Halliburton_SL_Man.pdf

Slickline Training
Prerequisite Manual
Introduction
Section I Slickline Services Introduction
Section II Toolstring Components
Section III Auxiliary Service Tools
Section IV Pulling Tools
Section V Tubing Set Flow Controls
Section VI X-Line Equipment
Section VII Related X-Line Equipment
Section VIII Circulating Devices & Service Tools
Section IX Gas Lift Equipment & Service Tools
Section X Slickline Fishing
Section XI Calculations
Optional Profile Selective Equipment

1 Slickline
Introduction
Table of Contents
Welcome ....................................................................................................................................................... 3
Our Vision and Core Beliefs......................................................................................................................... 4
Our Mission .................................................................................................................................................. 5
Safety ............................................................................................................................................................ 6
"one is too many" ...................................................................................................................................... 6
History........................................................................................................................................................... 7
How it all began ........................................................................................................................................ 7
Success brought rapid growth ................................................................................................................... 7
Innovation is the Key ................................................................................................................................ 7
Halliburton Wireline and Perforating Services............................................................................................. 9
Slickline success: The art of being the best............................................................................................... 9

2 Slickline
Introduction
Use for Section notes…

3 Slickline
Introduction
Welcome
First, we want to welcome you to Halliburton.
Halliburton provides many opportunities for personal development and travel.
As an oilfield service company; Halliburton has developed several different services to assist
our customer through the life of the well. We have services which start at the drilling phase
of oil or gas well development and extend those services through production to a point
when the well is ready to be plugged and abandoned.
Slickline Services may be called to assist the customer during any phase of the life of the
well. Therefore the Slickline PSL will provide you with lots of opportunity for learning and
development in the oil and gas industry.
This manual is designed with the intent to assist you with your competency development so
that you can advance in the Slickline Services PSL.
Disclaimer
The purpose of this manual IS NOT to serve as a guide and reference for an inexperienced
person to attempt the performance of slickline service and maintenance work.
Since all equipment is subject to engineering design changes which may alter the function
and/or part number of that equipment, the engineering data in this manual SHOULD NOT be
considered to be totally current and correct. Therefore the part numbers and engineering
data in this manual are intended only to facilitate training projects.
This manual was revised May 2009.
The information in this manual is proprietary information to Halliburton. The manual may
not be reproduced without the written consent of Halliburton.
This publication is intended for the internal use of Halliburton Employees. Halliburton
reserves the right to change equipment configuration, materials, specifications, operating
procedures and instructions without notice; Halliburton assumes no liability or responsibility
for the consequences of use of this publication by persons other than Halliburton employees
These instructions describe the desired results from use of Halliburton equipment, but such
results are not guaranteed. Operation of equipment is subject to mechanical limitations and
Halliburton shall only be liable for its merchandise and service as set forth in its general
terms and conditions. The operating instructions and procedures described in this
publication pertain to use of equipment under normal operating conditions.
This publication may contain information taken directly from the catalogues of Halliburton's
outside suppliers. Halliburton has not and cannot verify the accuracy of such information or
that such information is the most current information available from the supplier.
Halliburton accepts no liability or responsibility for the consequences of the use of such
information and recommends, with regard to equipment not manufactured by Halliburton,
that the supplier be contacted directly for current information and specifications

4 Slickline
Introduction
Our Vision and Core Beliefs
Vision – it defines who we are as a company and what we aspire to be and gives us an
image of what success will look like.
Halliburton’s vision is:
To be the preferred upstream service company for the development of global oil and gas
assets.
A preferred upstream service company:
 Maintains long-term sustainable customer relationships that meet the individual
differences of a global client base
 Understands that the reservoir is the source of all value, and it has the resources and
expertise to provide the right solutions
 Is a credible, reliable service provider that matches actions to words
 Is an effective innovator, applying technology that delivers results
 Is balanced geographically and in its portfolio offerings in order to serve and support
its customers
 Has a robust global supply chain that ensures a flow of critical supplies at a
competitive cost
 Epitomizes excellence in digital connectivity, using technology to link its global
network to maximize results.
Core Beliefs – they are our corporate DNA, the foundation for how we relate to each other
and every individual and entity with whom we interact.
Core Beliefs
- Safety leadership
- Ethical behavior
- Operational excellence
- Technology innovation

5 Slickline
Introduction
Our Mission
Mission - it identifies what an organization does, why it does it and for whom.
Halliburton’s mission is:
To create sustainable value by delivering outstanding products, services and Digital Asset
solutions that help our customers succeed by:
 Maximizing production and recovery
 Realizing reserves from difficult environments
 Improving operational efficiency.
Our motto is:
Unleash the Energy!

6 Slickline
Introduction
Safety
"one is too many"
In 2006, Halliburton’s HSE incident rate showed a disquieting rise. It’s an extraordinarily
serious matter—for a host of personal and professional reasons. And those reasons range
from loss of life to loss of significant business to loss of a sterling HSE reputation.
In HSE incidents worldwide, Halliburton is aiming for nothing less than zero. Zero fatalities.
Zero injuries. Zero environmental incidents. Zero health hazards. Zero regulator citations.
Zero anything that negatively impacts our stringent HSE policies. That’s why
one is too many
What is this one we’re talking about?
one unbuckled seat belt is too many
one flicked cigarette is too many
one frayed cable is too many
one highway cell phone call is too many
one outdated fire extinguisher is too many
one speeding incident is too many
and on and on and on and on………….
What does it take these days to effectively get our HSE message across?
It starts with a strong, bold, memorable rallying cry.
Something that instantly gets people talking, thinking, reacting. Something that rapidly
becomes part of our everyday conversations.
one is too many is unexpected in that, in everything else in life except HSE incidents, one is
not enough. This theme is effective not just because it is striking in its unexpected logic, but
because it makes perfect sense. It not only makes for a terrific hard hat sticker, bumper
sticker or office/trailer poster, but it is the perfect way to start any safety discussion or any
presentation on HSE.

7 Slickline
Introduction
History
How it all began
Halliburton’s Slickline Service Line (PSL) can trace its roots
back to the late twenties and the innovative genius of one
man, Herbert C. Otis, Sr. It was during that time that an
oil company offered to pay $1,000 to any man who could
remove and replace a broken valve on a high-pressure gas
well. The offer had stood for over a year when, despite the
dangers involved, Otis stepped forward to try.
Using a jury-rigged, drill-and-ratchet assembly, Otis
succeeded in drilling out the fouled disc on the valve. At
the same time, he put another valve on top of the broken
one and tied the new valve into the production line. It
worked and the gas well began flowing.
Success brought rapid growth
Tractor-mounteddrawworks,
typical of oilfield equipment
during the twenties.
Soon, Otis was swamped with requests for consultation by other companies. As time went
by, he developed other innovative ways to service oil and gas wells under high pressure.
Realizing the potential for such services, Otis formed his own company, called the Southern
States Company. Potential soon gave way to reality and the fledgling company grew rapidly.
In 1935, the organization was reincorporated under the name Otis Pressure Control, Inc. In
1957, the name changed again to Otis Engineering Corporation to more accurately reflect
the scope of the growing organization.
Innovation is the Key
Over the years, Otis Engineering Corporation continued to
innovate new tools and techniques to meet the changing
needs of the oilfield.
Products like the Tubing Safety Valve were developed to
control the higher pressures encountered as wells were
drilled steadily deeper. And for dual production zone wells,
the Side Door Choke was a major contribution towards
developing effective production zone stimulation.
The list of innovations could be recited on and on to
include such industry bywords as the Storm Choke, the
Bottom Hole Regulator and more recently, the Perma-
Trieve Packer.
The Otis "sidewinder" wireline
unit was state-of-the-art in its
day.

8 Slickline
Introduction
Mr. Otis alone accumulated over 50 patents and was co-
inventor of numerous other oil well tools. In 1957, he was
named the first recipient of the John Franklin Carl award,
given by the American Society of Petroleum Engineers for
outstanding contributions to petroleum engineering.
Otis Engineering Corporation became a subsidiary of the
Halliburton Company in 1959 and continues to thrive in this
capacity today. Spanning over half a century, the growth of
wireline service largely parallels the growth of the oil and
gas industry in the 20th century. Though blessed with
unbounded expansion, innovation remains the byword at
the Wireline PSL, a legacy of the founder.
In 1993 Halliburton integrated all of its oilfield services into
one company call Halliburton Energy Services, later to be
called Halliburton.
In 2006 Halliburton reorganized these services into two
basic divisions, the Completions and Production Division
and the Drilling and Evaluation Division. It was during this
reorganization that Slickline Services became an integrated
part of the Wireline and Perforating PSL.
Running an Otis casing caliper
around the late forties.
Today Halliburton has Slickline Service operations in over 40 countries around the world
with over 800 employees.

