetNear 1 – strongly water wet
OilOilNear zero – water/neutral wet or tightNear zero – water/neutral wet or tightNear 1 – strongly oil wetNear 1 – strongly oil wet
USBM Wettability IndexUSBM Wettability Index
2
1logAAUSBM Index
USBM Wettability IndexUSBM Wettability Index
2
1logAAUSBM Index
-0.1 to +0.1Neutral Wet
USBM Wettability IndexUSBM Wettability Index
2
1logAAUSBM Index
+0.1 to +0.3Moderately Water Wet
-0.1 to -0.3Moderately Oil Wet
USBM Wettability IndexUSBM Wettability Index
2
1logAAUSBM Index
Greater Than +0.3Strongly Water Wet
Less than -0.3Strongly Oil Wet
Example – Strongly Water Wet Example – Strongly Water Wet RockRock
2
1logAAUSBM Index
Example – Strongly Oil Wet RockExample – Strongly Oil Wet Rock
2
1logAAUSBM Index
Example – Neutral Wet RockExample – Neutral Wet Rock
2
1logAAUSBM Index
Example – Mixed Wet RockExample – Mixed Wet Rock
2
1logAAUSBM Index
Mercury Injection Capillary Mercury Injection Capillary PressurePressure
Most common capillary pressure determination Most common capillary pressure determination methodmethod
Uses clean dry core samples 2.5 x 2.5 cm in Uses clean dry core samples 2.5 x 2.5 cm in diameter/lengthdiameter/length
Mercury approximates the non wetting phase, air Mercury approximates the non wetting phase, air approximates the wetting phaseapproximates the wetting phase
Very high pressures of over 400 MPa (60,000 Very high pressures of over 400 MPa (60,000 psi) are used to intrude mercury into even the psi) are used to intrude mercury into even the very smallest (0.001 micron) poresvery smallest (0.001 micron) pores
Very useful for all different permeability ranges Very useful for all different permeability ranges of rock from micro to macro Darcy formationsof rock from micro to macro Darcy formations
Mercury Injection SystemMercury Injection System
Mercury Injection SystemMercury Injection System
Typical Computerized Air-Mercury Typical Computerized Air-Mercury Capillary Pressure Measurement Capillary Pressure Measurement
SystemSystem
Mercury Capillary PressureMercury Capillary PressureBecause the IFT between air and mercury Because the IFT between air and mercury
and the contact angle of mercury and rock and the contact angle of mercury and rock is precisely known, the primary use of Hg is precisely known, the primary use of Hg capillary pressure data is to map out the capillary pressure data is to map out the pore size distribution of specific reservoir pore size distribution of specific reservoir flow faciesflow facies
Pore Scale Intrusion VisualizationPore Scale Intrusion Visualization
Pore Throat ClassificationsPore Throat Classifications
MACROPORES MACROPORES - >3 - >3 MICRONS DIAMETERMICRONS DIAMETER
MESOPORESMESOPORES – 1-3 – 1-3 MICRONS DIAMETERMICRONS DIAMETER
MICROPORESMICROPORES – <1 MICRON – <1 MICRON
Pore Scale Intrusion VisualizationPore Scale Intrusion Visualization
pC rfP ,,
ThereforeThereforeMeasurement of specific volume of Measurement of specific volume of
mercury injected into the core at a given mercury injected into the core at a given applied pressure (Pc) allows us to applied pressure (Pc) allows us to determine the specific value of the pore determine the specific value of the pore throats being penetrated by the invading throats being penetrated by the invading mercury and the relative volume fraction of mercury and the relative volume fraction of the pore system that is ‘accessed’ by the pore system that is ‘accessed’ by these pore throatsthese pore throats
Thus the Raw Cap Pressure DataThus the Raw Cap Pressure Data
High Perm
Mid Perm
Low Perm
Thus For Our Three Example Thus For Our Three Example CasesCases
00.050.1
0.150.2
0.250.3
0.350.4
0.001 0.1 10 1000
Pore Throat Diameter - Microns
Volu
me
Frac
tion
of P
ore
syst
em High PermMid PermLow Perm
Pore Size Distribution Data Pore Size Distribution Data Invaluable forInvaluable for
Rock type classificationRock type classificationFlow unit typingFlow unit typingEstimation of residual and initial Estimation of residual and initial
saturationssaturationsPrediction of potential for various potential Prediction of potential for various potential
types of formation damagetypes of formation damageFraction split of ‘effective’ and ‘ineffective’ Fraction split of ‘effective’ and ‘ineffective’
porosity in a pore systemporosity in a pore system
Conversion of Mercury Capillary Conversion of Mercury Capillary Pressure Data to reservoir Pressure Data to reservoir
ConditionsConditionsRequires a good knowledge of exact fluid-Requires a good knowledge of exact fluid-
fluid IFT between the reservoir fluids and fluid IFT between the reservoir fluids and the wettability of the reservoir for accurate the wettability of the reservoir for accurate conversionconversion
Common conversion of Hg-air data to;Common conversion of Hg-air data to;Water-gasWater-gasWater-oilWater-oil
Capillary Pressure Conversion Capillary Pressure Conversion FactorFactor
airHgairhg
RFRFconvPc
coscos
