unlocked-461fd952f4656fee70de599ef77bd2ba.pptx

T
able of Contents
Wireline Defined
Applications
Wireline Types
Typical Wireline Units
Pressure Control Equipment
Adapters, Connectors and Flange Connectors
Barriers
Managing A Leak
My Tool Is Stuck
Broken Wire
Tool String Blown Up The Hole
Additional Considerations
3
4
5
6
9
80
85
93
103
115
132
135

Wireline Defined
Wireline is a method of conveying specialized strings of tools and associated
specialty tools into and out of a well. The tool string is attached to a single or multi-
strand wire.
The three types of wireline used are:
Slickline
Braided non-electric
Braided electric.
3

Applications
Setting and retrieving a variety of flow control devices
Providing access to the tubing/casing annulus (sliding sleeves and perforation)
Clearing obstructions from the tubing (sand, paraffin, scale)
Fishing tools and/or wire
Conducting surveys: bottom hole pressure and temperature, tubing/casing caliper,
cased hole logging, etc.
Broaching partially collapsed tubing
Temporary tubing repair (pack-offs)
Detecting fluid levels
Setting & retrieving packers
Installation and service of side pocket gas lift valves and dummies
Locating the measured end of the production tubing
Initiating well flow by swabbing
Assisting in Plug & Abandonment operations
4

Wireline units come in a wide variety of designs and
configurations. Pictured here are two skid mounted
units which can be fitted out with slickline, braided
line, or electric line. This design is commonly seen on
offshore locations but can be mounted to a flatbed for
land operations. The wireline truck pictured below is
the unit more commonly used on land locations.
6

Skid mounted units can be used on both land and
offshore locations. They can be fitted out with slickline
and braided line.
The truck mounted unit can carry both slickline and braided line. The gin
pole rig-up, although no longer used offshore, can still be seen on land
locations.
This truck mounted unit is equipped with a crane and
can also be fitted out with slickline and braided line.
7

8
Courtesy of Gulf Coast Fabricators
The iconic offshore slickline unit – the
sidewinder, is usually powered by a
50hp diesel engine, a 3-speed
transmission, contains a spool of wire
and a counter head.
The design of these units varies with the
imagination of the designer and fabricator.
The main benefit of the unit is its
diminutive size, low weight, and available
power. While esthetics and comfort aren’t
the main design criteria, it is definitely a
unit that can get the work done, just about
anywhere.

9
Configuration
The equipment at right illustrates the possible
equipment configuration used in slickline
operations.
Based on the job to be performed not all of the
pictured equipment may be used.
Sheave – may be a separate component or an
integral part of the stuffing box; is bearing-
loaded and guides the wire into the stuffing box;
in some cases the sheave is an integral part of
the stuffing box.
Stuffing Box – seals around the wire and
contains wellbore pressure and fluids
Head Catcher – uses internal dogs to latch the
rope socket when the tool string is pulled from
the hole; designed to prevent the wire from
Sheave
Stuffing Box
Head Catcher
Chemical Injection Sub
Lubricator
Bleed Off Valve
Quick Test Sub
Tool Trap
Hydraulic BOP
being pulled out of the rope socket Pump In Sub
Adapter Flange

10
Chemical Injection Sub – provides a means of
injecting chemicals such as anti-freezing fluids,
etc.
Lubricator – serves as a means of deploying
the tools string – much like the riser in a coiled
tubing rig-up
Bleed Off Valve – bleeds fluids and pressure
from the lubricator allowing the lower union of
the lubricator to be “broken” and the tool string
lowered for service, tool replacement, etc.
Quick Test Sub – provides a means of testing
the lubricator union prior to the tool string being
run back into the hole
Tool Trap – is manually or hydraulically
operated to close after the tool string passes the
trap into the lubricator – catches the tool string
in the event the wire is accidentally pulled out of
Sheave
Stuffing Box
Head Catcher
Lubricator
Bleed Off Valve
Quick Test Sub
Tool Trap
Hydraulic BOP
the rope socket Pump In Sub
Adapter Flange

11
Hydraulic BOP – one or more hydraulically
operated blowout preventers (wireline valve)
used to seal around the wire, cut the wire, or
close when there is no wire in the hole
Pump-In Sub – provides a means and
connection to pump into the well is desired
Adapter Flange/Swedge – a connection which
allows the surface equipment rig-up to be
connected to the tree
Sheave
Stuffing Box
Head Catcher
Lubricator
Bleed Off Valve
Quick Test Sub
Tool Trap
Hydraulic BOP
Pump In Sub
Adapter Flange

Stuffing Box
Basic Description
 Used in slickline operations to confine well fluids and gases to a well
 The stuffing box wipes the wire clean
 It is available in manual and hydraulic configurations
 Available in pressure ratings of up to 15,000 PSI and sizes up to 7”
Steps to take if stuffing box is not working
For the manual stuffing box, an indication of “time to repack” is given by the packing
nut. If the packing nut is screwed fully down, the packing needs to be replaced.
Packing may also need to be replaced if tightening the packing nut does not stop the
leaking.
12

Packing Nut
Sheave
Plunger
Body
Quick Union
O-Ring
Bearings
Valve Screw
Plunger Stop
Lower Gland
Upper Packing Gland
Packing
Slick Line – Manual Stuffing Box
The function of the stuffing box is to
allow entry of the wire into the wellbore
while sealing around the diameter of the
wireline and preventing the escape of
wellbore fluids.
Sheaves are available for wireline sizes
of .072” to .125” diameters, and with
working pressures up to 15,000 psi.
The plunger (blowout plug) prevents well
flow when wireline is pulled out of rope
socket or if the line breaks and is blown
out of the hole.
13

Slick Line – Hydraulic Stuffing Box
Sheave
Hydraulic Oil Inlet
Quick Union Collar
Spring
Packing
Body
Piston
Plunger
Retaining Ring
Hydraulic Cylinder
Upper Gland
Lower Gland
Another version of the slickline stuffing
box is the hydraulic model. Hydraulic
fluid is pumped through the quick
connect via a small hand pump. The
14
Bottom Sub
hydraulic
causing it
fluid acts on the piston
to travel in a downward
direction, compressing the spring, and
tightening the packing around the wire.
When hydraulic fluid is bled the spring
relaxes and the piston travels back
upward.
One main safety advantage of this type
over the manual stuffing box is that no
one is required to climb the lubricator
or be hoisted in order to manually
tighten the stuffing box while it is under
pressure

Plunger Stop
Lower Packing Gland
The plunger, which serves as an internal blowout
the stuffing box in the
preventer, essentially shuts-in
event of wire breakage.
If the wire breaks, the broken end will eventually pass
through, and out of the stuffing box. The well now has a
free path to the surface through the stuffing, so
technically, a blowout exists.
When the wire leaves the stuffing box a differential
pressure is created between the bottom of the plunger
(which is experiencing surface well pressure) and the top
of the plunger (atmospheric pressure). This differential
causes the plunger to rapidly move upward. The soft
rubber nose of the plunger collapses on itself and shuts
off the flow.
Plunger
Stuffing Box Plunger
15

Inlet with Check Valve
This device, usually placed just below the stuffing
box, is designed to inject chemicals and de-icing
agents onto the wire when there is a chance of
hydrate formation.
Chamber
Wire Seals
The sub incorporates a 2 liter internal chamber which is
filled using a high pressure hand pump. It also has
packing which seals around the wire minimizing
chemicals falling into the well.
The chemical inlet has an internal check valve which
prevents the escape of wellbore fluids.
16

Tool Catcher
Piston
Hydraulic
Inlet
Dogs
The tool catcher is designed to “latch” the
rope socket after it’s been pulled into the
lubricator and prevents the tools string from
falling in the event the wire is accidentally
pulled from the rope socket.
The spring-loaded dogs allow the rope
socket head to be pulled above the
dogs. If the wire is pulled out of the
rope socket the dogs latch the rope
socket fishing neck.
The rope socket can be released by
applying hydraulic pressure to the inlet
from a hand-operated pump. The dogs
open and the tool string can be
retrieved from the lubricator.
17

The lubricator acts as an extension of the
wellbore enabling a tool string to enter and be
retrieved from a live well.
The body sections, normally 8 feet or 10 feet in
length, are connected to male and female quick
unions at the top and bottom respectively.
Lubricator sections are available in pressure
ratings of 5000 psi, 10000 psi and 15000 psi
and in diameters up to 7”.
As an option there are those who install a pump-
in sub as part of the lubricator. The sub must be
of the same pressure rating as the lubricator,
wireline valve, and tree connection.
Pump-in Sub
18
Lubricators
Lubricator

19
Body
Needle Valve
Male Quick Union
O-Ring
Female Quick Union
Lubricator
The major components of the lower lubricator section.

Quick Test Sub
The Quick Test Sub is usually located
just above the WL Valve.
After the initial surface equipment test the
QT Sub is used to test the lowest
connection in the lubricator (or the
connection that is broken when tools are
removed and/or installed) prior to each
trip in the hole.
While not
equipment,
considerable
a mandatory piece of
it’s presence saves
testing time prior to each
trip in the hole.
T
est pressure is applied to the
connection via the external inlet.
20

Courtesy of Hunting Pressure Control
Tool Trap – Manually Operated
A tool trap is placed below the lubricator sections and
serves to prevent the tool string from falling down the hole
if the operator inadvertently pulls out of the rope socket.
There are two types of tool traps: manual and hydraulic.
Shown here is a manual tool trap and is recommended
when surface pressure is low.
The flapper is manually opened allowing the tool string to
descend into the well. After the tool string passes the tool
trap, the flapper is manually closed. The flapper, which is
spring-loaded (shown below) allows the wireline to move
unimpeded and will open upward when the rope socket
contacts the flapper. When the lower section of the tool
string passes the flapper it closes.
Flapper
21

Tool Trap – Hydraulically Operated
Pictured here is a hydraulic tool trap. Its purpose and
basic function is similar to the manual model on the
previous page but this one operates hydraulically and
incorporates a manual back-up.
The hydraulic model is recommended when
surface pressure exceeds 5000 psi or if
hydrogen sulfide is present at the surface.
22

Wireline BOP
Wireline BOP’s, or wireline valves as they are commonly known, are considered to be
“secondary barriers” used to contain wellbore surface pressures. There are both
manual and hydraulically operated models. The hydraulic models are complimented
with manual back-ups. Wireline valves between wellhead or Xmas Tree and wireline
lubricator
Dual rams can be used for slickline with one being a ram to seal around the wire and
the open hole and the other being a slickline cutter ram.
Dual rams are also common in braided line work. The top ram is installed
conventionally and the lower ram is inverted to assist in sealing around the braided
wire. Grease can be injected between the rams under pressure to effect the seal.
Wireline valves are customarily installed directly onto the tree to provide the
least number of potential leak points. Where needed, a riser can be installed
between the tree and the wireline valve/s.
All wireline valves are equipped with equalizing valves which serve to equalize
pressure across closed rams prior to opening.
23

24
Wireline BOP
Manual: Smaller, lighter and easier to handle. Operated by manually turning the two
handles to open and close the rams. Manual BOPs are used mainly for low pressure
non-gas service
Hydraulic: Mostly used, heavier and bulkier but operated remotely and quite rapidly.
It is operated by a hydraulic pump, but with manual backup. A hydraulic BOP can be
closed manually but must be opened hydraulically after the stems have been back
out manually. Used because of quick response closure time and ease of operation
Annular Type: Available in higher pressure models (10,000 psi and 15,000 psi).
Hydraulically operated and functions much like an annular preventer used to seal
around a workstring. With the application of hydraulic pressure a piston travels in the
upward direction causing the sealing elements to seal around the wireline.
The functions of the wireline valve are as follows:
To enable well pressure to be isolated from the lubricator when leaks develop
To permit assembly of a wireline cutter or cutter bar
To permit stripping of wire through closed ram when recovering broken wire from a
live well (stripping through a wireline valve should be conducted on a limited basis)

25
Single BOP
One set of rams generally used for low pressures (up to 5000 psi) – manual and
hydraulically operated
Dual or Twin BOP
Can be two rams in a single body or two independent rams; available in pressure
rating of 5000 psi to 15000 psi; configured as 2 wire rams or 1 wire ram and 1 cutter
ram
Annular Type
Used mainly for high pressure operations (10,000 psi and 15,000 psi); two models
are available: normally open, normally closed; both are hydraulically operated
BOP Configurations

26
Ram Inner Seal
Ram Guide
Body
O-Ring
Equalizing Valve
Male Quick Union
Operating Handle
End Cap
Stem
Ram Block
Otis Single Wireline Ram – Manually Operated
The Otis Wireline Valve has been a reliable
BOP for decades and is still in use on many
land locations. It is available in 5000 psi and
10000 psi models and can be completely
rebuilt in the field if the need arises.
Female Quick Union
Single Manual Ram

27
Single Manual Ram
Equalizing Assembly

28
Hydraulic Single Ram with Manual Lock

29
Hydraulic Connection - Open
Eastern Oil T
ools manufactures this single ram useable for both slickline and multi-strand line
service. It incorporates a double sealing surface which allows sealing to occur from both above
and below the ram block. This is especially helpful in grease seal applications where it may be
desirable to inject grease between ram blocks to effect a seal.
Ram Guide Ram Lock
Female Quick Union
Ram Change Collar
Equalizing Valve Ram Block
Ram Locking Stem
End Cap
Hydraulic Cylinder
Piston
Ram Shaft Packing
Hydraulic Connection - Close
Handle
Ram Outer Seal
Hydraulic Single Ram with Manual Lock

Ram Block
Piston
Ram Locking Screw
Closing
Ports
Opening
Ports
Equalizing
Valves
Hunting Pressure Control Equipment manufactures
this hydraulically operated double wireline valve. It is
equally suited for slickline and e-line applications
and is available in pressure ratings up to 15000 psi.
Hydraulic Dual Ram with Manual Locks
The slick line version can be equipped with two wire rams
or a wire ram and cutter ram while the braided line model
contains inverted braided line rams.
30

Hydraulic Dual Ram with Manual Locks
31

Equalizing Valve
Equalizing Valve for Otis Single Manual Wireline V
3a
2lve
All wireline valves incorporate an equalizing
valve which is located on the front of the body
of the preventer. The equalizer valve allows
pressure to be equalized across a closed set
of rams. A ¼ ” Allen wrench is used to open
the valve. Before operating make sure there is
a retaining screw installed.
Wireline BOP Equalizing Valve

Like other wireline valves, this one incorporates an
equalizing valve allowing pressurization of the
lubricator while the valve is closed.
Hydraulic Annular-Type Wireline BOP – Normally Open
This wireline valve manufactured by Bowen Oil T
ools is
designed to operate on the same principle as an
annular preventer used in drilling or workover. Hydraulic
pressure is applied to a piston which travels in an
upward direction and acts on the three sealing
segments in the same fashion that the piston acts on
the element of an annular preventer. The rubber
elements on the sealing segments will seal around
slickline as well as multi-strand wireline.
33

The operation of the Bowen High
Pressure Wireline Valve is much like
an annular preventer. Hydraulic fluid
is pumped in the closing inlet which
lift a piston.
The movement of the piston lifts and
brings together sealing segments
around
annular
damage
the wireline. Unlike an
no
preventer, there is
to the sealing elements
when this preventer is closed on the
open hole.
Opening Inlet
34
Closing Inlet
Hydraulic Annular-Type Wireline BOP

Another version of the high pressure wireline valve is the
fail-safe model. Its basic operation is similar to the model
on the previous page with the exception of the fail-safe
spring. Hydraulic pressure is applied to the piston which
moves against the spring to open the valve and hydraulic
pressure must be maintained in order to keep the valve in
the open position. If hydraulic pressure is lost the spring
takes over and closes the valve. An optional bleeder valve
is available in the event of lubricator needle valve failure
(pictured below).
Hydraulic Annular-Type Wireline BOP – Normally Closed
35

On the left, is a swedge connection
which is used on surface trees that
have an 8-round threaded box. The
working pressure for this type is
usually no more than 5,000 psi.
Tree Connectors
Quick Union x 8-Round Swedge
Quick Union x Flange
For higher pressure, it is prudent to
use a more substantial connection like
a flange of the appropriate pressure
rating.
Both are equipped with quick union
top connectors onto which the wireline
valve can be installed.
36

37
Pressure Testing – Slickline Equipment
A typical test consists of pressuring up the
lubricator against the closed tree swab valve to
the working pressure of the lowest pressure
rated item of equipment in the rig up or 110% of
anticipated surface pressure.
Make sure the surface equipment is purged of
air to obtain a satisfactory pressure trace on the
chart recorder.
Water or other suitable liquid should be used (a
fluid that does not contain solids) – nitrogen is
also a suitable test fluid.
Subsequent trips in the hole require that the
surface pressure be tested. This can be easily
accomplished using the Quick T
est Sub as this
is usually the only connection that’s broken.
Closed Swab Valve
Wireline
Valve
Pump In Sub
T
est Pressure
Lower
Lubricator
Section
Quick T
est Sub
T
est Inlet

Apply test pressure
or open the well
Install a gauge on the lubricator to
detect any pressure build-up which
would indicate a leaking ram element.
Close the rams and pull the rope socket
up to the ram block. Apply test pressure
either from a pump or the well could be
slowly opened. Monitor the lubricator
gauge for pressure build-up.
After testing the ram, open the
equalizing valve on the BOP which will
pressure up the lubricator. Check the
quick unions and stuffing box for leaks.
Shut-in the well, bleed pressure off the
lubricator, open the rams, and remove
the wire. Close the rams and apply
pressure below the closed rams to test
the rams against the open hole.
Open equalizing valve
0 5000
38

Install a gauge in the lubricator to monitor
pressure.
Close the lower set of rams, pull the rope
sock up to the closed rams and apply
test pressure. Monitor gauge for pressure
build-up.
Close the upper rams, open the
equalizing valve on the lower rams which
will pressure up the cavity between the
two sets of rams, and then open the
lower rams. Monitor the lubricator gauge
for pressure build-up.
Open the equalizing valve on the upper
rams to pressure up the lubricator.
Visually inspect the quick unions for
leaks.
Following this test, perform a test of the
rams without wire as described on the
previous page.
0 5000
Apply test pressure
or open the well
39

Braided Line Surface Pressure Control Equipment
The surface pressure control equipment commonly found on electric/braided
wireline units are as follows:
Wireline Control Head - used in braided and electric line operations and serves the
same purpose as a slickline stuffing box – available in working pressures up to
15,000 psi.
Grease Control Head - found on braided and electric line operations and serving the
same purpose as the two above – utilizes grease or very viscous oil to effect a seal
around the wire as opposed to rubber packing elements – available in working
pressures up to 15,000 psi.
Swabbing Stuffing Box - serving the same purpose as the stuffing box or grease
control head but used with braided line in low pressure operations.
Lubricator - sections of pipe equipped with unions on either end – serve to house
the tool string prior to entering the well and after the tool string has been retrieved
from the well – commonly in lengths of 8 feet – available in working pressures up to
15,000 psi.
40

Wireline Valve - wireline blowout preventer – available in manual and hydraulically
operated models – both for slickline and multi-strand wireline – available in single
and dual configurations – working pressures as high as 15,000 psi.
Tree Connection - several styles available: flanged connections (usually for high
pressure work), 8-round pin x hammer union, and 8-round pin x quick union are the
most common – working pressures as high as 15,000 psi.
41
Braided Line Surface Pressure Control Equipment

42
Electric/Braided Line Stack Configuration
Braided/Electric line wireline is generally used when
the strength of slickline is insufficient for the task or
when services are required which are specific to
electric line.
Pack-Off Liner Wiper – wipes the line free of
grease or oil as it is pulled from the hole
Grease Head – a device comprised of a low
pressure and high pressure section – seals around
the wire – braided line equivalent to the slickline
stuffing box
Head Catcher - uses internal dogs to latch the
rope socket when the tool string is pulled from
the hole; designed to prevent the wire from
being pulled out of the rope socket
Lubricator - serves as a means of deploying
the tools string – much like the riser in a coiled
tubing rig-up
Packoff Line Wiper
Grease Head
Head Catcher
Lubricator
Quick Test Sub
Tool Trap
Hydraulic BOP
Pump In Sub
Adapter Flange

he
ack
to
he
he
lly
ed
en
43
Quick Test Sub - provides a means of testing t
lubricator union prior to the tool string being run b
into the hole
Tool Trap - is manually or hydraulically operated
close after the tool string passes the trap into t
lubricator – catches the tool string in the event t
wire is accidentally pulled out of the rope socket
Hydraulic BOP - one or more hydraulica
operated blowout preventers (wireline valve) us
to seal around the wire, cut the wire, or close wh
there is no wire in the hole
Pump-In Sub – provides a means and
connection to pump into the well is desired
Adapter Flange/Swedge – a connection which
allows the surface equipment rig-up to be
connected to the tree
Packoff Line Wiper
Grease Head
Head Catcher
Lubricator
Quick Test Sub
Tool Trap
Hydraulic BOP
Pump In Sub
Adapter Flange

Another version of braided line surface equipment rig-up
44

Bowen Swabbing Stuffing Box
The swabbing stuffing box seals around
the multi-strand wireline commonly used in
swabbing operations. It is a low-pressure
sealing device since the object of
swabbing is to initiate flow by reducing
wellbore hydrostatic pressure and not
totally bringing the well in and having full
shut-in pressure at the surface.
Sealing around the wire takes place by
adjusting the manual packing nut which
either increases or decreases the force of
the packing against the wireline.
The swab head is a primary barrier.
45
Swab Head

Swabbing
Swabbing is an operation in which columns of fluid
are removed from the tubing, decreasing the
hydrostatic pressure in the tubing, thus
encouraging the well to come in.
This is usually done with a swab unit equipped
with braided wireline measuring anywhere from
3/16” OD to 5/8” OD. A standard tool string is
assembled and a swab mandrel with swab cups is
made up below the jars.
Swab sups are slotted rubber elements which
expand when the tool string is retrieved. The swab
cups seal against the tubing wall enabling the unit
to “pull” fluid from the well.
The operator pulls a “load of fluid” and observes
the well for a time. Any indication of flow or the
slightest hint of tubing pressure is a sign for the
swab operator that his job is done and the well is
then allowed to flow and clean up.
Swab Mandrel
Swab Cups
46

Grease Outlet
Line Bushing
Spray Guard Rubber
Hydraulic Packing Nut
Piston
Piston Return Spring
Line Rubber
Flow Tube
Body
Packing Nut
Hydraulic Oil Inlet
Grease Inlet
The wireline control head serves the same
function as the slickline stuffing box but is
designed to be used with multi-strand wireline
and without the use of grease injection to
effect a seal around the wire. The head has
high and low pressure sections.
The high pressure section entails the lower
body which houses the flow tubes. Above this
is the low pressure section which
47
Control Head
encompasses the line rubber and the spray
guard. The spray guard has no pressure
rating and serves only as a line wiper.
The seal in the low pressure section is
effected and maintained by the line rubber
and applied compression of the adjustable
hydraulic packing nut. Hydraulic pressure can
be applied to the piston via an inlet hose as
seen in the illustration.
Bowen Wireline
Control Head/Grease Head

48
Pictured here is another design of a
grease head. Although designs and parts
designation may a bit different from
manufacturer to manufacturer, the basic
function of each remains the same
Grease Inlet
Flow Tube Body
Hydraulic Packing Nut
Grease Outlet
Flow Tube
Bottom Sub
Grease Inlet
Quick Union Collar

49
Grease Control Head for Braided and
Electric Line
Low Pressure Section
Piston
Hydraulic Inlet
Pictured at left is the upper, low pressure
section of the grease head. The pressure
rating of the upper section is limited by the
performance of the line rubber, which is a
rather soft element and usually won’t hold
more than 1500 psi in a static state.
The seal around the wire is accomplished
by applying hydraulic pressure to the
piston from a small hand pump through
the hydraulic inlet.
Piston Spring
Line Bushing
Waste Grease Outlet
Line Rubber

50
Grease Head Particulars
Maintains a grease seal around wireline to prevent escape of wellbore fluids and
gases
Grease seal is achieved via a grease injection system pumping a viscous fluid
between the wireline and grease tube
Grease tubes are available in various sizes for slickline and braided line
Steps to take if grease control head is not working
 If the unit is blowing grease in the air, the rubber might be worn out and needs to
be changed
 If the unit is losing grease in the well, then the flow tubes are too big/worn, also
the braided line might be worn. This indicates too much clearance, and needs to
be changed
 If the unit uses too much grease, the operator may be pumping more grease than
needed or the flow tubes need to be re-sized.

Winch
Load Cell 51
Shown h
rig-up. D
the equi
is offsho
used in p
ere is a possible braided line/electric line Grease Head
epending on the job and location not all of
pment shown would be used. If the location
re a skid-mounted wireline unit would be
lace of a truck-mounted unit.
Lubricator
rol and Grease Injection Unit Waste Grease
BOP Opening Lines Pack-Off Line
Grease Injection
BOP Closing Lines
Wireline Valve
elescoping
Mast
T
ourtesy of NOVElmar
Hydraulic Cont
Pictured here is an example of a self-contained hydraulic control and grease injection
unit. These units supply grease to the grease head and hydraulic fluid to the wireline
grease head and the BOP’s. They are available in pressure ratings up to 15000 psi.
C
The control panel provides complete control of grease supplied to the grease head
and hydraulic fluid supplied to the grease head and the BOP’s. The diesel engine
throttle control is panel-mounted as well as gauges to monitor pressures, grease and
fluid levels as well as engine speed.

Air Supply
To Grease Head
Grease Pot
Pump
Regulators
Grease
Suction
Tube
Shown here is a
simplified version of a
grease injector. An air-
operated pump pumps
grease from the grease
pot to the grease head.
Regulators control the
pressure in the grease pot
and the pressure of the
injected grease to the
grease head
A good practice is to set the grease
injection pressure to about 125% of
the observed surface pressure.
52
Grease Injection Unit

The flow tube has just enough internal
clearance to allow passage of the braided
wireline. Fluids entering under pressure
undergo a significant reduction in volume
due to the restricted bore. The gaseous
phase of these fluids undergoes
pressure reduction. As the
each machined chamber it
substantial
gas enters
expands and pressure decreases.
The principle of the flow tubes is to
reduce pressure to a level that can be
handled by the upper low pressure
section of the grease head.
Residual fluid leaving the top of the flow
tube is vented via the flow hose where it
can be collected and properly discarded.
Flowtubes
Expansion
Chambers
Flow Tubes
53

The number of flowtubes used varies with surface pressure and
the type of produced fluids that will enter and travel through the
flowtubes. The chart below, while not a definitive source of
information, can serve as a guide in deciding the appropriate
number of flowtubes to install for a particular pressure situation.
High Pressure Section - Flow Tube
Flow Tube Housing
Coupling
Flow Tubes
54
Flow Tubes
Well Pressure Fluid Type Flow Tubes
0 – 5000 psi Liquid 3
0 – 5000 psi Gas 3
5000-10000 psi Liquid 4
5000-10000 psi Gas 4 or 5
10000-15000 psi Liquid 6
10000-15000 psi Gas 6 or more

55
As seen in the animation, grease is
injected under pressure into the grease
injection collar an up the tubes. The
grease creates a pressure seal around
the wireline and finally exits at the
grease drain hose at atmospheric
pressure. Pressure reduction takes
place in the flow tubes as explained in
earlier text.
Low pressure sealing around the wire is
provided by the line rubber. As the
rubber wears the hydraulic hand pump
is used to provide additional closing
pressure on the rubber.
Line Rubber
Hand Pump
Waste Grease
Injection Grease
Flow Tube
Flow Tube
Flow Tube
Grease Injection

56
If braided line breaks in the hole the remaining
line will be retrieved. When the end of the line
leaves the grease seal an open path is created
between the wellbore and the atmosphere –
technically a blowout exists. The ball check
serves to shut off the uncontrolled flow until the
tree can be shut-in.
As long as wire is running through the check
valve the ball resides to the side of the wire but
as the end of the wire leaves the well flow
“sucks” the ball up to the check valve seat and
shutting off the flow.
Ball Check Valve
The Ball Check Safety Valve is secondary barrier.

57
Courtesy of Elmar Wireline Tools
If the rope socket is pulled into the top of the lubricator
and the wire stripped from the rope socket, the tool
catcher will engage the tool's fishing neck, latching the
rope socket, and preventing the loss of the tool string into
the well bore. The tool catcher is designed to be fail-safe:
it is permanently in the catch position and requires
hydraulic pressure to release.
ASEP Elmar hydraulic tool catchers for electric line are
normally supplied with an integral ball check valve
assembly, and a top connection into which a grease head
can be directly screwed. As an option the tool catcher is
available with a glycol injection port. For slick line
operations ASEP Elmar hydraulic tool catchers are
available with quick unions top and bottom.
The hydraulic tool catcher is available with ratings from
5,000 psi to 15,000 psi WP
, STD and H2S service. The
catcher portion is available for all common rope socket
sizes.
Lubricator Check Valve & Tool Catcher
Ball Check
Valve
Hydraulic
Inlet
Hydraulic
Tool
Catcher

58
The lubricator acts as an extension of the
wellbore enabling a tool string to enter and be
retrieved from a live well.
The body sections, normally 8 feet or 10 feet in
length, are connected to male and female quick
unions at the top and bottom respectively.
Lubricator sections are available in pressure
ratings of 5000 psi, 10000 psi and 15000 psi
and in diameters up to 7”.
As an option there are those who install a pump-
in sub as part of the lubricator. The sub must be
of the same pressure rating as the lubricator,
wireline valve, and tree connection.
Pump-in Sub
Lubricators
Lubricator

Quick Test Sub
The Quick Test Sub is usually located
just above the WL Valve.
After the initial surface equipment test the
QT Sub is used to test the lowest
connection in the lubricator (or the
connection that is broken when tools are
removed and/or installed) prior to each
trip in the hole.
While not
equipment,
considerable
a mandatory piece of
it’s presence saves
testing time prior to each
trip in the hole.
T
est pressure is applied to the
connection via the external inlet.
59

Tool Trap – Manually Operated
A tool trap is placed below the lubricator sections and
serves to prevent the tool string from falling down the hole
if the operator inadvertently pulls out of the rope socket.
There are two types of tool traps: manual and hydraulic.
Shown here is a manual tool trap and is recommended
when surface pressure is low.
The flapper is manually opened allowing the tool string to
descend into the well. After the tool string passes the tool
trap, the flapper is manually closed. The flapper, which is
spring-loaded (shown below) allows the wireline to move
unimpeded and will open upward when the rope socket
contacts the flapper. When the lower section of the tool
string passes the flapper it closes.
Flapper
69

Tool Trap – Hydraulically Operated
Pictured here is a hydraulic tool trap. Its purpose and
basic function is similar to the manual model on the
previous page but this one operates hydraulically and
incorporates a manual back-up.
The hydraulic model is recommended when
surface pressure exceeds 5000 psi or if
hydrogen sulfide is present at the surface.
61

Dual or Twin BOP
Braided Line (and Electric line), hydraulically operated; configured in a single
housing/body with two set of rams; rams are inverted to facilitate sealing around the
wire by grease injection through an injection port
Triple BOP
Used mainly on high-pressure gas wells; two upper sets of “normal” rams for
redundancy; lower set of inverted rams
Quad BOP
Used mainly on high-pressure gas wells; two upper sets of “normal” rams for
redundancy; lower set of inverted rams; can also be fitted with wireline cutter rams
62
BOP Configurations

Braided Line Dual Inverted Hydraulic BOP
63

64
Braided Line Triple Inverted Hydraulic BOP
Configurations
Blind Rams Wire Rams
Wire Rams Wire Rams
Inverted Wire Rams Inverted Wire Rams

Shown here is a quad wireline valve more commonly
used in high pressure electric line or braided line
operations.
This type of stack is normally fitted out with three sets of
wireline rams and a set of blind rams. However, wireline
cutter rams can be substituted for wire rams if desired.
65
Two Configurations
Surface Equipment
Blind Rams Blind Rams
Wire Cutter Rams Wire Rams
Wire Rams Inverted Wire Rams
Inverted Wire Rams Wire Rams

66
Wireline Valve
Courtesy of WPCE
This quad set of wireline rams is manufactured by WPCE. This stack features a bore
size of 6 3/8” and a working pressure of 15000 psi. It incorporates independent
grease injection ports, a test port, and ram inversion is possible if desired. Ram
position indicator roads are standard as well as an equalization manifold. The stack is
“hard-piped” with stainless steel tubing which is mounted to the frame.
Front View
Rear View

Braided Line Rams
Braided line ram – designed to seal around a specific line OD
67
Blind rams – designed to seal around slickline and/or the open hole

“Constrictor” multi-line rams. These rams can seal on the
Multi-Line Rams
open hole as well as any size wireline up to 5/16” OD.
68

Shear/Seal Rams
The shear/seal rams blocks guide the wire to the center of the
shear blades, cuts the wireline and then seals on the open hole.
69

Braided Line Equipment Pressure Testing
Purge the surface equipment. Pump at a sufficient rate to vent air via the grease
injection head.
As the test liquid begins to leak out at the grease injection head, slow the pump rate
down and increase the grease injection pressure to effect a seal (if pump rate is not
reduced, grease may be stripped through the flow tube too quickly and a seal will not
be achieved).
Continue to pressure up with the test pump and hold stabilized pressure for the
prescribed time.
The grease injection system should always be pressure tested to its maximum,
regardless of the well pressure expected.
79

Slick Line/Braided Line and Shear Seal BOP
The shear/seal BOP is a pressure control equipment often fitted to the wellhead
during well-intervention operations on live wells.
The shear-seal BOP is a ram-type preventer that performs the dual functions of
shearing or cutting the wire or tool string and then fully closing to provide isolation
or sealing of the wellbore.
They mostly provide contingency/or emergency pressure barrier when needed to
secure the well – tertiary barrier.
It is rigged up directly on the Xmas Tree.
If the wire breaks and falls below the grease seal head, close the shear/seal
BOPs to secure the well.
The swab valve can be closed provided it can be determined that the wire is
below the swab valve.
71 71

Another BOP available from T
exas Oil T
ools is the Shear/Seal Ram intended
primarily for well intervention operations.
It has the capability of shearing the
following:
Wireline (slickline and braided)
Sinker bar
Coiled tubing of various sizes
Production tubing
Snubbing workstrings
Drill pipe
Bottom hole assemblies.
After shearing, the ram provides a blind seal on the wellbore.
72
Slick Line/Braided Line and Shear Seal BOP

BOP Test Before the Job
Check that the certification is within date and that the scheduled maintenance is up to
date
All blind (shear) inner seals need to be inspected after 30 pressure cycles and
replaced where necessary. Wire-line seals must be tested without the use of test rods
and must always be replaced after being closed on wire during normal operations.
Always inspect the wireline seals for signs of wear or damage and replace if
necessary
Examine the BOP Assembly, to make sure that it is good operating order and
assembled with the Rams in the correct orientation for the desired operation
Functioning of the Rams may be checked, by running both Rams to the closed
position.
73

BOP Test Before the Job
Special care should be taken that the Rams are fully open when passing any
equipment through them. The impact of the tool string hitting a Ram may damage the
Ram to such an extent that the Ram may no longer Seal, or prevents it from fully
opening
Only lift the BOP using suitable lift caps. Do not sling or attach lifting equipment to the
crash frame or bars to lift the BOP assembly
Care should be taken to completely remove any residual pressure or accumulated
pressure existing on Lubricator equipment above the BOP before disconnecting the
Lubricator
Only clean Hydraulic fluid should be used to operate the BOP
. The use of mixed
types, dirty, or very old fluid of unknown origin is not recommended. When one of
these conditions is known or suspected, the hydraulic system should be flushed
and the hydraulic fluid replaced.
74

Equipment Failures
Leak in lubricator: although the lubricator will have
been pressure tested prior to commencing operations,
the action of jarring etc. can induce bending in the
lubricator and hence cause leaks at the connections.
It is good practice to visually inspect and replace the
‘O’ ring at the connection used every time the
lubricator is broken open
Signs that a lubricator may need to be replaced
Visible leaks
Peeling or flaking paint
Corrosion on the inside of the lubricator body
Visible evidence of excessive line wear inside the
lubricator
75

Equipment Failures
Explosive decompression is a condition that occurs after an elastomer is
exposed to a gas laden fluid in the presence of high pressure. The pressure
compresses the gas and forces it into the interstices of the elastomer.
While operating under the pressurized condition, no harmful effects are noted. The
problem occurs when the system is rapidly depressurized. As the pressure outside
the elastomer falls below that of the gas contained in the elastomer, the gas begins
to expand and move toward the surface.
If the differential between the internal pressure of the gas bubble and external
pressure exceeds the bi-axial capability of the elastomer, a fracture or rupture will
occur.
76

Equipment Failures
Wireline can suffer the effects of Cyclic Fatigue just as coiled tubing and drill line
on a draw works. Fatigue and ultimately failure occurs when the pipe/wire is
“worked” over the same surfaces for an extended period of time. Along with the
physical contact with sheaves tension loading can also contribute to cyclic fatigue.
As a matter of safety, the unit should be positioned about 75 feet from the wellhead
if possible. Secure the unit completely, be it land or a mobile offshore unit. This may
mean chocking the wheels of a truck-mounted unit or securing a skid-mounted unit
with chains and binders to prevent the unit from moving while wireline work is in
progress.
If the job being performed requires many trip into and out of the hole it’s probably a
good idea to cut about 50’ to 100’ of wire each day and re-attach the rope socket.
This will also entail pressure testing the connection below the grease injector or
stuffing box prior to going in the hole.
77

Elastomer test specimen
prior to exposure to gas test
Elastomer test specimen showing surface
damages as a result of Explosive
decompression
Cut-away section of elastomer test specimen
showing elastomer surface damage as a result of
Explosive decompression
Steps in Explosive
Decompression
Explosive Decompression
78

Equipment Certification
All lubricator section must have full certification from the manufacturer or test house. A
standard color code identifies different pressure ratings of lubricator
A color coding system is usually adopted. The color coding system uses one or two bands of
color to identify the service
The pressure rating is identified by the base color of the item (e.g. lubricator) or accessory and
should satisfy the following:
Color coding and pressure rating of pressure control equipment
Maximum Working Pressure Color
79
3,000 psi Red
5,000 psi Dark green
10,000 psi White
15,000 psi Yellow

On the left, is a swedge connection
which is used on surface trees that
have an 8-round threaded box. The
working pressure for this type is
usually no more than 5,000 psi.
Adapters, Connectors and Flange Connectors
Quick Union x 8-Round Swedge
Quick Union x Flange
For higher pressure, it is prudent to
use a more substantial connection like
a flange of the appropriate pressure
rating.
Both are equipped with quick union
top connectors onto which the wireline
valve can be installed.
80
Adapters, Connections and Flanges

Ring gaskets are placed in the ring grooves of flanges. Below are four of the most
common types of ring gaskets. In all cases, the rings are designed to seal metal-to-
metal, so, no teflon tape is to be used, don’t grease the grooves or gaskets, and
clean the ring grooves with soap and water, not a solvent that may leave a film.
Additionally, when a flange is “broken” and then made back up, a new gasket
should be used.
Type R Ring Gasket
API type, non-energized by internal pressure. Sealing takes place along small bands
of contact between the groove and the gasket. Does not allow flange face-to-face
contact so periodic tightening of the flange is recommended.
81

API type, pressure energized ring.
Sealing takes place along small
bands between the grooves and the
OD of the gasket.
Does not allow flange or hub face-
to-face contact. It is recommended
that a new gasket be used each
time the joint is made up.
Type RX Ring Gasket Type BX Ring Gasket
API type pressure-energized
ring gasket. Sealing takes place
along small bands of contact
between the grooves and the
OD of the gasket.
Designed to provide flange face-
to-face contact. Frequently
manufactured with axial holes to
insure pressure balance.
82

Face-to Face Type RX Ring Gasket
API
ring
place
type pressure-energized
gasket. Sealing takes
along small bands of
contact between the grooves
and the OC of the gasket.
Provides for flange hub face-
to-face contact.
Face-to Face Type RX Ring Gasket (Modified)
API type pressure energized ring gasket –
modified from original RX design to
correct buckling. Sealing takes place
along small bands of contact between the
grooves and the OD of the gasket. The
gasket ID will also contact the grooves
when made up tightly. Provides for flange
hub face-to-face contact.
83

The GrayLoc connection can be used to join sections of lubricator – especially the
larger sizes. It can also be used to as a tree connection. The GrayLoc is available in
a wide range of sizes and working pressure up to 15000 psi.
84

Barriers
Wireline Mechanical Barriers
In general, a well barrier is defined as any substance or device that will prevent the
flow of a well. A barrier is an obstacle to well flow and pressure
The general philosophy requires that two mechanical barriers (for both the annulus
and the tubing) and one barrier be considered as the minimum
Primary barrier is a barrier that performs pressure control during normal operating
conditions. A primary barrier is usually a closed barrier
Secondary barrier is a barrier that performs pressure control in the event that the
primary barrier fails. A secondary barrier is usually a closable barrier
The hydraulic stuffing box serves as the primary barrier in a typical slick line rig up
while the grease injection head serves as the primary barrier in a typical braided line
rig up
The wireline BOP serves as the secondary barrier in both the slickline and braided
line rig up
85

Mechanical barriers are required for all wireline intervention work
The various mechanical barriers used in wireline intervention work includes:
o Grease or oil seal on the wire (for dynamic sealing)
o Packoff for static application
o Blind/Shear rams
o Master valve (can cut some wire, but poses a risk of valve damage)
In general, mechanical barriers are either closed or closable.
Wireline stuffing box and grease injection head (primary barrier) are closed barrier
systems
BOP systems (secondary barrier) and shearing devices are closable barrier
systems
86
Barriers

It is recommended to use a tool catcher, tool trap or similar device to protect the valve
below against damage in the event of accidentally dropping the toolstring during
operation.
It is acceptable to use another hydraulically remotely operated valve, e.g. the HMV, to
replace the WL safety head, provided the valve has documented wire cutting and
sealing capabilities
A double-valve kill inlet connection shall be included in the rig-up. The kill line itself is
not required. The valves shall be capable of holding pressure in both directions. The
inner valve shall be flanged and have metal to metal seal. The production tree kill
wing valve may be used as the inner valve. Both valves shall be leak tested in the
direction of flow. A bleed off/pressure monitoring port between the valves or a tested
blind cap with bleed off/pressure monitoring port shall be installed. If neither of the
valves are remotely controlled, a check valve shall be installed whenever connecting
a kill line.
87
Barriers

Primary and Secondary Barriers and Shearing Devices
When rigging up on a well where the primary well barrier (SCSSV) has failed, the WL
safety head shall be installed and tested prior to continuing to R/U the remaining
wireline well control equipment. If another valve, e.g. a HMV (hydraulic master valve)
with documented wire cutting capability, is used as WL safety head, then both the
primary and secondary barriers shall be tested prior to rigging up.
The riser/lubricator length between the surface production tree and the WL safety
head shall be as short as possible. If the WL BOP is installed high in the R/U (e.g.
when rigging up the WL BOP on a drill floor) a separate WL safety head shall be
installed close to the surface production tree
The number of riser/lubricator connections between the surface production tree and
the WL BOP/ WL safety head are critical and should be kept to a minimum but of
sufficient length to encompass the tool string for the job t hand.
88
Barriers

All tools or components that the WL safety head may not be able to cut shall be
identified prior to start of operation. Contingency procedures for how to act if such
tools or components are positioned across the WL safety head in critical situations
should be available
The shear/seal ram in the LRP (lower riser package) is defined as the upper closure
device in the secondary well barrier whenever running wireline in completed SSWs
(subsea wells). The same shear/seal requirements therefore apply to the LRP
shear/seal ram as to the WL safety head
The shear/seal ram in the subsea drilling BOP is defined as the upper closure device
in the secondary well barrier whenever a subsea drilling BOP is installed when
running wireline in sub-sea wells. The same requirements therefore apply to the
drilling BOP shear/seal ram as to the WL safety head.
89
Barriers

Legend:
o BLR = WL BOP cable ram
o SLR = WL BOP slickline ram
o SS = WL safety head (shear/seal ram), rigged up close to Xmas tree
Rigging WL equipment above surface production tree
90
Barriers
Well barrier elements Comments
Primary well barrier
Casing element
Casing Below production packer
Production packer
Completion string Below the SCSSV
Secondary well barrier
Casing element Common WBE with primary well barrier
Casing Common WBE with primary well barrier
below production packer
Wellhead Including casing hanger and access lines
with valves
Tubing hanger Including tubing hanger and access lines
with valves
Surface production tree Closed master valve

91
Running WL through surface production tree
Barriers
Well barrier elements Comments
Primary well barrier
Casing element
Casing Below production packer
Production packer
Completion string
Tubing hanger
Surface production tree Including kill and PWVs
Wireline BOP Body only. Act as back up element to the wireline
stuffing box/grease head
Wireline lubricator
Wireline stuffing box/grease head
Secondary well barrier
Casing element Common WBE with primary well barrier
Casing Common WBE with primary well barrier below
production packer
Wellhead Including casing hanger and access lines with
valves
Tubing hanger Common WBE with primary well barrier
Surface production tree Common WBE with primary well barrier
Wireline safety head Common WBE with primary well barrier