9 Slickline
Introduction
Halliburton Wireline and Perforating Services
Slickline success: The art of being the best
The range of tasks that Halliburton employees perform in the oil field has earned them a
variety of titles, from technician to advisor to field professional. However, it is rare for an
employee to be called an artist. Enter the Halliburton Wireline and Perforating Services
(WPS) product service line’s Slickline team. A superior combination of expertise, credibility
and a history of industry success set WPS apart from its competitors in this ever-changing
and critical area of subsurface service – making Halliburton the established market leader
in slickline technology and services.
Approximately the circumference of a wire coat hanger, slickline provides the most
innovative and efficient means for well intervention and completion. WPS’ expert slickline
specialists manipulate the slickline and a number of downhole tools, from several hundred
feet to several miles below the surface, to perform critical subsurface tasks using only depth
and line tension as their guide – a formidable task that takes years of experience to master.
The selective placement and strategic retrieval of wellbore hardware require precision
execution and innovation, and, when coupled with the fact that each inoperable moment
could lead to substantial losses in time and money, operator experience becomes the most
critical component to performing slickline operations safely and efficiently.
“Slickline operation is more than just a skill – it’s an art,” said David Larimore, Slickline
global product manager, WPS. “WPS’ team of experienced slickline technicians are the best
and the brightest – combining creativity, innovation, expertise and patience to produce
efficient and reliable results.”
As WPS continues to expand its slickline capabilities, customers can see the added value
that the PSL’s expert professionals and innovative tools bring to their projects. For example,
WPS’ downhole power unit (DPU) combines with slickline services to offer operators a
nonexplosive, precise, high-technology solution to the setting and retrieving of wellbore
devices.
Further, WPS’ unique slickline development program ensures that the PSL’s track record in
operational excellence and expertise continues. The program allows the industry’s
preeminent specialists to pass along their knowledge, skills and leadership to the next
generation of slickline and completion experts.
“Because of their unmatched skill and knowledge, WPS’ slickline operators are the preferred
choice when it comes to providing well intervention solutions for complex, high-profile
completions,” Larimore said. “This illustrates the industry’s respect for WPS’ slickline
employees, the value
they bring to our Company and the esteem they receive around the world.
“In today’s world of increasingly deep and more-complex well completions, the tasks that
slickline specialists are assigned are anything but simple, and the artistry they employ is
nothing short of remarkable. We applaud our world-class slickline personnel for the creative
ways they solve problems miles below the surface.”
HalWorld Today August 13, 2008 (David Larimore)

PRODUCT SERVICE LINE NUMBER
(OCCUPATIONAL GROUP CODE)
SERVICE EQUIPMENT
Surface Use
Part No.
Prefix
Part No.
Prefix
Pack-off Equipment. ..................................................13
Plugs. ........................................................................21
Lubricator. ................................................................. 46
Quick Unions............................................................. 46
Stuffing Box............................................................... 46
Wireline Reel............................................................. 46
Subsurface Use
Bailers. .................................................................. 50
Blind Box. .................................................................. 44
Circulating Plugs........................................................ 15
Cutter, Wireline.......................................................... 47
Extension Hanger...................................................... 31
Extractor.................................................................... 48
Gauge, Wireline Tubing............................................. 65
Go-Devil, Wireline...................................................... 47
Grab, Wireline............................................................ 52
Impression Tool......................................................... 52
Jars, Wireline............................................................. 44
Knuckle Joint & Jars.................................................. 45
Locator Tools............................................................. 46
Overshots.................................................................. 212
Perforators................................................................. 62
Positioning Tools. ...................................................... 42
Prongs, Equalizing..................................................... 49
Pulling Tools.............................................................. 40
Running Tools. .......................................................... 41
Sockets, Fishing. ....................................................... 52
Sockets, Wireline....................................................... 43
Stem, Wireline........................................................... 44
Stops, Perforator.................................................... 62 63
Swage Tool. .............................................................. 65
Telescoping Joint....................................................... 31
Test Tool, Tubing....................................................... 14
Wireline. .................................................................... 92
PRE-COMPLETION,
REGULAR MERCHANDISE COMMODITY
Blast Nipples.............................................................. 11
Flow Couplings.......................................................... 11
Nipples, Bypass......................................................... 11
Nipples, Drill Pipe. ..................................................... 11
Nipples, Landing........................................................ 11
Nipples, Packing........................................................ 11
Nipples, Side-Door. ................................................... 11
Sliding Side-Door®.................................................... 121
POST-COMPLETION,
REGULAR MERCHANDISE COMMODITY
Check Valve. ............................................................. 21
Dual Flow Choke....................................................... 21
Elements. .................................................................. 10
Equalizing Valves. ..................................................... 10
16
20
21
24
321
Mandrels.................................................................... 10
16
310
Pump Equipment.......................................................25
28
Regulators. ................................................................23
123
Separation Tools........................................................24
Standing Valves.........................................................14
Subsurface Safety Valve. ..........................................22
Tubing Stop. ..............................................................13
33
GAS LIFT COMMODITY
Gas Lift Nipple...........................................................121
Gas Lift Pack-off Equipment. .....................................13
33
Gas Lift Valves...........................................................211
221
Intermitters.................................................................270
Motor Valves..............................................................270
PACKER COMMODITY
Bridge Plugs. .............................................................312
Drillable Packer Accessories. ....................................13
212
Hydraulic Packers......................................................12
Sand Screens............................................................121
Mechanical Packers...................................................12
312
Telescoping Joints.....................................................31
Tubing Hold-down. ....................................................12
Tubing Seal Dividers..................................................212
Tubing Set Packers. ..................................................212
Twin Flow Conversion Units. .....................................212
Wireline-Set Drillable Packers. ..................................212
SURFACE SAFETY VALVE COMMODITY
Cylinder Assembly.....................................................70
170
Gate Valve Bodies.....................................................93
Lower Stem Kits. .......................................................70
Manifolds. ..................................................................22
71
Pilots..........................................................................70
Surface Safety Valves. ..............................................77
MISCELLANEOUS MERCHANDISE
Balls...........................................................................93
Bearings. ...................................................................93
Gaskets. ....................................................................93
O-Rings. ....................................................................91
Packing Cups. ...........................................................91
Pup Joints..................................................................92
Elements....................................................................91
Springs. .....................................................................90
Tubing Couplings.......................................................92
Tubing Swedges........................................................92
Vee-Packing..............................................................91
PUMPDOWN COMPLETION EQUIPMENT
Part Number Prefix - 500 series

SECTION I
SLICKLINE SURFACE EQUIPMENT

1 Slickline
© 2009, Halliburton
Slickline Introduction to Units,
Surface Equipment and Wire
Table of Contents
Introduction................................................................................................................................................... 3
Early Days................................................................................................................................................. 3
Slickline Units............................................................................................................................................... 5
Principles of Operation Open-Loop Hydraulic Slickline System (Chain Drive Units)................................. 6
Advantages................................................................................................................................................ 6
System Description.................................................................................................................................... 6
Principles of Operation Closed-Loop Hydraulic Slickline System (Direct-Drive Units) ............................. 7
Advantages................................................................................................................................................ 7
General ...................................................................................................................................................... 7
Reel Direction and Speed.......................................................................................................................... 7
Wire Tension............................................................................................................................................. 8
Controls for Drive Pump and Reel Motor................................................................................................. 9
Reel Braking.............................................................................................................................................. 9
Hydraulic Levelwind................................................................................................................................. 9
Spool-Off Accessory............................................................................................................................... 10
Filtration.................................................................................................................................................. 10
Heat Exchanger ....................................................................................................................................... 10
Surface Pressure Control Equipment .......................................................................................................... 11
Stuffing Box and Slickline Grease Head................................................................................................. 12
Liquid Chamber/Chemical Injection Sub................................................................................................ 13
Lubricator Purge Valve ........................................................................................................................... 14
Tool Catcher............................................................................................................................................ 14
Tool Trap................................................................................................................................................. 14
Lubricator Sections.................................................................................................................................. 15
Wireline Valves....................................................................................................................................... 15
Lubricator Ball Valves ............................................................................................................................ 15
Flanged Tree Connections....................................................................................................................... 16
Pressure Control Consoles....................................................................................................................... 16
Corrosion Resistant Alloy (CRA) Valves and Equipment ...................................................................... 16
Design Verification and Inspection Maintenance Procedures................................................................. 16
Design Verification Certification ............................................................................................................ 17
Inspection Maintenance Certification...................................................................................................... 17
Lubricator Marking Standard .................................................................................................................. 17
Conclusions............................................................................................................................................. 18

2 Slickline
Slickline Introduction
Wire Mechanical Capabilities .................................................................................................................... 19
Slickline Wire.......................................................................................................................................... 19
Braided Wireline ..................................................................................................................................... 19
Wireline – Breaking Strengths (lbs) .................................................................................................... 20
Braided Wireline – Breaking Strengths (lbs)....................................................................................... 20
Wireline Inspections on Location ............................................................................................................... 21
Logs......................................................................................................................................................... 21
Visual Inspection..................................................................................................................................... 21
Wireline Knot Test .................................................................................................................................. 21
Coil Test .................................................................................................................................................. 22
API 9A Torsion (Twist) Test................................................................................................................... 22
Test Procedures:................................................................................................................................... 22
Eddy Current Inspection Device ............................................................................................................. 23
Wireline Shear Force Analysis................................................................................................................ 24
Slick Wireline...................................................................................................................................... 24
Braided Wireline.................................................................................................................................. 24
Written Project ........................................................................................................................................ 25
Hands-On Projects................................................................................................................................... 26

3 Slickline
Introduction
Throughout the years, the petroleum industry
has called on Halliburton to help it find the
answer to many extremely complicated, difficult
and costly production problems; problems which
at the time were considered out of the range on
normal service company work, but problems
which needed a solution. It was generally
known that Halliburton wasn’t afraid to tackle
and problems which had to do with subsurface
flow control. This cooperative attitude, on the
part of Halliburton, resulted in an extremely
close association between itself and its
customers. And today provides the purchasers of
Slickline Services a variety of advanced features
not available from any other slickline service
company in the field today – features that are
synonymous with the name of Halliburton and
every service job it performs for its customers.
Halliburton development of slickline production
equipment is helping to simplify and reduce well
maintenance cost throughout the world.
Operators are saving money by performing a
variety of well servicing work downhole, under
pressure, using slickline methods, without
killing the well. They find “slickline” gives
them a wide range of completion possibilities to
solve most current well maintenance
requirements and to anticipate future
maintenance as well conditions change during
the life of their wells.
Slickline Service is a method whereby various
well maintenance, remedial controls and safety
functions are accomplished under pressure in the
wellbore below the earth’s surface. This is done
by “running” and “pulling” tools and equipment
into and out of the wellbore by using small
diameter slickline mounted on a powered reel at
the surface.
Some of the functions which are accomplished
by using slickline are: installing and retrieving
safety valves, plugs and pressure regulators;
removing sand and paraffin from the wellbore,
running instruments to record bottom-hole
pressure and temperature and installing or
retrieving gas lift valves.
Most of these functions require that metal pins
be sheared in the running and/or pulling tools
used to install or retrieve the control devices
from the well. This is accomplished by creating
jarring impacts to the shear pins by manipulation
of the slickline and tool string.
Recent advanced technology development in
depth measurement and downhole slickline tools
have expanded slickline services to include:
Memory Production Logging, real-time collar
logging in tubing and casing, setting packers and
bridge plugs on depth, tubing cutting, production
perforating, and recording job activities for
quality assurance. In addition to that methods
have been developed to inspect and track the
quality of the wire. All of this is done in an
effort to enhance performance and reduce cost to
our customers.
Early Days
The evolution of the surface equipment for
slickline operations has been closely associated
with new methods and tools for use in well
completions. In connection with the oil and gas
well drilling, wire has been used since the early
days of the industry. The uses of slick wire lines
included depth determinations, crooked-hole

4 Slickline
tests, temperature and pressure surveys, paraffin
cutting, following the plug in cementing
operations.
A discussion of the surface equipment must, of
necessity, be quite broad. As the first step in
this discussion the actual mobile equipment
must be mentioned.
In the early day of slickline operations, few
problems in mobile equipment presented
themselves. Trucks with winches, portable skid-
mounted equipment, and even fixed units
mounted at strategic locations provided a means
of handling most slickline problems and
procedures.
As the oil field moved to more remote locations
the slickline reel units were mounted to the then
existing equipment to provide mobility to
service the wells.
Probably among the earliest prime movers was
the human being with a small hand crank and a
spool containing a short length of slickline wire.
When the slickline wire proved a practical
means of depth determination and the need for
greater depth runs developed, the prime mover
needed changing. Devices for applying
mechanical power to the spool were devised.
These might include such prime movers as:
Steam or air motors, belts from spinning
catheads, gas or diesel engines with gears and
belts or chain drives, and then the use of
hydraulic and electric motors.
The earliest wire or measuring lines used in
connection with oil wells was flat steel tapes
with marked or stamped figures similar to a
surveyor’s tape. They were used for accurately
measuring well depths. As well depths
increased, getting tapes of sufficient length
became a problem. Stretching of the calibrated
tapes under loads made it necessary to correct
the readings to get accurate depths. When the
measuring line had to be run in a well under
pressure, the flat tape presented a problem when
running through the packing in a stuffing box.
These disadvantages brought about the adoption
of the circular slickline for depth measurements.
The line was tagged at equal increments of
length and the operator kept a record of the
amount of line paid out and retrieved. Later,
measuring devices with calibrated wheels came
into use because they were more convenient to
use and provided more accurate measurements.
As wells depths increased and loads imposed on
measuring lines increased, it became necessary
to develop high-strength materials of which to
make the lines and to draw them to a size to get
sufficient tensile strength in as small diameter
wire as possible. Keeping the diameter size of
measuring line to a minimum is desirable
because:
1. it reduces the load of its own weight,
2. it can be run over smaller diameter sheaves
3. it keeps the reel size to a minimum

5 Slickline
4. it provides a small cross-sectional area for
operating under pressure.
The most commonly used slickline is made from
Carbon Steel and is sometimes referred to as
Bright Steel or improved Plough Steel. Stainless
Steel and Alloy Steel are also finding a place in
slickline servicing as wells are drilled deeper
and H2S or CO2 gasses and higher temperatures
are encountered. These slicklines come in
varying lengths from 10,000 feet up to 30,000
feet.
Slickline Units
As mentioned earlier, the slickline is installed on
a reel, which is normally powered by a diesel
engine. The power is transmitted from the
engine to the reel either hydraulically or through
a gearbox or V-belts or chains, depending on the
type of unit being used.
The slickline unit is usually a complete, self-
contained unit in that it carries the slickline reel,
the power source, the slickline measuring device
and all the tools and equipment necessary to
accomplish routine jobs.
Slickline units in common use today are
installed on several conveyances such as:
trailers, trucks, boats and skid unit for offshore
platform use.
Arctic Slickline Trailer Unit
Truck Mounted Slickline Unit
with Crane
Offshore Slickline Skid Unit
Slickline Lift Barge
Advanced Slickline Skid Unit

6 Slickline
Principles of Operation
Open-Loop Hydraulic
Slickline System
(Chain Drive Units)
Advantages
1. Simplest system – fewer hydraulic
components, hoses and fittings.
2. Most common system – more familiar to
operators and maintenance personnel.
3. Less expensive components to repair or
replace.
4. Hydraulic components less susceptible to
contamination damage.
5. Fewer interconnections when using separate
power units and reel units.
6. Easier to “drift” tools into the well at light
tool weights.
7. Pumps and motors more tolerant of
“environmentally friendly” hydraulic fluids.
System Description
Hydraulic oil from the hydraulic power source
flows through a four-way directional control
valve. The directional control valve is a two-
bank valve. That is, it has two four-way
directional control sections with two operating
levers: the right-hand lever controls the wireline
reel; and the left-hand lever controls the bi-
directional spool-off motor (if so equipped).
With both levers in the center position, all motor
ports are blocked and oil flows freely back to the
reservoir.
When setting up on a well, when spooling wire,
or when performing maintenance functions, the
bi-directional motor that drives the reel can be
powered in either direction by moving the right
handle of the two-bank valve forward or back.
When performing normal slickline operations,
the right handle is positioned in the out-hole
position (handle pulled all the way back) and the
actual motion of the wire, in or out of the well, is
controlled by the variable pilot relief valve
mounted on the operator’s console. The pressure
setting of this valve controls the amount of
torque applied to the reel. With the right handle
pulled back, the system pressure can be reduced
just enough to allow the tools and wire to “drift”
into the well. When coming out of the well, the
system pressure is increased just enough so that
the wire and tools are pulled up the well. The
configuration of the hydraulic circuit assures
that the reel drive motor is not starved for oil
(cavitations) as the wire and tools drift into the
well, nor as they are pulled up.
A particular advantage to this control scheme is
the system’s reaction when the tools come
against obstructions in the well. When drifting
into the well, the combined weight of the tools
and wire actually is pulling the wire off the reel.
If the tools come against an obstruction when
drifting into the well, some load is removed
from the reel and the reel stops turning. This
prevents a “bird nest” of wire in the well. If the
tools meet an obstruction when moving up the
well, the hydraulic pressure will increase just
enough to open the main relief valve and prevent
over-pull on the wire.
The pilot valve that the operator controls is
connected to the pilot port on the main system
relief valve. This large relief valve limits the
maximum pressure that the pump can apply to
the motor. Under certain conditions, oil flowing
through any large relief valve can generate
considerable noise. With the main relief valve
mounted at the power unit some distance away
from the operator instead of at the control
console, the noise level at the operator’s position
is reduced.
Besides the main relief valve, a dual relief valve
is mounted at the hydraulic motor that drives the
reel. This valve protects the drive motor from
pressure spikes that can occur during quick
reversals of the directional control valve. This
valve is pre-set and is not controlled by the
operator.
The power source has an automatic oil cooling
system that controls the flow of hot return oil
through the cooling coils, which are mounted in
front of the engine radiator. When the oil

7 Slickline
temperature is below a pre-set temperature, the
thermostatic valve remains closed and the oil
bypasses the cooling coils. When the oil reaches
the operating temperature, the thermostatic valve
opens and oil flows through the cooling coils.
Besides the two-bank directional control valve
and the pilot relief valve, the operator’s console
has: a gauge that displays operating pressure (the
pressure on the reel motor); a gauge that
displays the return pressure, and a temperature
gauge that displays the temperature of the oil
returning to the power unit.
Principles of Operation
Closed-Loop Hydraulic
Slickline System (Direct-
Drive Units)
Advantages
1. Single-handle control of both reel direction
and reel speed.
2. No four-speed gearbox - continuous control
of the reel’s speed/torque range from
minimum to maximum.
3. No need to stop when changing the reel’s
speed/torque range.
4. Reduced maintenance – all drive
components operate in oil baths.
5. Reduced heat generation at speeds that are
less than the maximum speed – no oil
“blowing” over a relief valve.
6. No drive chains to tighten or adjust.
7. No clutch assembly required when powering
multiple-reel units.
General
Reels are driven by a closed-loop hydrostatic
hydraulic drive system. A variable displacement
pump circulates oil to the drive motor, which
plugs into a planetary gearbox on the reel. The
pump is designed so that the direction of flow,
and the rate of flow, can be changed with the
operator’s controls. Direction of flow
determines the direction of the reel’s rotation.
Flow rate determines the speed of the drive
motor and the speed of the reel.
A second pump supplies fluid to control and
power various functions. This auxiliary pump is
mounted on the rear of the main drive pump and
is powered by the drive pump’s through-shaft.
This pump is not controlled directly by the
operator. A pre-set controller inside this
auxiliary pump automatically adjusts the pump
output to match changes in the required flow
rate.
Reel Direction and Speed
At a fixed engine speed, reel direction (out and
in) and speed are determined by the position of
the drive pump’s cylinder block and by the
position of the motor’s cylinder block. Control
valves at the operator’s console are used to set
these positions.
An axial cylinder block in the drive pump (in
line with the pump axis) is turned by the drive
shaft and the pumping pistons reciprocate
parallel to the drive shaft. Shoes on the
spherical ends of the pistons are held against an
angled plate that turns with the shaft. The piston
heads are forced to follow a path that varies
according to the angle of the plate. When the
plate is vertical, the piston heads follow a
circular path, do not reciprocate, and no fluid is
pumped. As the plate tilts to different angles,
the pistons are forced to reciprocate within their
bores and fluid is pumped. When the plate is
near the center position, the flow rate is low. As
the angle of the plate increases, the piston stroke
increases and the flow rate increases. To change
flow direction, the plate can be made to tilt over-
center. This over-center movement and the
pump’s plate angle is under the operator’s
control. It is how the operator controls reel
direction, and is the primary method of
controlling reel speed.
The hydraulic motors used on the reels have a
different design than the drive pump, but the
displacements of the motors (volume of fluid

8 Slickline
pumped per revolution) can be changed also.
The motor is a bent-axis type. This means that
the centerline of the piston block is positioned at
a shallow angle to the motor’s output shaft.
Because of the angle between the piston block
and the output shaft, as hydraulic pressure
pushes the pistons, the pistons push on the
output shaft and cause it to turn and produce
torque. This angle between the piston block and
the drive shaft can be varied between preset
maximum and minimum values. Increasing the
angle increases the motor’s displacement, which
decreases maximum speed and increases the
maximum available torque. Decreasing the
angle increases shaft speed and decreases the
maximum available torque. The angle cannot be
decreased close to zero degrees because,
theoretically, the motor speed would approach
infinity and blow apart. Because of this, the
motor can be used to change reel direction
because it cannot go over-center
A comparison can be made between the variable
hydraulic motor and an infinitely variable
gearbox. The motor accepts the flow from the
pump and converts it to a smooth range of speed
and torque. Higher speed ranges results in lower
torque ranges.
Wire Tension
Tension on the wire relates directly to the torque
output of the hydraulic motor driving the reel.
Torque output of the motor depends on its
displacement setting and on the pressure across
the motor. Three different control features serve
to regulate the maximum wire tension.
 Pump Output Pressure Setting – A pilot-
operated control valve within the drive
pump is set during start-up testing. It limits
the maximum pressure that the pump can
maintain. At the maximum torque setting of
the motor (maximum displacement,
minimum speed range), this maximum
pressure will result in the maximum possible
torque output of the motor. Tension in the
wire will be equal to the motor torque,
multiplied by the reel drive gear ratio,
divided by the distance of the wire from the
axis of the reel.
 Varying the Pump’s Maximum Pressure -
One of the operator’s controls is a pilot
valve connected to the drive pump’s
pressure control valve. Using the pilot
valve, the operator can limit the output
pressure of the drive pump and limit the
motor torque to any value under the
designed maximum. If the pressure in the
drive system exceeds the pressure that has
been set by the operator, the pilot valve
sends oil to the drive pump controls. This
oil overcomes the pump’s flow setting and
causes the pump to move towards zero
displacement. As the flow rate decreases,
the pressure in the drive system decreases
and stabilizes at the setting of the pilot relief
valve.
 Excess Tension Control Valve -- A solenoid
valve can be plumbed into the drive pump
control circuit if the wireline unit is
equipped with an Advanced Measuring
System (AMS). Prior to performing service
work, the operator can adjust a setting on the
AMS to the maximum wire tension that is to
be allowed during the job. If the wire
tension reaches this setting, the AMS
actuates the solenoid valve. This drops the
control pressure to the drive pump, the pump
moves towards zero displacement, the
pressure decreases and the wire tension
decreases. After the tension has fallen
below the setting of the AMS, the valve
closes, the pump displacement increases, the
pressure increases and the tension increases.
The wire tension will alternately fall and
increase (to the AMS setting) until the
operator takes action to: reduce the setting
of the pilot relief valve, which reduces the
maximum wire tension or; increase the
maximum wire tension setting on the AMS.
The maximum wire tension setting on the
AMS can be reset higher or lower at any
time during operation.

9 Slickline
Controls for Drive Pump and
Reel Motor
Hydraulic pressure signals control angled plates
in the drive pump and the reel motor. There are
two short handles on a valve assembly at the
right side of the operator. This valve assembly
is supplied with pressurized oil from the
auxiliary pump. When the handles are moved,
the valve assembly sends pressure signals to the
pump and motor stroke controls. With the
handles centered, the pilot signals to the pump
and to the motor are at their minimum. Now the
pump is centered (zero flow) and the motor is at
the maximum displacement position (highest
torque range and lowest speed range). As the
pump control handle is moved forward, the pilot
signal causes the pump to increase its
displacement and to flow oil in a direction so
that the reel spools off wire. As the pump
control handle is moved backward, the pilot
signal causes the pump to increase its
displacement and to flow oil in a direction so
that the reel spools on wire. The control can be
set in any position from off to full-flow reeling
out, or from off to full-flow reeling in, and the
control may be moved or reversed at any time
and as quickly as the operator can move the
handle.
As the motor control handle is moved forward,
the pilot pressure to the motor’s displacement
control increases. This causes the motor to
move from maximum displacement (highest
torque range and lowest speed range) towards
minimum displacement (lowest torque range and
highest speed range). Like the pump control, the
motor control may be moved at any time and
may be set from zero to full stroke or visa-versa
as quickly as the operator can move the handle.
Moving the motor control handle backward from
neutral has no effect.
Reel Braking
As with all closed-loop hydrostatic hydraulic
drives, when the pump control is moved to zero
stroke, the pump moves to zero flow and flow
returning from the motor is blocked. However,
the inertia of the wireline reel and its wire
continues to drive the hydraulic motor in the
same direction. Pressure builds at the motor’s
outlet until it reaches the settings of the pressure
control valves. These valves limit the pressure
to the maximum pre-set value. This pressure on
the outlet of the motor results in a braking effect
that is equal to the motor’s maximum torque at
the motor’s displacement setting. With the reel
stopped, and with the pump at zero displacement
(no flow), flow out of the motor is blocked.
Because all hydraulic motors have some internal
leakage through the running clearances, the
motor may turn very slowly when the wire is
under load. Because of this, most closed-loop
hydrostatic hydraulic drives have a “parking
brake” feature.
When performing slickline service work, it often
is necessary to tension the wire when stopped
and to hold it tensioned for relatively long
periods. Also, some service work requires that
the reel be stopped more quickly that what the
hydraulic system can accomplish working alone.
All units have an operator-controlled band brake
mounted around one end of the reel. The brake
is self-actuated in the reel-out direction. That is,
when applying the brake during reel out, the
forces on the brake band and its actuating levers
intensify the braking action. Reel-out braking
action is sufficient to resist the maximum torque
output of the motor.
Two nested helical springs set the brake.
Pressure working on a hydraulic cylinder
releases the brake. Braking action can be
selected at any time with a lever-operated valve
at the operator’s console. A failure of hydraulic
pressure for any reason (power loss, pump
failure, hose rupture, etc.) causes the brake
cylinder to set.
Hydraulic Levelwind
Some units are equipped with a hydraulically
powered levelwind. A small hydraulic motor is
connected to the drive chain on the depth
counter. One type of control uses a spring-
centered four-way hydraulic valve on the
operator’s console. This allows the operator to
move the counter head back and forth as desired.

10 Slickline
Some slickline units also have hydraulic
cylinders to move the counter head up and down
as the rig-up angle changes. In these units, side-
to-side motion, and the lifting and lowering
motion, are controlled with a joystick-type
hydraulic pilot valve. As the operator moves the
handle from side-to-side or from right to left, the
counter head and its support moves accordingly
Spool-Off Accessory
A hydraulically powered spool off accessory
provides a means of supporting a slickline
shipping spool and tensioning the wire on the
reel. In closed-loop hydraulic systems, the
spool-off accessory is powered only in the
direction to tension the wire. Spool-off tension
is controlled with a pilot-operated pressure-
reducing valve. The operating pressure of this
valve is set with a pilot valve at the operator’s
console.
Filtration
As with all hydraulic systems, appropriate
filtration is an important contributor to long
service life and reliable operation. Closed-loop
hydraulic circuits use a combination of pressure
line and return line 3-micrometer filters. All
filters have devices that indicate increasing
differential pressures and that display warnings
to change the filter elements as the elements
accumulate debris.
Heat Exchanger
A proper fluid operating temperature also is
important. The oil flows through an oil-to-air
heat exchanger as it returns to the reservoir. At
low temperatures, a thermostat-operated
hydraulic valve bypasses oil around the cooler
until the oil temperature reaches the desired
operating range. The cooler may be mounted in
front of the engine radiator, or it may be
mounted separately and have a hydraulically
powered fan.

11 Slickline
Surface Pressure
Control Equipment
Since all wells that we will service will contain
or are subject to contain pressure, we must use a
safe and sensible means of gaining access to the
wellbore with our slickline tools. During the
performance of slickline and braided wireline
service operations on pressurized (live) wells,
slickline operators have traditionally employed
pressure-control equipment, commonly referred
to as lubricator stacks or risers, to control well
pressure and fluids. This equipment is
temporarily mounted on top of the wellhead as
the services are performed.
In general, lubricator stacks are manufactured
with threaded end connections that employ
elastomeric O-ring seals to enable the
components to be easily connected without
special tools. Equipment working pressures
range from 2,000 to 20,000 psi. The
components are usually sized to the tubing in the
well or the equipment that must be run in the
tubing and the ID sizes range from 2 to 9 inches.
In the 1930’s, the process of moving tools in and
out of a live wellbore using a pressure control
system or stack was developed. This process
was originally referred to as “lubricating the
tools” into and out of the well, and thus, the
pressure-control equipment became known as
“lubricator” or “lubricator stack.”
The first lubricator stacks consisted of a stuffing
box, lubricator sections, wireline valves or
blowout preventor (BOP’s), and a crossover to
the tree connection.
The stuffing box was used to provide a seal
around the slickline as it moved into and out of
the well. A manual packing nut could be
tightened to compress, and thus, energize special
packing within the stuffing box to affect the seal.
A sheave is used to affect an 180o
bend and to
guide the wire into the stuffing box packing.
Lubricator stacks were assembled with lengths
and ID’s that are sufficient to accommodate the
length and diameter of the anticipated tool string
that would be run into or pulled out of the well.
The sections are normally 8 feet in length but

12 Slickline
could be acquired in shorter or longer lengths, if
necessary.
The lower lubricator section(s) had ID’s large
enough to accommodate larger OD service tools
and included at least on bleed off valve to
release the well pressure in the stack after the
tools are retrieved.
Upper lubricator section(s) accommodated
smaller OD tool string components, which
generally consisted of the wireline socket, stem,
and jars.
The wireline valve or blowout preventor was
used to close off and seal around the slickline
when special operational conditions or
emergency situations occurred without causing
damage to the wire. As an example, if the
packing in the stuffing box were to prematurely
wear out or be blown out, or some component in
the lubricator stack failed, the wireline valve
would be closed to shut in the well until the
problem was corrected. In addition the wireline
valve could provide access for attaching other
tools to the wire providing control of the well
pressure during wireline fishing operations when
the wire or several strand of wire had to be
stripped out of the hole.
The crossover or swage was used to connect the
bottom of the wireline valve to the top of the
tree. In most cases, the top of the crossover
matched the bottom connection of the wireline
valve, while the bottom thread of the crossover
was designed to screw into the top thread of the
tree.
With the broadening scope and the increase of
slickline services into more hostile environment
with pressures in excess of 5,000 psi, several
enhancement and improvements were made to
the existing technology to further ensure safety
of personnel and the integrity of the pressure
control systems in use.
Stuffing Box and Slickline
Grease Head
The stuffing box now uses at least a 16-inch OD
sheave to reduce the fatigue stress on the large
diameter 0.108 and 0.125 slickline that are
gaining popularity. In addition, the hydraulic
packing nut was developed. The hydraulic
packing nut was one of the first environmental
and personnel safety enhancements made to the
equipment. Use of this type stuffing box with a
hydraulic pump and hose eliminates potential
hazards associated with personnel climbing the
lubricator stack to tighten the stuffing box
packing. This was necessary to prevent well
fluids from leaking to the atmosphere. With the
hydraulic packing nut feature, however, the
operator can control the energizing of the
packing from the ground.
A blowout preventor plunger is currently
incorporated into most stuffing box designs to
prevent the loss of well fluids to the
environment if the wire should inadvertently be
pulled or blown out of the stuffing box. Should
this situation occur, the elastomeric plunger is
pushed on seat, forcing the hole though the
plunger to be closed by differential well

13 Slickline
pressure. To ensure proper operation, in the
event of an emergency, it is extremely important
that this plunger be replaced when the hole
becomes worn.
In some stuffing box designs the
elastomeric plunger has been
replaced with a grease injection
system. In this design the lower
packing gland has been removed
and a short flowtube is installed.
Grease is then injected through the
port between the packing and the
flowtube to lubricate the wire and
reduce stuffing box packing
friction. The flowtube has a small
ball and seat incorporated into its
design to act as the BOP. When the
slickline has been pulled out or
blown out of the stuffing box the
ball is enabled to move onto its seat
and shut-off well flow.
There is also a slickline grease
head, installed below the stuffing box, that is
used primarily on high pressure gas wells
(10,000psi and above). Use of the slickline
grease head allows grease to be pumped into the
annular space between special close-tolerance
tubes and the wire to effect sealing. The grease
helps to lubricate the wire and provides a means
for adding inhibitors that reduce wire corrosion.
In high pressure wells, the amount of “squeeze”
imparted to the stuffing box packing to effect
sealing on the wire can impart a friction force
that exceeds the tool string weight, making it
difficult to move tools into and out of the
wellbore. In this application the stuffing box
packing is not fully energized and functions
primarily as a wiper to remove most of the
grease from the wire as it is pulled out of the
well.
Liquid Chamber/Chemical
Injection Sub
The liquid chamber/chemical injection sub is an
optional piece of equipment that is normally
located directly below the stuffing box. Liquid
chambers allow lubricants, inhibitors and
chemicals to be pumped into the lubricator and
onto the wire in situations where it is necessary
to inhibit for corrosion, provide lubrication to
the wire, or prevent hydrate formation. The
liquid chamber design creates a pocket into
which the liquid will pool so that the wire must
pass through it.

14 Slickline
Lubricator Purge Valve
The lubricator purge valve is a new development
that allows air to be purged from the lubricator
when opening the well or when performing a
hydro test on the stack before the well is opened
to production. The purge valve is positioned just
below the stuffing box at the highest part of the
lubricator where air can become trapped. To
open the purge valve, the operator pulls a bind
on the wire; an upward bind opens the purge
port. When all the air is purged from the
lubricator, the operator releases the bind and the
valve closes the port.
The purge valve can also be used to purge air
from the lubricator stack when performing the
hydrostatic (water) pressure test, now required
by a large number of producing companies
before slickline services are allowed. Normally,
the packing in the stuffing box will seal
sufficiently at low pressures without being
energized by the packing nut so that little or no
air can enter or leave the stack. Opening the
purge valve will help facilitate and speed up the
process of filling the lubricator with the test
fluid by allowing air to escape during the
process.
The purge valve is also used to prevent auto
ignition in the lubricator by exhausting the air
from the top of the lubricator as well fluids or
gases enter from the wellhead. Auto ignition is
a phenomenon that occurs in the lubricator with
disastrous results when hydrocarbons and
oxygen combine in the right proportions under
certain pressure and temperature conditions.
Tool Catcher
A tool catcher is used in conductor line
operations and is normally placed in the
lubricator stack just below the grease head. It
was developed to latch the fishing neck on the
tool string and serves two purposes. First, it
facilitates the handling of the lubricator and tool
string in a safer manner by insuring that the tool
string remains inside the lubricator as it is being
removed from the wellhead. Secondly, it
prevents the tools from falling downhole if the
tool string should make contact with the bottom
of the grease head with to much force, causing
the wire to pull out of the rope socket.
Tool Trap
The tool trap is an optional device that an
operator can use in place of a tool catcher. With
this device, the wire is run through a hinged
flapper, and when the tool string is moved into
the lubricator above the flapper, it closes to
prevent the tools from falling out of the
lubricator. The tool trap would normally be
placed just above the wireline valve in the
lubricator stack.

