Coiled Tubing
Coiled tubing
Prepared by
Team work
Mostafa Elazab
Ahmed Ibrahim
Admarine -2
Table of content
1.Introduction to Coiled Tubing Services
2.Advantages of Coiled Tubing
3.Applications of coiled tubing
4.ADES barge ,well information and well bore sketch
5.components of Coiled tubing system
5.1.power pack
5.9.Storage tank 250 bbl
5.2.Reel
5.10.Storage tank 150 bbl
5.3.Control cabin
5.11.Acid Tank
5.4.Crane
5.12.Acid Mixer
5.5.Injector head
5.13.Halliburton Pump
5.6.BOP stack and riser
5.14.Backup Triplex Pump
5.7 batch mixer
5.15.Nitrogen Tank and its pump
5.8.Water Filter
6.Most common failures in CTU and drifting the CTU
Table of content
7.Hydra-blast run(BHA)
7.1.Coil connector
7.2.Dual flapper check valve
7.3.Hydraulic Disconnect
7.4.Down hole inline filter
7.5.Hydra-Blast Indexing Tool
7.6.Hydra blast
8.Hydra-blast run on EDFU A5
9.Milling run (BHA)
9.1.CTU Connector
9.2.Back Pressure Valve(baker)
9.3.High Load Disconnect (baker)
9.4.Dual Actuated Circulating Valve(baker)
9.5.VIP Motor
9.8.Taper mill
1.Introduction to Coiled Tubing Services
• The coiled tubing unit is a portable, hydraulic-powered
unit designed to inject and retrieve the coiled tubing work
string safely under pressure to perform well maintenance
and remedial services.
available sizes of coiled tubing (in)
1
1 1/4
1 1/2
1 3/4
2
2 3/8
2 7/8
3 1/2
• Reel is driven hydraulically by large spool
• The system, adaptable to either land or offshore
applications, is designed so that components can be taken
off the trailer and placed on a barge for water work.
2.Advantages of Coiled Tubing
Coiled tubing offers the following advantages:
Self-Contained unit, requires no rig
Saves time and money do not have to kill well
Land or offshore system designs
No work over rig required when using coiled tubing
Reduced the damage to formation
Can be and is typically used on live wells (no kill fluids introduced in
to well)
Act as tool transport medium for deviated and horizontal wells
Performance and Efficiency
Computer prepares to optimize job design
Fast
Tubing Management
3.Applications
Halliburton coiled tubing units have been used in a variety of remedial
functions:
Cleaning operations using a down hole motor, or acid wash
Halliburton HYDRA-BLAST operations
Mud displacement and killing of wells
Unloading the tubing with nitrogen, foam or other media
Injection of paraffin or corrosion inhibitors
Light to intermediate fishing operations
Squeeze, plug and abandonment cementing
Salt washing with water
Sand washing with nitrogen, foam or other media
Spotting acid
Coiled tubing completions
Coiled tubing drilling
Applications with the red color applied on EDFU A5 by admarine-2 (ADES barge)
4.ADES barge ,well information and bore sketch
safety engineer room
Bridge or radio room
accommodation
Personal basket
Smoking room
All equipment on the main deck
platform
Power pack
Reel
Batch mixer
filter
Well
information
WELL
INFORMATION
Well bore sketch
According to the well
information and wellbore sketch
Coiled tubing units are chosen
5.components of Coiled tubing system
Coiled tubing system has the following components
• power pack
• Reel
• Control cabin
• Crane
• Injector head
• BOP stack and riser
• Fluid Pumps (Triplex),Tanks, Batch Mixer, Filter
• Nitrogen tanks and its pump
• In some cases, its own fluid pump and tank for kill
fluids
5.1.Power pack
It is a diesel-hydraulic unit used to supply power to the coiled tubing
unit.
It consists of :Diesel engine.
System of hydraulic pump.
Hydraulic tank.
Hydraulic pressure controls.
power pack
80K/100K
60K
30 K
15 K
tubing size range(in)
from
to
1.5
3.5
1.25
2.375
1.25
1.75
1
1.5
5.1.Power pack
Hydraulic tank
Diesel engine
Hydraulic pump
Hydraulic pressure lines
5.1.Power pack
problems
Power Pack Failure
In the case of power pack failure, the following steps should be
taken:
Hang-off coiled tubing in slips and manually lock.
