Slickline Operations Manual

Section 4
Technical Information
D01521428
Rev E

Document Owner: Global Operations Manager

Document Approved By: Slickline Technology Manager

Document Reviewed By: Slickline Global Advisor

HARD COPY UNCONTROLLED

 Section
For reference:
Completion Products Catalog
HES Equipment Catalog
Completion Products - Wellhead Pressure Control section
Completion Products - Slickline Equipment section
4
Technical Information

SL 4.1: . . . . . . . . . . . . . . . . . . .Wire Selection Criteria and Technical Charts and Tables

SL 4.2: . . . . . . . . . . . . . . . . . . . . . . Line Stretch Calculations - Weight and Temperature
SL 4.3: . . . . . . . . . . . . . . . . . . . . . . . . . . . Wire Twist/Torsion Tester - Twist Test Chart
SL 4.4: . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .Wire Inspection System
SL 4.5: . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Braided Line Information
SL 4.6: . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Wire Fallback
SL 4.7: . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . General Hydraulic Unit Specifications
SL 4.8: . . . . . . . . . . . . . . . . . . . . . . . Slickline Reel Chart - Dimensions and Capabilities
SL 4.9: . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Reel Capacity Calculation
SL 4.10: . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Mechanical Counter System
SL 4.11: . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Electronic Depth Counter System
SL 4.12: . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Advanced Measuring System (AMS)
SL 4.13: . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Weight Indicators
SL 4.14: . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . General Purpose Pump Skid
SL 4.15: . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Pressure Control Equipment Color Coding
SL 4.16: . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Halliburton Quick Union Connections
SL 4.17: . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Bowen Quick Union Connections
SL 4.18: . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other Quick Union Connections
SL 4.19: . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Stuffing Boxes List
SL 4.20: . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .Hydraulic Packing Nuts
SL 4.21: . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Stuffing Box Packing Stacks
SL 4.22: . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Braided Line/E-line Grease Head
SL 4.23: . . . . . . . . . . . . . . . . . . . . . . . . . Liquid Chamber (Chemical Injection Sub) List
SL 4.24: . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Lubricator Purge Tool (Valve) List
SL 4.25: . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Tool Catcher and Tool Trap
SL 4.26: . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Lubricator Section
SL 4.27: . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Lubricator Safety Valve
SL 4.28: . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Pump In/Flow Tee List
SL 4.29: . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Wireline Valve List
SL 4.30: . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Tree Connection List
SL 4.31: . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Blanking/Tree Caps List
SL 4.32: . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . O-Ring Service Selection Chart
SL 4.33: . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Lifting Champs and Caps
SL 4.34: . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Hay Pulleys and Ground Block Sheaves
SL 4.35: . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .Gin Poles and Accessories
SL 4.36: . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Rope Sockets - Slickline and Braided Line
SL 4.37: . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Stem — Non-Weighted and Weighted

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SL 4.38: . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Stem Weight vs. Pressure Chart Table

SL 4.39: . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Knuckle Joints
SL 4.40: . . . . . . . . . . . . . . . . . . . . . . Jars - Spang, Tubular, Hydraulic, and Spring Type
SL 4.41: . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Accelerators
SL 4.42: . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Tool String Connections
SL 4.43: . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Quick Connects and Tools
SL 4.44: . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Go Devils/Cutter Bars
SL 4.45: . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Kinley Perforator
SL 4.46: . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Kinley Power Jar
SL 4.47: . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Kinley Sneppers
SL 4.48: . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Sandline Cutters
SL 4.49: . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Shear Pin Guide
SL 4.50: . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . X and R® Nipple Selection Chart
SL 4.51: . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . API Tubing Tables
SL 4.52: . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . English to Metric Conversion Chart
SL 4.53: . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Handy Formulas and Data

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Slickline Operations Manual SL 4.1: Wire Selection Criteria and Technical Charts and Tables

SL 4.1: Wire Selection Criteria and Technical Charts and

Tables

Wireline Selection
Scope
Proper selection of the wire used in wireline service operations is important for the safe
and successful completion of any wireline job. It is important for the wireline service
specialist to understand the limitations of the wire and the effects that well environments
may have on the wire being used.

General Information
Natural wellbore environments and those induced by man may cause corrosion to the
wireline. This corrosion can be controlled either through chemical inhibition or by
changing to a wireline with a different composition. Recent advances in metallurgy have
led to new types of alloy wirelines that have a very high resistance to corrosion. The
following is a discussion of the normal types of corrosion and the methods used to combat
them, followed by a discussion of wireline minimum breaking strength.

Five types of corrosion will be discussed. These types of corrosion are pitting, general
weight loss, crevice corrosion, hydrogen embrittlement or sulfide stress cracking, and
stress corrosion cracking. Corrosion is caused by the presence of oxygen, acid, carbon
dioxide, hydrogen sulfide, and chlorides, whether naturally occurring or not.

The most common type of corrosion is pitting, which is caused by the presence of oxygen,
acid, or carbon dioxide. Oxygen converts iron or steel into rust or Fe2O3. In the case of
wireline, this can only occur on bright steel wire that has not been used for some time and
is not protected by a coating of oil or inhibitor. As rust appears, pitting occurs which mean
a loss of cross-sectional area. This means a reduction in breaking strength of the wireline.
Of course, all of the alloy steel wirelines are extremely resistant to this type of corrosion.

Acids can still be present in the wellbore during wireline operations, during or after
workover operations. Since wireline operations are of limited duration, pitting during
operations will not be a problem. However, acid left on the wireline will cause pitting to
occur. This can usually be eliminated through the use of an inhibitor placed in a chemical
injection sub (liquid chamber).

Carbon dioxide (CO2) in the presence of water creates carbonic acid which will in turn
cause pitting. CO2 is of great concern to producers and pipeline companies when selecting
their tubulars. It is considered to be of much less concern when selecting wireline. CO2
causes problems in tubulars mainly because the fluid or gas is constantly in motion. When
the fluids are not moving, acid will produce a thin oxidant film which will partially protect
the underlying metal. When the fluids are moving, this film is continuously removed
exposing fresh metal to attack. Wireline is normally done under static conditions and CO2
is not usually a problem; however, if CO2 corrosion is considered to be a concern, the use
of any of the wirelines with more than about 8% chrome (Cr) will reduce the corrosion to

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Slickline Operations Manual SL 4.1: Wire Selection Criteria and Technical Charts and Tables

almost nothing. However, if H2S is not present, it is usually considered more cost effective
to use bright steel wireline, accept the pitting that does occur, and replace the wire more
often.

Almost all of the alloy steels are quite resistant to this type of corrosion. However, duplex
steels have been found to be affected during extended tests using boiling hydrochloric
acid. As noted earlier, wireline is never exposed to this severe environment; however,
advances in metallurgy have led to comparably priced wirelines that are much more
resistant to acid. This has led to duplex steel being seldom used for wireline anymore.

Pitting is a localized type of corrosion. Another type of corrosion is referred to as weight

loss, which is a more generalized type of corrosion. It involves the same types of
chemicals and reactions that are involved in pitting corrosion, but the loss of material
occurs over a much larger area. This type of corrosion still reduces the OD of the wire and
thereby the minimum breaking strength.

Crevice corrosion is an accelerated type of pitting corrosion that takes place in a confined
area, or crevice. This is most often seen in a sealing area such as inside the wireline valve
ram bore or in the o-ring groove on a section of lubricator. This type of corrosion is not
normally experienced with wireline, but it might occur if wireline is allowed to stay inside
the stuffing box packing.

The presence of H2S can lead to hydrogen embrittlement or sulfide stress cracking if
present in sufficient quantities to be considered sour service. Hydrogen embrittlement is
caused by the presence of free hydrogen ions. Sulfide stress cracking (SSC) can be
considered a type of hydrogen embrittlement where the hydrogen ions are released by
H2S. SSC is caused by the hydrogen ions penetrating the metal along the grain boundaries,
thereby reducing the cohesion between the grains. The metal becomes brittle enough to
actually shatter under stress. The process can occur extremely quickly. Therefore, standard
(sweet) service equipment or wire cannot be used for sour service, even for short periods
of time. The use of one of the alloy steel wirelines virtually eliminates any problem caused
by H2S. These wirelines, like the alloy steels used for sour service lubricator equipment,
have a Rockwell hardness of less than Rc22.

Sour service is not determined solely by the presence of H2S. Instead, it is defined by the
partial pressure of the H2S which is a function of both the concentration (ppm) and the
pressure (psi) (see Figures 4.1-1 and 4.1-2). The ppm H2S divided by one million and
multiplied by the pressure equals the partial pressure of the H2S. If the resulting H2S
partial pressure is .05 psi or greater, the well is considered to be sour. For example, a well
with 10,000 psi is considered sour if the H2S concentration is only 5 ppm.

Stress corrosion cracking (SCC) can also cause premature failure of wireline. It is caused
by a combination of stress, high temperatures, and chlorides. Actually, the presence of salt
water or any of the salts used to make brine in the oil field, such as table salt, calcium
chloride, potassium chloride, or zinc bromide, can lead to SCC.The term chlorides is used
only as a general reference.

Metals containing almost no nickel (<2% Ni), or a large concentration of nickel (>40%),
exhibit essentially no stress corrosion cracking (see Figure 4.1-3). Therefore, as noted in
the wireline recommendation chart (Table 3), bright steel wireline will show only pitting

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Slickline Operations Manual SL 4.1: Wire Selection Criteria and Technical Charts and Tables

in hot chlorides. Therefore, if H2S is not present, bright steel wireline may be the best
choice. Most of the “mid-range” alloy steels contain between 5% and 30% nickel.
Unfortunately, concentrations of nickel in this range lead to severe stress corrosion
cracking. This means that for sour service, where bright steel wireline cannot be used, one
of the more exotic wirelines must be chosen. Extremely hostile environments containing
H2S, high chlorides and temperatures above 350°F may require the use of a cobalt-based
wireline such as MP35N. This decision must be weighed carefully because of the
extremely high cost, but this wireline has been used under the most severe conditions for
more than 10 years with essentially no corrosion.

Attached as Table 5 is a National Standard’s Wireline profiles. These show the tensile
strength, weight, and stretch for various types of wireline. These values were derived by
actual measurement and are considered the best available. These sheets include at least
one wireline from each of the wireline groups shown on Table 1. All of the wirelines in
each group have very similar compositions (see Table 2) and therefore similar physical
properties. Therefore, the minimum breaking strength shown on the NS profiles of a
wireline in the same group as a wireline not listed will be quite similar. If a more exact
value is required, contact the PSL manager for slickline services.

The maximum amount of straight pull normally allowed for new wire is 60 to 65% of the
minimum breaking strength. For heavy jarring loads, this is reduced to approximately
50%. For wire whose OD has been reduced either by corrosion or mechanical damage, the
value used for minimum breaking strength must be reduced. The wire should be measured
with calipers in two directions and the diameters averaged together. This current diameter
is divided by the original diameter and the result squared. This factor is then multiplied by
the original breaking strength to obtain an estimated current minimum breaking strength.

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Slickline Operations Manual SL 4.1: Wire Selection Criteria and Technical Charts and Tables

Appendix
1. Figure 4.1-1: NACE MR0175 Sour Gas Systems
2. Figure 4.1-2: NACE MR0175 Sour Multiphase Systems
3. Figure 4.1-3: Effect of Nickel Content on SCC
4. Table 4.1-1: General Categories of Available Wirelines
5. Table 4.1-2: Compositions of Common Wirelines
6. Table 4.1-3: Recommended Wireline Section
7. Table 4.1-4: Wireline Part Numbers
8. Table 4.1-5: National Standard Wireline Properties
9. Table 4.1-6: Definitions and Conversions

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Slickline Operations Manual SL 4.1: Wire Selection Criteria and Technical Charts and Tables

SOUR GAS SYSTEMS

MOL % H2S IN GAS

0.0001 0.001 0.01 0.1 1 10
10000 10000

SULFIDE STRESS CRACKING REGION

1000 1000
TOTAL PRESSURE, PSIA

0.05 PSIA PARTIAL PRESSURE

100 100

65 PSIA TOTAL PRESSURE

10 10
1 10 100 1000 10000 100000
PPM H2S IN GAS

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Slickline Operations Manual SL 4.1: Wire Selection Criteria and Technical Charts and Tables

NACE MR-01-75 SOUR MULTIPHASE SYSTEMS

MOL % H2S IN GAS

0.0001 0.001 0.01 0.1 1 10

10,000

SULFIDE STRESS
CRACKING REGION

1.5 PSIA PARTIAL PRESSURE

1,000
TOTAL PRESSURE, PSI

265 PSIA TOTAL PRESSURE

100
10 PSIA PARTIAL
PRESSURE

10
1 10 100 1,000 10,000 100,000
PPM H2S IN GAS

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Slickline Operations Manual SL 4.1: Wire Selection Criteria and Technical Charts and Tables

EFFEC T O F Ni O N SCC

1000

CRACKING

100
Breaking Time, Hrs

M inim um T im e to C racking in
B oiling 42% M agnesium
Chloride

10

N O C R ACKIN G

1
0 20 40 60 80
N ickel, %

Table 4.1 - 1: Composition of Common Wirelines

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Slickline Operations Manual SL 4.1: Wire Selection Criteria and Technical Charts and Tables

Wire Metallurgy
Carbon Steel
• Bright Steel (API 9A Level 3 or Improved Plow Steel)
• Bright Steel (API Extra Improved Plow Steel; Hi-Strength or Monitor AA)

Austenitic Stainless Steel

• 316

6 Moly Stainless Steel

• Avesta 254SMO
• Bridon Supa 75
• 25-6 MO
• Bridon Supa 70 (discontinued)
• Bridon Supa 80 (discontinued)

Cobalt-Based Alloys
• MP35N

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Slickline Operations Manual SL 4.1: Wire Selection Criteria and Technical Charts and Tables

Table 4.1 - 2: Composition of Common Wirelines

C Mn P S Si Cr Ni Mo Cu N

Bright Steel (API .45 .60 .04 .05 .15 - - - - -

9A Level 3) min .90 max max .30

Bright Steel .60 .60 .40 .50 .15 - - - - -

(Extra Improved min .90 max max .30
Plow Steel)

316 .04 1.0 - - .50 17.5 11.5 2.2 - -

Avesta 254SMO .02 1.0 - - .80 20 18 6.25 .75 .20

max max max

Bridon Supa 75 .02 2.0 .03 .005 .50 20 25 6.5 1.10 .16
max max max

25-6 MO .02 2.0 - - .50 20 25 6.5 1.0 .20

max max max

MP35N .025 .15 - - .15 20 35 9.75 - 35

max max max

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Slickline Operations Manual SL 4.1: Wire Selection Criteria and Technical Charts and Tables

Table 4.1 - 3: Recommended Wireline Selection, Use, and Environmental Consideration

<200F <350F >350F

Alloy Class H2S
Cl < 2% Cl > 2% Cl < 2% Cl > 2% Cl < 2% Cl > 2%

Carbon Steel1 NR P P P P P P
2 E NR NR NR NR NR NR
Austenitic Stainless

6 Moly Stainless3 E E E E E I NR

Cobalt Bases Alloys4 E E E E E E E

Legend:
• NR - Not recommended, may cause cracking or embrittlement
• P - Pitting, weight loss corrosion; may be used for short duration
• I - Satisfactory for intermittent service
• E - Satisfactory for extended service

Notes:

1. Carbon Steel - can be used in any temperature/chloride (salt water) range when there
is no H2S or other corrosive fluids. However, the chlorides will cause pitting-weight
loss corrosion. The pitting would need to be monitored and the wire discarded when
the pitting becomes excessive.
2. 316 Stainless Steel - Austenitic stainless can be used in salt water up to 150-180°F.
Since most wells are hotter than this temperature range and most have salt water
(chlorides), 316 SS is rarely recommended.
3. 6 Moly Stainless Steel - such as 254SMO (Supa 70 equivalent, which has been
discontinued) and 25-6MO (Supa 75 Equivalent) are good for any combination of H2S
and chlorides in temperatures up to 350°F. 25-6MO can also be used in H2S and CO2
wells that have low concentrations (2% or less) of chlorides for intermittent service at
temperatures above 350°F.
4. MP35N - is good for any combination of H2S and chlorides in temperatures over
350°F. As with the other wirelines acids can crack MP35N. However, MP35N will
withstand acids much better than the other wirelines. MP35N is considered the best
wireline available.

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Slickline Operations Manual SL 4.1: Wire Selection Criteria and Technical Charts and Tables

Table 4.1 - 4: Wireline Part Numbers for Reference*

Reference
Size Length Description
Part No.

.072 10M Bright Steel - Improved Plow 92L5

.082 15M Bright Steel - Improved Plow 92L2

.082 18M Bright Steel - Improved Plow 92L10

.082 18M Bright Steel - Extra Improved 92L24

Plow (Monitor AA)

.082 20M Bright Steel - Improved Plow 92L11

.082 25M Bright Steel - Improved Plow 92L25

.082 25M Bright Steel - Extra Improved 92L32

Plow (Monitor AA)

.082 25M 316 Stainless Steel 92L62

.092 10M Bright Steel - Improved Plow 996.MW005

.092 15M Bright Steel - Improved Plow 996.05364

.092 18M Bright Steel - Improved Plow 996.05369

.092 18M Bright Steel - Extra Improved 92L23

Plow (Monitor AA)

.092 18M 316 Stainless 92L31

.092 20M Bright Steel - Improved Plow 804.62188

.092 20M Bright Steel - Extra Improved 92L33

Plow (Monitor AA)

.092 20M 316 Stainless 92L21

.092 20M Bridon Supa 75 92L153

.092 25M Bright Steel - Improved Plow 996.05371

.092 25M Bright Steel - Extra Improved 996.05398

Plow (Monitor AA)

.092 25M 316 Stainless 92L73

.092 25M Avesta 254 SMO 92L151

.092 25M Bridon Supa 75 92L154

.092 25M MP35N 92L65

.092 30M Bright Steel - Improved Plow 92L140

.105 15M 316 Stainless 92L167

.105 15M Avesta 254 SMO 996.18993

.105 18M Bright Steel - Improved Plow 996.05389

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Slickline Operations Manual SL 4.1: Wire Selection Criteria and Technical Charts and Tables

Table 4.1 - 4: Wireline Part Numbers for Reference*

Reference
Size Length Description
Part No.

.105 18M Avesta 254 SMO 92L148

.105 20M Bright Steel - Improved Plow 996.05388

.105 20M 316 Stainless 92L138

.105 20M Avesta 254 SMO 92L150

.105 22M Bright Steel - Improved Plow 996.05392

.105 25M Bright Steel - Improved Plow 996.62003

.108 15M Bright Steel - Extra Improved 996.05396

Plow (Monitor AA)

.108 18M Bright Steel - Improved Plow 92L128

.108 20M Bright Steel - Improved Plow 804.62004

.108 20M Bright Steel - Extra Improved 92L102

Plow (Monitor AA)

.108 20M 316 Stainless 804.62008

.108 20M Bridon Supa 75 92L155

.108 20M MP35N 996.19205

.108 25M Bright Steel - Improved Plow 92L168

.108 25M Bright Steel - Extra Improved 92L90

Plow (Monitor AA)

.108 25M Avesta 254 SMO 996.MW006

.108 25M Bridon Supa 75 996.19180

.108 25M 25-6 MO 996.19184

.108 25M MP35N 996.05406

.108 30M Bright Steel - Improved Plow 92L108

.125 18M Bright Steel - Improved Plow 92L145

.125 20M Bright Steel - Improved Plow 996.18890

.125 20M Bright Steel - Extra Improved 996.18941

Plow (Monitor AA)

.125 20M 316 Stainless 996.18865

.125 25M Bright Steel - Improved Plow 92L134

.125 25M Bright Steel - Extra Improved 996.18942

Plow (Monitor AA)

.125 25M Avesta 254 SMO 996.MW001

.125 25M 25-6 MO 996.MW002

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Slickline Operations Manual SL 4.1: Wire Selection Criteria and Technical Charts and Tables

* Wireline part numbers above are for reference only. Refer to Equipment Catalog for
complete up-to-date information.

Table 4.1 - 5: Wireline Mechanical Properties

Stretch
Size Breaking Weight
Material (in./100 ft /
(dia - in.) Strength (lb) Per1000 ft (lb)
100 lb)

API-9A Bright .072 961 13.83 .996

Improved Plow Steel
(Carbon Steel) .082 1239 17.93 .771

.092 1547 22.58 .615

.105 1966 29.41 .476

.108 2109 31.11 .450

.125 2794 41.68 .340

API-9A Bright Extra .072 1169 13.83 .996

Improved Plow Steel
(Carbon Steel) .082 1479 17.93 .771
Monitor AA
.092 1828 22.58 .615

.105 2329 29.41 .476

.108 2455 31.11 .450

.125 3203 41.68 .340

316 Stainless Steel .082 1083 18.37 .812

(Austenitic Stainless)
.092 1363 23.14 .645

.105 1732 30.14 .495

.108 1786 31.88 .468

.125 2270 42.71 .349

254-SMO(6 Moly .092 1462 23.02 .622

Stainless)
.105 1818 29.98 .478

.108 1924 31.71 .452

.125 2454 42.48 .337

Bridon Supa 75(6 .092 1550 23.29 .79

Moly Stainless)
.105 N/A N/A N/A

.108 2030 32.1 .58

.125 2560 43.0 .43

25-6MO(6 Moly .092 1475

Stainless)
.105 N/A N/A N/A

.108 2050

.125 2550

Halliburton Company (Dallas, Texas) 4-15

Slickline Operations Manual SL 4.1: Wire Selection Criteria and Technical Charts and Tables

Table 4.1 - 5: Wireline Mechanical Properties

Stretch
Size Breaking Weight
Material (in./100 ft /
(dia - in.) Strength (lb) Per1000 ft (lb)
100 lb)

MP35N(Cobalt Based .092 1582 24.26 .547

Alloy)
.105 2009 31.59 .423

.108 2080 33.42 .401

.125 2724 44.77 .302

1. Sulfide Stress Cracking (SSC) - A form of hydrogen embrittlement which takes place
in the presence of H2S. Single hydrogen atoms, or ions, enter the metal matrix at the
grain boundaries. The presence of the hydrogen between the grains weakens the metal
and makes it brittle. If no stress occurs and the H2S is removed, the hydrogen ions will
eventually work their way out, leaving the metal in its former condition. If stress is
applied while the hydrogen ions are still between the grains, the metal may fracture.
2. Stress Corrosion Cracking (SCC)- In the presence of hot chlorides, corrosion cracking
is greatly accelerated in metals with nickel content between 2% and 40%. If no H2S is
present, it is common to use bright steel wireline since it is not susceptible to SCC. In
extremely hostile environments (>350°F), it may be necessary to use a cobalt-based
alloy such as MP35N.
3. 1 lb = 7000 grains
4. mol% H2S = moles of H2S/moles of gas
5. ppm H2S = Mol% H2S x 10,000
6. ppm H2S = (grains H2S per 100 ft 3 /6.7) x 1,000
7. Partial pressure = (ppm H2S/1,000,000) x pressure in psi
8. Partial pressure = (Mol% H2S/100) x pressure in psi
9. Partial pressure = (grains H2S per 100 ft 3 /6.7) x 1,000 x psi

Halliburton Company (Dallas, Texas) 4-16

Slickline Operations Manual SL 4.2: Line Stretch Calculations - Weight and Temperature

SL 4.2: Line Stretch Calculations - Weight and

Temperature
Wire Stretch Calculation
Formula 1 Unit Stretch = 4/(d2E) Ft/Ft/Lb; where d = wire diameter (inch), and E = Modulus of
Elasticity or Young’s Modulus (psi).

Total Stretch (Ft) = unit stretch x tool depth x total weight

For bright steel wireline with E = 30 x 106 lb/in2

Unit Stretch = 4/[d2(30 x 106)] = (.0424/d2 x 1/1 million) Ft/Ft/Lb; for E =

30 x 106 psi

Wire Size Unit Stretch

.062 11.04 / 1 mil

.072 8.19 / 1 mil

.082 6.31 / 1 mil

.092 5.01 / 1 mil

.105 3.85 / 1 mil

.108 3.64 / 1 mil

.125 2.72 / 1 mil

Example: Find total stretch and actual tool depth for .092 Bright Steel wire with 800 lb
total weight and at 18,000 ft tool depth.

Total Stretch (ft) = unit stretch x tool depth (ft) x total weight (lb)=
5.01/1,000,000 x 18,000 ft x 800 lb = 72 ft; actual tool depth = 18072 ft

Note Use Formula 1 for other steel with Modulus of Elasticity different from 30 x
106 psi.

Halliburton Company (Dallas, Texas) 4-17

Slickline Operations Manual SL 4.3: Wire Twist/Torsion Tester - Twist Test Chart

SL 4.3: Wire Twist/Torsion Tester - Twist Test Chart

Slickline Management System Wire Tester

Figure 4.3 - 1

Note Cover wire length with safety shield when testing.

Note Use appropriate PPE when using tester.

Tester Specifications

Grade Min Breaking Weight

Min. Twists
Diameter Strength Required

.066 11.62 32 min

.072 13.83 29 min

.082 1239 17.93 26 min

.092 1547 22.58 23 min

29.41 20 min

2109 51.11 19 min

41.68 17 min

Halliburton Company (Dallas, Texas) 4-18

Slickline Operations Manual SL 4.4: Wire Inspection System

SL 4.4: Wire Inspection System

Wireline Inspection Instrument

While not as thorough as a complete metallurgical analysis, the Halliburton Wireline
Inspection Device provides a portable, nondestructive, on-the-spot method of examining
the entire length of the wire for physical defects. The inspection method indicates
manufacturing defects, pitting, mechanical damage, necked areas and cracks in both
ferrous and non-ferrous metal wires from.092 in. to .125 in. OD.

The system consists of the Eddy Current Inspection Instrument, an AC adapter/charger

and connecting cable in a carrying case, and hardware for mounting the inspection coil to
the wireline unit’s depth counter. A different size coil is required for each wire size and is
ordered separately. The instrument can be programmed for various wires.

For a more in-depth explanation of this wire inspection tool and how it is used, see the
Slickline Manual titled “Eddy Current Tester, Part Number 996.17363”. It can be found at
the HalWorld web site that lists Slickline manuals:

http://halworld.halnet.com/hes/hesps/hespscp/hespscp_paslines_slickline_manuals.asp.

Wire Management Software

A slickline wire management program is available that tracks the life of wireline. Using an
Excel spreadsheet program, the operator records the wire history including job details and
well environment. The program uses this data to estimate and to display a graph of the
wire’s “used life”. Having the “used life” percentage, the operator knows when to remove
the wireline from service. The program also can be used to help determine when to make
adjustments in the length of the line or to reverse the line on the wireline unit. By
periodically cutting off a few feet of wireline or reversing the wireline, the operator can
increase the useable life of the overall wire length.

Though the program does not predict the “used life” with 100% accuracy, the program
will show which wireline sections have been subjected to the highest number of cycles.
Improving distribution of these cycles throughout the wireline is the key to increasing
wireline life. Long term use of the program and periodic testing of used wireline samples
will help improve the accuracy of the wireline management program.

The program, instructions for its use and a sample application can be obtained from the
Slickline Technology group in Carrollton, Texas.

Halliburton Company (Dallas, Texas) 4-19

Slickline Operations Manual SL 4.4: Wire Inspection System

A copy of API Specification 9A, “Specifications for Wire Rope”, can be ordered from the
API. Their Internet page is at http://www.api.org/. The web page for finding and ordering
API documents over the Internet is at:
http://www.cssinfo.com/apigate.html.

Documents also can be ordered by mail:

American Petroleum Institute

Order Desk
1220 L Street, NW
Washington, DC 20005-4070
USA

Or, the document can be ordered by telephone:

Call (202) 682-8375, 9:00 a.m. to 5:00 p.m. Eastern Time.

Halliburton Company (Dallas, Texas) 4-20

Slickline Operations Manual SL 4.5: Braided Line Information

SL 4.5: Braided Line Information

Braided line (wire rope) is produced in a number of sizes, type construction (strand
configuration), and materials. Braided line is 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 line 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 1500 psi, a grease head
and grease injection system is needed to pack-off the braided line against well pressure.

Table 4.5 - 1: Galvanized Steel Braided Line

Size > 3/16 3/16 7/32 7/32

** 1 X 19 ** 1 X 19
Construction > 1 X 16 1 X 16
Dycam Dycam

Length - ft

15,000 * 92L58 - 996.MW007 -

17,000 * 92L28 - - -

20,000 996.05385 - - 996.MW003

25,000 - * 92L157 - -

* - 92L, 804, and 996 series part numbers for reference only. These part numbers will be
replaced by SAP numbers at some point. For sizes not listed, order by description.

** Dycam (Camesa) is braided line pulled through a die to form a smooth OD. The
process closes some of the voids between braids and increases the strength of the line
compared to the same OD standard braided line. Bridon's version is called Dyform.

Table 4.5 - 2: Braided Line - Breaking Strengths (Galvanized Carbon Steel)

Size 3/16 3/16 7/32 7/32

Construction 1 X 16 ** 1 X 19 1 X 16 ** 1 X 19
Dycam Dycam

Breaking 4500 6400 6000 8600

Strength (lb)

Note Breaking strength will vary slightly depending on manufacturer.

Halliburton Company (Dallas, Texas) 4-21

Slickline Operations Manual SL 4.6: Wire Fallback

SL 4.6: Wire Fallback

“Rule of Thumb” for Wire Fallback
By cutting measured lengths of wire on numerous fishing exercises in a 3,000 ft training
well, the following table has been compiled. The table shows the distance that the wire
will fall back down the hole per 1,000 ft of length. Although not totally accurate under all
conditions, field experience has proved the table to be a reasonable guide in determining
the depth of the top of the broken wire.

Amount of Wireline Fallback per 1,000 ft

Fallback per
Tubing Size (in.) Wireline OD 1000-ft. of Wire Length
(ft)

2 3/8 .082 8

2 3/8 .092 10

2 7/8 .082 10

2 7/8 .092 12

3 1/2 .092 16

3 1/2 .108 15

3 1/2 3/16 20

4 1/2 .108 27

4 1/2 3/16 35

5 1/2 .108 40

5 1/2 3/16 50

7 .108 90

7 3/16 100

Halliburton Company (Dallas, Texas) 4-22

Slickline Operations Manual SL 4.7: General Hydraulic Unit Specifications

SL 4.7: General Hydraulic Unit Specifications

Open-Loop Hydraulic Drives

Most slickline units are configured with open-loop hydraulic systems. That is, the oil
flows in a path that is “open” at the reservoir, where the oil returning from the drive is
open to atmospheric pressure and the bulk of oil mixes together before returning to the
pump. The oil flows from the reservoir, to pump, to four-way valve, to motor, back to
four-way valve and back to the reservoir. Along the way, the oil is directed through filters
and a cooler, and may be directed to various control valves. The same power components
are used whether it is an all-in-one skid unit, or a two piece unit with separate power and
skid units where the hoses are coupled with quick-connectors. There are variations in the
control components and there are other variations between slickline units so always check
the units' parts list before ordering parts.

With two-piece slickline units, there is some flexibility in matching an open-loop power
unit to drive an open-loop reel unit. However, there is a difference in where the main relief
and pressure control valve is mounted and how it is controlled. Older reel units have the
pressure control valve mounted in their hydraulic system and the pressure control is
"local" to the reel unit. Newer reel units have the pressure control valve mounted on the
power unit. These newer reel units require that a pressure control pilot hose be connected
to the pilot-operated relief valve on the power unit.

A newer power unit with a remote control relief valve can be used with an older reel unit
that has the pressure control in its circuit. An older power unit that does not have a remote
pressure control valve cannot be used with a newer reel unit that requires this remote
pressure control valve. However, older power units can be modified to operate with the
newer reel units as well as with the older reel units.

Most heavy-duty open-loop slickline units require a hydraulic supply of:

Sustained Flow Rate Capability = 56 Gallons per Minute (212 Liters per Minute)
Sustained Pressure Capability = 2000 pounds per square-inch (138 Bar)

Halliburton Company (Dallas, Texas) 4-23

Slickline Operations Manual SL 4.7: General Hydraulic Unit Specifications

Closed-Loop Hydraulic Drives

Many newer slickline units have been equipped with closed-loop hydraulic systems, also
known as hydrostatic drives. In these systems, most of the oil follows a "closed" path.
Only a portion of the oil being circulated returns to the reservoir during each circuit of the
system. Most of the oil being circulated flows from the pump to the drive motor and
directly back to the pump. The direction and speed of the reel is varied through controls on
the variable pump and motor. A portion of the oil being circulated is removed through a
built-in valve and flows through a cooler and filters. This oil is put back into the system by
a charge pump that is part of the main pump. Units with closed-loop hydraulic systems
cannot be "mixed" with power units other than those specifically designed for the reel unit
being used.

Operating Procedures
Refer to Operation and Maintenance Manual(s) for the specific unit(s) being used.
Perform pre-start inspections, starting, operating and shutdown procedures, and post-job
inspection and maintenance as indicated in manual(s).

See the following HalWorld Intranet site for a link to operating manuals for hydraulic
units:
http://halworld.halnet.com/hes/hesps/hespscp/hespscp_paslines_slickline_manuals.asp

Slow Speed Kit Upgrade

To run a Pulse Neutron Logging tool, a steady, slow speed of approximately 3-10ft. per
minute is required.
Although most of the Halliburton direct drive units built after 2014 come with the slow
speed kit pre-installed as standard, if any location has a Halliburton unit that does not
have a slow speed kit, there may be slow speed kits available for those units.

As unit 101474238 was originally designed for fast speeds with excellent jarring
response, rather than a steady slow speed, Slickline Technology designed a slow speed
kit for the Single Piece Stainless Steel Unit (below). Technology came up with a solution
to replace the existing motor with a Rexroth motor (101883460) and a gear box
(102493758), both of which are part of slow speed kit 102491811.

The parts, the reference drawing and procedure required to complete the modification of
unit 101474238 with the slow speed kit are listed below

Halliburton Company (Dallas, Texas) 4-24

 Slickline Operations Manual SL 4.7: General Hydraulic Unit Specifications

Affected Parts
Equipment
Description Part Number Revision
Number

SKL STNLS STL UNIT,DIR DR,SNGL DRUM,DEUT 101474238 All 11965152

MTR,HYDR,FXD,20.7 CU.IN/REV. DISPL 100138379 NW
REEL,0.092/0.108,27000/20000 FEET CAP 100159208 NX

Required Parts

Description Part Number Revision

SLOW SPEED MODIFICATION KIT FOR SSU 102491811 C

Installation Procedure
 D01065032 – Slow Speed Installation Procedure

Slow Speed Modification Kit Drawing

 996.20726 – Slow Speed Modification Kit Drawing For SSU

Something worth noting is that when the Slow Speed Kit is installed into unit 101474238 the assembly
will grow by approximately 5 inches, causing the motor to extend outside the frame.

Halliburton Company (Dallas, Texas) 4-25

Slickline Operations Manual SL 4.8: Slickline Reel Chart - Dimensions and Capabilities

SL 4.8: Slickline Reel Chart - Dimensions and Capabilities

Table 3: Wireline Reel Capacities and Dimensions

"AMAP" Nominal Flange Between Core Shaft

Reference Recommended
Reference Capacity Diameter Flanges Diameter Diameter
Number Wire Size
Number (ft) (in.) (in.) (in.) (in.)

996.03486 82M2317 .092 16 19 8.25

996.03487 82M2318 .187 17,000 24 19 10.75

996.03495 82M2399 .187 20,000 24 22.8 10.75

996.03502 82M2496 .187 9000 18 15 8

996.03539 82M2934 .187 20,000

996.03564 82M3444 .108 26,000 18 22.8 7.88

996.03574 82M3582 7/32 25,000 30 24 11

996.03685 82M4420 .108 22,000 16 20 8

996.03715 82M4483 7/32 12,500 26 15 8

996.03732 82M4518 7/32 17,000 28 19 11

996.03743 82M4530 .108 20,000 16 19.8 7.88

996.03749 82M4563 7/32 25,000 30 24 11

996.03796 82T889 .092 20,000 15 18 6

996.04195

996.14389 .125 25,000 24 22.8 14.75

996.15483 .125 22,000 24 19.38 14.75

996.16529 .092 30,000 26 25.5 19.75 Direct

.125 20,000 Drive*

996.16530 .188 20,000 26 25.5 14.75 Direct

Drive*

996.17541 7/32 15,000 24 22.8 10.75

996.17958 .125 22,000 25 16 14.75 Direct

Drive*

996.18163 .188 22,000 28 25.5 14.75 Direct

7/32 20,000 Drive*

996.18167 .092 30,000 26 25.5 19.75 Direct

.125 25,000 Drive*

996.18682 .188 22,000 32 16 14.75 Direct

Drive*

996.18940 .092 27,000 18 18 7.88 Direct

.108 20,000 Drive**

996.19052 .092 25,000 16 19.32 7.88

Halliburton Company (Dallas, Texas) 4-26

Slickline Operations Manual SL 4.8: Slickline Reel Chart - Dimensions and Capabilities

Table 3: Wireline Reel Capacities and Dimensions

"AMAP" Nominal Flange Between Core Shaft

Reference Recommended
Reference Capacity Diameter Flanges Diameter Diameter
Number Wire Size
Number (ft) (in.) (in.) (in.) (in.)

996.19207 .092 27,000 18 18 7.88 Direct

.108 20,000 Drive**

996.19386 .188 30,000 30 25.5 14.75 Direct

7/32 22,000 Drive*

**Direct drive "Lightweight" unit.

Halliburton Company (Dallas, Texas) 4-27

Slickline Operations Manual SL 4.9: Reel Capacity Calculation

SL 4.9: Reel Capacity Calculation

Conversion Factors to Estimate Wire Capacities of Reels

The following table lists conversion factors that can be used to estimate the capacity of a
reel when spooling on a different size of wire.

CAUTION Using wire larger in diameter than the recommended size can cause structural failure of
the reel. Using wire on reels with smaller core diameters than recommended can shorten
the useful life of the wire on wraps closest to the reel core.

Multiply To Estimate
By This
Capacity of This Capacity of This
Factor
Wire Size Wire Size

.092 1.12 .082

.092 0.81 .108

.092 0.28 3/16

.108 1.23 .092

.125 1.33 .108

.125 0.44 3/16

3/16 0.73 7/32

3/16 0.61 1/4

3/16 0.39 5/16

7/32 0.534 5/16

Example: To estimate how many feet of .108 wire a reel will hold when it is known that
the reel will hold 30,000 ft. of .092 wire.

30,000-ft. capacity of .092 wire x 0.81 = 24,300 ft. estimated capacity of .108 wire

Halliburton Company (Dallas, Texas) 4-28

Slickline Operations Manual SL 4.9: Reel Capacity Calculation

Formula to Estimate Wire Capacity from Reel Dimensions

Following is a formula that can be used to estimate the wire capacity of a reel when only
the dimensions are known, not the capacity of any wire size.

WrapDia (in.) = Diameter of Outer Wrap (Usually the Rim Diameter minus 1-inch.)
CoreDia (in.) = Diameter of Reel Core
CoreWidth (in.) = Distance Between Inside Surfaces of Rims
WireDia (in.) = Diameter of Wire to be Spooled on Reel

Formula 2 Capacity in Feet = [(WrapDia² - CoreDia²) x CoreWidth] / (WireDia² x 15.28)

Note Capacities calculated with the above factors and formulas are approximate only.
Reel capacities vary depending on how the wire is spooled onto the reel.

Halliburton Company (Dallas, Texas) 4-29

Slickline Operations Manual SL 4.10: Mechanical Counter System

SL 4.10: Mechanical Counter System

Counter Wheels
Heavy-duty slickline units have "four-foot" counter wheels, sometimes called "16-inch"
wheels. Using this size of counter wheel helps to extend the useful life of slickline wire.
Running wire over smaller-diameter "two-foot" counter wheels can reduce the fatigue life
of the wire. For best accuracy, the counter wheel should be in good condition without
excessive wear of the surface on which the wire wraps. Each size of wire requires a certain
size of counter wheel and wheels measuring in feet are a different size than wheels
measuring in meters. Pressure wheels sometimes are different too, depending on the size
of the counter wheel. When the size of wire being used is changed the counter wheel and
pressure wheels also must be changed to the correct sizes. The following table lists the
various sizes of counter wheels and pressure wheels required for each wire size. During
manufacturing, the wheels are marked on their sides with their Part Number or Reference
Number. For checking purposes, the table also lists the nominal dimensions of the counter
wheel.

WIRE SIZE .082 .092 .105/ .108 .125 .187 .225 (7/32 NOMINAL) .250
FT/METER FEET METER FEET METER FEET METER FEET METER FEET METER FEET METER FEET METER
COUNTER
WHL. REF. NO. 996.13918 996.13922 996.03619 996.13921 996.03620 996.03625 996.14495 996.15378 996.13925 996.13920 996.13924 996.13919 996.13923 996.13917
“AMAP”
WHL. REF. NO. 82M4155 82M4156 82M4109 82M4157 82M4110 82M4152 82M4615 82M4620 82M4111 82M4158 82M4112 82M4159 82M4113 82M4160
GROOVE
DIA., IN. 15.197 15.583 15.187 15.573 15.171 15.557 15.153 15.540 15.092 15.478 15.054 15.439 15.029 15.415
GROOVE
WIDTH, IN. .179 .179 .197 .197 .226 .226 .272 .272 .408 .408 .490 .490 .544 .544
WHEEL
OD, IN. 15.70 16.375 15.70 16.375 15.70 16.375 15.70 16.375 15.70 16.375 15.70 16.375 15.70 16.375
WHEEL
WIDTH, IN. .64 .64 .64 .64 .64 .64 .67 .67 .77 .77 .83 .83 .86 .86
PRESSURE
WHL. REF. NO. 804.12338 804.12338 804.12534 804.12534 804.1331 804.1331 804.1227 804.1227 804.1321 804.1321 804.20069 804.20069 804.20072 804.20072

Right-Angle Drives and Veeder-Root Counters

A “four-foot” counter wheel measuring in feet makes exactly one revolution for each four-
feet of wire that goes past the wheel. A “four-foot” counter wheel measuring in meters
makes exactly one revolution for every 1.25 m of wire that goes past the wheel. Because
the length of wire being measured is different, each type of counter wheel (feet or meters)
must be matched with the correct right-angle drive (at the counter wheel) and Veeder-Root
indicating counter.

Halliburton Company (Dallas, Texas) 4-30

Slickline Operations Manual SL 4.10: Mechanical Counter System

Measuring in Feet
Counter Wheel, 1 Revolution Output = 4-feet
Right-Angle Drive with 1:2 Increasing Ratio 2 Revolution Output
Veeder-Root with 1:2 Increasing Ratio 2 Revolutions Input = 4 Counts
(Veeder-Root calls this a 0.5 Ratio, 0.5 turns input = 1 count)

Reference Numbers:
Right Angle drive, Reference 996.10260. “AMAP” Reference Number, 98C22 Veeder-

Root counter, Reference 996.04168. “AMAP” Reference Number, 82TO130

Measuring in Meters
Counter Wheel, 1 Revolution Output = 1.25
meters
Right-Angle Drive with 1:2 Increasing Ratio 2 Revolution Output
Veeder-Root with 1:0.625 Decreasing Ratio 2 Revolutions Input = 1.25
Counts
(Veeder-Root calls this a 1.6 Ratio, 1.6 turns input = 1 count)

Reference Numbers:
Right Angle drive, Reference 996.10260. “AMAP” Reference Number, 98C22

Veeder-Root counter, Reference 996.04229. “AMAP” Reference Number, 82TOM130

Halliburton Company (Dallas, Texas) 4-31

Slickline Operations Manual SL 4.11: Electronic Depth Counter System

SL 4.11: Electronic Depth Counter System

The Halliburton electronic depth-counter system consists of the Advanced Measuring
System (AMS), which is panel mounted or portable, an electronic load cell (instead of the
hydraulic Martin-Decker load cell) and an optical encoder, which is an “electronic
counter”. The electronic load cell can be mounted remotely at the bottom hay pulley, the
same as with hydraulic load cells, or it is mounted as part of the two-wheel counter. The
optical counter can be “added on” to an existing system, or it is mounted as part of the
Halliburton two-wheel counter. All types of AMS displays have features that adapt them
to many different rig-up and equipment combinations. Each equipment combination has
specific input requirements before the system will provide accurate and usable outputs.

Separate Load Cell and Optical Encoder, Any AMS Type

Instead of a hydraulic load cell (Martin-Decker), an electronic load cell is mounted at the
hay pulley. Additionally, an optical encoder is mounted to the slickline unit and driven by
its counter wheel. This setup can be used with any AMS unit, panel or portable type, as
long as an Intrinsically Safe (IS) load cell, and an IS optical encoder, is used with the
Portable-IS-AMS.

Note Be sure to use the correct values when setting the AMS.

1. Correct load angle at pulley where load cell is mounted. See Section SL 4.13 for
explanation.
2. Correct size of counter wheel: 2-ft.; 4-ft.; 1.25-m; etc.
3. Correct wire size.
4. Correct rotation. There are two choices. The wrong choice will cause the AMS to
count "backwards".

