petroleum reservoir engineering ii lecture 2: fundamentals
TRANSCRIPT
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Tishk International UniversityEngineering FacultyPetroleum and Mining Engineering Department
Petroleum Reservoir Engineering II
Third Grade- Spring Semester 2020-2021
Lecture 2: Fundamentals of Rock Properties (Wettability)
Instructor: Sheida Mostafa Sheikheh
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Fundamentals of Rock Properties:
β The material of which a petroleum reservoir rock may be composed can range from
very loose and unconsolidated sand to a very hard and dense sandstone, limestone,
or dolomite.
β The grains may be bonded together with a number of materials, the most common
of which are silicate, calcite or clay.
β Knowledge of the physical properties of the rock and the existing interaction
between hydrocarbon system and the formation is essential in understanding and
evaluating the performance of a given reservoir.
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Fundamentals of Rock Properties:
β Rock properties are
determined by performing
laboratory analyses on cores
from the reservoir to be
evaluated.
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Fundamentals of Rock Properties:
β There are basically two main categories of core analysis tests that are preformed on
core samples regarding physical properties of reservoir rocks.
Core Analysis Tests
Routine Core Analysis
Tests
Porosity Permeability Saturation
Special Tests
WettabilitySurface and Interfacial Tension
Capillary Pressure
Relative Permeability
Overburden Pressure
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Content (Theory):
β Wettability
β Wetting Characteristics
β Factors Affecting Wettability
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Wettability:
β Wettability is defined as the tendency of one fluid to spread on or adhere to a solid surface
in the presence of other immiscible fluids.
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Wettability:
β When a liquid is brought
into contact with a solid
surface, the liquid either
expand over the whole
surface or form small
drops on the surface.
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Wettability: β Small drops of three liquids- mercury, oil and water- are
placed on a clean glass plate. Once, the three droplets are
observed from one side, it is noted that the mercury
retains a spherical shape, the oil droplets develop an
approximately hemispherical shape, but the water tends
to spread over the glass surface.
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Wettability:
β The tendency of a liquid to spread over the surface of a solid is an indication of the
wetting characteristics of the liquid for the solid. This spreading tendency can be
expressed more conveniently by measuring the angle ΞΈ of contact at the liquid-solid
surface. This angle, which is always measured through the liquid to the solid, is
called the contact angle ΞΈ.
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Wettability:
β Contact angle and wettability are inversely proportional.
β As the contact angle decreases, the wetting characteristics of the liquid increases.
β Complete wettability would be evidenced by a zero contact angle.
β Complete nonwetting would be evidenced by a contact angle of 180Β°.
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Wettability:
β A wetting phase is one which spreads over the solid surface and preferentially wets
the solid. The contact angle approaches zero (and will always be less than 90Β°).
β A non-wetting phase has little or no affinity for a solid and the contact angle will be
greater than 90Β°.
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Wettability:
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Wettability:
Which Condition is more favorable for us as
Petroleum Engineers?
Water-wet or Oil-wet Rock?
Which one is preferable for Oil Recovery
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Wettability:
β The wettability of reservoir rocks to the fluids is important in that the distribution of the
fluids in the porous media is a function of wettability.
β’ Water-wet: the rock/mineral surface is coated with water, while oil and gas occupy the
central position of the largest pores.
β’ Oil-wet: the relative positions of oil and water are reversed with respect to the water-wet
state; the rock/mineral surface is coated with oil and the water is in the centre of the
largest pores.
β’ Intermediate wettability: this term applies to reservoir rocks where there is some
tendency for both oil and water to adhere to the pore surface
β Because of the attractive forces, the wetting phase tends to occupy the smaller pores of
the rock and the nonwetting phase occupies the more open channels.
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Wettability:
β In the oilfield terminology, a rock:
β’ Is strongly water-wet if the contact angle is π = 0 β 70Β°
β’ Has intermediate wettability if the contact angle is π = 70 β 110Β°
β’ Is strongly oil-wet if the contact angle is π = 110 β 180
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Wettability:
β The wettability of a reservoir rock system will depend on many factors:
βͺ Reservoir rock material
βͺ Geological mechanisms (accumulation and migration)
βͺ Composition and amount of oil and water
βͺ Physical conditions; pressure and temperature
βͺ Mechanisms occurring during production; i.e., change in saturations, pressure and
composition.
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Factors affecting Wettability:
β Factors related to rock properties:
β’ Rock composition: Different minerals
have different basic/acidic properties:
β Silicate minerals have acidic surfaces:
β’ Repel acidic fluids such as major polar
organic compounds present in some
crude oils
β’ Attract basic compounds
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Factors affecting Wettability:
β Factors related to rock properties:
β’ Rock composition: Different minerals
have different basic/acidic properties:
β Carbonate minerals have basic surfaces:
β’ Attract acidic compounds of crude oils
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Factors affecting Wettability:
β Factors related to water properties:
β’ Water:
β Presence of water inhibits oil wetting ability
β Low salinity water shifts of the contact angle distribution toward a more
waterβwet state.