Close coiled-tubing pipe rams and manual lock.
Apply the reel brake
Maintain circulation if required.
Repair or replace the power unit and resume operations.
5.2.Coiled tubing reel
A large steel storage drum suspended on a shaft or open centre
bearings
powered by a bi-directional hydraulic motor
The CTU reel must:
The capacity of the Reel depend upon:
 Core diameter (D)
 Width (L)
 flange height (H)
D
H
provide back tension during all injection operations
be equipped with rotating swivel for fluid injection while turning
(running pipe in or out of well);
Have variable core diameter for specific tubing diameters. The
coiled tubing reel is a fabricated steel spool with a core diameter of
48 to 130 inches and an 8 to 15 ft side-flange diameter
L
5.2.Coiled tubing reel
Reel Swivel and Manifold
Reel
Line form manifold
5.2.Coiled tubing reel
CTU
Depth counter
Drum
5.3.Control Cabin
CT control cabin unit in which
the operator can :
Control raising and lowering the
CT.
Monitor the CT depth, CT
pressure, CT Wt, Running speed
,Pumping rate and other
parameters
Controlling the Opening and
closing of BOP rams and Stripper.
5.4.Crane
port side crane
Used for lifting the equipment and People
from boats to barge and vice versa
Starboard side crane
Used for suspending CTU or slick line
head instead of using the mast
5.5.Tubing injector head
Tubing injector heads are designed to:
Provide the thrust to snub tubing into the well against
pressure or wellbore friction.
Control the rate of tubing entry into and removal from the
well under various well conditions.
Support the full-suspended tubing weight and accelerate
it to operating speed.
There are four sizes of Halliburton injectors:
Injector
80K/100K
60K
30 K
15 K
tubing size range(in)
Axial load(LB)
from
to
1.5
3.5
80000
1.25
2.375
60000
1.25
1.75
30000-38000
1
1.5
15000
5.5.Tubing injector head
Mechanism
Power is delivered to the injector through a pair of high pressure 1-1/2
inch hoses to the counter balance which distribute the power to the two
bi-directional hydraulic motors
The output of the two motor is directed to roller chain sprockets that turn
the gripper chains in opposite directions for snubbing the CTU down hole.
It includes the following components:
5.5.1-Drive System/Inner Frame:
The injector head uses dual opposing drive chains to drive the coiled tubing
into and out of the well. support the weight of the tubing and down hole
tools.
5.5.2-Outer Frame
The outer frame assembly supports the total load of the inner frame and work
string over the wellhead
5.5.Tubing injector head
injector
Drive system
Outer frame
Stuffing box
Quad BOP
stripper
5.5.Tubing injector head
Coiled tubing
gooseneck
Two hydraulic motors
5.5.Tubing injector head
5.5.1-Drive System/Inner Frame:
5.5.Tubing injector head
5.5.1-Drive System/Inner Frame:
roller chain
sprockets
Gripper block
Gripper chain
5.5.Tubing injector head
5.5.3-Load Cell/Pin
The load cell/pin is located at the bottom of the inner frame and the
outer frame assembly, which, in turn, is rigidly connected to the
wellhead equipment. Give the weight of the CTU string (weight
indicator)
Spring for absorbing vibration
Load cell
5.5.Tubing injector head
5.5.4.Tubing Guide(goose neck)
The tubing guide is attached to the top of the injector and used to
receive CTU from the reel.
It provides the support, straightening and alignment functions for
properly guiding the tubing into the gripper chains of the injector.
when it attached, becomes an integral part of the injector.
It consists of a semi-circular support frame (gooseneck) carrying
multiple roller assemblies or high-density plastic wear blocks.
5.5.Tubing injector head
5.5.4.Tubing Guide(goose neck)
Lifting bail
high-density plastic wear blocks.
Tubing guide
Tubing retainer
swivel
5.5.Tubing injector head
HALLI supervisor checking the
wearing of high-density plastic
wear blocks.