Halliburton Two-Wheel Counter Assembly

The Halliburton two-wheel combination counter was developed for direct measurement of
line tension and depth. It uses two in-line 4-foot-circumference wheels. One wheel is the
Universal “depth-counter” wheel used to count rotations, and the other wheel includes a
load sensor that is used as its axle. The two-wheel combination counter allows the wireline
to wrap around the two wheels in a non-reverse bend, thereby reducing wire fatigue. The
counter accommodates .092-in. to .125-in. slickline, 3/16-in.-braided line, and 7/32-in. to
5/16-in. electric line (the same selections as the AMS panels). The Universal counter
wheel is a fixed circumference wheel that is used with all the wire sizes above. The
operator inputs the wire size being used. Software in the AMS computes the depth using
this setting and the circumference of the Universal wheel. This way, the Universal
measuring wheel enables the AMS to compute the true depth without having to change
counter wheels to “match” the wire size.

Halliburton Company (Dallas, Texas) 4-32

Slickline Operations Manual SL 4.11: Electronic Depth Counter System

The rear-most wheel uses a load pin as an axle. A load pin is a device with strain gauges
that sends out an electrical signal in proportion to the load on the pin. The load pin is
mounted in an eccentric housing that is marked to indicate the effective load angle. When
a job is set up, the wire passes over the forward Universal counter wheel (toward the well),
passes over the rear wheel, which is on the load pin, and exits towards the well. The load
pin wheel pivots on the eccentric axis and the effective load angle is indicated on the load
pin housing. This angle is entered into the AMS so that the software can calculate the
correct value of wire tension. (See Section SL 4.13 for description of load angles.) The
AMS uses actual line tension to calculate line stretch. Line stretch is used in the depth
calculation.

Rotation of the Universal counter wheel drives an optical encoder (a counter) through the
“T”-shaped right-angle drive. The other leg of the “T” drives a flexible shaft connected to
a Veeder-Root mechanical counter. This supplies a backup depth indication if the
electronic system fails although the mechanical system is less accurate than the AMS.

Note Because one wheel (Universal wheel) is used for all wire sizes, the mechanical
and electronic depth systems will not agree. Refer to the AMS operating manual for
correlation charts used to correct the mechanical depth readout for the appropriate wire
size.

Under normal operating conditions, wire is held in contact with the wheel grooves by the
tension of the wire and the retainer wheels at the front counter wheel originally were
designed only to keep the wire inside the wheel groove. Under certain operating
conditions, however, tool weight may not be enough to keep the wire in contact with the
groove. If the contact is lost momentarily, some relative movement of the wire with
respect to the wheel may occur. The "slippage" will cause incorrect depth calculations by
the AMS. Slippage may not be apparent to the operator. See the following section, Two-
Wheel Counter Maintenance, for information on adjusting the retainer wheels.

Note Be sure to use the correct values when setting the AMS.

5. Input the load angle correctly so that the AMS correctly calculates he actual line
tension.
6. Correct size of counter wheel - Universal.
7. Correct wire size.
8. Correct rotation. There are two choices. The wrong choice will cause the AMS to
count "backwards".
9. Retainer wheels must be adjusted to maintain contact between the wire and the wheel
groove.
10. The eccentric bushing must move freely about its axis when not under load.

Halliburton Company (Dallas, Texas) 4-33

Slickline Operations Manual SL 4.11: Electronic Depth Counter System

Two-Wheel Counter Maintenance

• Refer to the Two-Wheel Counter Equipment Manual for general maintenance
instructions. The site is:
http://halworld.halnet.com/hes/hesps/hespscp/hespscp_content/slickline/2wcountr.pdf
• Make sure the optical encoder shaft is not end-loaded. Any end load on this shaft will
damage the encoder.
• Adjusting Retainer Wheels - Periodic adjustment is not needed unless a different size
wire size is used, new wire of the same size is spooled onto the reel, or the mounting
bolt has loosened. After a wire is placed in the groove, loosen the retainer-wheel
mounting bolts and slide the top retainer wheel against the wire. Maintain moderate
pressure against the wire while tightening the mounting bolt. Make sure that the wheel
is snug against the wire but avoid crushing the wire. Note that this wheel is used as a
retainer wheel, not a "pressure" wheel. Repeat this procedure on the lower retainer
wheel.
• Lubricate fairlead guide roller bearings using grease.
• Lubricate the tension angle indicator shaft using grease to protect the self-aligning
machined surface from corrosion.
• Lubricate swivel base and linear rod bearings using grease.
• Lubricate right angle drive adapter with powdered graphite and inspect condition of
drive tang.
• If equipped with optional line oiler, make sure the line oiler is supported properly to
avoid damage to the wire.

Two-Wheel Counter Reference Numbers

Reference Number Description

996.17927 Standard duty with Universal wheel and swivel base

996.18127 Intrinsically Safe with Universal wheel and swivel base
996.18375 Intrinsically Safe with Universal wheel and overhead pivot
996.18481 Standard duty with Universal wheel and overhead pivot

Halliburton Company (Dallas, Texas) 4-34

Slickline Operations Manual SL 4.12: Advanced Measuring System (AMS)

SL 4.12: Advanced Measuring System (AMS)

The AMS depth panel automatically corrects for wireline stretch and error caused by
temperature changes in the measuring wheel. The operator must select the wireline size to
ensure proper wireline stretch corrections to the depth display. Operators must also select
the ambient temperature so the panel can make automatic wheel error corrections.

The complete operator's manual can be accessed at the following Halliburton site:
http://halworld.halnet.com/hes/hesps/hespscp/hespscp_content/slickline/ams.pdf

Power required by the AMS panel is 9-30 VDC. The AMS depth panel is fused at 4
amperes maximum current and has reverse polarity protection. If improper polarity
voltage is applied to the panel no damage or possible fire can occur. Loss of power to the
AMS depth panel during operation will not cause a loss of depth data. The panel
continuously stores depth data every 100 milliseconds in a battery-supported memory
device. When power is applied to the panel, the last "Depth" is displayed.

Beginning a job, the Zero Depth switch sets the panel depth display at zero. This switch is
only recognized and read by the AMS when line speed is zero. If this switch is pressed
during a wire line operation the depth display will indicate zero depth. To avoid this
possible loss of depth data, the panel stores depth data until the depth changes from zero.

Note If this switch is pressed in error, do not allow the wire to move. To recover depth
while downhole, press this button again to recall the previous depth display. Do not allow
wire line to move before the switch is pressed again or the depth history will be lost.

The AMS panel is programmed to prevent almost all switches from making setting
changes during wire line operations. Most switch settings are recognized and read only
when depth is equal to zero and/or when line speed is equal to zero. Operator control
switches that directly change the depth display are accompanied by an audible tone when
depressed. These switches are "Zero Depth", "Up Depth" and "Down Depth".

Halliburton Company (Dallas, Texas) 4-35

Slickline Operations Manual SL 4.12: Advanced Measuring System (AMS)

Panel Mounted AMS Reference Numbers

Several panel-mounted AMS units have been supplied with special features. Following
are the three standard units. All panel-mounted AMS units display depth and speed using
Feet or Meters according to a switch selection by the operator.

Reference Number Description

996.18265 With analog and digital depth displays indicating Kilograms

996.18266 With analog and digital depth displays indicating Decanewtons
996.18808 With analog and digital depth displays indicating Pounds

Portable and Portable IS-AMS Units

The Advanced Measuring System is available in two portable versions, a standard-duty
unit for unclassified areas and an Intrinsically Safe (IS) unit designed and certified for
Class 1 Division 2 areas. Both units are housed in a weatherproof aluminum body and
have a color LCD screen with a row of operating buttons under the screen. Both models
have internal rechargeable batteries and may be operated independently of external power
supplies.

All portable AMS units require separate electronic load cells to measure line tension and
optical encoders to "count" wire displacement. Like the panel-mounted versions, the
portable units calculate the wire depth. Starting with the "counts" of the optical encoder,
the software program takes into account the stretch of the wire and the effects of
temperature upon the counter wheel.

The complete operator's manual can be accessed at the following Halliburton site:
http://halworld.halnet.com/hes/hesps/hespscp/hespscp_content/slickline/ams.pdf

Portable AMS Reference Numbers

Portable AMS units have been supplied separately, and with load cell and optical encoder.

Reference Number Description

996.18130 Intrinsically Safe portable unit only

996.18350 Standard service portable unit only for unclassified areas
996.18711 Intrinsically Safe portable unit with load cell and optical encoder
996.WM101 Standard service portable unit with load cell and optical encoder

Halliburton Company (Dallas, Texas) 4-36

Slickline Operations Manual SL 4.13: Weight Indicators

SL 4.13: Weight Indicators

Weight Indicator Correction Factor

Because of the way forces act, a load cell/weight indicator cannot directly measure the
tension on wireline. Figure 4.13 - 1 shows a wireline passing over a sheave suspended
over a lubricator stack. If the tool string weighs 150 lb, and the operator is pulling 150 lb.,
then a 300-lb force is exerted on the sheave. To make the weight indicator display a line
tension of 150 lb, the indicator manufacturer must build in a correction factor of 0.5.

LOAD CELL

300 LB.

150 LB. 150 LB.  150 LB.

STUFFING
Figure 4.13 - 1

Halliburton Company (Dallas, Texas) 4-37

Slickline Operations Manual SL 4.13: Weight Indicators

When there is an angle other than 0between the wires, the force on the weight indicator
no longer is twice the line tension. There will be a different correction factor for each
angle. The Martin-Decker weight indicator is manufactured with a correction factor for an
angle between the wires of 90. This factor built into the indicator is 0.7071. At an angle
of 90, as shown in Figure 4.13 - 2, a line tension of 150 lb exerts a force of 212 lb on the
weight indicator. The correction factor of 0.7071 multiplied times this 212 lb corrects the
reading to 150 lb. This correction factor is built in and cannot be changed. If the job
requires a rig-up where the angle is different than 90, the weight indicator reading must
be corrected. The equations at the bottom of Charts 1 and 2 show how the corrections are
calculated.

TO STUFFING BOX

90° HAY PULLEY

LOAD CELL

WIRELINE UNIT

Figure 4.13 - 2

Halliburton Company (Dallas, Texas) 4-38

Slickline Operations Manual SL 4.13: Weight Indicators

Example:

Figure 4.13 - 3 shows a situation where the angle between the wires is 60. Chart 1 shows
a correction factor of 1.225 for 60. Multiplying 200 lb x 1.225 = 245 lb. Therefore, the
weight indicator reading should be 245 lb at an actual line tension of 200 lb.

TO STUFFING BOX

60°
HAY PULLEY

LOAD CELL

Figure 4.13 - 3

These correction factors are useful when spooling wire on the reel and maintaining the
proper tension. The recommended spooling tension is 20% of the minimum breaking
strength of the wireline.

Example:

For .092 bright steel, 20% of the minimum breaking strength is approximately 309 lb.
When using a wireline unit's own spool off device, the angle between the wire at the load
cell sheave usually is less than 10. The factor from Chart 1 for 10is 1.410. Multiplying
309 lb x 1.410 = 436 lb. This shows that to have approximately 309 lb of tension on the
wire, the spool off drag should be adjusted so that the weight indicator at the sheave
indicates between 430 and 440 lb.

Halliburton Company (Dallas, Texas) 4-39

Slickline Operations Manual SL 4.13: Weight Indicators

Table 4.13 - 1: Known Load - What Should the Weight

Indicator Read?
Calculating the expected reading on the weight indicator for a known load. Knowing the
wire angle and the desired wire tension, multiply the desired wire tension by the factor to
determine the weight indicator reading.

Formula 3 (Desired Wire Tension) x (Conversion Factor) = Expected Weight

Indicator Reading

Table 4.13 - 1: Known Load - What Should the Weight Indicator Read?

Wire Angle Conversion

(Degrees) Factor

Less Than 10 1.410

20 1.393
30 1.366
40 1.329
50 1.282
60 1.225
70 1.158
80 1.083
90 1.000
100 0.909
110 0.811
120 0.707
130 0.598
140 0.484
150 0.366
160 0.246
170, Maximum 0.123

How it's calculated: Conversion Factor = cosine (angle/2) x 1.4142

Halliburton Company (Dallas, Texas) 4-40

Slickline Operations Manual SL 4.13: Weight Indicators

Table 4.13 - 2: Known Weight Indicator Reading - What is

Wire Tension?
Calculating the actual wire tension for a known weight indicator reading. Knowing the
wire angle and the actual weight indicator reading, multiply the weight indicator reading
by the factor to determine the actual wire tension.

(Weight Indicator Reading) x (Conversion Factor) = Actual Wire Tension

Table 4.13 - 2: Known Weight Indicator Reading - What is Wire Tension?

Wire Angle Conversion

(Degrees) Factor

Less Than 10 0.709

20 0.718

30 0.732

40 0.752

50 0.780

60 0.816

70 0.864

80 0.923

90 1.000

100 1.100

110 1.233

120 1.414

130 1.672

140 2.066

150 2.732

160 4.065

170, Maximum 8.130

How it's calculated: Conversion Factor = 1 / [cosine(angle/2) x 1.4142]

Halliburton Company (Dallas, Texas) 4-41

Slickline Operations Manual SL 4.14: General Purpose Pump Skid

SL 4.14: General Purpose Pump Skid

These pump skids are designed to test wireline lubricators and wireline valves and to be
used for chemical injection. Typically they have a holding tank of 225 gallons (852 liters).
The tank has been supplied made of stainless steel and some skid frames have been made
of corrosion-resistant metals. Nominal rating of the fluid pump is 10,000 psi (690 bar)
maximum pressure, 4800 psi (331 bar) working pressure, and maximum flow rate of
15.6 gal/min (59 liter/min).

A hydraulic power source is required for operation. For maximum rated output from the
pump skid, the hydraulic supply should be capable of providing 40 gal/min (151 liter/min)
of hydraulic fluid at 2000 psi (138 bar).

The pump skid units use a small triplex piston pump. These pumps can be supplied with
different plunger sizes. The size plunger that is used determines the skid unit's fluid
pressure and flow ratings. Be aware that some units have been supplied with smaller
plungers and those units can develop significantly higher pressures than other units. Check
the skid's Operation Manual and the piston pump nameplate to verify pressure and flow
specifications.

Note Never change the plunger size of a pump skid unit without thoroughly reviewing
the pressure and flow capabilities of the other components, particularly the valves and
piping connected to the piston pump's outlet.

Halliburton Company (Dallas, Texas) 4-42

Slickline Operations Manual SL 4.15: Pressure Control Equipment Color Coding

SL 4.15: Pressure Control Equipment Color Coding

Paint Specifications for H2S and Cold Service Equipment
Pressure Code Coating Per Engineering Drawing or Bill of Material:

1. H2S ES-C-62-*.
2. Cold, -50F to -75F (-45.5C to -59.4C) ES-C-62-*.

Service Code Coating Per Engineering Drawing or Bill of Material:

1. H2S ES-C-62-*. Pressure color code w/green stripe ES-C-115-6 over pressure code.
Stencil the letters “H2S” 1-in. high in white (ES-C-28) inside the green stripe on all
assemblies.
2. Cold, -50F to -75F (-45.5C to -59.4C) ES-C-62-*. Pressure color code with brown
stripe ES-C-115-14 over pressure code. Stencil the letters “cold” 1-in. high in white
(ES-C-28) inside the brown stripe on all assemblies.

Table 4.15 - 1: Pressure Rating Color Code Coating

ES-C-* Paint
Working Pressure Color ES-C-62-* Eng. Drawing
Spec.

2,000 ES-C-115-4 Blue ES-C-62-4

3,000 ES-C-1 Black ES-C-62-1

5,000 ES-C-115-3 Gray ES-C-62-3

6,000 ES-C-2 Red ES-C-62-2

10,000 ES-C-115-5 Yellow ES-C-62-5

15,000 ES-C-115-63 Orange ES-C-62-63

20,000 ES-C-28 White ES-C-62-28

30,000 ES-C-13 Aluminum ES-C-62-13

Lubricators: Class 46AO, 46AW, 46WO, 46FO, 46RF, 46RC.

Note For short lubricator sections (those with tube lengths too short for the
12-in. band or those with no tube at all) the ES-C-1 black finish can be eliminated with the
exception of 3,000 psi (20.7 MPA) working pressure assemblies (where the ES-C-1 is
used as the pressure color code). The external surfaces should be coated entirely with the
pressure code color. The service code stripe (with the exception of the masked thread and
seal areas) should be 2-in. wide and centered on the short lubricator sections.

Halliburton Company (Dallas, Texas) 4-43

Slickline Operations Manual SL 4.16: Halliburton Quick Union Connections

SL 4.16: Halliburton Quick Union Connections

Standard HES QUN Connections

QUN Seal Work Collar Standard

ID Service
Conn. Dia. Press OD Flange ID

5-4 3.50 2.06 5.000 STD 5.79 2-1/16

5-4 3.50 2.06 10.000 STD 5.79 2-1/16
5-4 3.50 2.06 15.000 STD 5.79 2-1/16
5-4 3.50 2.56 5.000 STD 5.79 2-9/16
5-4 3.50 2.56 10.000 STD 5.79 2-9/16
5-4 3.50 2.62 15.000 STD 5.79 2-9/16
5-4 3.50 3.00 5.000 STD 5.79 3-1/8
5-4 3.50 2.94 10.000 STD 5.79 3-1/16
5-3/4-4 4.00 2.06 5,000 H2S 6.54 2-1/16
5-3/4-4 4.00 2.06 10,000 H2S 6.54 2-1/16
5-3/4-4 4.00 2.06 15,000 H2S 6.54 2-1/16
5-3/4-4 4.00 2.56 5,000 H2S 6.54 2-9/16
5-3/4-4 4.00 2.56 10,000 H2S 6.54 2-9/16
5-3/4-4 4.00 3.00 5,000 H2S 6.54 3-1/8
5-3/4-4 4.00 3.00 10,000 H2S 6.54 3-1/16
6-1/4-4 4.00 2.62 15,000 H2S 7.54 2-9/16
7-1/2-4 5.50 3.00 15,000 H2S 8.54 3-1/16
6-1/2-4 4.75 4.00 5,000 STD 7.54 4-1/16
6-1/2-4 4.75 4.00 10,000 STD 7.54 4-1/16
8-3/8-4 5.25 4.00 5,000 H2S 9.55 4-1/16
8-3/8-4 5.25 4.00 10,000 H2S 9.55 4-1/16
9-1/2-4 6.25 4.00 15,000 H2S 10.94 4-1/16
8-1/4-4 6.18 5.00 5,000 STD 9.54 5-1/8
8-1/4-4 6.18 5.00 10,000 STD 9.54 5-1/8
9-4 6.75 5.00 5,000 H2S 10.40 5-1/8
9-4 6.75 5.00 10,000 H2S 10.40 5-1/8
12-1/4-4 7.00 5.12 15,000 H2S 14.54 7-1/16
8-3/4-4 7.50 6.38 5,000 STD 9.79 7-1/16
9-1/2-4 8.00 6.38 5,000 H2S 10.54 7-1/16
Figure 4.16 - 1
11-1/2-4 8.25 6.38 10,000 H2S 13.04 7-1/16
12-4 10.31 9.00 5,000 H2S 13.54 9

Halliburton Company (Dallas, Texas) 4-44

Slickline Operations Manual SL 4.17: Bowen Quick Union Connections

SL 4.17: Bowen Quick Union Connections

Standard Bowen QUN Connections

QUN Work
Seal Dia. ID Service
Conn. Press

4-1/16-4 3.00 2.00 7,500 H2S

4-1/16-4 3.00 2.00 10,000 STD
4-1/2-4 3.00 2.00 10,000 H2S
4-1/2-4 3.00 2.00 15,000 STD
4-3/4-4 3.75 2.50 5,000 STD
4-3/4-4 3.75 2.50 5,000 H2S
4-3/4-4 3.75 3.00 5,000 H2S
4-3/4-4 3.75 3.00 5,000 H2S
4-3/4-4 3.75 2.50 10,000 STD
5-1/2-4 4.38 3.00 5,000 STD
5-1/2-4 4.38 3.00 5,000 H2S
5-1/2-4 4.38 3.00 10,000 STD
6-4 4.88 3.50 5,000 STD
6-4 4.88 3.50 5,000 H2S
6-5/16-4 4.38 2.50 10,000 H2S
6-5/16-4 4.38 2.50 15,000 STD
6-5/16-4 3.63 2.00 15,000 H2S
6-5/16-4 3.75 2.50 15,000 H2S
6-5/16-4 4.00 2.00 20,000 STD
7-5 5.25 4.00 5,000 STD
7-5 5.25 4.00 5,000 H2S Figure 4.17 - 1
7-5 4.75 3.00 10,000 H2S
7-5 4.38 3.00 15,000 H2S
7-5 4.50 2.50 20,000 STD
7-25/32-4 4.88 3.50 15,000 H2S
8-1/4-4 6.00 4.00 10,000 STD
8-1/4-4 6.00 4.00 10,000 H2S
8-7/8-4 6.50 5.00 10,000 STD
8-7/8-4 6.50 4.75 10,000 H2S
8-7/8-4 6.00 4.00 15,000 STD
8-7/8-4 5.50 4.00 15,000 H2S
10-5/16-4 8.00 6.00 10,000 STD
10-5/16-4 7.50 6.00 10,000 H2S
13-4 9.50 7.00 10,000 STD
13-4 9.50 7.00 10,000 H2S

Halliburton Company (Dallas, Texas) 4-45

Slickline Operations Manual SL 4.18: Other Quick Union Connections

SL 4.18: Other Quick Union Connections

Figure 4.18 - 1

Halliburton Company (Dallas, Texas) 4-46

Slickline Operations Manual SL 4.19: Stuffing Boxes List

SL 4.19: Stuffing Boxes List

Stuffing Boxes
Scope
Stuffing boxes are considered critical pressure-containing components of the lubricator
stack, so it is very important that they be maintained and tested to ensure proper operation.

General Information
A wireline stuffing box is designed to control well pressure up to working pressure of the
equipment while still allowing the wireline to pass through the packing.

Stuffing boxes are available in sizes and ratings equivalent to the lubricator equipment.

All stuffing boxes must be color coded to reflect their pressure rating and service per ESC-
62 and ESC-63. Also, each stuffing box must have a metal tag with the property number
attached to it. All the scheduled testing and inspection will be documented against this
number per SO1103.

The sealing pressure exerted on the wireline by the stuffing box packing is adjusted using
the packing nut. Manual packing nuts are available, but hydraulic packing nuts are
recommended. Hydraulic packing nuts allow remote adjustment, thus eliminating the
necessity for climbing equipment. Climbing and fall safety is discussed in Section
WL1.23.

