This document provides an overview of drilling fluid systems and their components. It discusses the hoisting system used to lift drill pipe and casing as well as the drilling fluid circulation system, including mud pumps, solids control equipment, and treatment/mixing equipment. Mud pumps are either duplex or triplex and their flow rate and power requirements are calculated. Solids control equipment separates cuttings and maintains proper fluid properties, and includes shale shakers, degassers, desanders, desilters, centrifuges, and mud cleaners. Drilling fluid components like water, bentonite, and barite are also outlined along with the equipment used to mix and treat drilling fluids.

1. Drilling Engineering 1 Course (1st Ed.)

2. 1. Hoisting System:
A. The Block & Tackle
a.
Hook Power
B. Load Applied to the Derrick
2. Drilling Fluid Circulation System
A. Mud Pumps

3. 1. Drilling Fluid Circulation System
A. Mud Pumps (Duplex PDP & Triplex PDP)
B. Solids Control Equipment
a.
Mud Cleaners
C. Treatment and Mixing Equipment

5. Duplex pumps
Piston scheme (double action)
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A duplex unit
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6. Triplex pumps
Piston scheme (single action).
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A Triplex unit
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7. the pump factor
The duplex mud pump consists of
two double–action cylinders.
This means that drilling mud is pumped
with the forward and backward movement of the barrel.
For a duplex pump (2 double–action cylinders) the pump
factor is given by:
The triplex mud pump consists of
three single–action cylinders.
This means that drilling mud is pumped only in the
forward movement of the barrel.
For a triplex pump the pump factor is:
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8. Pump Flow Rate
For both types of PDP, the flow rate is calculated
from:
For N in strokes per minute (spm), dL, dR, and LS in
inches, Fp in in3, and q in gallons per minute (gpm)
we have:
Note that in this particular formulation,
the volumetric efficiency of the pump
is included in the pump factor.
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9. Pump Power
Pumps convert mechanical power into hydraulic
power. From the definition of power P=Fv
In its motion,
the piston exerts a force [F] on the fluid that is equal to
the pressure differential in the piston Δp times
the area A of the piston, and
the velocity v is equal to
the flow rate q divided by the area A, that is
For PH in hp, p in psi, and q in gpm we have:
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10. pump factor & hydraulic power
Compute the pump factor in gallons per stroke and
in barrels per stroke for a triplex pump having
5.5 in liners and
16 in stroke length,
with a volumetric efficiency of 90%.
At N = 76spm, the pressure differential between
the input and the output of the pump is 2400 psi.
Calculate
the hydraulic power transferred to the fluid, and
the required mechanical power of the pump if Em is 78%.
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11. pump factor & hydraulic
power
The pump factor (triplex pump) in in3 per stroke is:
Converting to gallons per stroke and to barrels per
stroke gives:
The flow rate at N = 76spm is:
The hydraulic power transferred to the fluid is:
To calculate the mechanical power required by the
pump we must consider the efficiencies:
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12. Surge Dampeners
Due to the reciprocating action of the PDPs,
the output flow rate of the pump presents a
“pulsation” (caused by the changing speed of the
pistons as they move along the liners).
This pulsation is detrimental
to the surface and downhole equipment
(particularly with MWD pulse telemetry system).
To decrease the pulsation,
surge dampeners are used at the output of each pump.
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13. schematic of a typical surge dampener
A flexible diaphragm
creates a chamber filled
with nitrogen at high
pressure.
The fluctuation of
pressure is compensated
by a change in the
volume of the chamber.
A relief valve located in
the pump discharge line
prevents line rupture in
case the pump is started
against a closed valve.
Surge dampener
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15. solids control equipment
The purpose of the solids control equipment is
to reduce to a minimum
the amount of inert solids and gases in the drilling fluid.
They are:
Shale shakers,
Degassers,
Desanders (hydrocyclones),
Desilters (hydrocyclones),
Centrifuges,
Mud cleaners.