Rigging WL equipment above surface production tree
Notes:
The WL safety head should be rigged up as close as possible to
the surface production tree
If a triple or quad wireline BOP including a safety head is used,
but is not installed as close as possible to the surface production
tree, then a separate WL safety head should be installed
Legend:
o BLR = WL BOP cable ram
o SLR = WL BOP slickline ram
o SSR = WL BOP cut valve, integrated in WL BOP
o SS = WL safety head (shear/seal ram) rigged up close to
Xmas tree
92
Barriers

Managing a Leak
Stuffing Box Leak (Slickline)
Hydrocarbons escaping from the stuffing box during slickline operations are
predominantly caused by packing wear. This should be quite an unusual situation and
is easily avoided by:
Correct packing nut setting (not over tightened)
Regular inspection of stuffing box packing and changing as required e.g.
every time wire is cut back
The packing nut compression is usually a small fraction of the maximum available.
Leaks are most often cured, by simply increasing the compression accordingly.
However, a rough or corroded cable can sometimes lead to excessive wear
If tightening the packing nut does not cure the leak at that point, particularly in oil
wells at moderate pressures, small leaks may be acceptable in order to pull out of
hole and make repairs. Alternatively, it may be acceptable to close one set of BOPs
and strip through them but stripping wire through a BOP should be considered a last
resort.
93

Managing a Leak
Stuffing Box Leak (Slickline)
Possible solution to a stuffing box leak that can’t be stopped conventionally:
oIf possible stop cable movement immediately or move tool string to a position
where the cable can be held stationary
o Close both sets of wireline BOP’s and bleed down lubricator pressure
oInflow test BOP’s to ensure they are sealing
o Open the bleed screw in the stuffing box to ensure that no pressure remains
o Unscrew the gland nut completely to expose the packing elements
o Clamp and cut the wire
o Withdraw the packing elements and remove them from the wire
oReam the new packing element with a piece of scored wire and place them on
the wire
oRejoin the wire
94

Managing a Leak
Grease injection Head Leak (Braided line)
A leak past the grease injection head is a common occurrence and is usually
associated with a lack of grease pressure
Normally this is due to simple operational factors which can be easily prevented and
remedied:
o Pulling out (or running in) too fast, particularly on the first run (dry cable)
o Setting the grease injection pressure too low
o An increase in wellhead pressure e.g. after perforating
o Not enough grease in the supply tank
o Restrictions in the grease supply system
o Low grease pump air supply pressure
95

Managing a Leak
Grease injection Head Leak (Braided line)
A leak could also be as a result of one or a combination of the following factors, with potentially
more serious consequences:
96
Grease type incompatible with conditions, e.g. ambient temperature or freezing due
gas escape
t
o
Contaminated grease becoming thinner
Incorrect flow tube insert ID or worn flow tubes
Insufficient flow tube length
Leaks are potentially serious in gas wells. If acted upon early enough, it may be possible to re
establish the grease seal in the following ways:
Increase grease injection pressure
RIH slowly to:
 Help the grease flow into the well rather than out
 Pass a well-greased section of wire through the flow tubes

Managing a Leak
Cable rupture (Braided line)
Breaking a single strand of a braided cable should be discovered by:
The winch operator noticing a dark spiral line in the cable caused by the
missing strand as the cable is winched in
Fluctuations in the line weight, caused by the lower end of the broken
strand striping back off the cable and bunching up inside the lubricator,
beneath the grease injection flow tube
A broken strand is more likely to occur after closing the BOP on the cable
Broken strands of wire can foul the BOPs causng them not to seal or be damaged
when actuated
If correctly functioning BOPs are not available, then the well will have to be killed
97

Managing a Leak
Hydraulic Master Valve Leak
The correct action to take when there is a hydraulic control line leak on a hydraulic
master valve is:
Lock out
Come out of hole
Secure well with master valve below the hydraulic valve
Repair the hydraulics
98

Managing a Leak
Hydraulic Control Line Leak
The opening and closing hydraulic pressures, closure mechanism integrity and other
features shall be verified according to the manufacturer’s operating manual prior to
valve installation
After installation of the SCSSV in the well, the SCSSV shall be closed under
minimum or no-flow conditions by operation of the surface control system
Verification of closure operation may be accomplished by pressure build-up/in-flow
test
The SCSSV can be tested for leakage by opening the surface valves to check for
flow. The SCSSV is reopened following the procedures in the manufacturer’s
operating manual
If there is a hydraulic control line leak on the hydraulic master valve, a surface
controlled subsurface valve (SCSSV) injection system should be used to pump
sealant into the hydraulic control line on the hydraulic master valve. Normal valve
operating pressure should be maintained
99

Managing a Leak
SCSSVs shall be tested by closure-mechanism operation to verify the rate of leakage
through the closure mechanism
Record the control pressure
Isolate the control system from the well to be tested
Shut the well in at the wellhead
Wait a minimum of 5 min. Check the control line for loss of pressure, which
may indicate a leak in the system
Bleed the control line pressure to zero to shut in the SCSSV. Close the
control line system and observe for pressure buildup, which may indicate a
faulty SCSSV system
100

Managing a Leak
Bleed the pressure off the wellhead to the lowest practical pressure and then shut in
the well at the wing or flow-line valve. When possible, bleed flow-line header pressure
down to or below wellhead pressure and observe the flow-line and wellhead for a
change in pressure, which would indicate a faulty surface valve. Any leaks through
the wing or flow-line valve shall be repaired before proceeding with the test
Conduct leakage test and document results. For gas wells, flow rates can be
computed from pressure build-up
For oil wells, the pressure build-up depends on the static fluid level and the amount of
gas in the oil. If the fluid level is below the SCSSV, the formulae for gas wells can be
used. If the fluid level is above the SCSSV, the leakage rate should be measured.
101

Managing a Leak
BOP Hydraulic Control Unit Malfunction
The correct action to take when a BOP hydraulic control malfunctions is to operate
the BOP manually to ensure safe operations
Manually operated BOP maintains control of the well in the event of a hydraulic
malfunction of BOP control unit
The accumulator pressure should always be monitored and maintained to prevent
BOP hydraulic control unit failure
102

A stuck toolstring is the one that can not be removed from the well (it can be moved
downward). It can become stuck for several and very different reason:
Sand, Paraffin or other deposited solids in wellbore or in tubing wall
Human error
Wire or tool failure
T
ools blown up hole
Collapsed tubing
The weight indicator will show a steady increase in tension.
The procedure to free the wire and the tool string depends greatly on the particular
situation.
103
My T
ool Is Stuck

Stuck While Pulling Out of the Hole:
Slack off to determine if toolstring is also stuck downward
If tool string is free downward, evaluate completion components
If tool string is also stuck downward, jar down mechanically
Work upward at different velocities increasing tension
Try applying drum break occasionally while pulling out immediately
before tagging the obstruction in an attempt to get movement in the tool
string downhole
104
My T
ool Is Stuck

After tagging obstruction while pulling out, run in hole few inches and
attempt to pick up vigorously
Although most probably it is open, attempt to fire the hydraulic jar
Evaluate if feasible to run to bottom and reset the hydraulic jar, pull
quickly and attempt to pass above obstruction using it
105
My T
ool Is Stuck

Stuck While Running In the Hole (tagging)
Pick up very slowly and observe if the mechanical jar is free and
working: it must be possible to observe hen it opens while pulling out of
hole
Jar up several times with the mechanical jars increasing velocity and
tension gradually
Run in hole and reset the hydraulic jar using the toolstring weight
Jar up several times with the hydraulic jars increasing the tension
gradually (if hydraulic jars are in the tool string)
106
My T
ool Is Stuck

My T
ool Is Stuck
If long-term jarring is required, it is strongly recommended that the unit be moved
farther from the well so the wire is not worked in the same place for too long. Working
the line in the same places across the pulleys of the unit and weight indicator will lead
to fatigue and ultimate wire failure.
Eventually there may come a time when it’s obvious no progress is being made.
Before the wire breaks, it’s a good idea to drop a cutter bar, remove the wire and
begin fishing on the rope socket of the stuck tool string.
The wire should never be cut with one of the valves on
the tree unless it’s designed to do so.
And never, “Pull it until somthin’ comes.”
Wire will break the same way pipe does – near the surface because that’s where the
highest loads are. More than likely, the wire would break at the stuffing box, the hay
pulley, or the counter head. And if it breaks at any on of these locations it’s very
possible that the wire would not fall far enough to clear the tree. Broken wire across
the tree is not a pleasant situation.
107