15 Slickline
Lubricator Sections
In the past, screwing or welding end connections
onto tubing pup joints made most lubricator
sections. These sections still work well for
pressures of 5,000 psi and below. In cases of
higher pressures, harsher well conditions, and
higher stress that can be exerted by larger
diameter slickline sizes, it is now recommended
that lubricator sections be manufactured from
tubing sections designed for these purposes.
These sections are integral units in which the
end connections and tube are cut from one solid
forging, or the end connections are threaded
onto a tube section. The threaded connection is
usually a thread with a separate seal
arrangement, and therefore, the joint does not
have to rely upon thread interference to affect
seal.
The lower lubricator section has been equipped
with two bleed ports for the installation of bleed
valves. Higher-pressure gas well might cause
the valve to freeze off when bleeding down the
lubricator, to change service tools, before the
pressure inside the lubricator is bled off. Thus,
the other valve can be opened to finish
depressurizing the lubricator.
Wireline Valves
Hydraulic wireline valve employ pistons to
engage and disengage the ram elements. These
valves allow remote valve operation with a
hydraulic pump and hose, and their usage has
increased considerably in recent years. They are
particularly beneficial for service operations
performed on H2S wells, as they eliminate the
need to manually operate the valve at the
wellhead, where potential of poisonous gas
leakage exists. They are also used on high rig-
ups where the operation of manual wireline
valves may not be safe or practical.
Quick disconnect hydraulic cylinders have been
incorporated into the latest wireline valve
designs to reduce the amount of time required to
remove and replace or repair the wireline rams.
This innovation reduces maintenance time
required to service wireline valves and allows
the wireline rams to be easily and quickly
changed out on location when job conditions
require wire size changes.
Dual and triple wireline valves are use to
provide additional safety on high pressure well
and H2S wells. Electric conductor and braided
line operators generally use dual wireline valves
on wells with pressures of 5,000 psi or greater.
In these applications, the lower rams are
inverted so that grease can be injected between
the rams to affect a seal in an emergency. These
rams can also be used in standard applications,
and the rams can be inverted only when
required. This capability provides greater cost
efficiency for the wireline operator since a
specific additional valve does not have to be
designated for an inverted lower valve
application. Previously, special wireline valves
had to be designed with keyed inverted rams or a
standard wireline valve was inverted for these
situations.
Dual and triple wireline valves can also be used
with one of the ram bores equipped with a set of
slickline rams and the other bore(s) equipped
with braided line rams.
Lubricator Ball Valves
The lubricator ball valve is a device that can be
made up in the lubricator stack as an emergency
shutdown system. This valve is a fail-close
valve, designed to cut up to 7
/32-inch conductor
or braided line when a loss of hydraulic pressure

16 Slickline
occurs. It can be remotely controlled with a
hand pump or pressure-controlled pump skid
and hydraulic hose. Fusible plugs can be
incorporated to facilitate closure in case of a fire.
It is used in applications in which there is a long
distance between the location of the wireline
valve and the top of the wellhead. This often
occurs on offshore platforms when a lubricator
section is run between the wellhead and an
upper deck to facilitate the slickline rig-up. The
lubricator ball valve is normally placed just
above the wellhead. The wireline valve and
lower lubricator section are placed above the
upper deck floor to enable easier performance of
slickline operations. This
Flanged Tree Connections
A flanged tree connection is now recommended
on the wellhead to accommodate the lubricator
stack during standard service operations on
wells with pressures greater than 5,000 psi and
during all H2S service operations. Threaded
crossover/tree connections that are used for
standard sweet service should be limited to
applications of 5,000 psi and lower for API-type
thread connections. Operators have recognized
that the addition of a threaded crossover
provides a potential leak path between the
wellhead and the wireline valve. Many are now
incorporating the connection adapters to the
bottom of wireline valve as part of their
wellhead tree cap to eliminate the threaded
connection.
Pressure Control Consoles
Pressure control consoles have been developed
to provide compact, easy-to-operate remote
controls for hydraulic slickline and braided line
stuffing boxes, grease heads, and multiple
hydraulic wireline valves.
The consoles usually contain a hydraulic
reservoir, pumps and hoses to control the
wireline valves and hydraulic packing nut. An
additional grease reservoir and high pressure
pump is supplied to operate the grease injection
head and to inject grease between the wireline
valve rams. All hoses are stored on easy-to-
dispense reels on the console. The consoles
provide a compact and easy method to ship a
unit. Some consoles are mounted in a shipping
frame; which also carries the wireline valves,
lubricator sections, stuffing box, and grease
head; and allows all of the slickline pressure
control equipment to be loaded on an offshore
rig in one lift.
Corrosion Resistant Alloy (CRA)
Valves and Equipment
CRA valves are gaining more prominence for
use in lubricator equipment. As more wells are
being developed in hostile environments that
contain higher concentrations of H2S and CO2,
the lubricator stacks are being exposed to a
greater variety of elements, many of which
adversely affect the alloy steels typically used in
lubricator equipment. In some cases, wireline
valves exposed to critical well effluents have
corroded to the point that they required replacing
in less than one year.
To combat the increase of corrosion incidence
experienced in some areas of the world, wireline
valves and other wetted surfaces within the
lubricator stack assembly are being
manufactured from corrosion-resistant alloys.
To reduce the initial cost of these valves, new
manufacturing methods such as the hot isostatic
process (HIP) and weld overlays are being
pursued.
Design Verification and
Inspection Maintenance
Procedures
In order to help increase assurance that the
safety of personnel and the environment will be
maintained, Halliburton has implemented a
safety inspection program that predetermines
whether its equipment has been designed,
fabricated and maintained to perform the service
for which it is intended.
The program consist of a design verification
(DV) certification, and periodic inspection
maintenance (IM) certification and focuses on
critical components of the oil field service

17 Slickline
equipment that can impact operational safety.
The term “critical” is used to define equipment
types that would cause hazardous situations for
personnel, property, and the environment if a
malfunction/failure of this equipment were to
occur during operation or handling.
Design Verification Certification
Each critical equipment component must pass
initial DV inspection before it can be placed in
service. The program was developed to
ascertain whether existing equipment as well as
new equipment conforms to current engineering
design standards. The intent of each DV
inspection procedure is to verify that:
1. Critical service equipment meets minimum
basic standards.
2. Equipment that fails DV inspection is either
upgraded to meet current standards or retired
from service.
3. The design standards used in the DV
program are established in accordance with
company-developed criteria along with
industrial requirements and regulatory
standards.
The following examination techniques are
generally required in all DV inspections and
documents:
1. Visual Inspection – ensures that the physical
appearance and condition of equipment is
appropriate for the function it performs
2. Design Requirement Verification – provides
assurance that the equipment meets
minimum company, industry, and regulatory
design standards. This examination requires
that documentation is collected or that
traceability to known documentation is
available. In the cases where no engineering
design documentation exist, the DV program
may allow design verification through
specific load testing followed by
nondestructive examination (NDE).
3. Pressure Testing – ensures integrity of the
part to the working pressure of the pressure-
containing equipment.
4. Nondestructive Examination – provides
assurance on critical areas designated in the
DV specifications package that there are no
discontinuities in the part that would
compromise standards.
5. Functional Testing – is required to
demonstrate that the equipment’s present
condition can satisfactorily perform the task
for which it is designed.
Inspection Maintenance
Certification
The Inspection Maintenance (IM) program was
designed to be a continuation of the DV
program. The IM program continues to verify
integrity of the equipment after it has passed the
initial one-time DV inspection. The IM program
stipulates that periodic inspections are to be
performed at specified intervals for all
equipment. Between IM inspections, the
equipment is subjected to regimen of preventive
maintenance.
IM inspections generally consist of the
following:
1. Visual Inspection
2. Pressure testing
3. Nondestructiveexamination
4. Visual and/or dimensional examination of
designated components.
IM policy requires that equipment failing any
requirement in the IM procedure must be
withdrawn from service. The failed equipment
must be tagged and isolated to prevent its use
until it has been properly repaired, in re-
inspected, and has been designated as
satisfactory for service.
Lubricator Marking Standard
An equipment marking standard has also been
developed to identify more clearly the pressure
and service rating of the lubricator equipment.
This identification procedure further insures
proper use of equipment, and thus, improves
selection capability for lubricator equipment for
slickline service operations.

18 Slickline
The chart shown below shows the standards
used for identifying standard service equipment.
A stripe of the specific color code is painted
around the body of the equipment as shown to
distinguish its pressure rating. For H2S and
cold-weather service, -50o
F to –75o
F, the
lubricator equipment would be identified with
the standard pressure stripe but would also have
an additional smaller stripe of green, designating
H2S service, and another of brown, for cold
weather service. In addition, “H2S” or “COLD”
is stenciled in white in this stripe to further
identify applicability.
Conclusions
The selection, proper use, and maintenance of
lubricator equipment for slickline service
operations are critical to the assurance of
personnel safety and protection of property and
the environment.
Slickline equipment has evolved greatly from its
initial designs, and many enhancements and
process developments that will help assure that
safety objectives can be met and that failures
resulting from improper usage of equipment will
be avoided. The process described will help to:
Insure equipment integrity,
Identify specific and proper equipment usage,
Prevent use of worn equipment, and
Prevent use of equipment in applications for
which it was not designed.