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Factors affecting Wettability:
β Factors related to oil properties:
β’ Oil composition
- Resins (NSOs)
β Nitrogen
β Sulphur
β Oxygen
- Heavy depositional polar components
β Asphaltene, kerogen, bitumen, wax
Increase of Heavy Components= Increase of Oil Wetness
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Factors affecting Wettability:
β Factors related to water properties:
β’ Temperate:
β Temperature has effect on both oil/water and water/mineral interfaces.
β Shift in wettability of mineral surfaces toward water-wet at elevated
temperatures.
β Increasing the solubility of adsorbed materials from surfaces and decreasing the
IFT are two different effects of temperature on wettability at elevated
temperature.
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Content (Practical):
β Wettability
β Imbibition and Drainage Processes
β Wettability Measurement
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Wettability:
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Drainage and Imbibition Process:
β Drainage: fluid flow process in which the saturation of the nonwetting phase
increases.
β Example of drainage is waterflood of an oil reservoir that is oil-wet.
β Mobility of nonwetting fluid phase increases as nonwetting phase saturation
increases.
β This process of displacing wetting phase by non-wetting phase is called drainage
process.
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Drainage and Imbibition Process:
β Imbibition: is a fluid flow process in which the saturation of the wetting phase
increases and the nonwetting phase saturation decreases.
β Example of imbibition is waterflood of a water-well oil reservoir.
β Mobility of wetting phase increases as wetting phase saturation increases.
β This process continues to a certain water saturation (maximum value) at which no
more oil can be displaced. This point is called residual oil saturation.
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Measurement of Wettability:
β No satisfactory method exists for in situ measurement of wettability.
β Therefore, it is necessary to estimate the wettability from laboratory measurements.
β Imbibition and displacement (Amott β Harvey method) is the most accepted and
widely used test in the oil industry.
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Measurement of Wettability:
β The Amott-Harvey Method:
1. Spontaneous Imbibition:
Oil-saturated sample is placed in an
imbibition cell surrounded by water. The
water is allowed to imbibe into the core
sample displacing oil until equilibrium is
reached. The volume of water imbibed is
equal to the oil displaced; ππ1
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Measurement of Wettability:
β The Amott-Harvey Method:
2. Forced Imbibition:
The core is moved to a core holder and water
is pumped through. The volume of oil
displaced may be measured; ππ2
Water Index:
ππ€ =ππ1
ππ1 + ππ2
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Measurement of Wettability:
β The Amott-Harvey Method:
3. Spontaneous Uptake of Oil:
The core, now saturated with water at
residual oil saturation, is placed in an Amott
cell and surrounded by oil. The oil is
spontaneously taken up and water is
displaced. The volume of water displaced is
measured; ππ€1
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Measurement of Wettability:
β The Amott-Harvey Method:
4. Forced displacement of water
The core is removed from the cell after equilibrium is reached, and remaining water in the core is forced out by displacement in a flooding rig. The volume of water displaced is measured; ππ€2
Oil Index:
ππ =ππ€1
ππ€1 + ππ€2
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Measurement of Wettability:
β Amott-Harvey Wettability Index:
ππΌ =ππ1
ππ1 + ππ2β
ππ€1ππ€1 + ππ€2
= ππ€ β ππ
ππ1= volume of oil produced during water imbibition
ππ2= volume of oil produced during water flooding
ππ€1= volume of water produced during oil βimbibitionβ
ππ€2= volume of water produced during oil flooding
ππ€= water index
ππ= oil index
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Measurement of Wettability:
Amott β Harvey Method:
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Measurement of Wettability:
Amott β Harvey Method:
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Measurement of Wettability:
β Amott-Harvey Wettability Index:
ππΌ =ππ1
ππ1 + ππ2β
ππ€1ππ€1 + ππ€2
= ππ€ β ππ
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Measurement of Wettability:
β Amott-Harvey Wettability Index:
ππΌ =ππ1
ππ1 + ππ2β
ππ€1ππ€1 + ππ€2
= ππ€ β ππ
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Measurement of Wettability:
Example: The following table provides the displacement data for an Amott wettability
test on three cores from an Alaska North Slope reservoir.
Calculate the Amott-Harvey wettability index for each core and determine the wetting
characteristics of each core.
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Measurement of Wettability:
Solution:
Water Index:
ππ€ =ππ1
ππ1 + ππ2
ππ€ =0.81
0.81 + 0.85
ππ€ = 0.488
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Measurement of Wettability:
Solution:
Oil Index:
ππ =ππ€1
ππ€1 + ππ€2
ππ =0.05
0.05 + 1.25= 0.038
ππ = 0.038
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Measurement of Wettability:
Solution:
Wettability Index:
ππΌ =ππ1
ππ1 + ππ2β
ππ€1ππ€1 + ππ€2
= ππ€ β ππ
ππΌ = 0.488 β 0.038
ππΌ = 0.488 β 0.038
ππΌ = 0.45
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Measurement of Wettability:
Homework: The following table provides the displacement data for an Amott wettability test:
Calculate the Amott-Harvey wettability index for each core and determine the wetting
characteristics of each core.
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Measurement of Wettability: