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- 1. Pakistan Inhibited Water-Base Fluids Presentation – April 2001
Page 1
© 2001 Baker Hughes Incorporated
All rights reserved.
WHY HAVE
INHIBITED WATER-
BASE
DRILLING FLUIDS?
- 2. Pakistan Inhibited Water-Base Fluids Presentation – April 2001
Page 2
© 2001 Baker Hughes Incorporated
All rights reserved.
What is INHIBITION?
•Inhibition is essentially PREVENTION and
PROTECTION.
•We are PREVENTING an event, by
PROTECTING ourselves against that event.
- 3. Pakistan Inhibited Water-Base Fluids Presentation – April 2001
Page 3
© 2001 Baker Hughes Incorporated
All rights reserved.
What are we trying to
PREVENT?
We are trying to PREVENT undesirable
changes to a number of things:
– The Drilled Cutting!
– The Drilling Fluid Properties!
– The Formation!
- 4. Pakistan Inhibited Water-Base Fluids Presentation – April 2001
Page 4
© 2001 Baker Hughes Incorporated
All rights reserved.
UNDESIRABLE Changes to
the Drilled Cutting!
One of the FUNCTIONS of a drilling fluid is
carry the cuttings to the surface and to
remove them.
If the cutting has been ALTERED in any way,
this function may not be achieved efficiently.
So, our goal is to get that cutting to the
surface with MINIMAL changes to its shape
and structure.
- 5. Pakistan Inhibited Water-Base Fluids Presentation – April 2001
Page 5
© 2001 Baker Hughes Incorporated
All rights reserved.
What TYPES of Drilled
Cuttings?
The type of drilled cutting reflects the type of
formation being drilled.
The GENERAL types fall into four main
groups:
– Shales: Includes silts, clays and shales.
– Sandstone
– Limestone: Includes dolomite and limestones.
– Others: Includes marl, massive halite, anhydrite,
etc.
- 6. Pakistan Inhibited Water-Base Fluids Presentation – April 2001
Page 6
© 2001 Baker Hughes Incorporated
All rights reserved.
Different
CHARACTERISTICS!
Sandstones are virtually INERT!
Most limestones have little or no adverse
effect!
Massive salt, extensive halites and anhydrite
are special considerations.
Our concern is with SHALE!
However, we will briefly examine the others!
- 7. Pakistan Inhibited Water-Base Fluids Presentation – April 2001
Page 7
© 2001 Baker Hughes Incorporated
All rights reserved.
What about SANDSTONE?
Sandstones are generally
INERT!
– They have no reaction!
They MAY have up to 20-30%
clay minerals contained
within their matrix.
These clay minerals can
REACT!
- 8. Pakistan Inhibited Water-Base Fluids Presentation – April 2001
Page 8
© 2001 Baker Hughes Incorporated
All rights reserved.
What of LIMESTONE?
Limestone formations are mainly
sedimentary rocks formed from the
calcareous remains of marine animals.
Limestone is primarily CALCIUM
CARBONATE.
It is largely INERT!
Dolomite is a CALCIUM MAGNESIUM
CARBONATE.
- 9. Pakistan Inhibited Water-Base Fluids Presentation – April 2001
Page 9
© 2001 Baker Hughes Incorporated
All rights reserved.
And What of the OTHERS?
Marl
– A fine-grained sedimentary rock of silts, clays and
calcite.
Massive Halite
– Salt Domes
– Zechstein (mixed halites)
Anhydrite
– Consists of ANHYDROUS CALCIUM SULPHATE!
– May be in stringers or as a massive interval.
- 10. Pakistan Inhibited Water-Base Fluids Presentation – April 2001
Page 10
© 2001 Baker Hughes Incorporated
All rights reserved.
Why are Shales Considered
a PROBLEM?
Shales are DEPOSITS of clay minerals that
have undergone certain changes to their
structure and chemistry through:
– De-watering
– Compaction
– Formation pressures
They have TWO undesirable properties:
– Hydration
– Dispersion.