5.5.Tubing injector head
5.5.5.stripper or stuffing box
•
•
•
•
It placed below the base of the injector head. contains a split
elastomer element which is compressed against the CTU to
form a dynamic seal isolating the well pressure.
The design of the stripper allows replacement of worn
elastomer elements whilst the well is under pressure with CT
in the hole.
It contains:
Piston operated hydraulically to open or close the stripper
Packing Rubber element
Teflon (to isolate between the stripper and the upper nut)
Tapered bushing nut
5.5.Tubing injector head
Tapered Bushing
Nut
Teflon
Packing element
(stripper)
5.5.Tubing injector head
5.5.5.stripper or stuffing box
stripper
Hydraulic line to control the stripper
5.5.Tubing injector head
Stripper problems
Leaking Stripper Assembly
In the case of a leaking stripper assembly, the following steps should be
taken if increasing the hydraulic pressure fails to stop the leak.
Stop coiled tubing movement.
Close the slip rams and lock manually.
Close the pipe rams and lock manually.
Bleed down the surface pressure within the well control stack through
the kill line
Reduce the hydraulic pressure to the stripper assembly, and bleed
down to relax the stripper element.
Replace the stripper elements.
Pressure test of
Stuffing box
against Swab
valve
Tapered bushing nut
Teflon
stripper
1- Make sure that the CTU below stuffing box.
2-pump the fluid through CTU.
Blind Ram
3- Apply low pressure 500 psi hold, ok.
4- Apply high pressure gradually
to 5000 psi, hold, ok.
Shear Ram
Kill Line
Slips Ram
Swab Valve is closed
Tubing Ram
5.6.Quad BOP
kill line
Slip ram
Tubing ram
5.6.Configuration of quad BOP
Blind ram
seal off the wellbore when no tubing is in
the wellbore.
Shear ram
Designed to cut the coiled tubing and/or wireline
in the wellbore in an emergency situation.
kill line
allows kill fluids to be pumped down
the outside of the CT when the tubing is
intact, or allows kill fluids to be pumped
down the CT after the tubing is cut. It is
not used for taking returns
Slip ram
hold the pipe either in the pipe-light
(snub) or pipe-heavy position.
Tubing ram
seal off the annular area around the
coiled tubing.
5.6.Quad BOP
Hydraulic lines for controlling quad BOP
Selection
of BOP
5.6.Quad
BOPsize
Selection of BOP size
BOP Bore Size
Working Pressure Range (psi)
Tubing Size
2.50''
5000-10000
up to 2.00"
3.06'‘=3 1/16
5000-10000-150000
up to 2.00"
4.06''
5000-10000-150000
up to 2.00"
5.12''
5000-10000-150000
up to 2.87"
7.06''
5000-10000
up to 3.50"
3 1/16” 10 K psi quad BOP.
5.6.Quad BOP and riser
riser
Single BOP
Slips ram
TBG ram
Adaptor flange
Testing of BOP
1- Pressure test of single BOP:
1-RIH till CTU reach blow single BOP.
2-Close single BOP around CTU.
3- Apply low pressure 500 psi for 5 min hold, ok.
4- Apply high pressure gradually to 5000 psi for
10 min hold, ok.
Single BOP
Closed
Open
Swab Valve
UMV
LMV
Wing Valve
Testing of Quad BOP
2- Pressure test of tubing ram of quad BOP:
1- RIH till CTU reach blow
tubing ram of quad BOP.
Blind Ram
2- Close tubing ram around
CTU.
3- Apply low pressure 500 psi
Shear Ram
hold, ok.
Kill Line
4- Apply high pressure
gradually to 5000 psi, hold,
Slips Ram
ok.
Tubing Ram
Swab Valve is closed
Testing of Quad BOP
1-POOH till CTU reach above
blind ram of quad BOP.
Blind Ram
2-Close blind ram which
closes the well.
3-Pump the fluid through the
Shear Ram
kill line.
Kill Line
4-Apply low pressure 500
psi hold, ok.
Slips Ram
5-Apply high pressure
gradually to 5000 psi, hold,
Tubing Ram
ok.
Swab Valve is closed
5.7.Batch mixer
• Used for mixing fluids.
• Contains hopper and agitator.
• Has C pump (centrifugal pump) which:
1- Takes the water from the source.
2- Reverse the mixture from downward to upward for
mixing the fluids.
3- pump the mixture to the tanks after mixing it.
• Maximum capacity 50 BBL.
• For Example:
In Cleaning job it is used for mixing Water with Xanthan Gum.
1 sack of xanthan + 50 bbl of water
2 sacks of xanthan + 50 bbl of water
30 cp High Vis
50 cp High Vis
5.7.Batch mixer
Xanthan Gum
hopper
Batch mixer
C pump
5.8.Water Filter
Inlet
outlet
5.9.Storage tank 250 bbl
5.10.Storage tank 150 bbl
5.11.Acid Tank
Storage tank of acid
Used to store the raw acid
which is very dangerous .
It is coated to prevent the
reaction of acid with the metal
of the tank
5.12.Acid Mixer
Coated tank used for mixing acid
with other additives and using
vacuum pumps to transport acid
from acid tanks to the mixer or
wash tanks
High corrosion resistance
Acid mixer
The facility for pressure-pumping
hydrochloric acid through a
flexible pipe such as a rubber hose
must be equipped with a pressure
gauge, and an anticorrosive
pressure-resistant hose must be
used.
vacuum pump
5.13.Halliburton Pump
Triplex pump ( 3 piston )
Single-acting plunger type
Maximum pressure rating of 15,000 psi
Acid-resistant steel plungers capable of pumping
•acid
•water
•drilling fluids and other fluids
•cement slurries
Contains centrifugal pump (c pump) to transport the fluids
from tanks to the triplex pump
Contains a tank with 20 bbl capacity for preparing and mixing small
HVP and slurry because if any other tank is used to prepare this 20 bbl
we must prepare the 20 bbl + the dead volume of the tank (10 bbl)
5.13.Halliburton Pump
3 Pistons
C-Pump
Suction Lines
5.13.Halliburton Pump
Discharge lines and manifold
From backup
pump
From master
pump
Line to CT reel
Kill line
Manifold line
5.14.Backup Triplex Pump
5.15.Nitrogen Tank and its pump
Properties of N2
Nitrogen (N2) is a colorless, odorless and tasteless gas that makes up
78.09% (by volume) of the air we breathe. It is nonflammable and it will
not support combustion
Nitrogen gas is slightly lighter than air and slightly soluble in water. It
is commonly thought of and used as an inert gas
Nitrogen condenses at its boiling point, -195.8o C (-320.4o F), to a
colorless liquid that is lighter than water.
Lines for transporting the
N2 liquid from the tank to
N2 pump(covered by ice
layer due to low temp. )
5.15.Nitrogen Tank and its pump
The liquid to gas expansion ratio of nitrogen is 1:700, which
means liquid nitrogen boils to fill a volume with nitrogen gas very
quickly. So that N2 is stored and transported in liquid phase
If anything cooled in liquid nitrogen touches your skin it will
instantaneously freeze to you. You should gloves and goggles (not
glasses) when working around liquid nitrogen.
Halliburton nitrogen services can improve practically every aspect of a
well including:
•Coiled Tubing Services
•Aids in acid spotting
•well cleanout
•chemical placement
•squeeze cementing operations
5.15.Nitrogen Tank and its pump
This tank consist of other inner
tank to store the liquid N2 and
isolate between these tanks
Bleed the N2 (gas phase ) from
the tank due to vaporization of
liquid N2 with changing the
temperature
5.15.Nitrogen Pump
Control panel
Diesel tank
Heat exchanger
6.Most common failures in CTU
A Hole in the CTU above the Stripper
Stop the injector and the reel.
Reduce the pump pressure as much as possible, but do not shut down
the pumps completely.
Inspect the hole.
If it is a pinhole or if there is only minimal leakage
continue to pull out of the hole.
If the hole is large-and leaks significantly
run in the hole with the CTU, and position the hole between the stripper
and pipe Rams
Close the slips and pipe rams.
Initiate a kill procedure down the coiled tubing to eliminate the
surface pressure.
When the well is dead, pull out of the hole and repair or replace the
coiled tubing string.
6.Most common failures in CTU
CTU Buckled between the Stripper and Injector
Close the slip and pipe rams.
Close the shear rams, and cut the CTU.
Pick up the CTU 1 to 2 feet, and close the blind rams.
Discuss options for killing the well, if required, and fishing the CTU
out of the well.
A Hole in the CTU Downhole
Stop pumping and observe the pressure on the CTU annulus.
If there is no pressure on the annulus pull out of the hole while
pumping slowly and repair or replace the CTU string.
If there is pressure on the annulus
kill the well by bull-heading through the CTU, kill line. Pull out
of the hole while pumping slowly and repair or replace the CTU string.
Drifting of coiled tubing
Drifting the CTU for the first run
Cut 1 m of CTU and drifted by 1’’ ball
Drift the CTU with 7/8’’ ball by inserting the ball into the reel manifold
inside the reel
Record the volume pumped to calculate the actual capacity of the reel
during drifting
CTU
1m
7/8’’ ball
7.Hydra-blast run
The cleaning by Hydra-Blast depend on the jetting effect of the
fluid by its small nozzles in removing any obstruction ( Scale
or Salt) inside TBG.
There are two types of hydra-blast tool the first one is bottom blast
which it used to open path in the obstruction and the second
one used to widen the path and removing the scale by jetting
effect
7.Hydra-blast BHA
Coil connector
1.75’’
Hyd. X-over
Hydra-Blast
indexing Tool
Down hole
In-Line Filter
Hydraulic
Disconnect
Side Blast Nozzle
2’’
7.1.Coil connector
It is used for attaching a tool string to the end of the coiled tubing.
When installed correctly, provide strong sealed connection to the
coiled tubing
All of the connectors have been designed with a fishing neck
The connectors utilize o-ring seals to seal off the coiled tubing in order
to maintain pressure integrity for the tool string.
Advantages
High tensile strength
High torsional strength for motor applications
Large ID for maximum flow rates and pump through of
actuation balls
Manufactured with fishing profile on top of connector
7.1.Coil connector
Make up the connector
1 Remove any sharp edges @the end of CTU end
2
Use the threader to make threads at the end of the coiled tubing
Connect the coil connector to the end of CTU
4 Push the socket to slide the slips to the connector and fasten the
socket with connector
5 Fasten the connector with end of CTU and socket with connector
tightly
3
connector
slips
1
2
3
4
5
7.1.Coil connector
pulling test of coil connector
1-install pull test sub with needle valve
2-put T shape above test sub
3-pull CTU till reach to riser .
T shape prevent coil connector from entering
the riser
5- Pull gradually till 15 klb, hold, ok
Coil connector
T shape
Test sub
Needle valve
7.1.Coil connector
pressure test of coil connector
riser
1-open needle valve and pump the
fluid to bleed gases in the CTU
2-close needle valve and increase
pump pressure to low pressure 300 psi
hold for 5 min
Coil
connector
3- Increasing pump pressure to high
pressure gradually till reach to 3000 psi
hold for 10 min
Test sub
Needle valve
7.2.Dual flapper check valve
It is normally run directly below the coiled tubing connector
in CTU operations and at the top of the BHA in snubbing
operations.
It is run as a well control measure to prevent wellbore
pressure from entering the work string.
The Back Pressure Valve is a flapper type valve that allows
flow down the tubing, but stops flow coming back up the
tubing. The Back Pressure Valve has two flappers and
flapper seals.
7.2.Dual flapper check valve
Pressure test of dual flapper check valve
method-1
1- the string between stuffing box and swab
valve
2- Pump the fluid through the kill line
3- Fluid flow from annulus to inside the BHA
5- Apply pressure gradually to 1500 psi, hold,
ok
Swab Valve is closed
7.2.Dual flapper check valve
method-2
1- Install bit sub (box-box) to connect between the lower end
of check valve and the pin of the coil connector
2- Pump the fluid through the CTU
Coil connector
3-Apply pressure gradually to 1500 psi, hold, ok
Bit sub
Dual flapper
Installed in opposite direction
7.3.Hydraulic Disconnect
Description of the Hydraulic Disconnect
Releases the tubing from other downhole tools run below.
It is activated by a ball and tubing pressure.
The hydraulic disconnect is used as an emergency
safety joint with other downhole tool assemblies.
Applications
Hydraulic-disconnect assemblies are used in at least two
distinct operational situations:
The assembly allows mechanical packers, bridge plugs,
and tubing hangers for velocity strings to be run, set,
and released from coiled tubing.
For an emergency disconnect, the hydraulic-disconnect
assembly can be incorporated into other CT bottomhole
assemblies, such as the heavy-duty workstring.
7.3.Hydraulic Disconnect
Operation
Pump a ball down to the seat of the hydraulic
disconnect to activate it.
Apply pressure above the ball
prop in the hydraulic disconnect and allow the tubing
string to be disconnected from the bottomhole
assembly.
Hydraulic pressure > = shear strength of one shear pin
X no. of the shear pin
For example
Shear pin sheared at 1100 psi and number of shear
pin 3
The required hydraulic pressure to disconnect the
string=3X1100 =3300 psi
4. Trip the ball and prop of the hydraulic disconnect
out of the hole with the tubing.
7.4.Down hole inline filter
CT Downhole Inline Filter
It is used between the coiled tubing and jet
cleaning tools to prevent contaminants from
entering and plugging the jet orifices.
Benefits
It extends the life of jet orifices.
Screens are reusable after cleaning.
Applications
The primary application for this tool is for filtering
the cleaning fluid used in Hydra-Blast service
operations. However, the filter can be used in
other tool strings when clean fluid is important.
Operation
Install the filter between the coiled tubing and the jetting tools.
Retrieve and clean the filter if pumping pressures rise during the job.
7.4.Down hole inline filter
Double pin connection
Straight bar
Pin for installing the filter in straight bar
Pin for installing the filter in indexing tool
7.5.Hydra-Blast Indexing Tool
Hydra-Blast Indexing Tool
uses a series of nozzles, high-pressure fluid from the coiled
tubing, and an indexing tool to cut, erode, or dissolve deposits
on the tubing or casing wall without damaging any of the
surfaces.
Benefits
Service is performed without killing the well.
It uses no mills or abrasives, reducing wear on tubulars.
It can clean diameters much larger than the tool OD
application
Scale buildup can cause a choking effect, increasing the bottom
hole pressure required to maintain flow capacity. By combining
fluid-jet technology with the proven performance of CTU the
Hydra-Blast service provides an extremely effective solution for
many wellbore cleanout problems.
7.5.Hydra-Blast Indexing Tool
Operation
Follow these steps to operate the Hydra-Blast indexing tool:
1. Use coiled tubing to run the tool to the desired depth.
2. Pump and run the tool over the depth interval to be cleaned.
3. Decrease pressure to a point below 200 psi.
4. Increase pressure to a point above 200 psi. indexing tool rotate the
nozzle 30°. Pull the Hydra-Blast tool over the same interval.
5. Repeat Steps 2 and 4 until you determine that the cleanup is
complete.
6. Stop the pumping operation.
7. Retrieve the tool from the well.
7.6.Hydra blast
0 30 60 90 120 150 180 210 240 270 300 330 360
7.6.Hydra-blast
Types of hydra-blasting tool
Side blast nozzle
Hydra-blast with indexing tool
Nozzles on the side
bottom blast
nozzle
Hydra-blast without indexing tool
Nozzles on the bottom
7.6.Hydra blast
The following fluids have been pumped through the H-B Pro tool:
Water
HCl acid
Turpine
Acetic acid
Nitrogen foams
Indexing tool
Side hydra-blast
7.6.Hydra-blast
Function test of hydra-blast
1. Make up the hydra-blat with the string
2. Start the pumping and noticed the
jetting of fluid through the nozzles
3. Decrease pressure to a point below 200 psi.
4. Increase pressure to a point above 200 psi.
indexing tool rotate the nozzle 30°.
5. Repeat Steps 2 and 4 until you determine
Complete cycle
8.Hydra-blast run on EDFU A5
surface
5-10 BPm
HVP 30 cp
Water +xanthane
4000 ft
20-30 BPm
Change the fluid from 8000 ft
to end of tbg
Nitrified HVP
N2+HVP 30cp
8000 ft
20-30 BPm
9000 ft
5-10 BPm
10230 ft
End of tbg
9.Milling run
Removing scale is one of the most common through-tubing
applications on coiled tubing. The Scale build up along the tubing
and liner section which affects the well performance and may lead
to complete loss of production.
Cleaning the wells by removing the hard scale by milling using
Tungsten carbide Mill that rotates by mud motor.
Milling run starts by making pilot hole with small size and then
enlarge this small hole with a larger size.
9.Milling BHA(baker Hughes)
CTU
Connector
2.13’’
Dual back
pressure
valve 2.13’’
High load
disconnect
2.13’’
Dual
circulating
sub 2.13’’
VIP motor
2.13’’
Taper mill
2.5’’
9.1.CTU Connector
CTU Connectors provide a means of attaching a tool
string to the end of the coiled tubing. The connectors,
when installed correctly, provide a reliable, strong
sealed connection to the coiled tubing.
9.2.Back Pressure Valve
The Back Pressure Valve is a flapper type valve that allows
flow down the tubing, but stops flow coming back up the
tubing. The Back Pressure Valve has two flappers and flapper
seals.
The flapper is designed so that a ball can be pumped
through it at minimum fluid flow rate.
It is normally run directly below the coiled tubing connector in
CT operations and at the top of the BHA in snubbing
operations.
It is run as a well control measure to prevent wellbore pressure
from entering the work string.
9.2.Back Pressure Valve(baker)
Advantages
Dual flapper valves
Flapper valve seats
Short length
Large ID
High pressure/high temperature
9.3.High Load Disconnect (baker)
Function of high load disconnect
Releases the tubing from other down hole tools run
below.
It is activated by a ball and tubing pressure.
The hydraulic disconnect is used as an emergency
safety joint with other down hole tool assemblies
Advantages
Used for jarring and motor applications
Large ID
Shear screws have a predetermined value
Can be fitted with smaller piston to run below jars
9.4Dual Actuated Circulating Valve(baker)
The Dual Actuated Circulating Valve is designed to allow a
circulation path above a mud motor from tubing to annulus.
When the motor service is complete, fluids may need to be
pumped for several hours to clean or displace the wellbore.
The use of this valve can save unnecessary wear on the mud
motor during this operation.
it is a ball actuated and is normally run below the hydraulic
disconnect and above the down hole motor.
Operation
Pumping a ball which will shift the piston sleeve, exposing
circulation ports.
When the bottom hole assembly becomes plugged, increased
pressure from the surface will rupture the disc and allow
circulation of an actuation ball
9.4.Dual Actuated Circulating Valve(baker)
Advantages
Saves wear on the mud motor
Large ID permits maximum flow rates
Predetermined values on shear
screws and secondary rupture disc
ports
9.5.VIP Motor
It is a PDM design with modular capabilities and “fit for purpose” power
section configurations.
The Navi-Drill V.I.P. can be configured and aligned to suit a wide range of
thru-tubing applications.
Operation:
Separate stator, top sub and bearing housing to allow “plug and
play” of new modular power sections tailored to suit specific
work over applications.
The operating pressures and flow rates required to run the Navi-Drill
V.I.P. are aligned with coiled tubing and slim pipe to achieve optimum
horsepower.
Slower rotational speeds improve performance of milling and cutting
products, and increase reliability during workover operations such as
milling, underreaming, cutting, wash over, or any other operation
requiring rotation of a down hole assembly.
9.5.VIP Motor
stator
Stop ring
rotor
Flex shaft
Retaining disk
Drive shaft
stator
rotor
9.5.VIP Motor
Benefits
• Modular design for customized operations
• Controlled rotational speeds protects cutting matrix
• May be powered by fluid/air/foam
• Capable of operating in temperatures over 300°F (149°C)
9.6.Taper mill
nozzles
9.7.Taper mill
Different sizes of taper mill
9.8.Taper mill
Function test of motor with taper mill
Pumping the fluid which rotate the motor @ different rates and
pressure
Q (BPM) 0.25
0.5
0.75
1
1.25
P (psi)
VIP motor
Taper mill
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Thank you
Mostafa elazab
01066099889
azabmm@gupco.net
Ahmed Ibrahim
01061121949
Hadyai@gupco.net