CAUTION Cat lines should never be used to lift personnel.

Stuffing box packing is sized for only one diameter of wireline. Packing kits are available
for rapid conversion to another size wire (see Technical Section XX.XX). A 16-in. stuffing
box sheave should be used with .108-in. and .125-in. wire. Use of the 10-in. sheave with
the larger wire size will greatly reduce the anticipated life of the wireline. Converting a
stuffing box to the larger size sheave will require the replacement of both the sheave and
the sheave staff.

Operation
When threading the wire through the stuffing box it is important to check the condition of
the upper packing gland, the condition of the packing, and the condition of the wireline
valve rubber which is in the bottom of the stuffing box. Periodically the bearings in the
yoke housing and the bearings on the shaft should be lubricated and checked for wear. If a
hydraulic packing nut is being used it should be serviced periodically. The o-ring on the
quick union should be inspected each time the stuffing box is installed, and should be
replaced if necessary.

Halliburton Company (Dallas, Texas) 4-47

Slickline Operations Manual SL 4.19: Stuffing Boxes List

Appendix
Stuffing Box Drawing

Figure 4.19 - 1

Halliburton Company (Dallas, Texas) 4-48

Slickline Operations Manual SL 4.20: Hydraulic Packing Nuts

SL 4.20: Hydraulic Packing Nuts

Figure 4.20 - 1

Halliburton Company (Dallas, Texas) 4-49

Slickline Operations Manual SL 4.21: Stuffing Box Packing Stacks

SL 4.21: Stuffing Box Packing Stacks

Stuffing Box Packing Inspection and Replacement Frequency

The Slickline Stuffing Box forms part of the WPCE stack that consists of primary,
secondary and tertiary barriers, all of which are designed to contain wellbore pressure and
all of which fall within one of our Critical Focus Areas, Barriers.

As there are no two wells with the same parameters the stuffing box packing selection must
be made on an individual well basis. What works on one well may not be suitable for
another well.

For further guidance with regards to elastomer material and its suitability to specific
wellbore conditions, refer to the Seal Selection Guideline.

When we select elastomers for our Wellhead Pressure Control Equipment there are a
number of factors to consider. If the information listed below is not available SWA must
be implemented until it is.

 Maximum Anticipated Surface Pressure (MASP)

 Well Type (Oil/Gas/Steam/Water etc)
 Temperature
 Chemicals present in well
 H2S and CO2 present in well
 Ambient temperature
 Service to be performed and maximum run time
 Well History
 Previous failures, lessons learned and best practices.

Proper selection, inspection and replacement frequency of slickline Stuffing Box Packings
will ensure their integrity throughout the operation, something that will prevent a
hydrocarbon release and a possible serious HSE incident.

Packing Stack Configuration

There is no set rule for the configuration of a Slickline Stuffing Box Packing stack,
however it will more often than not comprise of a number of different types of
packings. This will be determined by wellbore conditions and any lessons learned or
best practices from previous runs.

Halliburton Company (Dallas, Texas) 4-50

Slickline Operations Manual SL 4.21: Stuffing Box Packing Stacks

Premature and Excessive Stuffing Box Packing Wear Prevention

During operations there are a number of controls that can be put in place to mitigate the
risk of premature and excessive packing wear.

The use of a Liquid Seal Stuffing Box is one. This is recommended for operations in dry
gas wells or wells with sour, corrosive or sandy conditions.

The Liquid Seal Stuffing Box is used in conjunction with the conventional Stuffing Box.
Short flow tubes directly under the elastomeric packing enable injection of a lubricant
such as honey oil (wire-line grease) between the packing and the flow tubes; a small
amount of the oil will also help reduce the friction and affinity between the elastomer and
the wire.

This will protect the Stuffing Box packings from wellbore conditions and will lubricate the
wire when retrieving the toolstring back to surface, doing so reducing the likelihood or
even eliminating the risk of a hydrocarbon release due to excessively worn packings.

In addition to the use of a Liquid Seal Stuffing Box, lubricating the wire prior to running
in hole and reducing the running speed during the run will also mitigate the risk of
premature packing wear.

Prior to feeding the wire through the Slickline Stuffing Box it is important to check that all
internal components are free from damage, wear and they are the correct material and size
for the wire to be run. All components must be visually checked periodically throughout
the job and replaced before they become worn. The replacement frequency will be
dependent on the well conditions, depth and number of runs. Failure to replace worn
components will affect the integrity of the Stuffing Box seal, ultimately leading to a
potential hydrocarbon release.

When the lubricator is rigged down, between runs, it is important to inspect the condition
of the packings and if there is any sign of damage or wear they must be replaced.

During operations with H2S present, if working in daylight operations only, at the end of
the working day the stuffing box packings must be replaced.

During this time if excessive wear is observed, consideration must be given to either
changing to a more suitable packing material or reducing the number of runs between the
packing inspection.

Halliburton Company (Dallas, Texas) 4-51

Slickline Operations Manual SL 4.21: Stuffing Box Packing Stacks

Stuffing Box Packing Selection

In this section there is a list of Stuffing Box Packings, with guidance on their compatibility
with specific wellbore conditions.
A list of RMZ Stuffing Box Packings, along with their compatibility to specific wellbore
conditions, has been added as alternative packing option.

Stuffing Box Packings

Wire Size Description Halliburton Part Number
.092 5M Solid Nitrile 75 Durometer 91M1624
.092 5M Solid Nitrile 75 Durometer 91M2086 *
ALL 10M Nitrile Red Fabric 91M2112 *
ALL 10M Nitrile Gold Fabric 91M2467 *
ALL 15M Nitrile 12 Layer Black Fabric 91M2708
ALL 10M Yellow Polyurethane 75 Durometer 91M2709
.092 20M Red Polyurethane 90 Durometer 91M2743
.092 20M Black Polyurethane 75 Durometer 91M2744
ALL 15M Nitrile 12 Layer White Fabric 91M2906 *
.092 20M Blk Polyu w/.110 ID 75 Durometer 91M3077-3 **
.108 20M Red Polyu w/.125 ID 90 Durometer 91M3077-4 **
.082 10M Nitrile Red Fabric (91M2112) 91T6
.092 Bowen Nitrile One Layer Black Fabric 91T97
.082 20M Red Polyurethane 90 Durometer 91T120 *
.082 20M Blk Polyurethane 75 Durometer 91T136 *
ALL Certified 10M Nitrile Red Fabric 791M2112
*Packing most commonly used.
**For use with grease seal such as 46G0111.

Halliburton Company (Dallas, Texas) 4-52

Slickline Operations Manual SL 4.21: Stuffing Box Packing Stacks

Stuffing Box Packing Kits

46DHK1-3 3-91M2906 15M Nitrile 12 Layer White Fabric

0.092” 10M
4-91M2467 10M Nitrile Gold Fabric
46DHK1-4 3-91M2906 15M Nitrile 12 Layer White Fabric
0.108” 10M
4-91M2467 10M Nitrile Gold Fabric

46DHK1-8 3-91M2906 15M Nitrile 12 Layer White Fabric

0.125 10M
4-91M2467 10M Nitrile Gold Fabric

3-91T136 20M Blk Polyu 75 Durometer 20M

46DHK2-3 .092 20M
4-92T120 Red Polyu 90 Durometer

3-91T136 20M Blk Polyu 75 Durometer 20M

46DHK2-4 .108 20M
4-92T120 Red Polyu 90 Durometer

46DHK3-3 .092 5M 7-91M2467 10M Nitrile Gold Fabric

46DHK3-4 .108 5M 7-91M2467 10M Nitrile Gold Fabric

3-91M3077-3 Oversized ID (.110) Blk Polyu 75 Duro 10M

46DHK4-3* .092 20M
4-91M2112 Nitrile Red Fabric

3-91M3077-4 Oversized ID (.125) Blk Polyu 75 Duro 10M

46DHK4-4* .108 20M
4-91M2112 Nitrile Red Fabric

* For use with grease seal such as 46GO111.

Slickline Stuffing Box Packing Comparison of Various Materials

Advantages Disadvantages
Nitrile
Cheap
Readily available Not recommended for H2S conditions
Good up to 200oF for extended use Pressure rating is limited
Good for low temperatures It swells in the presence of toluene or xylene
Good with diesel It swells in the presence of Zn and Ca bromide
Good with inhibitors
Polyurethane
Cheap Brittle in cold weather
Good up to 20M Degraded by amines and methanol
Good for H2S Degraded by diesel Degraded
Readily available by temperatures above 150oF

Fluorel/Viton
Various durometers available Expensive
Good for high or low pressures Degrades in amines and methanol
Good for high temperatures Not a standard part (special order)
Good for H2S Brittle in low temperatures
Kalrez/Aflas
Various durometers available Very expensive
Good for high or low pressures Very brittle in low temperatures Not a
Good for high temperatures standard part (special order)
Good with amines and methanol
Good with diesel
Expanded Teflon
Good for low pressure Very expensive
Good for low temperatures Not recommended for high pressures Not
Good with amines and methanol recommended for high temperatures Not a
Good with diesel standard part (special order)
Good for H2S and CO2

Halliburton Company (Dallas, Texas) 4-53

Slickline Operations Manual SL 4.21: Stuffing Box Packing Stacks

RMZ Stuffing Box Packing Options

OEM Part Halliburton

Visual Aid Description
Number Part Number

Medium Pressure High Temperature Service.

From ‐20F to 325F. Viton Shore 80 ±5 Black, 990000769 102780905
Mild‐to‐Severe chemical service.

Standard Low to Medium Pressure service.

From ‐70F to 200F. polyurethane Shore 80 ±5 Amber, 990001864 102780907
Crude Oil, Natural Gas, Water, H2S.

Medium Pressure service.

From ‐50F to 320F. Nitrile Shore 70+Fabric Black,
990000902 102780909
Crude Oil, Natural Gas, Water, Mild‐To‐Severe Chemical
Service.
Medium Pressure service.
From ‐35F to 275F. Blue Nitrile Shore 60+Fabric Blue,
990000880 102780918
Crude Oil, Natural Gas, Water, Mild‐To‐Severe Chemical
Service.
High Pressure Service.
From ‐35F to 275F. Blue Nitrile Shore 60±5,
990025539 102780920
Oil, Natural Gas, Water, Mild Chemical Service.
Internally Lubricated with Graphite.

High Pressure Service.

From ‐50F to 275F. Black Nitrile Shore 70+Fabric Crude 990004673 102780921
Gas, Water, and mild chemical service.

Low Pressure, High Seal ability. Use alone or mix with

higher pressure packings. From ‐50F to 320F. Nitrile
990004799 102780922
Shore 70±5 Black, Oil, Natural Gas, Water, Mild
Chemicals.

Urethane Packing for High Pressure Service and H2S

990054794 102780923
Service. From ‐20F to 165F. Urethane Red.

Halliburton Company (Dallas, Texas) 4-54

Slickline Operations Manual SL 4.21: Stuffing Box Packing Stacks

SL 4.22: Braided Line/E-line Grease Head

Halliburton Company (Dallas, Texas) 4-55

Slickline Operations Manual SL 4.23: Liquid Chamber (Chemical Injection Sub) List

SL 4.23: Liquid Chamber (Chemical Injection Sub) List

Figure 4.23 - 1

Halliburton Company (Dallas, Texas) 4-56

Slickline Operations Manual SL 4.24: Lubricator Purge Tool (Valve) List

SL 4.24: Lubricator Purge Tool (Valve) List

Lubricator Purge Valve

Scope
Lubricator purge valves are considered critical pressure-containing components.

General Information
Prior to performing an onsite hydrostatic test of the lubricator stack, the lubricator must be
filled with water. A purge valve can be placed near the top of the lubricator stack to allow
the air to be purged while the lubricator is being filled. This is especially helpful when
using an extremely long rig-up. The purge valve is placed immediately below the stuffing
box and chemical injection sub. The valve consists of an exhaust port and a plunger which
is moved off-seat by pulling the rope socket up against it. Relaxing the tension on the
wireline allows the plunger to again form a seal. The pressure test can then be continued as
usual. Obviously, this cannot be used simultaneously with a tool catcher.

Appendix
Figure 4.24 - 1: Purge valve drawing.

Figure 4.24 - 1

Halliburton Company (Dallas, Texas) 4-57

Slickline Operations Manual SL 4.25: Tool Catcher and Tool Trap

SL 4.25: Tool Catcher and Tool Trap

Tool Catcher and Tool Trap

Scope
Both tool catchers and tool traps are considered critical pressure-containing components.

General Information
Tool Catcher
The tool catcher is placed immediately below the stuffing box and chemical injection sub.
It is designed to latch the fishing neck of the rope socket to prevent the tool string from
falling back downhole in the event that the wire pulled out of the rope socket. The catcher
is composed of a collet-type catcher and a hydraulically operated piston used to retract the
collet fingers and release the tool string. Tool catchers are used most often with electric
line tool strings containing expensive and extremely fragile logging tools.

Tool Trap
The tool trap is placed immediately above the wireline valve. It is manually or
hydraulically operated flapper with a slot that is slightly larger than the wireline. It is
opened just before the tool string is lowered into the well and just before the string is
pulled back into the lubricator. The flapper is intended to prevent any part of the tool
string, or anything fished from the hole, from falling back out of the lubricator.

Figure 4.25 - 1

Halliburton Company (Dallas, Texas) 4-58

Slickline Operations Manual SL 4.26: Lubricator Section

SL 4.26: Lubricator Section

Description
The lubricator sections are tubing risers which allow the running and removal of wireline
service tools from the well without having to kill the well. The standard stack and optional
equipment lubricator sections shown in the Standard Stack and Options section are 8 ft
(2.44 m) long. Other lengths are available upon request. All lower lubricator sections have
two needle valves for pressure bleedoff.

The lubricator sections of braided/E-line are identical to those used in slickline. While the
middle and upper lubricator sections normally have smaller IDs than with the lower
sections for slickline and braided-line operations, for E-line operations all lubricator
sections normally have the same ID throughout the stack because of the increased logging
tool size. In some cases, lubricator crossover sections may be needed. These crossovers
are not listed in catalog but are available upon request.
Lubricator Section Chart
Part Tube Up End Working Quick Union Quick Union Length Needle
Number ID ID Pressure Service Box End Pin and Collar Valve
See
Note psi MPa in. mm
46LA11101 2 2 5,000 34.474 STD 5-4 (3.50) 5-4 (3.50) 96 243.84 NONE
3 3
46LC11201 2 2 5,000 34.474 H2S 5 / -4 (4.00) 5 / -4 (4.00) 96 243.84 NONE
4 4

46LC12101 2 2 10000 68.948 STD 5-4 (3.50) 5-4 (3.50) 96 243.84 NONE
3 3
46LC12201 2 2 10,000 68.948 H2S 5 / -4 (4.00) 5 / -4 (4.00) 96 243.84 NONE
4 4

46LC13101 2 2 15,000 103.421 STD 5-4 (3.50) 5-4 (3.50) 96 243.84 NONE
3 3
46LC13201 2 2 15,000 103.421 H2S 5 / -4 (4.00) 5 / -4 (4.00) 96 243.84 NONE
4 4
3 1
46LC13202 2 2 15,000 103.421 H2S 5 / -4 (4.00) 6 / -4 (4.00) 96 243.84 NONE
4 4
3
46LC13203 2 2 15,000 103.421 H2S 5 / -4 (4.00) 7 1/2-4 (5.50) 96 243.84 NONE
4
1 1
46LC14201 2 2 20,000 137.895 H2S 6 / -4 (4.00) 6 / -4 (4.00) 96 243.84 NONE
4 4

46LA21101 2.42 2.42 5,000 34.474 STD 5-4 (3.50) 5-4 (3.50) 96 243.84 NONE
1
46LA21102 2.42 2.42 5,000 34.474 STD 5-4 (3.50) 6 / -4 (4.75) 96 243.84 NONE
2
1
46LA21103 2.42 2.42 5,000 34.474 STD 5-4 (3.50) 8 / -4 (6.18) 96 243.84 NONE
4
1
46LA21150 2.42 2.42 5,000 34.474 STD 5-4 (3.50) 5-4 (3.50) 96 243.84 / NPT
2
3 3
46LC21201 2.5 2.5 5,000 34.474 H2S 5 / -4 (4.00) 5 / -4 (4.00) 96 243.84 NONE
4 4
3 3
46LC21202 2.5 2.5 5,000 34.474 H2S 5 / -4 (4.00) 8 / -4 (5.25) 96 243.84 NONE
4 8
3
46LC21203 2.5 2.5 5,000 34.474 H2S 5 / -4 (4.00) 9-4 (6.75) 96 243.84 NONE
4
3 1
46LC21204 2.5 2.5 5,000 34.474 H2S 5 / -4 (4.00) 9 / -4 (8.00) 96 243.84 NONE
4 2
3 3 1
46LC21251 2.5 2.5 5,000 34.474 H2S 5 / -4 (4.00) 5 / -4 (4.00) 96 243.84 / NPT
4 4 2

46LC22101 2.5 2.5 10,000 68.948 STD 5-4 (3.50) 5-4 (3.50) 96 243.84 NONE
1
46LC22102 2.5 2.5 10,000 68.948 STD 5-4 (3.50) 6 / -4 (4.75) 96 243.84 NONE
2
1
46LC22103 2.5 2.5 10,000 68.948 STD 5-4 (3.50) 8 / -4 (6.18) 96 243.84 NONE
4
1
46LC22151 2.5 2.5 10,000 68.948 STD 5-4 (3.50) 5-4 (3.50) 96 243.84 / NPT
2
3 3
46LC22201 2.5 2.5 10,000 68.948 H2S 5 / -4 (4.00) 5 / -4 (4.00) 96 243.84 NONE
4 4
3 3
46LC22202 2.5 2.5 10,000 68.948 H2S 5 / -4 (4.00) 8 / -4 (5.25) 96 243.84 NONE
4 8
3
46LC22203 2.5 2.5 10,000 68.948 H2S 5 / -4 (4.00) 9-4 (6.75) 96 243.84 NONE
4
3 3 1
46LC22251 2.5 2.5 10,000 68.948 H2S 5 / -4 (4.00) 5 / -4 (4.00) 96 243.84 / NPT
4 4 2

46LC23101 2.56 2.56 15,000 103.421 STD 5-4 (3.50) 5-4 (3.50) 96 243.84 NONE
9
46LC23150 2.56 2.56 15,000 103.421 STD 5-4 (3.50) 5-4 (3.50) 96 243.84 / HP AUTOCLAVE
16
1 1
46LC23201 2.56 2.56 15,000 103.421 H2S 7 / -4 (5.50) 7 / -4 (5.50) 96 243.84 NONE
2 2
1 1
46LC23202 2.56 2.56 15,000 103.421 H2S 6 / -4 (4.00) 6 / -4 (4.00) 96 243.84 NONE
4 4
1 1
46LC23203 2.56 2.56 15,000 103.421 H2S 7 / -4 (5.50) 9 / -4 (6.25) 96 243.84 NONE
2 2
(Continued)

Halliburton Company (Dallas, Texas) 4-59

Slickline Operations Manual SL 4.26: Lubricator Section

Lubricator Chart (Continued)

Part Tube Up End Working Quick Union Quick Union Length Needle
Number ID ID Pressure Service Box End Pin and Collar Valve
See
Note psi MPa in. mm
1 1 9
46LC23250 2.56 2.56 15,000 103.421 H2S 6 / -4 (4.00) 6 / -4 (4.00) 96 243.84 / HP AUTOCLAVE
4 4 16
1 1
46LC24201 2.56 2.56 20,000 137.895 H2S 6 / -4 (4.00) 6 / -4 (4.00) 96 243.84 NONE
4 4
1 1 9
46LC24250 2.56 2.56 20,000 137.895 H2S 6 / -4 (4.00) 6 / -4 (4.00) 96 243.84 / HP AUTOCLAVE
4 4 16

46LA31101 2.93 2.93 5,000 34.474 STD 5-4 (3.50) 5-4 (3.50) 96 243.84 NONE
3
46LA31102 3 3 5,000 34.474 STD 5-4 (3.50) 8 / -4(7.50) 96 243.84 NONE
4

46LA31103 2.93 2.93 5,000 34.474 STD 5-4 (3.50) 5-4 (3.50) 48 121.92 NONE
1
46LA31150 2.93 2.93 5,000 34.474 STD 5-4 (3.50) 5-4 (3.50) 96 243.84 / NPT
2
3 3
46LC31201 3 3 5,000 34.474 H2S 5 / -4 (4.00) 5 / -4 (4.00) 96 243.84 NONE
4 4
3 3 1
46LC31251 3 3 5,000 34.474 H2S 5 / -4 (4.00) 5 / -4 (4.00) 96 243.84 / NPT
4 4 2

46LC32101 2.93 2.93 10,000 68.948 STD 5-4 (3.50) 5-4 (3.50) 96 243.84 NONE
1
46LC32151 2.93 2.93 10,000 68.948 STD 5-4 (3.50) 5-4 (3.50) 96 243.84 / NPT
2
3 3
46LC32201 3 3 10,000 68.948 H2S 5 / -4 (4.00) 5 / -4 (4.00) 96 243.84 NONE
4 4

46LC32202 3 3 10,000 68.948 H2S 5 3/ -4 (4.00) 11 1/ -4 (8.25) 96 243.84 NONE

4 2

46LC32203 3 3 10,000 68.948 H2S 5 3/ -4 (4.00) 5 3/ -4 (4.00) 144 365.76 NONE

4 4
5 3/ -4 (4.00) 5 3/ -4 (4.00)
1
46LC32251 3 3 10,000 68.948 H2S 96 243.84 / NPT
4 4 2

46LC33201 3 3 15,000 103.421 H2S 7 1/ -4 (5.50) 7 1/ -4 (5.50) 96 243.84 NONE

2 2

46LC33202 3 3 15,000 103.421 H2S 7 1/ -4 (5.50) 12 1/ -4 (7.00) 96 243.84 NONE

2 4
1
46LC33250 3 3 15,000 103.421 H2S 7 / -4 (5.50) 7 1/ -4 (5.50) 96 243.84
9
/ HP AUTOCLAVE
2 2 16

46LA41101 3.94 3.94 5,000 34.474 STD 6 1/2-4 (4.75) 6 1/2-4 (4.75) 96 243.84 NONE
46LA41150 3.94 3.94 5,000 34.474 STD 6 1/2-4 (4.75) 6 1/ 2-4 (4.75) 96 243.84 1
/2 NPT
46LA41180 3.94 3 5,000 34.474 STD 5-4 (3.50) 6 1/ -4 (4.75) 96 243.84 NONE
2