- 11. Pakistan Inhibited Water-Base Fluids Presentation – April 2001
Page 11
© 2001 Baker Hughes Incorporated
All rights reserved.
What Are SHALES?
How would you describe a ‘SHALE’?
A more accurate description might be
MUDSTONES, CLAYSTONES or SILTSTONES!
However, we will use SHALE to cover all of
these!
- 12. Pakistan Inhibited Water-Base Fluids Presentation – April 2001
Page 12
© 2001 Baker Hughes Incorporated
All rights reserved.
What Exactly Are SHALES?
Shales are complex mixtures of CLAY
MINERALS and non-clay minerals.
– The clay minerals include:
• Oxygen Silica Aluminium
• Calcium Magnesium Potassium
– The non-clay minerals include:
• Quartz Feldspar
• Pyrite Calcite
Shales are rocks composed of more than 50%
clay minerals.
- 13. Pakistan Inhibited Water-Base Fluids Presentation – April 2001
Page 13
© 2001 Baker Hughes Incorporated
All rights reserved.
The Clay TYPES!
There are SEVEN major clay types that make
up most of the clay minerals.
These fall into TWO major groups.
– LAYERED Clays
– CHAIN-TYPE Clays
- 14. Pakistan Inhibited Water-Base Fluids Presentation – April 2001
Page 14
© 2001 Baker Hughes Incorporated
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The TYPES of Clay Minerals!
The MOST common clay minerals are:
– Kaolinite
– Illite
– Chlorite
– Montmorillonite, or smectite
Each exhibits different characteristics and
was deposited in a different environment!
- 15. Pakistan Inhibited Water-Base Fluids Presentation – April 2001
Page 15
© 2001 Baker Hughes Incorporated
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The HYDRATION ABILITY of
Clay Minerals!
In order of INCREASING hydration ability:
– Chlorite
– Kaolinite
– Illite
– Montmorillonite, or smectite
- 16. Pakistan Inhibited Water-Base Fluids Presentation – April 2001
Page 16
© 2001 Baker Hughes Incorporated
All rights reserved.
Knowing Your SHALES!
SHALES are sedimentary deposits of clay
and non-clay minerals!
They have undergone changes in their
chemistry and their structure, due to age,
compaction and tectonic forces.
They are generally de-watered!
They have ONE primary, easily recognised
difference from MUDROCKS!
- 17. Pakistan Inhibited Water-Base Fluids Presentation – April 2001
Page 17
© 2001 Baker Hughes Incorporated
All rights reserved.
We Have a WORD!
FISSILITY!
Another way of looking at this is to say that
they exhibit FRACTURE-PLANES!
- 18. Pakistan Inhibited Water-Base Fluids Presentation – April 2001
Page 18
© 2001 Baker Hughes Incorporated
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So! What About
MUDROCKS?
MUDROCK is a general term used to describe
all sedimentary rocks containing clay
minerals that are not a SHALE.
Mudrock can be classified into OTHER types
of rocks, based on the particle size.
- 19. Pakistan Inhibited Water-Base Fluids Presentation – April 2001
Page 19
© 2001 Baker Hughes Incorporated
All rights reserved.
Sediment
PARTICLE SIZE!
Claystone
Mudstone
Clay
Silt
Sand
Sandstone Siltstone
% Clay < 4micron
% Silt (4- 62 microns)
50% 50%
50%
after M.D. Picard
- 20. Pakistan Inhibited Water-Base Fluids Presentation – April 2001
Page 20
© 2001 Baker Hughes Incorporated
All rights reserved.
So What’s the PROBLEM?
The problem is simply that boreholes are not
stable when drilled with any drilling fluid
system.
It is true that they are MORE stable when
OBM or SBM is used!
It is also true that more problems are
experienced when WBM is used.
WHY?
- 21. Pakistan Inhibited Water-Base Fluids Presentation – April 2001
Page 21
© 2001 Baker Hughes Incorporated
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Defining the PROBLEM!
The core issue is the reaction that takes
place between the drilling fluid’s EXTERNAL
phase and the formation that is being drilled!
When water comes into contact with the clay
minerals found in SHALES and MUDROCKS,
these rocks attempt to revert to their original
state.