19 Slickline
Wire Mechanical
Capabilities
Slickline Wire
Wireline (slickline or measuring line) is
available for use in a broad range of well
conditions. Material choices range from bright
(carbon) steel to cobalt based alloys such as
MP35N. Wireline diameters .066”, .072”, and
.082” are normally limited for use in well depth
surveys, with lengths from 6,000 to 20,000 feet.
Wireline diameters .092”, .105”, .108”, and
.125” are used for depth measurement as well as
more aggressive well service work. These wires
typically range from 10,000 to 30,000 feet in
length. In many locations, .125” wireline has
replaced braided line where the .125” wire has
sufficient strength to handle the expected
workload.
To standardize on wireline materials, those listed
have been selected as the preferred wireline
materials for Halliburton. Breaking strengths
are given for each wireline material in the
common wire sizes. The wireline are listed
according to resistance to H2S and chlorides
(with the carbon steels having the least
resistance to H2S and the cobalt alloys having
the most resistance to both H2S and chlorides).
Carbon steels are recommended for use only in
standard (sweet) service wells. Austenitic
stainless steels can be use in all H2S
concentrations but are not recommended for use
in chlorides. The super austenitic stainless steels
and 6% molybdenum stainless steels can be used
in any concentration of H2S, but the well
temperature and percentage of chlorides must be
considered before a recommendation can be
made for use in sour wells containing chloride.
Cobalt based wirelines can be used in any H2S
and chloride combination. Recommendations
for wireline materials will be changed
periodically as other materials are evaluated.
Refer to Engineering Bulletin 354 or contact
Technology – Dallas Center for further
assistance with selecting wireline materials.
Halliburton uses both “name brand” wireline
materials such as Bridon’s “Supa 75” and it
generic equivalent “25-6MO”. The generic
equivalents are typically less costly than the
name brand wirelines while still maintaining
good quality. To insure that only quality wire is
purchased; it is recommended that all wireline
be purchased through Halliburton or from
suppliers recommended by Technology – Dallas
Center.
To reduce the chance of premature fatigue
failures of wireline, it is recommended that four
(4) foot counter wheels be used on the wireline
unit and 16” sheaves be used on hay pulleys and
stuffing boxes for all wireline sizes through
.125”. The 10” stuffing box sheave and 7” hay
pulley can be used for .092” and smaller carbon
steel wireline, but using 16” sheaves with these
wires will increase the life of the wireline. Also,
the stuffing box packing gland material and ID
should be compatible with the wireline used.
Use of a chemical injection sub is highly
recommended when performing work in wells
containing dry gases. Lubricant can be injected
into the sub to reduce line friction and wireline
wear.
Braided Wireline
Braided wireline (wire rope) is produced in a
number of sizes, type construction (strand
configuration), and materials. Braided lines are
available plain, galvanized, or die
drawn/formed. Galvanized wire has better
resistance to saline conditions than the uncoated
plain line, but the protection from the zinc is
sacrificial. Once the zinc is corroded, the line is
no longer protected. The die formed line gives a
higher breaking strength for any given diameter
as compared to the standard braided line.
Braided wireline is recommended for heavy-
duty wireline work including difficult fishing
jobs. For low-pressure wells, a swabbing
stuffing box is used as part of the lubricator rig-
up to pack off pressure around the line. For well
pressures above 1,500 psi, a grease head and
grease injection system is needed to pack-off the
braided line against well pressure.

20 Slickline
Wireline – Breaking Strengths (lbs)
Carbon Steel – API 9A
Material 0.072 0.082 0.092 0.105 0.108 0.125
Bright Steel – (API Level 3 or Improved
Plow Steel)
961 1239 1547 1966 2109 2794
Bright Steel – (API Extra Improved
Plow Steel, Hi-Strength, or Monitor AA)
1150 1460 1830 2360 2490 3300
Austenitic Stainless Steel
316 Stainless Steel 1083 1363 1732 1786 2270
Super Austenitic Stainless Steel
Sandvik Sancrico 28 1445 1885 1995 2675
6 Moly Stainless Steel
Avesta 254 SMO 1462 1818 1924 2454
Bridon Supa 75 1550 2030 2030 2560
25-6MO 1475 N/A 2050 2550
Cobalt Based Alloy
MP35N 1582 2009 2080 2724
Braided Wireline – Breaking Strengths (lbs)
Size 3/16 3/16 7/32 7/32
Construction 1 x 16 1 x 19 Dycam 1 x 16 1 x 19 Dycam
Material – Galvanized Carbon Steel 4500 6400 6000 8600
NOTE: Breaking strengths will vary slightly depending on manufacturer

21 Slickline
Wireline Inspections on
Location
Below are the most commonly used methods for
inspection of wireline to determine if
replacement is needed. A combination of these
methods should be used to inspect wireline, as
there is no one inspection method that will
consistently catch all wirelines before it actually
breaks. By inspecting the wire before and after
each job, it will be easier to determine at what
point the wireline should be replaced. If the
wireline fails the visual inspection, wireline knot
test, API 9A torsion test, or the eddy current test,
wireline should be cut off in 50-100 ft intervals
until the wireline will pass the inspection/test. If
the wireline fails the coil test, use one or more of
the other inspection methods to further test the
line.
Logs
It is recommended that a log be kept for all
wireline spools. A copy of the log should be
sent in with any CPI/TER. This Log should
include:
 All details of the wireline: part number,
material type, size, trace numbers, and date
installed.
 Well data to include: well environment (at
minimum the % H2S, % chlorides, % CO2,
and downhole temperature) and well
location/number.
 Wireline operations performed: run plug,
fishing, jarring (duration and maximum
load), etc.
 Wireline Inspection results.
Note: See attached Wireline Log
Visual Inspection
At the beginning and end of the wireline job,
check the first fifty feet of wire for brightness,
pitting, necking down, flaking, flat spots, or
other surface damage.
Wireline Knot Test
Tie a standard wireline knot before and after
each job. If wireline breaks or cracks when the
knot is tied, the wireline is either hardened or
has been damaged by the well environment. It’s
helpful to periodically compare the knot tying
capabilities of the used wireline with new
wireline (preferably saved from the same
wireline spool when new). Even if a No-Knot
rope socket is normally used on the actual job,
tying a knot for specifically for inspection
purposes is recommended. This test can be
performed on all wireline materials and
diameters, including .125” line, and should be
considered the “everyday” wireline inspection
method for all wireline materials.

22 Slickline
Coil Test
Pull about 100 ft of wireline off the slickline unit
and allow the line to lay on the ground.
Overworked (work hardened) wires will not coil
freely, looses its spring, and tends to lay flatter
than wireline that is not overworked.
If a new spool of wire tends to lie flat after a
couple of jobs, this could be the result of the
wireline being feed through the counter
assembly wrong. In that case, remove the wire
from the counter and install it properly.
Tightly coiled wire could be the result of pulling
heavy loads from the well bore where the tools
were not able to rotate. As above on a new
spool of wireline, this could be the result of
improper installation of the wireline through the
counter assemble. Continuously working the
wireline in this condition could result in rapid
deterioration of the wire.
API 9A Torsion (Twist) Test
An API torsion or ductility test machine is used
to conduct this test. The device consist of a base
with two jar/clamps spaced 8” apart, one jaw is
stationary while the other is rotated with a crank.
Wireline placed between the jaws is twisted until
the wireline breaks. The minimum turns before
breakage is listed in the API 9A specification.
Note: The torsion tester can only be used for
carbon steel lines (also known as bright
steel).
Torsion Test
Material Size
Torsion
Twists
Standard Bright
Steel
0.092 23
0.105 20
0.108 19
0.125 17
Hi-Strength
Monitor AA
0.092 21
0.105 18
0.108 18
0.125 15
Test Procedures:
1. Before the wireline job, cut two 10” lengths
of wireline from the end of the wire.
2. Cut another wire sample about 12” long and
label with date, well location, and with
“before wireline job”. Save sample for step
9.
3. Bend the ends of the 10” samples, and for
the first sample, position the bent ends in the
tester jaws.
4. Rotate crank until wireline breaks. Record
the number of turns needed to break the

23 Slickline
wire. Compare to API Chart for Pass/Fail
results.
5. Repeat test for the second 10” sample and
record number of turns.
6. Compare the results of the two twist tests.
Test a third 10” sample if there is a large
difference in the test results.
7. After the wireline job is completed, repeat
the torsion test with two sample (use a third
sample if there is a large difference in test
results).
8. Compare the results of the torsion tests
performed before and after the job. If there
is a large difference between the before and
after tests, cut off 50-100ft of wireline and
retest.
9. If the wireline fails the torsion test:
a. 1. And the wireline has gradually lost
ductility and no longer passes the torsion
test (even after many cut-offs and retests),
replace the wireline. No need to submit a
CPI/TER.
b. 1. If the wireline torsion test values have
dropped significantly between the
before/after tests, proceed to the step
below.
b. 2. Cut a 6 ft length of line from the end of
the wireline and tag with date, well
location, and with the note “after wireline
job”
b. 3. Fill out a CPI/TER form for the
wireline.
b. 4. Send the CPI/TER form (including the
before and after job torsion results),
wireline log 12” wireline sample (from
Step 2), and the 6-ft wireline sample (from
Step 9.b.2.) to Dallas Center, Attn:
Technical Services. The actual torsion
test samples do not need to be sent.
b. 5. Repeat Step 8 until the wireline passes
the twist test. If the wireline repeatedly
fails the test, pull the wireline from
service.
Eddy Current Inspection Device
The eddy current inspection device uses an
electrical current call “eddy current” to inspect
wireline. Passing the line through an electrical
coil inspects the wireline. Any changes in the
wireline (such as cracks, flats, laps, and other
flaws) will be highlighted by the instrument.
Refer to the eddy current inspection device
manual for details.
The eddy current tester is currently the only
inspection device/method that can test the entire
length of wireline. All field locations should
review the benefits of the eddy current tester.
Depending on the type of wireline used and
services performed; the eddy current tester often
can pay for itself in just a few months.