46LC41201 4 4 5,000 34.474 H2S 8 3/ -4 (5.25) 8 3/ -4 (5.25) 96 243.84 NONE

8 8
3
8 3/ -4 (5.25)
1
46LC41251 4 4 5,000 34.474 H2S 8 / -4 (5.25) 96 243.84 / NPT
8 8 2

46LC42101 4 4 10,000 68.948 STD 6 1/2-4 (4.75) 6 1/2-4 (4.75) 96 243.84 NONE
6 1/2-4 (4.75) 6 1/ 2-4 (4.75)
1
46LC42151 4 4 10,000 68.948 STD 96 243.84 /2 NPT
46LC42201 4 4 10,000 68.948 H2S 8 3/ -4 (5.25) 8 3/ -4 (5.25) 96 243.84 NONE
8 8
8 3/ -4 (5.25) 8 3/ -4 (5.25)
1
46LC42251 4 4 10,000 68.948 H2S 96 243.84 / NPT
8 8 2
1
46LC43201 4 4 15,000 103.421 H2S 9 / -4 (6.25) 9 1/ -4 (6.25) 96 243.84 NONE
2 2
9 1/ -4 (6.25)
9
46LC43250 4 4 15,000 103.421 H2S 9 1/2-4 (6.25) 96 243.84 / HP AUTOCLAVE
2 16
1 1
46LC51101 5 5 5,000 34.474 STD 8 / 4-4 (6.18) 8 / 4-4 (6.18) 96 243.84 NONE
8 1/ 4-4 (6.18) 8 1/ 4-4 (6.18)
1
46LC51150 5 5 5,000 34.474 STD 96 243.84 /2 NPT
8 1/ 4-4 (6.18) 8 1/ 4-4 (6.18)
1
46LC51151 5 5 5,000 34.474 STD 48 121.92 /2 NPT
46LC51201 5 5 5,000 34.474 H2S 9-4 (6.75) 9-4 (6.75) 96 243.84 NONE
1
46LC51251 5 5 5,000 34.474 H2S 9-4 (6.75) 9-4 (6.75) 96 243.84 / NPT
2

46LC52101 5 5 10,000 68.948 STD 8 1/ 4-4 (6.18) 8 1/ 4-4 (6.18) 96 243.84 NONE
8 1/ 4-4 (6.18) 8 1/ 4-4 (6.18)
1
46LC52151 5 5 10,000 68.948 STD 96 243.84 /2 NPT
46LC52201 5 5 10,000 68.948 H2S 9-4 (6.75) 9-4 (6.75) 96 243.84 NONE
1
46LC52251 5 5 10,000 68.948 H2S 9-4 (6.75) 9-4 (6.75) 96 243.84 / NPT
2

46LC52280 5 3 10,000 68.948 H2S 5 3/ -4 (4.00) 9-4 (6.75) 96 243.84 NONE

4
3 1
46LC52282 5 3 10,000 68.948 H2S 5 / -4 (4.00) 9-4 (6.75) 96 243.84 / NPT
4 2

46LC53201 5.12 5.12 15,000 103.421 H2S 12 1/ -4(7.00) 12 1/ -4 (7.00) 96 243.84 NONE
4 4
12 1/ -4(7.00) 12 1/ -4 (7.00)
9
46LC53250 5.12 5.12 15,000 103.421 H2S 96 243.84 / HP AUTOCLAVE
4 4 16
3 3
46LC61101 6.37 6.37 5,000 34.474 STD 8 / 4-4(7.50) 8 / 4-4(7.50) 96 243.84 NONE
8 3/ 4-4(7.50) 8 3/ 4-4(7.50)
1
46LC61150 6.37 6.37 5,000 34.474 STD 96 243.84 /2 NPT
46LC61201 6.37 6.37 5,000 34.474 H2S 9 1/ -4 (8.00) 9 1/ -4 (8.00) 96 243.84 NONE
2 2
9 1/ -4 (8.00) 9 1/ -4 (8.00)
1
46LC61251 6.37 6.37 5,000 34.474 H2S 96 243.84 / NPT
2 2 2
(Continued)

Halliburton Company (Dallas, Texas) 4-60

Slickline Operations Manual SL 4.26: Lubricator Section

Lubricator Chart (Continued)

Part Tube Up End Working Service Quick Union Quick Union Length Needle
Number ID ID Pressure Box End Pin and Collar Valve
See
Note psi MPa in. mm
1 1
46LC62201 6.37 6.37 10,000 68.948 H2S 11 / -4 (8.25) 11 / -4 (8.25) 96 243.84 NONE
2 2
1 1
46LC62202 6.37 6.37 10,000 68.948 H2S 11 / -4 (8.25) 11 / -4 (8.25) 48 121.92 NONE
2 2
1 1 1
46LC62251 6.37 6.37 10,000 68.948 H2S 11 / -4 (8.25) 11 / -4 (8.25) 96 243.84 / NPT
2 2 2

46LC43250 4 4 15,000 34.474 H2S 9 1/2-4 (6.25) 9 1/2-4 (6.25) 96 243.84 9/16 HP AUTOCLAVE
46LC51101 5 5 5,000 34.474 STD 8 1/4-4 (6.18) 8 1/4-4 (6.18) 96 243.84 NONE
1
46LC51150 5 5 5,000 34.474 STD 8 1/4-4 (6.18) 8 1/4-4 (6.18) 96 243.84 / NPT
2
1
46LC51151 5 5 5,000 34.474 STD 8 1/4-4 (6.18) 8 1/4-4 (6.18) 48 121.92 / NPT
2
46LC51201 5 5 5,000 34.474 H2S 9-4 (6.75) 9-4 (6.75) 96 243.84 NONE
1
46LC51251 5 5 5,000 34.474 H2S 9-4 (6.75) 9-4 (6.75) 96 243.84 / NPT
2
46LC52101 5 5 10,000 68.948 STD 8 1/4-4 (6.18) 8 1/4-4 (6.18) 96 243.84 NONE
1
46LC52151 5 5 10,000 68.948 STD 8 1/4-4 (6.18) 8 1/4-4 (6.18) 96 243.84 / NPT
2

46LC52201 5 5 10,000 68.948 H2S 9-4 (6.75) 9-4 (6.75) 96 243.84 NONE
1
46LC52251 5 5 10,000 68.948 H2S 9-4 (6.75) 9-4 (6.75) 96 243.84 / NPT
2
1
46LC52280 5 3 10,000 68.948 H2S 5 3/4-4 (4.00) 9-4 (6.75) 96 243.84 / NPT
2
1
46LC52282 5 3 10,000 68.948 H2S 5 3/4-4 (4.00) 9-4 (6.75) 96 243.84 / NPT
2
46LC53201 5.12 5.12 15,000 103.421 H2S 12 1/4-4(7.00) 12 1/4-4(7.00) 96 243.84 NONE
46LC53250 5.12 5.12 15,000 103.421 H2S 12 1/4-4(7.00) 12 1/4-4(7.00) 96 243.84 9/16 HP AUTOCLAVE
46LC61101 6.37 6.37 5,000 34.474 STD 8 3/4-4(7.50) 8 3/4-4(7.50) 96 243.84 NONE
1
46LC61150 6.37 6.37 5,000 34.474 STD 8 3/4-4(7.50) 8 3/4-4(7.50) 96 243.84 / NPT
2

46LC61201 6.37 6.37 5,000 34.474 H2S 9 1/2-4 (8.00) 9 1/2-4 (8.00) 96 243.84 NONE
1
46LC61251 6.37 6.37 5,000 34.474 H2S 9 1/2-4 (8.00) 9 1/2-4 (8.00) 96 243.84 / NPT
2

46LC62201 6.37 6.37 10,000 68.948 H2S 11 1/2-4 (8.25) 11 1/2-4 (8.25) 96 243.84 NONE
46LC62202 6.37 6.37 10,000 68.948 H2S 11 1/2-4 (8.25) 11 1/2-4 (8.25) 48 121.92 NONE
1
46LC62251 6.37 6.37 10,000 68.948 H2S 11 1/2-4 (8.25) 11 1/2-4 (8.25) 96 243.84 / NPT
2

Halliburton Company (Dallas, Texas) 4-61

Slickline Operations Manual SL 4.27: Lubricator Safety Valve

SL 4.27: Lubricator Safety Valve

Figure 4.27 - 1

Figure 4.27 - 2

Halliburton Company (Dallas, Texas) 4-62

Slickline Operations Manual SL 4.27: Lubricator Safety Valve

Figure 4.27 - 3

Figure 4.27 - 4

Halliburton Company (Dallas, Texas) 4-63

Slickline Operations Manual SL 4.28: Pump In/Flow Tee List

SL 4.28: Pump In/Flow Tee List

Part Number ID Working Service Quick Unions Side Port Weco
Pressure
psi MPa
46LE22201 2.50 10,000 68.948 H2S 5 3/4-4 (4.00) 1502
46LE23101 2.56 15,000 103.421 STD 5-4 (3.50) 1502
46LE23201 2.56 15,000 103.421 H2S 6 1/4-4 (4.00) 2202
46LE32101 2.93 10,000 68.948 STD 5-4 (3.50) 1502
46LE32201 3.00 10,000 103.421 H2S 5 3/4-4 (4.00) 1502
46LE33201 3.00 15,000 103.421 H2S 7 1/2-4 (5.50) 2202
46LE42101 4.00 10,000 68.948 STD 6 1/2-4 (4.75) 1502
46LE42201 4.00 10,000 68.948 H2S 8 3/8-4 (5.25) 1502
46LE43201 4.00 15,000 103.421 H2S 9 1/2-4 (6.25) 2202
46LE52101 5.00 10,000 68.948 STD 8 1/4-4 (6.18) 1502
46LE52201 5.00 10,000 68.948 H2S 9-4 (6.75) 1502
46LE53201 5.12 15,000 103.421 H2S 12 1/4-4 (7.00) 2202
46LE61101 6.37 5,000 34.474 STD 8 3/4-4 (7.50) 1502
46LE61201 6.37 5,000 34.474 H2S 9 1/2-4 (8.00) 1502
46LE62201 6.37 10,000 68.948 H2S 11 1/2-4 (8.25) 1502

Halliburton Company (Dallas, Texas) 4-64

Slickline Operations Manual SL 4.29: Wireline Valve List

SL 4.29: Wireline Valve List

Description
The wireline valve is normally placed on top of the wellhead (tree) connector and is
designed to allow work to be performed on the other surface equipment above the valve
while the wireline is in the well. The wireline valve uses rams to close on the wireline and
seal off pressure below the well without damaging the wire.

Wireline valves with a single set of rams are normally used for slickline and in low
pressure [below 3,000 psi (207 bar)] braided line or E-line operations. When pressures rise
above the level at which a single set of rams can effect a seal on braided or E-line, a dual
wireline valve is used. In braided and E-line operations, grease can be injected between
the ram bores to help effect a seal. Dual/triple valves may also be used when working with
different wire sizes on the same wireline unit. Logging operators often use triple or quad
valves for additional safety on high-pressure wells.

Note Hydraulic wireline valves are recommend for STD service above 5,000 psi
(345 bar) and for all H2S service wells.

Halliburton Company (Dallas, Texas) 4-65

Slickline Operations Manual SL 4.29: Wireline Valve List

Wireline Valve Chart

Part Number ID Working Pressure Service Quick Unions Type Ports
psi MPa
46BA21101-* 2.42 5,000 34.474 STD 5-4 (3.50) MAN/SNGL 1/2 NPT
46BA21102-* 2.42 5,000 34.474 STD 5-4 (3.50) HYD/SNGL 1/2 NPT
46BA21150-* 2.42 5,000 34.474 STD 5-4 (3.50) MAN/DUAL 1/2 NPT
46BA21151-* 2.42 5,000 34.474 STD 5-4 (3.50) HYD/DUAL 1/2 NPT
46BE22102-* 2.50 10,000 68.948 STD 5-4 (3.50) HYD/SNGL 1/2 NPT
46BE22152-* 2.50 10,000 68.948 STD 5-4 (3.50) HYD/DUAL 1/2 NPT
46BE22153-* 2.50 10,000 68.948 STD 5-4 (3.50) HYD/TRIPLE 1/2 NPT
46BE22202-* 2.50 10,000 68.948 H2S 5 3/4-4 (4.00) HYD/SNGL 1/2 NPT
46BE22252-* 2.50 10,000 68.948 H2S 5 3/4-4 (4.00) HYD/DUAL 1/2 NPT
46BE22253-* 2.50 10,000 68.948 H2S 5 3/4-4 (4.00) HYD/TRIPLE 1/2 NPT
46BE23101-* 2.56 15,000 103.421 STD 5-4 (3.50) HYD/SNGL 9/16 HP AUTOCLAVE
46BE23150-* 2.56 15,000 103.421 STD 5-4 (3.50) HYD/DUAL 9/16 HP AUTOCLAVE
46BE23151-* 2.56 15,000 103.421 STD 5-4 (3.50) HYD/TRIPLE 9/16 HP AUTOCLAVE
46BE23152-* 2.56 15,000 103.421 STD 5-4 (3.50) HYD/QUAD 9/16 HP AUTOCLAVE
46BE23201-* 2.56 15,000 103.421 H2S 6 1/4-4 (4.00) HYD/SNGL 9/16 HP AUTOCLAVE
46BE23250-* 2.56 15,000 103.421 H2S 6 1/4-4 (4.00) HYD/DUAL 9/16 HP AUTOCLAVE
46BE23251-* 2.56 15,000 103.421 H2S 6 1/4-4 (4.00) HYD/TRIPLE 9/16 HP AUTOCLAVE
46BE23252-* 2.56 15,000 103.421 H2S 6 1/4-4 (4.00) HYD/QUAD 9/16 HP AUTOCLAVE
46BE24201-* 2.56 20,000 137.895 H2S 6 1/4-4 (4.00) HYD/SNGL 9/16 HP AUTOCLAVE
46BE24250-* 2.56 20,000 137.895 H2S 6 1/4-4 (4.00) HYD/DUAL 9/16 HP AUTOCLAVE
46BE24251-* 2.56 20,000 137.895 H2S 6 1/4-4 (4.00) HYD/TRIPLE 9/16 HP AUTOCLAVE
46BE24252-* 2.56 20,000 137.895 H2S 6 1/4-4 (4.00) HYD/QUAD 9/16 HP AUTOCLAVE
46BA31101-* 2.93 5,000 34.474 STD 5-4 (3.50) MAN/SNGL 1/2 NPT
46BA31102-* 2.93 5,000 34.474 STD 5-4 (3.50) HYD/SNGL 1/2 NPT
46BA31150-* 2.93 5,000 34.474 STD 5-4 (3.50) MAN/DUAL 1/2 NPT
(Continued)

Halliburton Company (Dallas, Texas) 4-66

Slickline Operations Manual SL 4.29: Wireline Valve List

Wireline Valve Chart (Continued)

Part Number ID Working Pressure Service Quick Unions Type Ports
psi MPa
46BA31151-* 2.93 5,000 34.474 STD 5-4 (3.50) HYD/DUAL 1/2 NPT
46BE32103-* 2.93 10,000 68.948 STD 5-4 (3.50) HYD/SNGL 1/2 NPT
46BE32104-* 2.93 10,000 68.948 STD 5-4 (3.50) MAN/SNGL 1/2 NPT
46BE32152-* 2.93 10,000 68.948 STD 5-4 (3.50) HYD/DUAL 1/2 NPT
46BE32153-* 2.93 10,000 68.948 STD 5-4 (3.50) HYD/TRIPLE 1/2 NPT
46BE32203-* 3.00 10,000 68.948 H2S 5 3/4-4 (4.00) HYD/SNGL 1/2 NPT
46BE32204-* 3.00 10,000 68.948 H2S 5 3/4-4 (4.00) MAN/SNGL 1/2 NPT
46BE32252-* 3.00 10,000 68.948 H2S 5 3/4-4 (4.00) HYD/DUAL 1/2 NPT
46BE32253-* 3.00 10,000 68.948 H2S 5 3/4-4 (4.00) HYD/TRIPLE 1/2 NPT
46BE33201-* 3.00 15,000 103.421 H2S 7 1/2-4 (5.50) HYD/SNGL 9/16 HP AUTOCLAVE
46BE33250-* 3.00 15,000 103.421 H2S 7 1/2-4 (5.50) HYD/DUAL 9/16 HP AUTOCLAVE
46BE33251-* 3.00 15,000 103.421 H2S 7 1/2-4 (5.50) HYD/TRIPLE 9/16 HP AUTOCLAVE
46BE33252-* 3.00 15,000 103.421 H2S 7 1/2-4 (5.50) HYD/QUAD 9/16 HP AUTOCLAVE
46BA41101-* 4.00 5,000 34.474 STD 6 1/2-4 (4.75) MAN/SNGL 1/2 NPT
46BA41102-* 4.00 5,000 34.474 STD 6 1/2-4 (4.75) HYD/SNGL 1/2 NPT
46BA41150-* 4.00 5,000 34.474 STD 6 1/2-4 (4.75) MAN/DUAL 1/2 NPT
46BA41151-* 4.00 5,000 34.474 STD 6 1/2-4 (4.75) HYD/DUAL 1/2 NPT
46BE41202-* 4.00 5,000 34.474 H2S 8 3/8-4 (5.25) HYD/SNGL 1/2 NPT
46BE41251-* 4.00 5,000 34.474 H2S 8 3/8-4 (5.25) HYD/DUAL 1/2 NPT
46BE41282-* 4.00 5,000 34.474 H2S 6 1/2-4 (4.75) HYD/SNGL 1/2 NPT
46BE41283-* 4.00 5,000 34.474 H2S 6 1/2-4 (4.75) MAN/SNGL 1/2 NPT
46BE42102-* 4.00 10,000 68.948 STD 6 1/2-4 (4.75) HYD/SNGL 1/2 NPT
46BE42152-* 4.00 10,000 68.948 STD 6 1/2-4 (4.75) HYD/DUAL 1/2 NPT
46BE42153-* 4.00 10,000 68.948 STD 6 1/2-4 (4.75) HYD/TRIPLE 1/2 NPT
46BE42202-* 4.00 10,000 68.948 H2S 8 3/8-4 (5.25) HYD/SNGL 1/2 NPT
46BE42252-* 4.00 10,000 68.948 H2S 8 3/8-4 (5.25) HYD/DUAL 1/2 NPT
46BE42253-* 4.00 10,000 68.948 H2S 8 3/8-4 (5.25) HYD/TRIPLE 1/2 NPT
46BE43201-* 4.00 15,000 103.421 H2S 9 1/2-4 (6.25) HYD/SNGL 9/16 HP AUTOCLAVE
46BE43250-* 4.00 15,000 103.421 H2S 9 1/2-4 (6.25) HYD/DUAL 9/16 HP AUTOCLAVE
46BE43251-* 4.00 15,000 103.421 H2S 9 1/2-4 (6.25) HYD/TRIPLE 9/16 HP AUTOCLAVE
46BE43252-* 4.00 15,000 103.421 H2S 9 1/2-4 (6.25) HYD/QUAD 9/16 HP AUTOCLAVE
46BA51101-* 5.00 5,000 34.474 STD 8 1/4-4 (6.18) MAN/SNGL 1/2 NPT
46BA51102-* 5.00 5,000 34.474 STD 8 1/4-4 (6.18) HYD/SNGL 1/2 NPT
46BA51150-* 5.00 5,000 34.474 STD 8 1/4-4 (6.18) MAN/DUAL 1/2 NPT
46BA51151-* 5.00 5,000 34.474 STD 8 1/4-4 (6.18) HYD/DUAL 1/2 NPT
46BE51202-* 5.00 5,000 34.474 H2S 9-4 (6.75) HYD/SNGL 1/2 NPT
46BE51252-* 5.00 5,000 34.474 H2S 9-4 (6.75) HYD/DUAL 1/2 NPT
46BE52102-* 5.00 10,000 68.948 STD 8 1/4-4 (6.18) HYD/SNGL 1/2 NPT
46BE52152-* 5.00 10,000 68.948 STD 8 1/4-4 (6.18) HYD/DUAL 1/2 NPT
46BE52153-* 5.00 10,000 68.948 STD 8 1/4-4 (6.18) HYD/TRIPLE 1/2 NPT
(Continued)

Halliburton Company (Dallas, Texas) 4-67

Slickline Operations Manual SL 4.29: Wireline Valve List

Wireline Valve Chart (Continued)

Part Number ID Working Pressure Service Quick Unions Type Ports
psi MPa
46BE52203-* 5.00 10,000 68.948 H2S 9-4 (6.75) HYD/SNGL 1/2 NPT
46BE52252-* 5.00 10,000 68.948 H2S 9-4 (6.75) HYD/DUAL 1/2 NPT
46BE52253-* 5.00 10,000 68.948 H2S 9-4 (6.75) HYD/TRIPLE 1/2 NPT
46BE53201-* 5.12 15,000 103.421 H2S 12 1/4-4 (7.00) HYD/SNGL 9/16 HP AUTOCLAVE
46BE53250-* 5.12 15,000 103.421 H2S 12 1/4-4 (7.00) HYD/DUAL 9/16 HP AUTOCLAVE
46BE53251-* 5.12 15,000 103.421 H2S 12 1/4-4 (7.00) HYD/TRIPLE 9/16 HP AUTOCLAVE
46BE53252-* 5.12 15,000 103.421 H2S 12 1/4-4 (7.00) HYD/QUAD 9/16 HP AUTOCLAVE
46BA61101-* 6.37 5,000 34.474 STD 8 3/4-4 (7.50) MAN/SNGL 1/2 NPT
46BA61102-* 6.37 5,000 34.474 STD 8 3/4-4 (7.50) HYD/SNGL 1/2 NPT
46BA61150-* 6.37 5,000 34.474 STD 8 3/4-4 (7.50) MAN/DUAL 1/2 NPT
46BA61151-* 6.37 5,000 34.474 STD 8 3/4-4 (7.50) HYD/DUAL 1/2 NPT
46BE61202-* 6.37 5,000 34.474 H2S 9 1/2-4 (8.00) HYD/SNGL 1/2 NPT
46BE61251-* 6.37 5,000 34.474 H2S 9 1/2-4 (8.00) HYD/DUAL 1/2 NPT
46BE62202-* 6.37 10,000 68.948 H2S 11 1/2-4 (8.25) HYD/SNGL 1/2 NPT
46BE62252-* 6.37 10,000 68.948 H2S 11 1/2-4 (8.25) HYD/DUAL 1/2 NPT
46BE62253-* 6.37 10,000 68.948 H2S 11 1/2-4 (8.25) HYD/TRIPLE 1/2 NPT

Halliburton Company (Dallas, Texas) 4-68

Slickline Operations Manual SL 4.30: Tree Connection List

SL 4.30: Tree Connection List

Wellhead Adapters
Wellhead Adapters
When rigging-up pressure control equipment to a wellhead, there are generally two
methods used. The preferred method is a flanged adapter connected to the uppermost
flange on the wellhead. In low pressure work, a threaded adapter may be screwed into the
top threaded connection on the wellhead.

Flanged Adapters
This is the preferred and safest method of connecting to a wellhead. This connection must
carry the weight of the entire lubricator string, which, if subjected to side loading, can
impose a considerable bending stress on the wellhead adapter.

Flanged adapters are used for through tubing work, 2 1/2-in. ID up to 13 5/8-in. for
adapting to rig wireline valve stacks.

Information needed to identify the particular flanged adapter required, would be:

• Nominal size, pressure rating and ring number.

Note Instead of a pressure rating, the obsolete series number might still be used.

• The top connection, which may be a quick union box or a threaded connection for
large diameter risers.
In general, API type 6B flanges are for 2,000 psi through 5,000 psi working pressure and
type 6BX flanges are for 5,000 psi through 20,000 psi working pressure. 6B flanges
require R or RX ring joint gaskets and 6BX flanges require BX ring joint gaskets.

Flange identification charts

Example:
3 1/6-in. 10,000 psi, 6BX with a 4 3/4-in. -4 Union Box
3 1/16-in. is the nominal ID or bore in this flange, however the 4 3/4-4 union box
limits the ID to a maximum of 2 1/2-in. 10,000 psi is the working pressure. This
flange will require a BX-154 ring gasket.
Threaded Adapters
Threaded adapters can be used for lower working pressure requirements and rely on
torque to seal rather than a replaceable gasket or seal rings.

Halliburton Company (Dallas, Texas) 4-69

Slickline Operations Manual SL 4.30: Tree Connection List

Size Grade API Thread Torque

2-3/8 J-55 8RD 1,200 ft/lbs

2-3/8 N-80 8RD 1,500 ft/lbs

2-7/8 J-55 8RD 1,500 ft/lbs

2-7/8 N-80 8RD 1,800 ft/lbs

The use of threaded adapters is limited to 5,000 psi maximum working pressure. Line
pipe, 2 1/2-in. and larger, is limited 3,000 psi maximum working pressure.

Use a suitable thread compound with threaded adapters.

Adapting to Rig Wireline Valve Stack

While the configuration of rig wireline valve stacks varies considerably, the uppermost
element to which pressure-control equipment must be connected is usually an annular type
(Hydril) wireline valve. The annular wireline valves rubber packing element is energized
hydraulically by the wedge-shaped piston squeezing the packing element inward till it
closes and seals around pipe or cable.

• Flanging up to the top of the Hydril is the safest way to rig up. Flanges with a threaded
connection are available in all sizes. Hydrolex adapter flanges with Slimline riser con-
nections have Acme threads with o-ring seals.
• Hydril Adapters have replaced the old “shooting nipple.” These adapters are a section
of riser, usually six feet long, with a flange at the lower end. The Hydril Adapter is set
in the Hydril so that the flange is below the sealing element and the Hydril is closed
around it. Care should be take to not deform the riser.
• The Hydril flange adapter is, by far, the fastest way to rig up for a logging job. A
flange sized to the Hydril has a large ID union box connection up, and a union half on
the lower end of the Bell Nipple is connected to it during drilling. When ready to log,
the union connection is broken out and a section of riser with the same union connec-
tion is made up.

Crossovers and Union Adapters

1. Crossovers are required in special situations and come in three basic configurations:
• Quick union box by box
• Quick union pun and collar by pin and collar
• Quick union box by pin and collar
2. Union adapters are used when it is necessary to combine two assemblies of pressure-
control equipment that have different union sizes.

Halliburton Company (Dallas, Texas) 4-70

Slickline Operations Manual SL 4.30: Tree Connection List

Figure 4.30 - 1

Halliburton Company (Dallas, Texas) 4-71

Slickline Operations Manual SL 4.31: Blanking/Tree Caps List

SL 4.31: Blanking/Tree Caps List

Part Number Working Service Quick Union Port Type
psi Mpa
46AS88 10,000 68.948 STD 5-4 (3.50) 1/2 NPT
46AS608 15,000 103.421 STD 5-4 (3.50) 9/16 HP AUTOCLAVE
46AH382 10,000 68.948 H2S 5 3/4-4 (4.00) 1/2 NPT
46AH597 15,000 103.421 H2S 6 1/4-4 (4.00) 9/16 HP AUTOCLAVE
46AO595 20,000 137.895 H2S 6 1/4-4 (4.00) 9/16 HP AUTOCLAVE
46AS211 10,000 68.948 STD 6 1/2-4 (4.75) 1/2 NPT
46AO588 15,000 103.421 H2S 7 1/2-4 (5.50) 9/16 HP AUTOCLAVE
46AS598 10,000 68.948 STD 8 1/4-4 (6.18) 1/2 NPT
46AH599 10,000 68.948 H2S 8 3/8-4 (5.25) 1/2 NPT
46AS411 5,000 34.474 STD 8 3/4-4 (7.50) 1/2 NPT
46AH602 10,000 68.948 H2S 9-4 (6.75) 1/2 NPT
46AH601 15,000 103.421 H2S 9 1/2-4 (6.25) 9/16 HP AUTOCLAVE
46AH604 5,000 34.474 H2S 9 1/2-4 (8.00) 1/2 NPT
46AH603 15,000 103.421 H2S 12 1/4-4(7.00) 9/16 HP AUTOCLAVE
46AH179 10,000 68.948 H2S 11 1/2-4 (8.25) 1/2 NPT

Halliburton Company (Dallas, Texas) 4-72

Slickline Operations Manual SL 4.32: O-Ring Service Selection Chart

SL 4.32: O-Ring Service Selection Chart

The information below is Halliburton’s “best practices” for the design, manufacture, and
periodic test and inspection of Wellhead Pressure Control Equipment (WPCE). These
guidelines should be used to ensure that all WPCE will perform safely and as intended.
This document replaces the Otis Standard of Operations (SO) 1 103 and Engineering
Bulletin 441.

For reference:
CPS010

Definitions
WPCE - Stuffing boxes, lubricators, liquid chambers, wireline valves, swages, tool traps,
tree connections, grease injection heads, crossovers, and like equipment used to control
well pressure during wireline operations (Slickline, braided line, or E-line).

H2S Service - Sour gas - Wells are considered sour if the H2S partial pressure is .05 psi or
above. The parts per million of H2S must be used in a calculation that involves the
maximum down-hole pressure to calculate the “gas partial pressure.” Multiply either the
mol percent or volume percent H2S in the gas by the maximum pressure; for example: a
well producing a gas containing 10 ppm H2S at 5,000 psi would result in an H2S partial
pressure of 10/1,000,000 x 5,000 psi, or 0.05 psi. A well producing 0.001 mol % H2S in
5,000 psi gas would also represent 0.05 psi H2S partial pressure, because 0.001 x 0.01 x
5,000 psi = 0.05 psi. The significance of 0.05 psi partial pressure H2S is that it is the cutoff
for either sweet or sour service. Wells producing 0.05 psi H2S partial pressure are, by law
in Texas and per NACE, sour; H2S partial pressures less than 0.05 psia are sweet.

Standard (STD) Service - "sweet" wells, standard wells, those not considered H2S or
Cold service.

CO2 Service - CO2containing well. No special WPCE is built for this service. STD
service WPCE is used for CO2 Service.

Cold Service - Temperatures below - 20F (-28.9C). Any WPCE used below -20F must
be rated for Cold Service. New equipment should be ordered with a -75F (-59.49C)
temperature rating, though existing cold weather equipment may be rated for a higher
temperature. See Technology Bulletin CPE 96004 for further details.

High Temperature Service- above 250F (121.1C). ES-I-* and ES-T-* Specifications
- these are Halliburton D/FW Center specifications. Equivalent Halliburton alliance
partner specifications or IMS specifications from other Halliburton centers are also
acceptable.

Halliburton Company (Dallas, Texas) 4-73

Slickline Operations Manual SL 4.32: O-Ring Service Selection Chart

General Requirements and Design Standards

• All Wellhead Pressure Control Equipment (WPCE) and devices used for lifting
WPCE (such as lift caps, lubricator clamps, slings, etc.) must be built, repaired, and
tested by approved Halliburton suppliers or facilities.
• Halliburton drawings and specifications furnished to non-Halliburton facilities must
be handled according to company policy which includes a Manufacturing and
Confidentiality Agreement.
• WPCE must be designed, manufactured, and hydrostatically tested in compliance with
accepted engineering and industry standards. Although API 6A does not specifically
cover WPCE, API 6A should be used as a guide. All WPCE used in H2S service must
comply with NACE Standard MR-01-75. industry standard materials and calculations
(to determine pressure ratings, acceptable loading, and safety factors) must be used.
• Components must be built to engineering drawings and specifications.
• All pressure containing or load bearing components must be traceable.
• Field welding on WPCE should not be performed for any purpose unless authorized
by Halliburton D/FW Center Technology - Production Services and Equipment
Engineering.
• Repairs of all WPCE is limited to existing engineering drawings or written
instructions from the manufacturer.
• Maintenance, Testing, and Inspection
• WPCE must receive regular maintenance and periodic testing and inspection to ensure
that the equipment functions correctly and remains safe to use.
• Inspection and test records must be maintained for all WPCE.

Equipment Selection/Safety
• On all wireline jobs, the WPCE selected for use must be designed and built for the
intended pressure and service.
• An assembled unit cannot be rated or used at a pressure higher than the rated working
pressure of the lowest pressure rated item in the assembly.

Elastomer
1. STD or CO2 Service - Nitrile (Buna-N)
2. H2S Service - Fluorocarbon (Viton or Fluorel)
For Fluorocarbon o-rings purchased from D/FW Center, 91QV@---M series should
be used for quick unions or other equipment that may be experiencing difficulty
sealing pressure. The 91QV@---H series o-rings are too hard to effect a seal in
many cases (see Engineering Bulletin 355 for details).
3. Cold Service - Low Temperature Nitrile (see Technology Bulletin CPE 96 004 for
further details).

Halliburton Company (Dallas, Texas) 4-74

Slickline Operations Manual SL 4.32: O-Ring Service Selection Chart

4. Temperature Service

Note Ratings below are for elastomers meeting requirements of Halliburton

D/FW Center ES-R-* specifications. Ratings of elastomers from other Halliburton
Centers or suppliers may differ.

• Fluorel - up to 400F (204.4C)

• Viton - up to 325F (162.8C)
• EPDM - up to 575F (301.7C) - applies only to modified Y-267. EPDM is
intended for geothermal wells and cannot be used when elastomers come in direct
contact with hydrocarbons.
• Aflas - between 100F (37.8C) and 400F (204.4C). Aflas cannot consistently
seal pressure at temperatures below 100F and is therefore seldom used for WPCE
since surface temperatures are almost always below 100F at some point during a
wireline operation.
• Metals - primary material is 4130/4140 for WPCE, with stainless steels or high
alloys such as Incoloy 925 used for some smaller components to extend life.
Yield strengths and hardness listed below are for 4130/4140 components; consult
manufacturer for values for other materials.

Note No cold worked steels are to be used to manufacture WPCE.

5. STD or CO2 Service - 80,000 to 110,000 psi minimum yield; screw type swages (tree
connections) must be no less than P-105 grade (105,000 psi minimum yield material).
Rockwell hardness must be 36HRC (Brinell 341) or less.

Note CO2 produces a weight loss corrosion that should be monitored. WPCE built of
4130/4140 material will have an equal amount of weight loss corrosion whether the
material is heat treated for STD or for H2S Service. WPCE used periodically in CO2 can
typically be used for years without excessive corrosion problems. For extended use on
CO2 wells, more frequent inspections of the WPCE should be made until the rate of
corrosion is known. If little corrosion is found, the frequency of inspection can be reduced
to that listed in this manual.

Halliburton Company (Dallas, Texas) 4-75

April 29, 2020

Slickline Operations Manual

Halliburton Energy Services
(1)

General Guidelines For Seals

Compound PEEK(2), (4) Ryton(2), (4) Fluorel (3) Aflas (3) Chemraz(3) Viton(3) Neoprene(3) Nitrile(3) Kalrez (3) Teflon (3)
Filled Unfilled Unfilled Filled Unfilled Filled Filled Filled Filled Unfilled
Service °F 350 350 450 350 325 300 275 450 400 325
(°C) (177) (177) (232) (177) (163) (149) (135) (232) (204) (163)

(2), (4) Above Below

Pressure psi 15,000 10,000 15,000 5000 5000 5000 3000 15,000 15,000 5000
(MPa) (103) (68.9) (103) (34.4) (34.4) (34.4) (20.7) (103) (103) (34.4)
Environments

H2S A A A A A B B NR NR A A A
CO2 A A B B A B B C A A A AA
CH4 (Methane) A A A A A A B B A A A
Hydrocarbons
(Sweet Crude)
A A A A A A A B C A A A AA
Xylene A A C A A A NR NR A A A
Alcohols A A C B A C C B A A A AA
Zinc Bromide A A A A A A NR NR A A AA A
Inhibitors NR A A NR NR NR B A A AA A A
Salt Water A A A A C A B A A
Halliburton Company (Dallas, Texas)

Steam A A NR A A NR NR NR NR NR B B

SL 4.32: O-Ring Service Selection Chart

Diesel A A A NR A A A B B A A A

A-Satisfactory B - Little or no effect C - Swells D - Attacks NR - Not recommended NT - Not tested

NOTE: (1) This information provides general guidelines for the selection of seal materials and is provided for informational purposes only. Seal Specialists with Halliburton Energy Services should be consulted for the actual
selection of seals for use in specific applications. Halliburton Energy Services will not be liable for any damage resulting from the use of this information without consultation with Halliburton Seal Specialists.
(2) Contact Technical Services at Halliburton Energy Services - Dallas for service temperature and pressure.
(3) Back-Up Rings must be used.
(4) There could be a slight variation in both temperature and pressure rating depending on specific equipment and seal designs.

Figure 4.32 - 1
4-74
April 29, 2020

Slickline Operations Manual

Halliburton Energy Services
(1)

General Guidelines For Seals

Compound(2) Nitrile Fluoro-Carbon Fluoro-Carbon Aflas(5) Urethane Neoprene Chemraz(4) Fluoro-Silicone EPDM Kalrez(4)
Series Q QV QVM QVA QE QS QCH QY QEP QP
Service (6) °F -10 to 275 -10 to 325 -10 to 400 100 to 400 -70 to 200 -20 to 250 40 to 400 -50 to 175 -30 to 300 100 to 400
(°C) (-21 to 135) (-21 to 162) (-21 to 204) (38 to 204) (-57 to 93) (-29 to 121) (4.4 to 204) (-46 to 79) (-34 to 149) (38 to 204)
Pressure(3) psi 10,000 9000 9000 8000 2000 2000 6000 6000 3000 6000
(MPa) (69) (62.1) (62.1) (55.2) (13.8) (13.8) (41.4) (41.4) (20.7) (41.4)

Environments
H2S NR A A A B NR A C NR A

CO2 A B B B B C A C NR B

CH4 (Methane) B A A A B B A C NR B
Hydrocarbons
(Sweet Crude) A A A A A B C A A NR A
Xylene NR A A C NR NR A A NR A
Alcohols A C C B D B A A B A
Zinc Bromide NR A A A NT NR A NT NT A
Inhibitors B(7) NR NR A NT C A NT NT B
Salt Water A A A A A C A A A A
Steam NR NR NT B NR NR B NR A B
Diesel B A A C B B A A NR A
Halliburton Company (Dallas, Texas)

Hydrochloric
Acid (HCI) NR A A A NT NR A NR NR A

SL 4.32: O-Ring Service Selection Chart

A-Satisfactory B - Little or no effect C - Swells D - Attacks NR - Not recommended NT - Not tested Good for O-rings, Packer
Elements and Molded Seals

NOTE: (1) This information provides general guidelines for the selection of seal materials and is provided for informational purposes only. Seal Specialists with Halliburton Energy Services should be consulted for the actual
selection of seals for use in specific applications. Halliburton Energy Services will not be liable for any damage resulting from the use of this information without consultation with Halliburton Seal Specialists.
(2) These materials are mainly used as o-rings.

(3) All pressure tests were done using 6 mil (.006) g aps, — larger radial gaps will reduce pressure rating.

(4) Back-up rings must be used above 250 0F (121.1 0C) and 4000 psi (27.6 Mpa).
(5) B ack- up rings must be used above 2500 F (121.10C) and 5000 psi (34.5 Mpa).
(6) C = ( F-32) x 5/9.
0 0

(7) Water soluble inhibitors only.

Figure 4.32 - 2
4-75
Slickline Operations Manual SL 4.32: O-Ring Service Selection Chart

(1)

Packer Element Selection Chart

N N Y N PACKER N Y
IN BROMIDE

STEAM/THERMAL PERMANENT PACKER IN OIL TEMP

START APPLICATION W/NO BASE MUD OVER 24 COMPLETION FLUIDS 40°F TO NITRILE ELEMENTS
PACKER
MORE THAN 36 HOURS W/STANDARD METAL BACKUPS
HYDROCARBON DESIGN HOURS BEFORE 325°F
BEFORE
FLUIDS SET? SET? N

Y N Y Y
Y
TEMP NITRILE ELEMENTS W/TEFLON
40°F TO AND METAL BACKUPS
400°F

Y
TEMP AFLAS ELEMENTS
100°F TO W/STANDARD METAL BACKUPS
400°F

Y
TEMP
AFLAS ELEMENTS W/TEFLON AND
100°F TO
GRAFOIL WIREMESH AND METAL BACKUPS
450°F
N

TEMP CHECK WITH YOUR HALLIBURTON

GREATER THAN 450°F REPRESENTIVE FOR SPECIAL APPLICATIONS

N Y
TEMP
RETRIEVABLE PACKER NITRILE ELEMENTS
40°F TO
PACKER EXPOSED TO W/BONDED GARTER SPRINGS
275°F
DESIGN BROMIDES?
Y N

N Y
PACKER
ELEMENTS TEMP FLUOREL ELEMENTS

EXPOSED TO AMINE 40°F TO

CORROSION W/BONDED GARTER SPRINGS
400°F
INHIBITORS?
Y N

Y
TEMP
AFLAS ELEMENTS
100°F TO W/BONDED GARTER SPRINGS
400°F
N

CHECK WITH YOUR

TEMP HALLIBURTON REPRESENTIVE
GREATER THAN 400°F FOR SPECIAL APPLICATIONS

Y
TEMP EPDM ELEMENTS WITH

LESS THAN
BACKUPS
550°F
NOTE: (1) This information provides general guidelines for the selection of seal materials and is provided for informational purposes only. N
Seal Specialists with Halliburton Energy Services should be consulted for the actual selection of seals for use in specific
applications. Halliburton Energy Services will not be liable fo r any damage resulting from the use of this information without CHECK WITH YOUR
TEMP HALLIBURTON REPRESENTIVE
consultation with Halliburton Seal Specialists. GREATER THAN 550°F FOR SPECIAL APPLICATIONS

Figure 4.32 - 3

N Y N PACKER N Y
PACKER IN OIL IN BROMIDE TEMP

STEAM/THERMAL PERMANENT BASE MUD OVER

START APPLICATION W/NO
COMPLETION FLUIDS
40°F TO NITRILE ELEMENTS
PACKER 24 HOURS MORE THAN 36 HOURS
HYDROCARBON BEFORE SET? BEFORE 325°F W/STANDARD METAL BACKUPS
DESIGN
FLUIDS SET?

Y N Y Y N

Figure 4.32 - 4

April 29, 2020 Halliburton Company (Dallas, Texas) 4-76

Slickline Operations Manual SL 4.32: O-Ring Service Selection Chart

Y
TEMP 40°F TO
400°F NITRILE
ELEMENT
N S
W/TEFLO
N AND
Y METAL
TEMP 100°F TO BACKUPS
325°F

Y
TEMP 100°F TO AFLAS
450°F ELEMENTS
W/STANDA
N
RD METAL
BACKUPS

TEMP GREATER
THAN 450°F

AFLAS
ELEMENTS
W/TEFLON
AN GRAFOIL
WIREMESH
AND METAL
BACKUPS

CHECK
WITH YOUR
HALLIBURT
O
REPRESENT
IVE FOR
SPECIAL
APPLICATIO
NS

April 29, 2020 Halliburton Company (Dallas, Texas) 4-77

Slickline Operations Manual SL 4.32: O-Ring Service Selection Chart

N Y
STEAM/THERMAL
PERMANENT
START APPLICATION W/NO
PACKER DESIGN
HYDROCARBON
FLUIDS

Y N

N Y
RETRIEVABLE PACKER TEMP NITRILE ELEMENTS
PACKER EXPOSED TO 40°F TO W/BONDED GARTER SPRINGS
DESIGN BROMIDES? 275°F

Y N

N Y
PACKER
ELEMENTS TEMP
FLUOREL ELEMENTS
EXPOSED TO AMINE 40°F TO
CORROSION W/BONDED GARTER SPRINGS
400°F
INHIBITORS?

Y
TEMP
100°F TO AFLAS ELEMENTS
400°F W/BONDED GARTER SPRINGS

TEMP CHECK WITH YOUR HALLIBURTON

GREATER
Figure 4.32 - 5 THAN
REPRESENTIVE FOR SPECIAL
APPLICATIONS
400°F

N
STEAM/THERMAL
START APPLICATION W/NO
HYDROCARBON
FLUIDS

Y
TEMP
LESS THAN EPDM ELEMENTS WITH BACKUPS
550°F

TEMP CHECK WITH YOUR HALLIBURTON

GREATER REPRESENTIVE FOR SPECIAL
Figure 4.32 - 6 THAN 550°F APPLICATIONS

April 29, 2020 Halliburton Company (Dallas, Texas) 4-78

Slickline Operations Manual SL 4.32: O-Ring Service Selection Chart

Relative Production Seal Costs

Compared with Molded Nitrile
Cost Comparison
80

X74 X75
70
X69
60
X60

50

40

X36
30
X29 X30
20
X21
X20
10 X15 X15

X1
0 X6

MSN MSF VTR RTR MSA VTP ATR PTP ATP CTR KTR CTP KTP
275 400 350 450 400 350 450 450 450 450 450 450 450

TEMPERATURE IN FAHRENHEIT

Figure 4.32 - 7

April 29, 2020 Halliburton Company (Dallas, Texas) 4-79

Slickline Operations Manual SL 4.33: Lifting Clamps and Caps

SL 4.33: Lifting Clamps and Caps

Pick-up Clamp F/Standard Stacks

Assembly Lub Tube Tube OD Pick-up Clamp Size

46RF78 46R108 2.63 46W458 96WO91 2-5/8

46RF41 46R134 2.63 46W458 96WO91 2-5/8

46RF58 46R104 3.00 46W668 96WO138 2-7/8

46RF211 46R187 3.00 46W668 96WO138 2-7/8

46RF165 46R145 3.38 46W705 96WO137 2-5/16

46RF202 46R164 3.25 46W662 96WO126 3-1/8

46RF215 46R149 3.25 46W662 96WO126 3-1/8

46RF204 46R205 3.50 46W704 96WO136 3-5/8

46RF227 46R17 3.50 46W704 96WO136 3-5/8

46RF206 46R164 3.25 46W662 96WO126 3-1/8

46RF217 46R149 3.25 46W662 96WO126 3-1/8

46RF208 46R174 3.50 46W704 96WO136 3-5/8

46RF237 46R47 5.00 46W654 5

46RF209 46R164 3.25 46W662 96WO126 3-1/8

46RF220 46R55 4.12 46W613 4

April 29, 2020 Halliburton Company (Dallas, Texas) 4-80

Slickline Operations Manual SL 4.34: Hay Pulleys and Ground Block Sheaves

SL 4.34: Hay Pulleys and Ground Block Sheaves

Hay Pulley and Sheave Selection

Scope
Hay pulleys and sheaves are used to guide wireline from the wireline unit to the lubricator.
Proper selection of pulleys and sheaves will prevent undue stress on the wireline.