We call this HYDRATION and this is the
problem!
- 22. Pakistan Inhibited Water-Base Fluids Presentation – April 2001
Page 22
© 2001 Baker Hughes Incorporated
All rights reserved.
The Problems with SHALES!
Many of the problems we have drilling shales
are MECHANICAL!
– Tectonic stresses
– Pore Pressure Transmission
– Sloughing
We can solve most of the CHEMICAL
problems with the correct fluid!
- 23. Pakistan Inhibited Water-Base Fluids Presentation – April 2001
Page 23
© 2001 Baker Hughes Incorporated
All rights reserved.
The CHEMICAL Problems
with Shales!
As we will see, there is effectively just one –
HYDRATION!
However, hydration leads to DISPERSION!
- 24. Pakistan Inhibited Water-Base Fluids Presentation – April 2001
Page 24
© 2001 Baker Hughes Incorporated
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Hydration is swelling!
– Caused by the shale taking up water - either through
ADSORPTION or ABSORPTION!
ADSORPTION is basically the attachment of
water to the OUTSIDE of the shale!
ABSORPTION is essentially the entry of water
INTO the clay structure!
The HYDRATION of Shales!
- 25. Pakistan Inhibited Water-Base Fluids Presentation – April 2001
Page 25
© 2001 Baker Hughes Incorporated
All rights reserved.
The THREE Hydration
Mechanisms!
SURFACE HYDRATION:
– The BONDING of water molecules to oxygen atoms
on the surface of the clay platelets.
IONIC HYDRATION:
– The hydration of INTERLAYER CATIONS with
surrounding shells of water molecules.
OSMOTIC HYDRATION:
– Occurs on some clays AFTER they are completely
surface and ionically hydrated.
- 26. Pakistan Inhibited Water-Base Fluids Presentation – April 2001
Page 26
© 2001 Baker Hughes Incorporated
All rights reserved.
Are Shales PREMEABLE?
Yes!
– The permeability of shales ranges from 10-6 to 10-12
Darcy!
This very LOW value means that “fluid loss”
as we normally understand it, does not
occur!
But, a gradual equilibrium between mud
hydrostatic pressure and pore pressure does
occur!
- 27. Pakistan Inhibited Water-Base Fluids Presentation – April 2001
Page 27
© 2001 Baker Hughes Incorporated
All rights reserved.
A Little MORE on Hydration!
Water adsorption or hydration can cause the
wellbore to enlarge.
– This in turn leads to problems with drag when trying
to pull out of the hole.
Wiping the hole - or pulling the bit back
through a section - releases these hydrated
clays into the mud system and also cleans
the hydrated interval.
It is now free to hydrate new faces.
- 28. Pakistan Inhibited Water-Base Fluids Presentation – April 2001
Page 28
© 2001 Baker Hughes Incorporated
All rights reserved.
CHARGES on Clay
Particles!
Charges on clays are important as they
determine properties such as :
– Ion Exchange
– Swelling Behaviour
– Viscosity of Muds
Charges can arise from :
– Broken edges on clay particles
– Substitution of Ions in the clay structure
- 29. Pakistan Inhibited Water-Base Fluids Presentation – April 2001
Page 29
© 2001 Baker Hughes Incorporated
All rights reserved.
Some FINAL Points on
Hydration!
ALL clays experience hydration to some
degree.
The ILLITES and SMECTITES exhibit varying
degrees of IONIC hydration.
Shale hydration is essentially SURFACE
ADSORPTION and OSMOTIC ADSORPTION.
- 30. Pakistan Inhibited Water-Base Fluids Presentation – April 2001
Page 30
© 2001 Baker Hughes Incorporated
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The AGE of a Shale!
YOUNG shales tend to soften, swell and
disperse when mixed with water!
OLD shales have usually undergone
diagenesis and may remain hard when
exposed to water - not easily dispersing into
the drilling fluid.
DIAGENESIS is essentially a satisfying of all electrical
charges - leading to chemical stability!