24 Slickline
Slick Wireline
Wire Size (in) Wire Type Shear Force(#)
0.092 IP 1,400
0.092 EIP 1,700
0.108 EIP 2,500
0.108 IP 2,100
0.125 IP 3,000
Braided Wireline
Line Size (in) Line Type Shear Force #
3
/16 Swab Line 5,000
3
/16 Dycam 5,900
7
/32 Swab Line 6,500
1
/4 Dycam 12,500
Wireline Shear Force Analysis
A test fixture was specially designed to simulate
a three- (3) inch gate valve to measure the force
required to cut wireline and braided cable. The
following is a table with the results:
Notes:
1. If the wireline breaks during use, the
fractured end(s) (at the end of about
6-ft of wireline) should be sent to Dallas
Technical Services with a CPI/TER. The
fractured end should NOT be cleaned, but
should be wrapped to preserve the fracture
for evaluation.
2. While it is recommended that a log be kept
which lists the complete history of the well
environment in which the wireline has been
used, it is recognized that complete well data
is not always known. In dealing with TERs,
the more well history that can be provided to
Technical Services, the more accurate the
findings will be.
3. For API 9A torsion (twist) tests, pass/fail
values used may very from one field
location to the next due to the severity or
type of wireline service being performed.
Acceptable twist test values may be lower
for wireline units primarily performing
downhole pressure surveys than for units
involved with service jobs requiring heavy
jarring. Experience will dictate what values
are acceptable. It should be noted that the
torsion values in API 9A are for new
wireline. Torsion values for used wireline
will be lower.

25 Slickline
Written Project
1. List some of the functions accomplished by the use of slickline:
a.
b.
c.
d.
e.
2. The power to move the slickline in and out of the well is transmitted to the reel from the
engine by:
3. What is the purpose of the Slickline BOP (Wireline Valve)?
4. What is the purpose of the Lubricator?
5. What is the purpose of the Stuffing Box?
6. What material and size of the slickline most commonly used in your area?
7. What is the breaking strength of that wire?
8. Write a description of the procedures that are used to rig-up slickline in your area (If you are
involved in more than one type of rig-up, describe the various types of rig-ups that you are
involved in; e.g. on land, offshore, land rig, offshore rig, drilling rig etc.)

26 Slickline
Hands-On Projects
This page is used to check the individual’s ability to perform the disassembly, assembly, repining, inspection and
maintenance of tools and/or equipment of this Section. (Dependant on what is used at the Individuals Location)
Check
Box ()
Tool
Type
Ability to Perform Task Witnessed By:
Initial Emp. #
Test Wire (wrap & torsion)
Weight Indicator (calibration)
Counterhead Measurement system (calibrate)
Redress a Stuffing box
Redress a Chemical Injection Sub
Strip a Slickline Valve (BOP)
Rebuild a Slickline Valve (BOP)
Strip/Rebuild Equalizing valve on Slickline Valve
Invert a set of Dual Rams
Strip/Rebuild Greasehead and Packoff (braided line)
Function a Tool Catcher
Function a Tool Trap
Operate a Control Pump Module
Operate Winch Controls (Slickline Unit)
Basic Checks on a Power Pack.
Operate and reset a shutdown system on a Power Pack
Change out “O” ring on Pressure Control Equip
Make up a Quick Union correctly
Understand how the Xmas tree valves work and
closing sequence
Demonstrate the Principals of double isolation
Demonstrate the Operation of a Lubricator Manifold

SECTION II
SLICKLINE TOOL STRING

1 Slickline
Slickline Tool String
Table of Contents
Introduction................................................................................................................................................... 3
Tool String Components............................................................................................................................ 4
Rope Socket........................................................................................................................................... 4
Stem....................................................................................................................................................... 5
Mechanical Jars ..................................................................................................................................... 6
Knuckle Joint......................................................................................................................................... 7
Hydraulic Jars........................................................................................................................................ 7
Spring Jars ............................................................................................................................................. 9
Accelerator........................................................................................................................................... 10
Compact Tool Strings.......................................................................................................................... 11
Tool String Design Considerations ......................................................................................................... 12
Toolstring Calculations........................................................................................................................ 14
Section II Project Two ............................................................................................................... 16
Hands-On Projects............................................................................................................................... 17

2 Slickline

3 Slickline
Introduction
In order to accomplish “slickline” work
downhole, we must have a slickline tool string
attached to the wire. A typical slickline tool
string (Fig. 1) would consist of:
1. Rope Socket
2. Stem (Weight Bar)
3. Mechanical (Link) Jars
4. Knuckle Joint
This assembly is essentially the “work string” of
the slickline operation. Depending upon the
operation to be performed, (retrieving a plug,
safety valve, etc.) the pulling tool would be
attached to the tool string below the knuckle
joint.
In every area there seems to be a standard tool
string that is used. These consist of
configurations that have proven to give the most
success during standard operations in that area.
For example, in some areas the standard tool
string might consist of a rope socket, 5 foot – 1
½” stem, and mechanical jar would make up the
tool string. In other areas, the standard tool
string would consist of a rope socket, 8 foot – 2
3
/8” stem, knuckle joint, and mechanical jars.
What causes variations in the standard tool
string in given areas?
And if these are the standards, what causes the
use of non-standard tool strings?
In this section we hope to give you the
information that you need to select the
components to make up a tool string for
whatever well conditions and slickline
operations that you might encounter.

4 Slickline
Part Description
1 Body
2 Spring
3 Spring Support
4 Disc
Tool String Components
Rope Socket
The slickline rope socket provides a means of
connecting to tool string to the end of the wire.
For slickline operations there are two basic types
of rope sockets available:
1. Conventional “Knot” type, and
2. Wedge “No-Knot” type.
reduced to 1 ½ to 2 wraps. With only 1 ½ to 2
wraps, the operator could pull the wire out of the
rope socket if the tool string became stuck.
The No-Knot (Fig. 4) rope socket is quickly
becoming the favored method of connecting the
wire to the tool string for two reasons.
1. It is easier to make up (with larger wire
sizes currently being used).
2. It is stronger.
1
2
3
Part Description
1
2
3
Body
Thimble Eye
Thimble (Wedge)
Fig. 2
The knot type rope socket (Fig. 2) is what we
will call the traditional type, because it has been
around the longest. In this type of rope socket
the wire is threaded through the body, spring and
spring support, wrapped around a disc, and then
wrapped around itself with tight coils (Fig. 3).
For typical slickline operations, the operator
would make between 7 to 14 wraps to complete
the knot.
Fig. 4
With the No-Knot rope socket the wire is
threaded through the body and thimble eye and
folded around the thimble (wedge). The wedge
is then inserted into the thimble eye.
The strength of this type of rope socket is due to
the reduction of tight bending radiuses.
There is a downfall to this type of connection,
due to its design it loses its ability to swivel.
Therefore a knuckle or tool string swivel should
be used below the “No-Knot” rope socket to
keep the natural twist of the wire.
Note: The rope socket used should be sized to
ensure that a pulling tool could retrieve it and the
tool string from the wellbore.
Fig. 3
However, there are situations (crooked tubing,
wire fishing, etc.) where the wraps would be

5 Slickline
Stem
The stem (weight bar) (Fig. 5) provides the
weight to:
1. Overcome the friction of the stuffing box
packing on the wire.
2. Overcome the force created by the well
pressure acting on the cross sectional area
of the wire which is “packed off” (sealed)
in the stuffing box. This force is trying to
push the wire up and out of the well.
Fish Neck
Top Sub
Housing
Lead or
Mallory
Housing
The stem also provides the “mass” or weight
which is needed to deliver the impact
(hammering effect) that is required to set
(install) or retrieve the various subsurface flow
control devices.
The amount of stem used in a tool string is
determined primarily by:
1. The amounts of well pressure (working
against the area of the wire).
2. The impact required to accomplish the
downhole work to be done.
The deviation of the well at the depth of
operations, the type of fluid in the well, and the
size of the tubing also affect the amount and size
of the stem being used.
In some situations the rig-up conditions can
affect the type of stem that is used. On some
offshore platforms, there is limited space and
special “weighted” stem (Fig. 6) has to be used
to reduce length and maintain the weight
required for successful operations.
Note: When selecting the stem size,
consideration needs to be given to the tubing
size and the cutter bar that might be used to cut
the wire at the rope socket. If the cutter bar and
the stem can fit side-by-side in the tubing, when
the cutter bar is dropped, it might fall along side
of the tool string creating a very difficult fishing
operation.
Fig. 5 Fig. 6
The stem must provide the weight necessary to
overcome the friction and force and pull the wire
into the well.

6 Slickline
Mechanical Jars
With the mechanical jars attached below the
stem, the weight of the stem can be used to “jar”
up by quickly pulling up on the wire to rapidly
“open” (extend) the jars to create an upward
impact. To jar down, the wire would be pulled
up slowly to extend the jars and then released
quickly to allow the stem to fall, closing the jars
and creating a downward impact.
We might think of the stem as the weight of a
hammer and the length of the jar stroke as the
distance the hammer can move up or down and
the slickline as the hammer handle.
A greater impact can be obtained while jarring
up because the wire can be pulled rapidly by the
slickline unit, to move the stem at a very fast
rate of speed. When jarring down, only the
weight of the stem controls the rate of speed at
which it falls. We can not use the wire to
“push” the stem downward.
There are two types of mechanical jars:
1. “Spang” Link Jars (Fig. 7), and
2. Tubular Jars (Fig. 8)
Spang jars are available in two different stroke
lengths 20” and 30” stroke. The 20”-Stroke jars
are most commonly used because it is felt that
they are stouter, with less chance of becoming
“scissored”. The 30”-Stroke jars are used when
extensive upward jarring is required.
Tubular jars are used most often when well
conditions or the operation might cause the
Spang jars to become fouled.
Note: The OD of the jars should match the OD
of the stem.
Fig. 7 Fig. 8

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