Rope Socket
Stem
Blind Box
If the tool string gets stuck in the hole and the jars are ineffective in freeing
the string or if the tool string gets blown up the hole it will become
necessary to cut and retrieve the wire and then begin fishing on the rope
socket of the stuck tool string.
We’ll first consider that the tool string is stuck, has not been blown up the
hole, and the wire is intact. The first order of business is to secure the well
and make ready for wire-cutting and fishing operations. The wireline valve
is closed on the wire and pressure bled from the lubricator.
The next step is to cut the wire and pull it from the hole leaving a clean
rope socket to fish on. If there is an unobstructed path to the rope socket
then a cutter bar can be dropped in hopes of cutting the wire at the rope
socket. A cutter bar (illustrated at right) is a simple tool made up of a rope
socket (spring, button, and or teardrop removed), a 5’ section of stem,
and a blind box.
My T
ool Is Stuck
108
Cutter Bar

Try Nipple
Blind Box
Rope Socket
The size of the blind box used should cover
about half of the rope socket similar to the
illustration at left. If the blind box is too large or
too small the wire will not be bent over and cut.
The wireline unit on location should contain a collection of “try nipples.” These are
short pieces (about 6” in length) of various sizes of tubing and are used to “get a
look” at how things might be down hole. The illustration above is what the operator is
looking for as far as selecting the right blind box to make up to the cutter bar.
109
Cutter Bar
My T
ool Is Stuck

110
Cutter Bar
Cutting Unbroken Wire
Procedure for Dropping the Cutter Bar
STEP 1 Shut-in the wireline valve
STEP 2 Bleed off the lubricator – raise the lubricator
STEP 3 Insert the cutter bar
STEP 4 Lower the lubricator and make up the quick union
STEP 5 Open the equalizing valve on the wireline valve
STEP 6 Open the rams and let the cutter bar fall
My T
ool Is Stuck

Make sure the line is not in tension – it should have some
slack in it. Give the cutter bar sufficient time to fall. Pick
up on the line to see if a cut has taken place. If not, work
the line for a few minutes to see if the crimped line parts.
If the line fails to come, make up and drop another cutter
bar.
Cutter Bar
Cutting Unbroken Wire - Dropping the Cutter Bar
111
Dropping additional cutter bars should not be looked at as
adding more potential junk in the hole. Cutter bars rarely
get stuck and are easy to retrieve once the wire has been
cut and removed.
The success of the cutter bar is significantly affected by
hole angle. It can be difficult to get a cut with a cutter bar
in a highly deviated well.
My T
ool Is Stuck

Cutting Unbroken Wire – Kinley Snepper
If a cutter bar is not available or one has been dropped
without success, another tool can be tried – that being
the Kinley Snepper.
The Snepper components spilt which allows them to be
disassembled and reassembled around the wire. The
Snepper is then inserted into the lubricator and dropped
like the cutter bar.
The Snepper contains beveled knife surfaces and a
slipper that move together when the cutter makes contact
with the rope socket or some other solid object. The tool
is designed to cut the wire on impact.
If the Snepper doesn’t cut the wire when dropped, a
cutter bar can be dropped on top of the Snepper.
Wire
Retaining Screw
Crimper Screw
Crimper
Slipper
Keeper Wire
Knife
112
Snepper
My T
ool Is Stuck

My T
ool Is Stuck
Cutting Unbroken Wire – Peak
The Peak Cutter is made up on the wire similar to the Kinley Snepper. It features a
rope socket head for easy fishing after the cut has been made and the wire retrieved.
The cutter is capable of cutting both slickline and braided line up to 5/16” without
explosives or hydraulics.
Rope Socket Fishing Neck
Wire Cutter Sub
113
Snepper

14
1
The Kinley Snepper is attached to the wire and uses it as a
guide to the rope socket. If all goes well the internal knives will
cut and crimp the wire allowing it and the snepper to be
retrieved in a single trip.
If the snepper fails to crimp the wire or falls off it can easily be
latched and fished on the next trip with a standard pulling tool.
If the snepper fails to cut the wire it may need a little help from
above. Assemble a cutter bar and drop it on top of the snepper.
This additional impact is usually sufficient to complete the
cutting of the wire.
NOTE: Multiple free-falling tools like the cutter bar and snepper
do not add complications to the fishing job as they are free and
not stuck, have clean fishing necks, and therefore are easily
retrieved once the wire is out of the way.
My T
ool Is Stuck
Snepper

115
Mandrel
Upper Cutter
Collet Retainer
Lower Cutter
Guide
Set Screw
Shear Pin
Split Ring
A means of cutting broken wire in the hole is with a Side Wall
Cutter. However, this is not a tool for the faint-of-heart. It’s
designed to do what every slickline operator is told not to do:
“Never run anything passed the top of broken wire. The
broken wire will wrap around the fishing string and get
stuck – you now have two stuck tool strings. Good luck
getting’ that out.”
C Running Tool
Sidewall Cutter
When the desired
sudden lowering of
depth
the
has been reached a
tool string causes the
mandrel to wedge the overlapping cutters against
the tubing wall and trapping the wire to be cut.
Downward jarring cuts the wire and shears the pin
in the C Running T
ool.
The tool string is slowly pulled out of the hole and
a wire finder followed by a wire grab are run to
retrieve the wire. After the wire is pulled from the
hole the side wall cutter is retrieved.
Sidewall Cutter
Broken Wire

Broken Wire
At right is depicted the sidewall cutter after having cut the wire. Under no
circumstances should attempts be made to retrieve the side wall
cutter before the cut wire has been removed from the hole.
Additionally, it would be a good idea to run tubular jars in the string used to
convey the side wall cutter. Running spang jars would be too risky given
the high potential of having the end of the wire getting caught up in the
jars.
The sidewall cutter should not be run by an inexperienced operator.
Additionally, the operator should be “riding the wire” by hand so he
can detect the subtleties of downhole conditions which no weight
indicator can show.
Sidewall Cutter
116

Broken Wire
Broken Wireline
The chart below can be used as a guide to estimate how far various size wire will fall
in various tubing ID’s. Contrary to popular belief, it doesn’t fall very far.
Slickline Breaks and Falls Downhole
Tubing Size Slickline OD Estimated Fall (Feet)
2 3/8 .092 3 - 6
2 7/8 .092 3 - 6
3 ½ .092 8 – 10
3 ½ .108 8 – 10
3 ½ 3/16 8 – 12
4 ½ .092 8 – 10
4 ½ .108 8 – 10
4 ½ 3/16 8 – 12
5 ½ .092 10 – 14
5 ½ .108 10 – 14
5 ½ 3/16 12 – 16
7 .108 & 3/16 14 - 16 117

Broken Wire
This tool, aptly named, is designed to find the top of the broken
wire in the tubing and to “ball it up.” Once in a ball, the wire is
easier for a wire grab or wire spear to latch (actually get tangled
in) the wire.
The basic wire finder is made of a relatively thin, flexible metal
and is slightly flared at the end for the purpose of “hugging” the
wall of the tubing and guiding the wire into the finder.
Wire Finder
Care must be taken when running this tool as it is possible to
bypass the top of the wire. When this happens there may be no
indication that the wire has been located so the operator will pull the
tools to a depth suspected to be above the top of the wire. While
pulling up and through the bypassed wire it is possible for the wire to
become bunched around and on top of the finder or in and around
spang jars (run tubular jars when attempting to find the top of the
wire). Naturally this can make it somewhat difficult to retrieve and
may even add to the fishing job.
Wire Finder
118

Broken Wire
When running a tool string in search of the top of broken wire
it’s probably worth considering placing a length of “spacer
stem” between the wire finder and the jars to minimize the
possibility of the wire becoming tangled in the jars.
A good precaution is to make up a rope socket to the wire
finder and latch the rope socket with a shear-up pulling tool (a
“baited” string). If the wire finder gets stuck in wire, the pulling
tool pin can be sheared and the tool string retrieved. This also
leaves a “clean” fishing profile for the next tool string to latch
on to.
Spacer Stem
119
Baited Wire Finder
Tubular Jars
Wire Finder

120
Broken Wire
Fishing Neck
Shear Pin
Grub Screw
Housing
Wire Finder
The Petroline Wire Finder is very similar to the
wire finder on the previous page. The wire
finder is inserted and pinned in the housing
and the assembly will stop at the first nipple
encountered. Downward jarring shears the pin
allowing the wire finder to be released and
then lowered to the expected depth of the wire.
The tool is then worked in a reciprocating
fashion to ball up the wire. When retrieved, it
enters the housing and both are pulled from
the well.
Wire Finder
Petroline Wire Finder

Broken Wire
Running Sleeve
Shear Pin
No-Go Shoulder
Running Position
Expanded
Illustrated here is one of the many
expandable wire finders on the market. The
benefit of an expandable wire finder is its
ability to rub the tubing wall which serves to
guide the broken wire into the finder.
121
One of the major problems encountered with
expandable wire finders is difficulty getting
through tubing nipples. This tool incorporates
individual adjustable legs that work in
conjunction with adjoining webs made from
spring steel plates allowing the tool to function
at a very wide range of expansion. This
flexibility enables the tool to go through the
smallest of restrictions and then open out into
large diameter tubing.
Expandable Wire Finder by Wireline Engineering, Ltd.
Wire Finder

122
Broken Wire
The wire finder is made up and pinned
to its carrier sleeve with a no go
and
shoulder, which is then run
positioned in a suitable restriction or
nipple in the well.
Running Position
Downward jarring will shear the retaining pins
and allow the finder to move down through
the sleeve and expand out into the tubing
below.
When returning back out of the well, the
finder will totally collapse back into the sleeve
and pick it up for recovery at surface.
Wire Finder