Typical Conversion Factors to Gas-Typical Conversion Factors to Gas-Water and Gas-OilWater and Gas-Oil
IFT THETACorrection
Factor
Dyne/cm Degrees
70 0 8.578
70 30 7.429
70 60 4.289
70 90 0.000
70 120 -4.289
70 150 -7.429
70 180 -8.578
IFT THETACorrection
Factor
Dyne/cm Degrees
25 0 24.019
25 30 20.801
25 60 12.010
25 90 0.000
25 120 -12.010
25 150 -20.801
25 180 -24.019
Typical Air-Mercury Capillary Pressure Typical Air-Mercury Capillary Pressure Conversion Factor Data as a Function of IFT Conversion Factor Data as a Function of IFT
and Wettabilityand Wettability
-60.000
-40.000
-20.000
0.000
20.000
40.000
60.000
Reservoir Oil/Gas - Water Contact Angle - Degrees
Hg -
Air P
c Co
rrec
tion
fact
or
IFT= 70 dynes/cm
IFT = 50 dynes/cm
IFT = 30 dynes/cm
IFT = 20 dynes/cm
IFT= 10 dynes/cm
Ways in Which we Use Cap Ways in Which we Use Cap Pressure on a Reservoir ScalePressure on a Reservoir Scale
Initial saturation and transition zone Initial saturation and transition zone determinationsdeterminations
Effect of cap pressure on residual and Effect of cap pressure on residual and trapped saturationstrapped saturations
Cap pressure related formation damage Cap pressure related formation damage issuesissues
Countercurrent imbibition effects induced Countercurrent imbibition effects induced by cap pressure in non-hydrostatic by cap pressure in non-hydrostatic equilibrium situationsequilibrium situations
Typical Water-Gas Capillary Typical Water-Gas Capillary Pressure CurvePressure Curve
Swir
Transition ZoneWater & Oil Produced
Water Free Production
Water Based Phase TrappingWater Based Phase Trapping
Water Saturation
Water Saturation
Cap
illar
y P
ress
ure
Rel
ativ
e P
erm
Water Based Phase TrappingWater Based Phase Trapping
Water Saturation
Water Saturation
Cap
illar
y P
ress
ure
Rel
ativ
e P
erm
Water Based Phase TrappingWater Based Phase Trapping
Water Saturation
Water Saturation
Cap
illar
y P
ress
ure
Rel
ativ
e P
erm
Large Vertical Standoff From Water-Oil Large Vertical Standoff From Water-Oil Contact in Water Wet FormationContact in Water Wet Formation
W-O CONTACT
Initial Saturation DistributionInitial Saturation DistributionControlled byControlled by
Capillary pressure characterCapillary pressure characterHeight above free water contactHeight above free water contact IFTIFTSurface WettabilitySurface Wettability
Hydrostatic Equilibrium Reservoirs Hydrostatic Equilibrium Reservoirs – Typical Sw Profile– Typical Sw Profile
W-O CONTACT
Hydrostatic Equilibrium Reservoirs Hydrostatic Equilibrium Reservoirs – High Permeability– High Permeability
W-O CONTACT
Hydrostatic Equilibrium Reservoirs Hydrostatic Equilibrium Reservoirs – Low Permeability– Low Permeability
W-O CONTACT
What About the Same Rock With What About the Same Rock With Variable Initial Wettability?Variable Initial Wettability?
W-O CONTACT
What About the Same Rock With What About the Same Rock With Variable Initial Wettability?Variable Initial Wettability?
W-O CONTACT
What About the Same Rock With What About the Same Rock With Variable Initial Wettability?Variable Initial Wettability?
W-O CONTACT
What About Rock and Wettability What About Rock and Wettability With Variable IFT?With Variable IFT?
W-O CONTACT
What About Rock and Wettability What About Rock and Wettability With Variable IFT?With Variable IFT?
W-O CONTACT
What About Rock and Wettability What About Rock and Wettability With Variable IFT?With Variable IFT?
ConclusionsConclusionsThe Mystery of Capillary The Mystery of Capillary
PressurePressureSolvedSolved
ConclusionsConclusionsCapillary pressure is an important variable Capillary pressure is an important variable
that controlsthat controlsOriginal distribution of fluids in a reservoirOriginal distribution of fluids in a reservoirDisplacement efficiency and residual Displacement efficiency and residual
saturationssaturationsUnderstanding of capillary pressure basics Understanding of capillary pressure basics
is essential for optimizing the performance is essential for optimizing the performance of a the reservoirof a the reservoir
ConclusionsConclusionsCapillary pressure is influenced by many Capillary pressure is influenced by many
phenomenaphenomenaPore size distributionPore size distributionReservoir wettabilityReservoir wettability Interfacial tensionInterfacial tensionOffset from free water contactOffset from free water contact
Reservoirs may or may not be in capillary Reservoirs may or may not be in capillary equilibrium – understanding this plays a equilibrium – understanding this plays a key factor in many situationskey factor in many situations
ConclusionsConclusionsA variety of methods are available for the A variety of methods are available for the
measurement of classical two phase measurement of classical two phase capillary pressurescapillary pressuresSingle cell porous plateSingle cell porous plateBulk porous plateBulk porous plateCentrifuge methodsCentrifuge methodsMercury injection (scaling methods)Mercury injection (scaling methods)
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