- 31. Pakistan Inhibited Water-Base Fluids Presentation – April 2001
Page 31
© 2001 Baker Hughes Incorporated
All rights reserved.
To RECAP!
When we consider SHALES, we must also
consider each of these UNDESIRABLE
properties:
HYDRATION:
• The swelling of the clays!
DISPERSION:
• The breaking-down into smaller particles!
BOTH of these mechanisms can, and do,
occur!
- 32. Pakistan Inhibited Water-Base Fluids Presentation – April 2001
Page 32
© 2001 Baker Hughes Incorporated
All rights reserved.
A SHALE Cutting!
This drawing
represents a
shale cutting at
the moment it
is released into
the annulus!
The BLUE is
water in the
shale!
- 33. Pakistan Inhibited Water-Base Fluids Presentation – April 2001
Page 33
© 2001 Baker Hughes Incorporated
All rights reserved.
A SHALE Cutting!
In normal
water-base
system, filtrate
begins to
invade the pore
spaces of the
cutting almost
immediately!
- 34. Pakistan Inhibited Water-Base Fluids Presentation – April 2001
Page 34
© 2001 Baker Hughes Incorporated
All rights reserved.
A SHALE Cutting!
Causing
weakening of
the clay matrix,
and dispersion!
Hydration may
also occur,
depending on
the type of
clays!
- 35. Pakistan Inhibited Water-Base Fluids Presentation – April 2001
Page 35
© 2001 Baker Hughes Incorporated
All rights reserved.
The OVERBURDEN
Pressure!
Overburden pressure is the weight of the
formations overlying a particular shale
section.
Weakens the shale when the shale is
penetrated - allowing a combination of
STRESS RELIEF and the OVERBURDEN
PRESSURE to cause the shale to collapse
into the hole.
- 36. Pakistan Inhibited Water-Base Fluids Presentation – April 2001
Page 36
© 2001 Baker Hughes Incorporated
All rights reserved.
The Development of PORE
PRESSURE!
Pore pressure is the
pressure that results
from the effects of
OVERBURDEN pressure
pushing DOWN and
FORMATION pressure
pushing UP!
Overburden
Pressure
Formation
Pressure
- 37. Pakistan Inhibited Water-Base Fluids Presentation – April 2001
Page 37
© 2001 Baker Hughes Incorporated
All rights reserved.
The Effects of PORE
PRESSURE!
Shales can fail when the OVERBURDEN
pressure exceeds the hydrostatic pressure!
The strength of the rock determines the
TOLERABLE MAGNITUDE of pressure
differential!
Normal drilling practise is to maintain the
hydrostatic pressure in BALANCE with the
overburden pressure!
- 38. Pakistan Inhibited Water-Base Fluids Presentation – April 2001
Page 38
© 2001 Baker Hughes Incorporated
All rights reserved.
PRESSURE SUPPORT and
INVASION!
Pm > Pf
Shale Boreholes are
stabilized by the support
of drilling fluid pressure
Pm > Pf
Pm = Pf
Support Invasion
Pressure invasion.
Pressure invades the shale,
differential pressure support at the
wall is lost
- 39. Pakistan Inhibited Water-Base Fluids Presentation – April 2001
Page 39
© 2001 Baker Hughes Incorporated
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Borehole SLOUGHING!
Pm < Pf
Loss of support at the wall
allows overburden stress to
collapse the wall and slough
it off
- 40. Pakistan Inhibited Water-Base Fluids Presentation – April 2001
Page 40
© 2001 Baker Hughes Incorporated
All rights reserved.
A Look at Borehole STRESS
RELIEF!
The consolidation process of shale
deposition produces STRESS!
When a well is drilled through a compacted
sedimentary rock, the stress is relieved
toward the well bore!
Radial fracturing around the wellbore can
occur!
This can cause instability!
- 41. Pakistan Inhibited Water-Base Fluids Presentation – April 2001
Page 41
© 2001 Baker Hughes Incorporated
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The Formation of MICRO-
FRACTURES!
Try to visualise a shale
section that has just been
drilled.
Stress relief occurs around
the well bore in the form of
micro-fractures!