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16. inactive solids effects
Fine particles of inactive solids are continuously
added to the fluid during drilling.
These solids increase the density of the fluid and
also the friction pressure drop, but
do not contribute to the carrying capacity of the fluid.
The amount of inert solids must be kept as low as
possible.
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17. sketch of
a typical solids control system
Figure shows
a sketch of a
typical solids
control system
(for
unweighted
fluid).
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18. shale shaker mechanism
 The shale shaker
removes
the coarse solids
(cuttings) generated
during drilling.
 It is located at the
end of the flow line.
 It constitutes of
one or more
vibrating screens in
the range of
10 to 150 mesh
over which the mud
passes before it is
fed to the mud pits.
Shale shaker configurations
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19. a typical two–screen shale shaker
The screens
are vibrated by
eccentric heavy
cylinders
connected to
electric motors.
The vibration
promotes an
efficient
separation
without loss of
fluid.
A two–screen shale shaker
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20. Degassers
Gases that might enter the fluid
must also be removed.
Even when the fluid is overbalanced,
the gas contained in the rock cut by the bit
will enter the fluid and must be removed.
The degasser removes gas from the gas cut fluid
by creating a vacuum in a vacuum chamber.
The fluid flows down an inclined flat surface
as a thin layer.
The vacuum enlarges and coalesce the bubbles.
Degassed fluid is draw from chamber
by a fluid jet located at the discharge line.
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21. A typical degasser diagram
(A vacuum chamber degasser)
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22. Hydrocyclones
(Desanders and Desilters)
Hydrocyclones are simple devices with no internal moving parts.
The drilling fluid enters the device through a tangential opening in
the cylindrical section, impelled by a centrifugal pump.
The centrifugal force generated by the whirling motion pushes the
solid particles towards the internal wall of the inverted cone.
As the whirling flux moves downwards the rotating speed
increased and the diameters decreases.
The fluid free of solid particles is “squeezed” out of the flow and
swirls upwards in a vortex motion, leaving the hydrocyclone from
the upper exit.
The solids leave the hydrocyclone from the apex of the cone
(underflow).
For maximum efficiency, the discharge from the apex exit of
hydrocyclone should be in a spray in the shape of a hollow cone
rather than a rope shape.
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23. Flow path in a hydrocyclone
Figure shows
the
fluid/solids
paths in a
hydrocyclone.
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24. Hydrocyclone classifications
Hydrocyclones are classified
according to the size of the particles removed as
desanders (cut point in the 40–45μm size range) or
desilters (cut point in the 10–20μm size range).
At the cut point of a hydrocyclone
50% of the particles of that size is discarded.
The desander
is a set of two or three 8in or 10in hydrocyclones, and are
positioned after the shale shaker and the degasser (if used).
The desilter
is a set of eight to twelve 4in or 5in hydrocyclones.
It removes particles that can not be removed by the desander.
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25. Solid control equipment
(a) Desander
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(b) Desilter
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26. Particle size classification
A typical
drilling solid
particle
distribution
and particle
size range
classification
are shown in
the diagram.
The diagram
includes the
particle size
distribution of
typical
industrial
barite used in
drilling fluids.
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27. Centrifuges
The centrifuge is a solids control equipment
which separates particles even smaller,
which can not be removed by the hydrocyclones.
It consists of a rotating cone–shape drum,
with a screw conveyor.
Drilling fluid is fed through the hollow conveyor.
The drum rotates at a high speed and creates a centrifugal
force that causes the heavier solids to decant.
The screw rotates in the same direction of the drum but at a
slight slower speed, pushing the solids toward the discharge
line.
The colloidal suspension exits the drum through the
overflow ports.
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28. Internal view of a centrifuge
The drums
are enclosed
in an external,
non–rotating
casing not
shown in the
figure.