General Information
Slickline
Slickline normally travels horizontally from the wireline unit to the hay pulley/weight
indicator at the base of lubricator. It makes a 90° turn around the hay pulley, travels up the
lubricator, and makes a 180° bend at the stuffing box to pass into the lubricator.

For .092-in. wireline and smaller, a standard 7- or 8-in. hay pulley is used. For the larger
sizes of slickline, a 16-in. hay pulley is recommended. Use of the small hay pulley with
.108-in. and .125-in. wireline will cause the wire to be overstressed and can lead to
premature wire failure.

More unusual rig-ups may necessitate the use of several hay pulleys to achieve a 90° bend
at the weight indicator and to prevent the wireline from scraping on obstructions. If a 90°
angle at the hay pulley/weight indicator is not possible, a correction factor must be applied
to the weight indication. This can be found in section WL1.20.

Several operational difficulties with the 16-in. hay pulley have recently been addressed. It
has been impossible to use a standard line wiper with the large hay pulley. An adaptor
(part # 46PA16204) is now available which allows the use of the standard slickline wiper.
Another problem has been noted with the large hay pulley that usually occurs during
downward jarring. As the wire becomes slack, the hay pulley and wire will “flop” against
the tree or deck. When tension is again applied, the wire shows a tendency to slip off of the
wheel and can become kinked around the shaft. A hay pulley stand (part #46PA16205) is
now available that will prevent the pulley from laying over on its side. Care must be taken
to prevent the stand from interfering with the weight indicator.

Braided Line
Braided line is most commonly run using a floor sheave and a crown block sheave. Most
logging units have a weight indicator built into the levelwind assembly. This eliminates
the need for a weight indicator to be attached to the floor sheave (hay pulley). A crown
block sheave is commonly used instead of having a sheave attached to the lubricator. The
wireline can be used to pick up the lubricator. This arrangement also allows heavy jarring
without any danger of bending the lubricator. See Figure 4.34 - 2.

Reference Number Type

312SM3 8-in. F/.092 and smaller

46PA16203 16-in. Aluminum

April 29, 2020 Halliburton Company (Dallas, Texas) 4-81

Slickline Operations Manual SL 4.34: Hay Pulleys and Ground Block Sheaves

Reference Number Type

996.19436 16-in. Composite

Figure 4.34 - 1

Figure 4.34 - 2

April 29, 2020 Halliburton Company (Dallas, Texas) 4-82

Slickline Operations Manual SL 4.35: Gin Poles and Accessories

SL 4.35: Gin Poles and Accessories

Gin Poles

Part Number Description

82TO233 Standard

82TO239 Heavy Duty

82TO260 Heavy Duty - 70oF

Detail Part Name Part Number Quantity

1 Weight Indicator 82TO110 M/D 0-2000 1

93GO2 M/D 0-4000 1

2 Hay Pulley 312SM3 1

3 Wireline Clamp 93G1 1

4 Lubricator Pick-Up Clamp See Listing For Size 1

5 Wire Rope Clip 94C296 2

6 Rope Block 94S8 2

7 Rope 94R2 150 ft

8 Screw Pin Anchor Shackle 3/8 in. 3

9 Load Binder (Ratchet Type) 92TB15 1

10 Proof Coil Chain 94CO1 3/8 in. x 15 ft 4

with 2 hooks

11 Grab Hook 3/8 in. 7

12 Cold Shut 3/8 in. 11

13 Turn Buckle 3/8 in. eye and eye 4

14 Proof Coil Chain 94C34 (2 ft length) 4

15 Bolt 410BH229 4

16 Nut 410NH130 4

17 Stake 46K83 4

18 Wire Rope 94C309 40 ft

19 Line Wiper 312PM213 1

20 Hay Pulley Chain 94CO9 1/4 in. x 4 ft 1

with 1 hook

21 Gin Poles 82TO233 Standard

82TO239 Heavy Duty
82TO260 Heavy Duty - 70°F

April 29, 2020 Halliburton Company (Dallas, Texas) 4-83

Slickline Operations Manual SL 4.35: Gin Poles and Accessories

Figure 4.35 - 1

April 29, 2020 Halliburton Company (Dallas, Texas) 4-84

 Slickline Operations Manual SL 4.36: Rope Sockets - Slickline and Braided Line

SL 4.36: Rope Sockets - Slickline and Braided Line

Wireline Rope Socket provides a means for connecting the wireline to
the tool string. A disc in the socket is free to rotate to provide a swivel
connection between the wireline and tools below the socket. A small
spring within the socket serves as a cushion to prevent the wireline tie
from straightening out and releasing during prolonged jarring.

Otis© Rope Socket

Specify: nominal size, wire size,
type (knot, no-knot).
Part number prefix: 43BO

Figure 4.36 - 1

NOMINAL FISH NECK

WIRE SIZE TYPE MAXIMUM OD THREAD SERVICE
SIZE OD

3/4 .092 Knot .687 .750 1/2-13 NC Std.

3/4 .092 Knot .750 .750 5/8-11 Std.

1 .092 Spring 1.00 1.00 5/8-11 Std.

1-1/4 .092 Disc 1.00 1.25 3/4-10 Std.

1-1/4 .105 Disc 1.187 1.25 15/16-10 Std.

1-1/2 .105 Disc 1.375 1.375 15/16-10 Std.

1-1/2 .105 Disc 1.375 1.375 15/16-10 H2S

1-1/2 .092/.105 No Knot 1.375 1.375 15/16-10 Std.

1-1/2 .108 No Knot 1.375 1.375 15/16-10 Std.

1-1/2 .108 No Knot 1.375 1.375 15116-10 H2S

1-1/2 .187 Wedge 1.375 1.50 15/16-10 Std.

1-1/2 .187 3-Hole 1.375 1.50 15/16-10 Std.

Thimble

1-1/2 .250 3-Hole 1.375 1.50 15/16-10 Std.

Thimble

1-1/2 .187 Slip-Type 1.375 1.50 15/16-10 Std.

1-1/2 .250 Slip-Type 1.375 1.50 15/16-10 Sid.

1-7/8 .092 Disc 1.750 1.875 1-1/16-10 Std.

1-7/8 .092/.105 No Knot 1.750 1.875 1-1/16-10 Std.

1-7/8 .108 No Knot 1.750 1.975 1-1/16-10 Std.

1-7/8 .108 No Knot 1.750 1.875 1-1/16-10 H2S

April 29, 2020 Halliburton Company (Dallas, Texas) 4-85

Slickline Operations Manual SL 4.36: Rope Sockets - Slickline and Braided Line

NOMINAL FISH NECK

WIRE SIZE TYPE MAXIMUM OD THREAD SERVICE
SIZE OD

1-7/8 .092 Disc 1.750 1.075 1-1/16-10 H2S

2 .187 Wedge 1.750 1.90 1-1/16-10 Std.

2 .187 Thimble 1.750 1.90 1-1/16-10 H2S

2-1/2 .108 No Knot 2.313 2.313 1-1/16-10 Std.

2-1/2 .187 3-Hole 2.313 2.31 1-1/16-10 Std.

Thimble

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:

• Conventional "knot" type

• Wedge “no-knot” type

Figure 4.36 - 2

The knot-type rope socket (Fig. 4.36-2) 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, then wound around itself with
tight wraps (Fig. 4.36-3). For typical slickline operations, the operator would make
between 7 to 14 wraps to complete the knot.

Figure 4.36 - 3

April 29, 2020 Halliburton Company (Dallas, Texas) 4-86

Slickline Operations Manual SL 4.36: Rope Sockets - Slickline and Braided Line

However, there are situations (crooked tubing, wire fishing, etc.) where the wraps would
be reduced to 1 ¾ to 2 wraps. With only 1 3/4 to 2 wraps, the operator could pull the wire
out of the rope socket if the tool string became stuck.

The no-knot (Fig. 4.36-4) rope socket is quickly becoming the favored method of
connecting the wire to the tool string for two reasons.

• It is easier to make up (with larger wire sizes currently being used).

• It is stronger.
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 radii.

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.
Figure 4.36 - 4
Note The rope socket used should be sized to ensure that a pulling
tool could retrieve it and the tool string from the wellbore.

April 29, 2020 Halliburton Company (Dallas, Texas) 4-87

Slickline Operations Manual SL 4.37: Stem — Non-Weighted and Weighted

SL 4.37: Stem — Non-Weighted and Weighted

Otis Stems are used as weight to overcome stuffing-box
packing friction and well pressure on the cross-sectional
area of the wireline. The stem can also transmit force either
upward or downward to set or retrieve subsurface controls.
Size and weight of the stem are determined by the impact
force required and the size of the subsurface control to be
run or pulled. For normal conditions, five feet of 1 3/4-in.
OD stem is made up by combining 2, 3, or 5 ft (0.61, 0.91,
1.22 m) lengths of standard stem. For high-pressure
applications when additional weight is needed, lead or
mallory-filled stems are available.

Otis® Stem
Otis© Stem

Specify: nominal size; length:

2, 3, 4 ft (.61, .91, 1.22 m);
solid or filled (Y/N-lead, mallory).
Part number prefixes:
44B-solid stem, 44AO-filled stem

April 29, 2020 Halliburton Company (Dallas, Texas) 4-88

Slickline Operations Manual SL 4.37: Stem — Non-Weighted and Weighted

Weight required to equal (balance) the force of the surface, shut-in well pressure that is
trying to push the wireline up and out of the stuffing box packing. Additional weight will
be required to pull the wireline into the well.

250 250
240
230
.125 220
210
200 200
.108 190
180
170
160
.105

STEM WEIGHT, LB
STEM WEIGHT, LB

150 150
140
130
120
.092
110
100 100
.082 90
80
.072 70
60
.066
50 50
40
30
20
10
0 0
0 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20
TUBING S URFACE P RES S URE, (P S I IN THOUS ANDS )

Figure 4.37 - 1

The stem (weight bar) (Fig. 4.37 - 2) 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.

April 29, 2020 Halliburton Company (Dallas, Texas) 4-89

Slickline Operations Manual SL 4.37: Stem — Non-Weighted and Weighted

The stem must provide the weight

necessary to overcome the friction
and force and pull the wire into the
well.

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 accom-
plish 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
effect the amount and size of the stem
being used.
CN03561

In some situations the rig-up

conditions can effect the type of stem
Figure 4.37 - 2
that is used. On some offshore
platforms, there is limited space and
special “weighted” stem (Fig. 4.37 -
2) 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.

April 29, 2020 Halliburton Company (Dallas, Texas) 4-90

Slickline Operations Manual SL 4.38: Stem Weight vs. Pressure Chart Table

SL 4.38: Stem Weight vs. Pressure Chart Table

CAUTION When determining the wireline tool string weight that is required to pull the wireline into
the well when running a sub surface device, consideration must be given to the design of
the device being run. In the larger ID of the wireline lubricator and in the larger ID of the
tree, the weight of the device may be beneficial in pulling the wireline into the well.
However, if the device has centralizers or spring loaded components that contactthe
tubing wall, a portion (if not all) the weight of the device, and possibly some of the tool
string weight, way be supported by the centralizers or spring loaded components when
they enter the smaller ID of the tubing. Therefore, it is a general practice to disregard the
Weight of this type of device when calculating the weight required to pull the wireline into
the well. In fact, additional weight will be required to overcome the “drag” effect of the
centralizers or spring loaded components that may be in contact with the tubing wall.
Although the following chart is extended to 20,000 psi well pressures and to wire sizes up
to .125-in. diameter, under certain conditions such as extremely high well pressures and/or
smaller tubing sizes, it may be impractical to use the larger wire sizes.

Cross Sectional Areas of W/L Approximate Weights of W/L

Wt/1000 Ft in
Diameter Area wt/ft in pounds
pounds

.066 .0034 sq. inch .01162 11.62

.072 .0040 sq. inch .01382 13.82

.082 .0052 sq. inch .01793 17.93

.092 .0066 sq. inch .02257 22.57

.105 .0087 sq. inch .02940 29.40

.108 .0092 sq. inch .03110 31.10

.125 .0123 sq. inch .04167 41.67

April 29, 2020 Halliburton Company (Dallas, Texas) 4-91

Slickline Operations Manual SL 4.39: Knuckle Joints

SL 4.39: Knuckle Joints

The knuckle joint (Fig. 4.39 - 1) has a ball and socket design to allow
for “swivel” and angular action between the jars and the tool or
control device that is attached below the knuckle joint. In most
slickline operations the tool or control device attached to the lower
end of the knuckle joint is considerably large in diameter than the tool
string. The importance of the knuckle joint is to allow the larger tool
or control device to align or centralize itself in the tubing bore,
especially if the tubing is crooked or “corkscrewed.”

Some operators will not use knuckle joints because they feel that it
will create a weak link in their tool string. If a knuckle joint is not
properly cared for, it could easily part.

When you look at the design of the knuckle joint, where the top sub
screws into the socket, the connection has a thin wall on the socket. A
roll pin keeps the socket from backing off.

Maintenance is the key to ensure that the knuckle joint remains in

CN03562
operational condition. Careful placement of the pipe wrenches to
keep them off the thin wall of the socket, removing the roll pin and
socket to clean and grease the threads are part of the maintenance
required. The condition of the socket should be inspected before each Figure 4.39 - 1
use to determine its condition.

April 29, 2020 Halliburton Company (Dallas, Texas) 4-92

Slickline Operations Manual SL 4.40: Jars - Spang, Tubular, Hydraulic, and Spring Type

SL 4.40: Jars - Spang, Tubular, Hydraulic, and Spring Type

Otis Accelerators are used with and just above hydraulic jars for shallow, weighty jarring. Accelerators
help maintain constant pull as the hydraulic jars begin to open. The accelerator inhibits pulling the wireline
out of the wireline socket at these shallow depths.

Otis Knuckle Joints have a special ball and socket design allowing angular
movement between the jars and the running or pulling tool to help align them
with the tubing. Knuckle joints are important if the tubing is corkscrewed and
when wireline work is done in a directional hole. In these conditions, joints
are used at every connection in the tool string. Where stem and jars will not
align or move freely, tool operation may be impossible; however, the knuckle
joint inhibits the wireline tools from hanging up.

Otis Jars are available in mechanical and hydraulic types. With a set of
mechanical jars below the stem, the weight of the jars and stem can be used
to jar-up or down by pulling and releasing the wireline. A Halliburton
Wireline Specialist can easily feel the jars and manipulate the wireline.
Hydraulic jars are designed to provide jarring action in wells in which it is

CN03562

CN03563
difficult to obtain good jarring action with mechanical jars. Hydraulic jars,
which allow an upward impact only, are usually run just above the regular
mechanical jars. They require careful maintenance for maximum use in the
tool string. Jar operation is monitored by a weight indicator. Otis® Otis®
Knuckle Joint Blind Box

Otis B Blind Box serves as the impact point when downward jarring
operations are required.

Standard Wireline Tool String

Normal Tool OD Fishneck OD
Thread Connection*
in. mm in. mm
3/4 19.05 5/8 in. - 11 UNC 0.750 19.05
1 25.40 5/8 in. -11 UNC 1.000 25.40
1 1/4 31.75 15/16 in. - 10 UNS 1.188 30.18
1 1/2 38.10 15/16 in. - 10 UNS 1.375 34.93
1 7/8 47.63 1 1/16 in. - 10 UNS 1.750 44.45
2 50.80 1 1/16 in. - 10 UNS 1.750 44.45
2 1/2 63.50 1 1/16 in. - 10 UNS 2.313 58.75

*Other thread connections available

Ordering Information
Specify: nominal size, stroke: 20-in. or 30-in. (50.8 - 76.2 cm) — mechanical only.
Part number prefixes:
44AO—mechanical jars, 44HO—hydraulic jars, 44BA—knuckle jars,
CN03565
CN03564

CN03566

44AC—accelerator 45BO—knuckle joint

Ordering Information
Specify: nominal size and thread, maximum OD, tubing size and weight.
Part number prefix: 44B—blind box Otis® Otis® Hydraulic Otis®
Mechanical Jar Accelerator
Jar

April 29, 2020 Halliburton Company (Dallas, Texas) 4-93

Slickline Operations Manual SL 4.40: Jars - Spang, Tubular, Hydraulic, and Spring Type

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:

• “Spang” link jars

• Tubular jars
Spang jars are available in two different stroke lengths
20-in. and 30-in. stroke. The 20-in.-stroke jars are most
commonly used because it is felt that they are stouter,
with less chance of becoming “scissored.” The 30-in.-
stroke jars are used when extensive upward jarring is
required.
CN03566

Tubular jars are used most often when well conditions

or the operation might cause the Spang jars to become “Spang” link Tubular jars
fouled. Jar

Note The OD of the jars should match the OD of the stem.

Hydraulic Jars
The Hydraulic Jar (Fig. 4.40 - 1) is designed to provide upward jarring impacts under
conditions where it may be difficult or impractical to obtain adequate upward jarring
impacts with the mechanical jars.

Hydraulic jars are capable of providing an upward jarring impact only. They do not
provide a downward jarring impact. When used, the hydraulic jar should be installed
immediately above the mechanical jars in the slickline tool string. The hydraulic jar is not
intended to replace the mechanical jar in the slickline tool string.

April 29, 2020 Halliburton Company (Dallas, Texas) 4-94

Slickline Operations Manual SL 4.40: Jars - Spang, Tubular, Hydraulic, and Spring Type

Essentially the hydraulic jar

consists of two basic sub
assemblies:

• The mandrel sub assembly

that has a piston at its lower
end and a top sub (fishing
neck) at its upper end. Inside
the piston, there is a valve
and port assembly that will
not allow fluid flow from
above the piston to below but
will allow fluid flow from
below to above the piston.
• The body (housing) sub
assembly. Near its lower end,
the body has a restricted
internal diameter (cylinder)
that will accept the piston
end of the mandrel assembly.
Also note that a balance pis-
ton is installed in the lower
end of the restricted internal
diameter (cylinder) in the
body. The balance piston
seals in the cylinder and is
free to move up and down as
required to equalize the pres-
sure of the hydraulic fluid,
inside the jar, with the well
pressure outside the jar. The
balance piston also compen-
sates for any expansion of
the hydraulic fluid, and
resultant pressure increase,
that could be caused by tem-
perature.
When the hydraulic jar is in the Figure 4.40 - 1
“closed” position, the piston (at
the lower end of the mandrel
assembly) is inside the restricted internal diameter (cylinder) of the body. When an
upward strain is taken on the slickline, the mandrel assembly is pulled upward in relation
to the body. The upward movement of the mandrel is impeded by the hydraulic fluid that
must pass through the extremely narrow annular space between the outside diameter of the
piston (on the mandrel) and restricted internal diameter (cylinder) in the body. As soon as
the piston moves out of the restricted internal diameter (cylinder) of the body and into the
enlarged internal diameter of the body, the fluid resistance ceases. At this point, the
“stretch” that has been pulled in the slickline causes the mandrel subassembly to travel

April 29, 2020 Halliburton Company (Dallas, Texas) 4-95

Slickline Operations Manual SL 4.40: Jars - Spang, Tubular, Hydraulic, and Spring Type

upward at a constantly accelerating velocity until the top shoulder on the piston strikes the
stop in the upper end of the body. This transmits an upward jarring impact to the tool(s)
that are below the hydraulic jar.

After the upward jarring impact has been completed, the wire is slacked off to allow the
weight of the slickline stem to "close" the hydraulic jar. During closing, as the piston
enters the cylinder, the valve assembly in the piston is moved off seat to permit rapid
displacement of hydraulic fluid from below the piston to above. When the mandrel/piston
assembly has completed its downward travel, the valve in the piston is closed by a small
spring and the jar is ready for the next upward jarring impact.

The slickline operator can control the intensity of the upward jarring impact of the
hydraulic jar by increasing or decreasing the amount of tension (and the resulting stretch)
that is pulled on the wire.

One of the problems associated with the use of hydraulic jars is that they can "gas up" and
created a shock absorber that hinders jarring. Understanding the operation and function of
the components of the hydraulic jars and using good redress practices can reduce the risk
of getting gas into the jars.

When the hydraulic jars enter the wellbore, a pressure differential is created if the balance
piston does not move. The fluid inside the jars will remain at atmospheric pressure. Then
when the mandrel/piston is pulled out to effect an upward jar the differential is greater.
This pressure differential, causes rapid deterioration of the seals and gas enters.

Pre-testing the hydraulic jars on the surface, and visually inspecting the movement of the
balance piston, will assure longer use.

April 29, 2020 Halliburton Company (Dallas, Texas) 4-96

Slickline Operations Manual SL 4.40: Jars - Spang, Tubular, Hydraulic, and Spring Type

Spring Jars
Spring jars (Fig. 4.40 - 2) were developed in response to the “gas up” problems of the
hydraulic jars and to increase the effective stroke thereby increasing the impact forces
downhole.

Spring jars uses a stack of disc spring washers, that are fully
adjustable giving them the ability to simulate the function of
hydraulic jars without the risk.

Figure 4.40 - 2

April 29, 2020 Halliburton Company (Dallas, Texas) 4-97

Slickline Operations Manual SL 4.41: Accelerators

SL 4.41: Accelerators
The accelerator is used in conjunction with the hydraulic or spring jars, primarily, when
unseating and retrieving unusually heavy sub surface devices from shallow depths in the
well.

At shallow depths and deeper depths in highly deviated wells, the amount
of “stretch” that could be pulled in the slickline to activate the hydraulic
jar would be minimal. Slickline riding along the tubing wall can cause a
change in the effective stretch of the wire. Additionally, this load applied
to the slickline at shallow depths would tend to either break the slickline
or cause it to pull out of the slickline socket.