Broken Wire
Combination Wire Finder & Grab
Wire locating position Retrieving Position
This tool, manufactured by Bowen, incorporates a flexible
skirt which rubs against the tubing wall thus guiding the
wire into the grab.
Care should be taken when passing through tubing
nipples – the fingers can be damaged if excessive or
rough jarring is used to get through the nipple.
Anytime a wire grab of any sort is used, it’s
best to run this in conjunction with a rope
socket and pulling tool combination. This
provides the ability of getting off the wire
finder if it get caught in wire and can ’ t
release the wire.
123

Broken Wire
Conventional Wire Grabs
Illustrated here are of three different types of wire grabs.
The first two, similar in design and construction, are
intended to be run into a “bundle” of wire following a
run or two with a wire finder.
If the conventional wire grab fails to secure the wire the
wire spear may prove to be a successful alternative.
Wire Spear
Wire Grabs & Wire Spear
124

Broken Wire
Pulling Tool
Rope Socket
Wire Grab
When the tool string is pulled from the well wire will be hanging
from below the wire grab extending beyond the tree making it
impossible to shut-in the well. The wire must then be stripped from
the hole. To accomplish this the following steps are taken:
Shut-in the wireline valve and bleed pressure from the
lubricator
Raise the lubricator several feet above the wireline valve and
secure it
Install a bar clamp on the wire
Wire Grabs & Wire Spear
Stem
125

126
Broken Wire
Bolt
Flat Washer
Nut
Stripping the wire from the hole:
A bar clamp is made up of two plates of steel about ¼” thick that are drilled and can
be bolted together. The clamp is installed across the top quick union box of the
wireline valve and around the wire and bolted together tightly to support the wire
remaining in the hole. Do not strip wire through the closed rams on the BOP!!
Closed Rams
Bar Clamp
Wireline
The Bar Clamp
Slickline Stripping

Broken Wire
The “Chicago” wireline clamp is another means of securing the wire at the surface
during fishing operations. It is available in both braided and slickline models
accommodating slickline sizes from .092” to .125” and braided line from 3/16” to
5/16”. As seen in the illustration it is equipped with load-bearing shackles to which
wither rope or cable can be attached. The jaws are lined with bronze to prevent
wireline damage when the jaws are engaged.
Slickline Stripping
The Bar Clamp 127

Broken Wire
A blanking cap is used as the main body, the
needle valve removed and replaced with the
wire stripper. The stripper serves the same
function as a stuffing box.
Stuffing Box Packing
Blanking Cap
Line Stripper
Packing Nut
After installing the bar clamp, the lubricator can be laid down and wire pulled
from it.
Set the lubricator and stuffing box aside.
Cut the wire just below the wire grab and run this through a wire stripper.
The Wire Stripper 128
Slickline Stripping

Broken Wire
Slickline Stripping
Splice the wire removed from the wire grab to the wire extending above the bar clamp with
the button of a rope socket.
Rig up a sheave overhead and run the wire through the sheave making sure the splice
button is passed the sheave (the wireline unit side of the sheave).
Remove the wire from the wireline unit counter head and then with the unit, take out the
slack in the line. Spool wire onto the unit until the button is on the spool. Thread the wire
back through the counter so the retrieved length can be measured.
Slowly remove the bar clamp and make the stripper onto the wireline valve.
Open the equalizing valve on the wireline valve and check for leaks in the stripper – the
packing nut may have to be tightened.
Pull the wire from the well.
129

Broken Wire
The stripper rigged up to the wireline valve
is pictured at right. As already stated,
once the wireline valve is opened check
the stripper for leaks and tighten the
packing nut as needed.
Strip the wire through the stripper onto the
unit. At some point the wire will begin
being blown from the well because the
force on the wire is greater than the total
weight of the wire remaining in the well.
Stuffing Box Packing
Blanking Cap
Line Stripper
Packing Nut
At this point, let the wire get blown from the
well making sure all personnel are clear of
the area and then shut-in the well after the
wire has been blown completely free.
139
Slickline Stripping

Broken Wire
Here is an example of a rig-up for stripping wire from the hole. The lubricator, no longer
needed, has to be laid aside a safe distance from the operation. The wire should be
threaded through the counter head to measure the length of wire retrieved for the purpose
of determining if any wire remains in the hole.
After all the wire has been stripped, a fishing tool string is assembled, the lubricator is
picked up and fishing of the stuck tool string can begin.
Sheave
131
Wire Stripper
Slickline Stripping

132
T
ool String Blow Up the Hole
Go-Devil
Occasionally a string of tools can get blown up the hole. This
usually happens when an unresolved differential exists across
a plug, safety valve, or some other flow control device.
If the tools get blown up the hole the tool string will often by-
pass the wire and get tangled in the wire. This results in no
“clean” access to the rope socket so dropping a cutter bar
would be useless (as seen in the illustration at right).
Therefore, a rope socket of sorts, will have to be installed
(dropped) into the well so the wire can be cut and retrieved.
The remaining wire has to be fished along with the tool string.
The tool to be dropped that provides the rope socket needed
is the Go-Devil.

133
Filler Plate
Retaining Pins
The Go-Devil is comprised of two parts: the
body and inner sleeve, sometimes called the
filler plate. The filler plate is removed by
removing the retaining pins. The wire is then
inserted into a slot machined over the length of
the Go-Devil. The filler plate is reinstalled and
pinned in place.
The Go-Devil is inserted into the lubricator in the
same fashion as described for the Cutter Bar.
The lubricator is made up and the equalizing
valve on the wireline valve is opened. The
wireline valve is then opened and the Go-Devil
is allowed to fall. This won’t usually cut the wire
but does provide a rope socket-like surface for a
Cutter Bar to act on. Shown at right is a “roller”
version used in highly deviated wells.
Go-Devil
T
ool String Blow Up the Hole
Go-Devil

34
1
Use of the Go-Devil
Shown here are two instances
when the Go-Devil would be used.
In both cases the rope socket of
the fish is inaccessible for a cutter
bar. The Go-Devil provides the
needed rope socket profile onto
which a cutter bar can be dropped.
After the wire is cut and retrieved,
fishing for the tool string can begin.
Tool string buried in sand
Tool string blown up the hole
Tool String Blown Up the Hole

An “interesting” situation develops when a wireline operator has successfully latched
and retrieved a fish only to find the tree cannot be shut-in due to inadequate lubricator
length.
Should this happen:
Close the rams and bleed pressure from the lubricator
Clamp the wire with a bar clamp and cut the wire a couple of feet above the
clamp
Add an additional section of lubricator, run the wire from the unit through the
stuffing box and lubricator and then splice this to the wire above the clamp
Make up the lubricator, equalize and re-open the wireline valve, and then
pull the tool string up into the lubricator – the well can then be shut-in
Another option:
If the fish has a lock mandrel on the bottom of the tool string, and if it can be located
in a nipple, and if the fishing tool used to latch the fish can be made to release the
fish, then the fish can be lowered to a nipple and left there. The fishing string can
then be retrieved from the well after extra sections of lubricator added.
135

Additional considerations:
Have a plan of attack – nothing makes a fishing job go bad more than
haphazard shots in the dark with this tool or that. Don’t go in the hole with
tools that “might work if we’re lucky.” Get the appropriate tools on location
136
– the fish isn’t going anywhere.
Have additional rubber goods for the lubricator, stuffing box, and wireline
valve.
Make sure the unit can be secured in the event extended heavy jarring is
required.
If oil jars are to be used, have at least 2 sets of jars on location and ample
spare parts.
If additional sections of lubricator are to be used, get additional help in
handling the additional iron.
Give some serious thought to calibrating the weight indicator

Importance of Gauge Runs Before Other Downhole Operations
A gauge cutter is a tool with a round, open-ended bottom which
is milled to an accurate size. Large openings above the bottom
of the tool allow for fluid bypass while running in the hole.
137
Gauge Cutters
surface equipment
are run in hole before running sub
Gauge Cutters are used to check if sub surface equipment can
pass freely thru tubing and there are no obstructions and to
locate top of nipple

Importance of Gauge Runs Before Other Downhole Operations
A gauge ring that is just undersized will allow the operator to ensure clear tubing
down to the deepest projected working depth
A gauge ring can also be used to remove light paraffin that may have built up in the
tubing
The bottom of Gauge Cutter is suitable to cut paraffin, scale and any other obstacles
in tubing
138

Safety Valve Integrity
It is important to ensure the downhole safety valve is held open and monitored
throughout the operation:
The downhole safety valve is not a classed barrier. It acts as a failsafe to
prevent the uncontrolled release of reservoir fluids in the event of a worst-
case scenario surface disaster.
These valves are commonly uni-directional flapper valves which open
downwards such that the flow of wellbore fluids tries to push it shut while
pressure from the surface pushes it open.
139

Safety Valve Integrity
When closed, it isolates the reservoir fluids from the surface.
Mostly controlled hydraulically. When hydraulic pressure is applied down a
control line, the hydraulic pressure forces a sleeve within the valve to slide
downwards.
140

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