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31. mud cleaner
Inert solids in weighted fluid
(drilling fluid with weight material like
barite, iron oxide, etc)
can not be treated with hydrocyclones alone
because the particle sizes of the weighting material are
within the operational range of desanders and desilters.
Weighting material are relatively expensive additives,
which must be saved.
A mud cleaner is a desilter unit in which
the underflow is further processed by a fine
vibrating screen, mounted directly under the cones.
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32. mud cleaner schematic
The mud
cleaner
separates the
low density
inert solids
(undesirable)
from the high
density
weighting
particles.
Unit of a mud cleaner
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33. Hydrocyclones
Hydrocyclones discriminate light particles from
heavy particles.
Bentonite are lighter than formation solids
because they are of colloidal size
(although of the same density).
Barite particles are smaller than formation solids
because they are denser.
The desilter
removes the barite and
the formation solids particles in the underflow,
leaving only a clean mud
with bentonite particles
in a colloidal suspension in the overflow.
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34. Hydrocyclones (Cont.)
The thick slurry in the underflow
goes to the fine screen,
which separate the large (low density) particles
(formation solids)
from the small (high density) barite particles,
thus conserving weighting agent and the liquid phase
but at the same time returning many fine solids to the
active system.
The thick barite rich slurry is treated with dilution
and mixed with the clean mud (colloidal bentonite).
The resulting mud is treated
to the right density and viscosity and
re–circulates in the hole.
Fall 13 H. AlamiNia
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35. Principle of the mud cleaner
Mud cleaners
 are used mainly
with oil– and
synthetic–base
fluids
where the liquid
discharge from
the cone cannot
be discharged,
either for
environmental
or economic
reasons.
 may also be
used with
weighted
water–base
fluids
 to conserve
barite and the
liquid phase.
A diagram of a mud cleaner
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37. Drilling fluid components
Drilling fluid is usually a suspension of clay
(sodium bentonite) in water.
Higher density fluids can be obtained
by adding finely granulated (fine sand to silt size)
barite (BaSO4).
Various chemicals or additives are also used
in different situations.
The drilling fluid continuous phase is usually water
(freshwater or brine) called water–base fluids.
When the continuous phase is oil
(emulsion of water in oil) it is called oil–base fluid.
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38. Mixing Equipment
Water base fluids are normally made at the rig site
(oil base mud and synthetic fluids
are normally manufactured in a drilling fluid plant).
Special treatment and
mixing equipment exists for this purpose.
Tank agitators, mud guns, mixing hoppers, and
other equipment are used for these purposes.
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39. drilling fluids physical properties
blenders
The basic drilling fluids physical properties are density,
viscosity, and filtrate.
Fresh water density is 8.37 pounds per gallon (ppg).
Bentonite adds viscosity to the fluids and also increases the
density to about 9 to 10 ppg.
Higher density (15 to 20 ppg) is obtained with barite, iron
oxide, or any other dense fine ground material.
Tank agitators or blenders
are located in the mud tanks
to homogenize the fluid in the tank.
help to keep the various suspended material
homogeneously distributed in the tank
by forcing toroidal and whirl motions of the fluid in the tank.
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40. Mud agitator
Tank agitators or blenders
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toroidal and whirl motions
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41. Mud guns
Mud guns
are mounted in gimbals
at the side of the tanks,
allow aiming a mud jet
to any point in the tank
help to homogenize the
properties of two tanks,
and spread liquid
additives in a large area
of the tank
(from a pre-mixed tank).
Centrifugal pumps
power the mud guns.
Mud gun
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42. mixing hopper
The mixing hopper
allows adding powder substances and
additives in the mud system.
The hopper is connected to a Venturi pipe.
Mud is circulated by centrifugal pumps and
passes in the Venturi at high speed,
sucking the substance into the system.
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43. Mud hopper
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44. 1. Jorge H.B. Sampaio Jr. “Drilling Engineering
Fundamentals.” Master of Petroleum
Engineering. Curtin University of Technology,
2007. Chapter 2