- 42. Pakistan Inhibited Water-Base Fluids Presentation – April 2001
Page 42
© 2001 Baker Hughes Incorporated
All rights reserved.
The Effects of BALANCED
Pressures!
When the pore pressure and
hydrostatic pressure are
equalised, the shale will
probably remain stable!
The fluid and formation are in
equilibrium!
- 43. Pakistan Inhibited Water-Base Fluids Presentation – April 2001
Page 43
© 2001 Baker Hughes Incorporated
All rights reserved.
The Effects of an OVER-
BALANCED Condition!
If the hydrostatic pressure
exceeds the formation
pressure, fluid is forced into
the shale!
This can lead to instability
inside the shale matrix!
- 44. Pakistan Inhibited Water-Base Fluids Presentation – April 2001
Page 44
© 2001 Baker Hughes Incorporated
All rights reserved.
The Effects of an UNDER-
BALANCED Condition!
If the formation pressure
exceeds the hydrostatic,
sloughing can occur!
The fluid and formation are
NOT in equilibrium!
- 45. Pakistan Inhibited Water-Base Fluids Presentation – April 2001
Page 45
© 2001 Baker Hughes Incorporated
All rights reserved.
Blocking PORE PRESSURE
TRANSMISSION!
Introduction of materials
designed to reduce, or stop,
this invasion can minimise
any instability!
ALPLEX is one such product,
effectively minimising PPT!
So do CLOUD-POINT
GLYCOLS!
- 46. Pakistan Inhibited Water-Base Fluids Presentation – April 2001
Page 46
© 2001 Baker Hughes Incorporated
All rights reserved.
The Effects of PORE
PRESSURE Equilibrium!
As the transfer of water into the shale matrix
takes place, several things happen:
– The effective internal stresses INCREASE!
• Due to the ELEVATION of pore pressure!
– SWELLING pressures are generated within the shale
matrix!
• Caused by WETTING and HYDRATION of clay within the
shale!
Instability takes TIME to develop!
- 47. Pakistan Inhibited Water-Base Fluids Presentation – April 2001
Page 47
© 2001 Baker Hughes Incorporated
All rights reserved.
A Look At PORE PRESSURE
TRANSMISSION!
This is the party line.
A better way of looking at this might be to call
it ‘PORE PRESSURE DIFUSSION!”
Can you describe this phenomenon?
- 48. Pakistan Inhibited Water-Base Fluids Presentation – April 2001
Page 48
© 2001 Baker Hughes Incorporated
All rights reserved.
What is PORE PRESSURE
TRANSMISSION?
Pore Pressure Transmission, or PPT, is the
condition where the hydrostatic exceeds the
formation pressure and filtrate is forced INTO
the shale!
The chemistry of the filtrate can reduce the
effects, ANY change to the shale can weaken
the strength of the rock!
- 49. Pakistan Inhibited Water-Base Fluids Presentation – April 2001
Page 49
© 2001 Baker Hughes Incorporated
All rights reserved.
Pore Pressure
TRANSMISSION!
Key mechanism for structural destabilisation
of shales
– Can be critical when drilling fractured shales
Results in hole instability which is frequently
treated by increasing mud density which can
make the problem worse
Prevention is the only cure!
- 50. Pakistan Inhibited Water-Base Fluids Presentation – April 2001
Page 50
© 2001 Baker Hughes Incorporated
All rights reserved.
The Effects of TECTONIC
FORCES!
Tectonic forces are those forces within the
rock that bend, twist and move deposits,
causing instability.
It can also result in high-angle bedding
planes, allowing the “high” side of the hole to
fall into the well bore.
Stress relief can also cause the borehole to
become oval, rather than round.
- 51. Pakistan Inhibited Water-Base Fluids Presentation – April 2001
Page 51
© 2001 Baker Hughes Incorporated
All rights reserved.
What Is An INHIBITED
Drilling Fluid?
The Baker Hughes INTEQ U.K. Region Fluid
Systems Field Manual offers this definition:
– A Drilling Fluid having an aqueous phase
with a chemical composition that tends to
retard or even prevent (INHIBIT) appreciable
hydration (SWELLING) or dispersion of
formation clays and shales through chemical
and/or physical means (PROTECTION).
- 52. Pakistan Inhibited Water-Base Fluids Presentation – April 2001
Page 52
© 2001 Baker Hughes Incorporated
All rights reserved.
The FAMILY of Inhibited
Water-Base Drilling Fluids!
NEW-DRILL:
– Utilises a PHPA and KCl!
AQUA-DRILL:
– Enhances with GLYCOLS!
AQUA-DRILL Plus:
– Further enhancement with ALPLEX!
AQUA-DRILL Plus:
– Leave out the KCl and use POTASSIUM CARBONATE!
- 53. Pakistan Inhibited Water-Base Fluids Presentation – April 2001
Page 53
© 2001 Baker Hughes Incorporated
All rights reserved.
How do we INHIBIT?
By understanding the mechanisms of
HYDRATION and DISPERSION, we can design
additives to prevent, or minimise, these
occurrences.
– We can use a SALT to reduce, or prevent, hydration!
– We add ENCAPSLATING POLYMERS to reduce
dispersion!
– We can use a CLOUD-POINT GLYCOL to enhance the
inhibition levels!
– We add a PORE PRESSURE TRANSMISSION reducer!
- 54. Pakistan Inhibited Water-Base Fluids Presentation – April 2001
Page 54
© 2001 Baker Hughes Incorporated
All rights reserved.
Completing the PACKAGE!
A typical drilling fluid will be exposed to
BOTH types of clay particles.
Our INHIBITION mechanisms will prevent
both HYDRATION and DISPERSION!
The encapsulating polymer coats BOTH
types of clay.
- 55. Pakistan Inhibited Water-Base Fluids Presentation – April 2001
Page 55
© 2001 Baker Hughes Incorporated
All rights reserved.
The LIMITATIONS of
INHIBITON!
We must REMOVE that cutting at the
surface the first time it arrives there.
The importance of an efficient solids
removal package cannot be under-
estimated!
- 56. Pakistan Inhibited Water-Base Fluids Presentation – April 2001
Page 56
© 2001 Baker Hughes Incorporated
All rights reserved.
The LIMITATIONS of
INHIBITON!
The Shale Shakers MUST be capable of
handling the maximum flow rate of the
pumps!
De-sanders, De-silters, Mud Cleaners and
Centrifuges should be used with caution!
ALWAYS RELY UPON THE SHALE
SHAKER AS THE PRIMARY DEVICE TO
REMOVE SOLIDS!
- 57. Pakistan Inhibited Water-Base Fluids Presentation – April 2001
Page 57
© 2001 Baker Hughes Incorporated
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A SHALE Cutting-Revisited!
Again, a shale
cutting at the
moment it is
released into
the annulus!
The BLUE is
water in the
shale!
- 58. Pakistan Inhibited Water-Base Fluids Presentation – April 2001
Page 58
© 2001 Baker Hughes Incorporated
All rights reserved.
A SHALE Cutting -Revisited!
In an Inhibited
system, like the
AQUA-DRILL
system, each
mechanism
starts to work
immediately!
The KCl stops
swelling!
- 59. Pakistan Inhibited Water-Base Fluids Presentation – April 2001
Page 59
© 2001 Baker Hughes Incorporated
All rights reserved.
Reducing HYDRATION with
Salts!
The addition of a SALT to the water phase
will aid in reducing hydration!
The most common salt is Potassium
Chloride (KCl)!
THE ONLY THING THAT POTASSIUM ION
DOES IS REDUCE HYDRATION!
- 60. Pakistan Inhibited Water-Base Fluids Presentation – April 2001
Page 60
© 2001 Baker Hughes Incorporated
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A SHALE Cutting -Revisited!
At the same
time, the PHPA
coats the
cutting in a
high viscosity
‘shell’!
- 61. Pakistan Inhibited Water-Base Fluids Presentation – April 2001
Page 61
© 2001 Baker Hughes Incorporated
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Reducing DISPERSION!
The addition of an ENCAPSULATING
polymer can minimise the dispersion of
these clays!
– It accomplishes this through a COATING
mechanism!
Even though dispersion may still take
place, the polymeric coating CONTAINS
everything in a single, removable solid!
- 62. Pakistan Inhibited Water-Base Fluids Presentation – April 2001
Page 62
© 2001 Baker Hughes Incorporated
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A SHALE Cutting -Revisited!
While all of this
is happening,
the CLOUD-
POINT Glycol
as also entered
the pore
throats and
‘solidifies’!
- 63. Pakistan Inhibited Water-Base Fluids Presentation – April 2001
Page 63
© 2001 Baker Hughes Incorporated
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We Can IMPROVE This
Inhibition with GLYCOLS!
Glycols are soluble until a certain
temperature is reached, when they
CLOUD and fill pore spaces with an
INSOLUBLE glycol, but they also COAT
the surface of the particle, as well as the
surface of the well bore.
- 64. Pakistan Inhibited Water-Base Fluids Presentation – April 2001
Page 64
© 2001 Baker Hughes Incorporated
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A SHALE Cutting -Revisited!
Both
HYDRATION
and
DISPERSION
are minimised!
- 65. Pakistan Inhibited Water-Base Fluids Presentation – April 2001
Page 65
© 2001 Baker Hughes Incorporated
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THE BEAUTY OF IT ALL!
The AQUA-DRILL system has been run at
densities up to 2.21 sg (18.7 ppg).
It CAN be run with a minimal set of
components, thus reducing logistic
problems on remote locations.
It is a highly flexible, highly tolerant system.
- 66. Pakistan Inhibited Water-Base Fluids Presentation – April 2001
Page 66
© 2001 Baker Hughes Incorporated
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We Can further IMPROVE
Inhibition with ALPLEX!
ALPLEX is an Aluminium complex that
effectively PLUGS pore spaces within a
shale structure.
- 67. Pakistan Inhibited Water-Base Fluids Presentation – April 2001
Page 67
© 2001 Baker Hughes Incorporated
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We Can further IMPROVE
Inhibition with ALPLEX!
This plugging mechanism reduces PORE
PRESSURE TRANSMISSION:
– This in turn prevents the invasion of water into the
clay structure.
– It prevents further fracture development.
– It ENHANCES the performance of the basic inhibited
water base system.
- 68. Pakistan Inhibited Water-Base Fluids Presentation – April 2001
Page 68
© 2001 Baker Hughes Incorporated
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How Alplex FUNCTIONS!
Alplex is a mixture of aluminium salts and
organic acids
Aluminium is in solution at pH values above
10 and below 3
Precipitates of aluminium hydroxide form at
intermediate pH’s
Precipitation occurs in shale pores and
microfractures on contact with connate water
- 69. Pakistan Inhibited Water-Base Fluids Presentation – April 2001
Page 69
© 2001 Baker Hughes Incorporated
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ALPLEX Pore Plugging!
Filtrate invasion zone
ALPLEXPrecipitate
Uncontaminated formation
External filter cake
FRACTURE
HOLE
Schematic
of Formation
- 70. Pakistan Inhibited Water-Base Fluids Presentation – April 2001
Page 70
© 2001 Baker Hughes Incorporated
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Looking at it ANOTHER
Way!
Filtrate WILL invade
the structure of the
clay matrix!
- 71. Pakistan Inhibited Water-Base Fluids Presentation – April 2001
Page 71
© 2001 Baker Hughes Incorporated
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Adding ALPLEX Will Block
the Pores!
When the ALPLEX comes in contact with the connate
water, the pH drop causes it to solidify, plugging the
pore spaces in the clay matrix!
- 72. Pakistan Inhibited Water-Base Fluids Presentation – April 2001
Page 72
© 2001 Baker Hughes Incorporated
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FAILURE to Address the
PPT Issue is Dangerous!
The Clay Matrix will DE-STABILISE
and begin to fall apart!
- 73. Pakistan Inhibited Water-Base Fluids Presentation – April 2001
Page 73
© 2001 Baker Hughes Incorporated
All rights reserved.
WHY use Glycol with
Alplex?
“Belt & braces” approach
Lubricity contribution above and below cloud
point
Keeping the bit face clean
Cuttings protection in annulus
Contributes to well-bore stability
Synergistic with Alplex
- 74. Pakistan Inhibited Water-Base Fluids Presentation – April 2001
Page 74
© 2001 Baker Hughes Incorporated
All rights reserved.
ENHANCEMENT of Glycol
Systems with Alplex!
% Recovery % Hydration % Hardness
0
20
40
60
80
100
KCl/Polymer(A) A+glycol @ 3%(B) B+Alplex (2ppb)
- 75. Pakistan Inhibited Water-Base Fluids Presentation – April 2001
Page 75
© 2001 Baker Hughes Incorporated
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The PROOF on Pore
Pressure Transmission!
40
50
60
70
80
90
100
110
120
130
140
150
160
170
0 10 20 30 40 50 60 70 80 90 100 110
HOURS
FORMATION
PRESSURE
(psi)
BOREHOLE: 195 PSI
CONFINING: 315 PSI
TEMPERATURE: 158F (70C)
FORM: 5PPB ALPEX, 0.1% NEWDRILL, 1% PAC LV
CORE: PIERRE II
EQUILIBRATION TIME: 9 HOURS
2% NaCl
5 PPB ALPLEX
+ PHPA + PAC
20% KCl, neat
20% KCl + PHPA + PAC
5 PPB ALPLEX + PHPA
+ PAC
Salt and polymers
have minimal effect on
PPT
Alplex completely
eliminates PPT
Alplex lines are repeat
results to confirm
findings
- 76. Pakistan Inhibited Water-Base Fluids Presentation – April 2001
Page 76
© 2001 Baker Hughes Incorporated
All rights reserved.
Effect of PENETREX (1)
PDC bit after drilling
Catoosa Shale in a full-
scale drilling simulator
Left: no Penetrex
Right: Penetrex at 3%
- 77. Pakistan Inhibited Water-Base Fluids Presentation – April 2001
Page 77
© 2001 Baker Hughes Incorporated
All rights reserved.
Effect of PENETREX (2)
PDC bit after drilling Pierre
Shale in a full-scale drilling
simulator
Left: no Penetrex
Right: Penetrex at 3%
- 78. Pakistan Inhibited Water-Base Fluids Presentation – April 2001
Page 78
© 2001 Baker Hughes Incorporated
All rights reserved.
The BENTONITE Question!
PHPA inhibits dispersion of ALL clay solids
through encapsulation.
– BENTONITE is a highly dispersible clay solid.
– DRILL CUTTINGS are dispersible clay solids.
Why add another clay that requires
encapsulation - and takes up part of the
material added to treat drilled cuttings?
- 79. Pakistan Inhibited Water-Base Fluids Presentation – April 2001
Page 79
© 2001 Baker Hughes Incorporated
All rights reserved.
BENTONITE - To Be or Not
to Be!
There are only two VALID reasons to add
BENTONITE to a NEW-DRILL system:
– Because the Customer wants it!
– For wall cake building characteristics!
If you have to add Bentonite, make sure you
use a WYOMING-GRADE PREMIUM
BENTONITE, like MIL-GEL!
- 80. Pakistan Inhibited Water-Base Fluids Presentation – April 2001
Page 80
© 2001 Baker Hughes Incorporated
All rights reserved.
Performance
CHARACTERISTICS!
CARBODRILL
BIOGREEN
AQUADRILL
NEWDRILL
SYNTEQ
BENTONITE
- 81. Pakistan Inhibited Water-Base Fluids Presentation – April 2001
Page 81
© 2001 Baker Hughes Incorporated
All rights reserved.
RELATIVE Shale
Inhibition!
1. Gypsum mud
2. Seawater polymer
3. KCl Polymer
4. KCl Polymer/glycol
5. Enhanced glycol mud
6. Oil based/pseudo oil-based
mud
0
10
20
30
40
50
60
70
80
90
100
1 2 3 4 5 6