Installation of the accelerator in the slickline tool string between the

slickline socket and the stem allows the hydraulic jar to be used at
shallow depths or more effectively in highly deviated wells.

When a strain is pulled on the slickline, with the accelerator in place, the
spring in the accelerator is compressed a given distance. The distance
that the spring is compressed is greater than the distance that the
mandrel/piston assembly of the hydraulic jar must travel when moving
from its "closed" to its "open" position. By maintaining a constant
tension on the slickline, the compressed spring in the accelerator tends to
accelerate the upward speed of the mandrel/piston assembly of the
hydraulic jar when it activates. This delivers an upward jarring impact to
the tools below the hydraulic jars.

CN03566
In effect, at shallow depths, the accelerator simulates the wire "stretch"
Otis®
that is normally required to operate the hydraulic jar. The accelerator also Accelerator
provides a cushioning effect that helps to avoid either breaking or pulling
the wire out of the slickline socket at shallow depths. At deeper depths
the accelerator can increase the speed of the impact to generate more force.

April 29, 2020 Halliburton Company (Dallas, Texas) 4-98

Slickline Operations Manual SL 4.42: Tool String Connections

SL 4.42: Tool String Connections

Figure 4.42 - 1

Item Number Description

51C1 SUB 1 1/16-10 X 15/16-10

51C2 SUB 3.00

51C 3 SUB X-OVR ADPT 1 1/16-

51C5 SUB 15/16-10 UNS X 1 1/16

51C 9 SUB 15/16-10 X 3/4 API

51D 1 SUB 15/16-10 X 1 1/16-10

51D 3 SUB 1 1/16-10 X 5/8-11

51D 4 SUB 1 9/16-10 X 15/16-10

51D 5 SUB 1 1/16-10 UNS X 15/16

51D 6 SUB 15/16-10 X 3/4-16

51D 7 SUB 1 1/16-10 X 3/4-16

51D 8 SUB 3/4-16 X 15/16-10 P-B

April 29, 2020 Halliburton Company (Dallas, Texas) 4-99

Slickline Operations Manual SL 4.43: Quick Connects and Tools

SL 4.43: Quick Connects and Tools

Before its extensive field history, the
Otis Quick Connect was thoroughly
tested in both the engineering
laboratory and the Halliburton test well
in Dallas, Texas. During the design
proving phase, a 1 3/4-in. (38.1 cm)
Otis Quick Connect was jarred through
50,000 cycles at impact loads of 9,000
to 10,000 lb (4082.33 to 4535.92 kg) in
both directions. Tensile testing on the
tool after jarring revealed the Otis
Quick Connect had retained full
strength throughout the operation.

Now Halliburton toolstring

components and wireline service tools
are available with integral Otis Quick
Connects.

Features
• spacing of load-bearing shoulders
will not allow coupling to connect
until full engagement of all
shoulders are in place
• self-washing feature minimizes
sand buildup in the locking
mechanism
• designed for manual operation; no
special tools are required
CN00756

CN00757

CN00758

Mechanical Wireline Quick Knuckle Joint

Benefits Wireline Jar Connect Stem Quick Connect
• Otis Quick Connect design ensures
proper tool string make-up
• reliable disconnect, even in sandy
environment
• safe assembly/disassembly on
location; no special tools required
• faster turnaround on location
minimizes job time

April 29, 2020 Halliburton Company (Dallas, Texas) 4-

100
Slickline Operations Manual SL 4.43: Quick Connects and Tools

Part Numbers for HES Toolstring Components with Integral Quick Connects

1 7/8 in.

Rope Socket 43 QC 1870

Stem 24 in. 44 BQ 1870

Stem 36 in. 44 BQ 1871

Stem 60 in. 44 BQ 1872

Jars 20 in. Stroke 44 AOQ 18701

Knuckle Joint 45 BQ 1870

1 1/2 in.

Rope Socket 43 QC 1500

Stem 24 in. 44 BQ 1500

Stem 36 in. 44 BQ 1501

Stem 60 in. 44 BQ 1502

Jars 20 in. Stroke 44 AOQ 15000

Knuckle Joint 45 BQ 1500

April 26, 2018 Halliburton Company (Dallas, Texas) 4-100

Slickline Operations Manual SL 4.44: Go Devils/Cutter Bars

SL 4.44: Go Devils/Cutter Bars

Auxiliary Tools for Use with
Slickline Tool String
Otis® Gauge Cutter and
Swaging Tools

CN03568
CN03567

CN03569
It is important to run a gauge cutter before running
subsurface controls to: (1) determine if control will
pass freely through the tubing; and (2) to locate the
top of the landing nipple if any are in the tubing. The Otis® Otis® Otis®

gauge cutter knife (larger than OD of the control) is Swaging Tool Gauge Cutter Impression Tool
designed to cut away paraffin, scale, and other debris
in the tubing. Mashed spots in the tubing and large
obstructions may be removed with the swaging tool.
These tools are available in sizes for all tubing IDs.
Otis Impression Tool is a lead-filled cylinder with a
pin through the leaded section to secure it to the body
of the tool. It is used during a fishing operation to
ascertain the shape or size of the top of the fish and to

CN03572
CN03571
CN03570

indicate the type of tool necessary for the next

operation.
Otis Tubing Broach is made up of three major parts: Otis® Otis® M Otis®
(1) mandrel, (2) nut, and (3) a set of three spools. Tubing Broach Magnetic Fishing G Fishing Socket
Spools are tapered and used to cut burrs in the tubing Tool
ID caused by perforation, rust, bent tubing, etc. A
small OD spool is run first followed by the next
larger size, followed by a spool corresponding to the
original ID of the tubing. Broach assemblies are run
on wireline.
Otis M Magnetic Fishing Tool is designed to
remove small particles of ferrous metals from the top
of tools in the well.
CN03574
CN03573

Otis G Fishing Socket was designed primarily to

extract prongs with fishing necks from Halliburton
subsurface equipment, such as the Otis PS Plug
Otis® P Otis®
Choke. Wireline Grab Go-Devil
Otis P Wireline Grab is a fishing tool designed to Ordering Information

extract broken wireline or cable from the tubing or Gauge Cutter, Swaging Tool, Impression Tool, Tubing Broach
Specify: nominal size and thread, maximum OD, tubing size and weight.
casing. Part number prefixes: 65A—swaging tool, 65G—gauge cutter, 52C—impression tool,
65B—tubing broach
Otis Go-Devil is a slotted stem with a fishing neck. Ordering Information
A small strip of metal is pinned in the slot to inhibit Magnetic Fishing Tool, Fishing Socket
Specify: nominal size and thread.
the wireline from coming out. Its use is usually Part number prefixes: 52MO—magnetic fishing tool, 52GO—G Fishing socket
limited to fishing operations in which a wireline Ordering Information
socket is inaccessible and the line must be cut. Otis Wireline Grab, Wireline Retrievers
Specify: tubing size and weight, wireline toolstring nominal size and thread.
Go-Devils designed to cut the wireline at the wireline Part number prefixes: 52P—wireline grab, 52PO—wireline retrievers

socket are also available. Ordering Information

Go-Devil
Specify: nominal size, length,
style bottom (flat or angled).
Part number prefix: 47AO

April 26, 2018 Halliburton Company (Dallas, Texas) 4-101

Slickline Operations Manual SL 4.45: Kinley Perforator

SL 4.45: Kinley Perforator

Uses
• Effective economical gas lift
• Produce alternate zones
• Circulate your well and kill it
• Loosen sand-bridges or mud between tubing and casing
• Place a standard orifice, or a check valve, in order to inject glycol, inhibitor, or hot oil
• Perforate a hole to avoid pulling a “Wet String!”
• Perforate tubing inside sand screen without damaging screen

Advantages
• Runs on wireline through a lubricator, without killing the well.
• Punches a hole. Does not burn or perforate the casing!
• Works in deep wells. Jobs have been performed below 17,000 ft.
• Can be run and fired with electric line for critical depth location.
• New programmable timer can fire the perforator at any depth.
• Works safely; exclusive safety feature helps prevent premature firing.
• Power: Can punch 3/4-ft hole or place a 1/2-ft Orifice Insert thru 5/16-ft thick tubing.
• Orifices and check valves temporarily extend the productive life of the tubing.

Sizes
• Standard Orifice Insert: 2/64 ft thru 32/64 ft
• Check Orifice sizes: 2/64 in. thru 16/64 ft
Figure 4.45 - 1
• Circulating button will punch a .25 ft, .34 in., .48 ft, or .75 ft hole in tubing from
1.315.
• OD thru 10-3.4 ft OD tubing

April 26, 2018 Halliburton Company (Dallas, Texas) 4-102

Slickline Operations Manual SL 4.46: Kinley Power Jar

SL 4.46: Kinley Power Jar

Service
The Kinley power jar was adapted from the Kinley tubing perforator, which has given
safe and dependable service in thousands of wells.

It hits hard enough to cut out the bottom of a 2-7/8-ft and is estimated to hit 40 times
harder than Bull Plug any Mechanical Jar.

Uses
• knock a stuck choke loose
• knock out bridge plug
• knock out flapper valve
• shift a sliding sleeve
• drive a spear into tangled wire
• knock loose stuck tool string
• knock out packer ball seat

Advantages
• Tremendous savings possible by avoiding workovers. One job saved a customer over
$2,000,000.00.
• Power jar does not anchor itself and can be pulled and reloaded after each shot.
Figure 4.46 - 1 • Force of blow can be varied to suit the job by changing to a more powerful cartridge
for each shot.
• Hits a harder, straighter blow, even in deep wells, as compared with any mechanical
jar propelled by gravity and impeded by well fluids. It is less apt to batter the Fish off-
center.
• A hammer, chisel, cutter, etc., can be used to perform different jobs. These
attachments remain a part of the tool and are pulled with the jar.

Sizes
Available for use in 2-1/16-ft, 2-3/8-ft, 2-7/8-ft, and 3-1/2-ft tubing. The 3-1/2-ft size is
suitable for use in larger tubing and casing sizes.

April 26, 2018 Halliburton Company (Dallas, Texas) 4-103

Slickline Operations Manual SL 4.46: Kinley Power Jar

Safe and Effective Operation

The power jar is run on a wireline to contact with the fish. A few strokes of the jars shears
two safety pins and causes a firing pin to strike the primer and to fire the cartridge. The
explosion forces the drive pin downward to strike the drive head, which rests on the fish.
The drive head delivers a quick, hard blow. The explosive force is entirely contained
within the tool and does not the line above the tool string.

April 26, 2018 Halliburton Company (Dallas, Texas) 4-104

Slickline Operations Manual SL 4.47: Kinley Sneppers

SL 4.47: Kinley Sneppers

The Kinley Snepper is a dependable mechanical wireline tool designed to be dropped
into the hole to cut slick line. It operates by the impact of its own weight and cuts the
line when it hits bottom. Tests show that it will do the job with a free fall of only two
feet. The cut is made just 2-1/2-ft above the rope socket, making an easy fishing job. The
Snepper has cut a .082' line at 11,000 ft and will cut any size line up to and including
.108'. There are Snepper sizes to cut in wells as small as 1.25-ft ID. We also have an
Upside-Down Snepper for cutting in deviated wells, wells with side pocket gas-lift
mandrels, standing fluid levels, or where Snepper could strike a solid surface and cut
prematurely.

Available Sizes
Jumbo Snepper, 1-7/8-ft x 36-7/16-ft Junior Snepper, 1-1/4-ft x 26-3/8-ft'

Instructions for Use

The Kinley Snepper is simple to assemble and use. It won't go together in any way but
the right one. The knife, slipper and crimper make up a sub-assembly which is pushed
into the body and held there by the bottom cap. The procedure for assembly is as
follows:

1. The first step is to cover the well hole so that none of the small parts can drop into it
while the cutter is being assembled on the measuring line.
Figure 4.47 - 1
2. Cut 1/16-in. brass welding rod to 4-in. long, and push it clear through the two
lengthwise holes in the slipper. The upper end of the slipper may be identified by the
rounded (crimper) edge where the slot comes to the diagonal end.
3. Put the slipper on the measuring line so that the measuring line lies in the back of
the slot.
4. Put the crimper on the measuring line in the same way, above the slipper, and bring
the two pieces together, pushing the 1/16-in. brass shear pin up into the crimper, and
out the far side just enough so that it can be crimped down into the recess for it.
5. Screw the set screw into the tapped hole at the top of the crimper until it is tight.

April 26, 2018 Halliburton Company (Dallas, Texas) 4-105

Slickline Operations Manual SL 4.47: Kinley Sneppers

6. Put the knife on the measuring line in the same way, below the slipper, and
bring the pieces together, pushing the 1/16-in. brass shear pin down into the
knife. Crimp the end of the shear pin slightly, and screw the set screw in all
the way. This completes the sub-assembly.
7. Put the body on the measuring line and push the subassembly up into it.
8. Line up the 1/16-in. shear pin hole which goes across the knife with the correspond-
ing 1/16-in. shear pin slot which is to be found in the last 3 or 4 threads at the bottom
of the body. Push another 1/16-in. shear pin through and cut it off so that it won't
interfere with the threads.
9. Put the bottom cap on the measuring line, below the body and sub-assembly, and
screw it tightly onto the body.
10. The cutter is now ready to drop into the well. If the well is not full of fluid, run in a
few barrels ahead of the cutter to break its fall, and to be sure it doesn't cut the line
when it hits fluid. Drop the cutter.
11. The cutter will cut the measuring line when it hits the rope-socket. It will also crimp
the end of the line and clamp onto it at the same time. When the line is brought out
of the hole, the cutter will be on the end of it.

Figure 4.47 - 2

April 26, 2018 Halliburton Company (Dallas, Texas) 4-106

Slickline Operations Manual SL 4.48: Sandline Cutters

SL 4.48: Sandline Cutters

The Kinley Sand Line Cutter can save the whole line in one piece by cutting it just above
the Rope Socket. This saved line alone can pay for the cutting job and make an easier
fishing job.

Advantages
1. Economical and efficient. Most jobs in tubing take only an hour. Compare this with
the usual long time and heavy expense of pulling the line in two, and then cutting the
remaining line, joint by joint, as the tubing is pulled.
2. Helps to save the fish as well as the line. When the cutter rests on the fish and cuts the
line just ten inches above it, the stub is short and it is possible to fish for the stuck
tools.
• Cuts in casing, tubing, or coiled tubing (1-in. OD or larger).
• Cuts in drill pipe (1-7/8-ft minimum OD. or larger).
• Cuts sand line any size up to, and including 1/4-in. 1 1/2-ft OD tubing,
1/2-in. 2 1/16-ft OD tubing, 9/16-in. 2-3/8-ft OD tubing, 3/4-in. 2-7/8-ft OD
tubing, 7/8-in. 3-1/2-ft OD tubing and 1-1/8-in. 5-ft OD tubing.
3. Optional electronic programmable timer designed to fire the sand line cutter after a
Figure 4.48 - 1 pre-selected interval.

Operation
The cutter can be lowered or dropped into the well. A groove down one side keeps the
line in front of the knife. After the cutter rides the stuck line down to the top of the rope
socket, it is fired by a drop weight or timer. It is the powder charge that drives the wedge,
which forces the knife to cut the sand line.

In 2-3/8-ft tubing (or larger) the drive wedge that operates the cutting knife also forces a
crimper (not shown) to clamp the line against a sleeve. This crimper allows the cutter and
the drop weight to be recovered on the end of the cut line, which can eliminate the fishing
job (which may be necessary in smaller sizes of tubing).

April 26, 2018 Halliburton Company (Dallas, Texas) 4-107

Slickline Operations Manual SL 4.49: Shear Pin Guide

SL 4.49: Shear Pin Guide

Some of the many functions which can be accomplished by the use of slickline include the
installation and retrieval of safety valves, plugs, and prongs from the wellbore, as well as
the shifting of sleeves and the installation or retrieval of gas lift valves. All of these
functions either require that shear pins be sheared, or have the ability of shearing them,
during the retrieval process. This shearing action is accomplished by creating jarring
impacts to the shear pins by manipulation of the slickline and tool string in either an
upward or downward direction. Whether the shear pin to be used is steel, brass, or
aluminum, is determined by a number of factors, including but not limited to the
following:

• Well fluids
• Well pressure
• Deviation
• Depth
• Wire breaking load
• Toolstring weight and jar setting
• Rig heave
• Run history
• Surface to be jarred against – hard or soft tag
• Lessons learned

Other factors to consider:

Shear pin breaking force – Shear pin breaking force can be obtained by taking the
product of the shear pin cross-sectional area and the material's Ultimate Shear Strength
from a straight pull. The values shown in Table 4.49-1 are the Ultimate Shear Strength
ratings for commonly used shear stock material.

Table 4.49-1: Common Material Guide for Ultimate Shear Strength

Material Ultimate Shear Strength

Aluminum 41,000 psi

Brass 43,000 psi

Mild Steel 58,000 psi

Single or double shear face – Shear pins can be either single shear or double shear
(shown below). If a shear pin extends through a core touching either side of the sleeve,
then the pin is said to be in a double shear, and thus the force required to shear it is twice
that of a single shear. Double shear face is the most common condition in slickline
shearable tools.

April 26, 2018 Halliburton Company (Dallas, Texas) 4-108

Slickline Operations Manual SL 4.49: Shear Pin Guide

Single Shear Face Double Shear Face

To produce a pure and smooth shear in materials can be very difficult. The cutting edges of
the shear face need to be sharp with the shear stock closely supported. If the shear force
required is critical in determining the success of the operation, then a pull test should be
conducted prior to the run to confirm any figures. However, Table 4.49-2 (below) can be
used as a guide:

Table 4.49-2 Pin Shear Strength Guide

Breaking Force lb Breaking Force lb Breaking Force lb

Cross
Size in. Aluminum Brass Mild Steel
Section Area
(Single Face Shear) (Single Face Shear) (Single Face Shear)

1/16 0.003 123 129 174

3/32 0.007 287 301 406

1/8 0.012 492 516 696

5/32 0.019 779 817 1,102

3/16 0.028 1,148 1,204 1,624

7/32 0.038 1,558 1,634 2,204

1/4 0.049 2,009 2,107 2,842

9/32 0.062 2,542 2,666 3,596

5/16 0.077 3,157 3,311 5,182

3/8 0.11 4,510 4,730 7,025

In a given well, if you are concerned about your ability to shear a pin via downward or
upward jarring due to inhibited jar action, start conservatively with a brass or aluminum
pin.

When a pulling tool is being run to either set or retrieve a flow control device, or to
retrieve a fish, it is recommended the pulling tool is pinned with aluminum or brass, unless
it can be confirmed from a previous run the pin in the tool can be sheared without too
much difficulty. In the event the flow control device or fish cannot be pulled free, this

April 26, 2018 Halliburton Company (Dallas, Texas) 4-109

Slickline Operations Manual SL 4.49: Shear Pin Guide

should enable the pulling tool to be sheared, retrieving the toolstring to surface while
leaving a clean fishing neck for future runs. The same methodology can be followed while
shifting an SSD or retrieving a gas lift valve.

Note Although aluminum has similar shear strength to brass, if the cutting surface or
the tolerance between the two cutting surfaces is worn, an aluminum pin can smear
making the shearing process more difficult.

Although the decision tree shows the cautious approach, with all runs having brass pins,
for a number of reasons, including but not limited to the following, a steel pin may be
preferred over a brass or aluminum pin:

• Confirmed hard surface which will allow the steel pin to be sheared.
• Good jar action obtained in previous run and deemed sufficient to shear a steel pin.
• Pin sheared prematurely when working toolstring through restrictions during previous
run.
• Weight of toolstring would cause the brass or aluminum pin to shear prematurely.
• Risk of pin shearing prematurely leading to additional rig time.

Each run should be reviewed with the risk assessed on an individual basis, taking into
account the effect of deviation, fluid viscosity, etc. Changing the spring jar setting, adding
stem, integrating accelerators or roller systems into the toolstring can all greatly increase
the impact force generated at the toolstring, ultimately increasing the mechanical shock to
the shear pin. Additionally, the tool BDMI should be used as a reference regarding correct
tools to be run in the correct order (for example, R-series before S-series).

In instances where more than one shear pin may be in place to help facilitate stronger
manipulation of downhole tools without prematurely releasing the tool being deployed,
consideration must be given to the capability to shear both pins in downhole conditions
versus the expected force required to manipulate the deployed tool without shearing to
release.

Note All toolstring components shall be functioned prior to running in the well. This
will ensure the tool operating envelope and specifications are verified to meet the job
requirement. Consideration should also be given to the physical condition of any shear pin
previously run in the well. If the shear pin is not replaced prior to each run, any loads
applied during previous runs may cause a reduction in shear pin value with premature
shearing a possibility

Note When replaced, shear pins should be cross center punched to ensure they stay in
place during the running operation and filed flush with the OD of the tool to ensure the
tool OD is not affected.

April 26, 2020 Halliburton Company (Dallas, Texas) 4-110

Slickline Operations Manual SL 4.49: Shear Pin Guide

Shear Pin Decision Tree

*** When deciding to change from a jar up to shear pulling tool to a jar down to shear
pulling tool, it is recommended to first run the pinned up pulling tool with the keys or dogs
removed to ensure the tool will shear and release from the flow control device in the event
it is latched. If the pin can be sheared, the operation can continue with the pulling tool c/w
dogs or keys.

April 26, 2020 Halliburton Company (Dallas, Texas) 4-111

Slickline Operations Manual SL 4.50: X and R® Nipple Selection Chart

SL 4.50: X and R® Nipple Selection Chart

Otis X and R Landing Nipples and Lock Mandrels

Halliburton X and R landing nipples are run into the well on the
completion tubing to provide a specific landing location for
subsurface flow control equipment. The common internal
profiles of these landing nipples make them universal. The X

CN03542
landing nipple is used in standard weight tubing; the R landing

CN03539
nipple is typically used with heavyweight tubing.

The completion can have as many selective nipples with the

same ID in any sequence as desired on the tubing string. This X® Landing Nipple
versatility results in an unlimited number of positions for setting and Lock Mandrel
and locking subsurface flow controls. The flow control, which is
attached to the required X or R lock mandrel, is run in the well
via the selective running tool on slickline.

CN03540
The slickline operator using the selective running tool can set
the flow control in any one of the landing nipples at the desired

CN03541
depth. If this location is unsatisfactory or if well conditions
change, the flow control may be moved up or down the tubing
string to another nipple location. These operations can be done
by slickline under pressure without killing the well. R® Landing Nipple
and Lock Mandrel

Otis XN and RN No-Go Landing Nipples

and Lock Mandrels
This equipment is designed for
use in single nipple
Fishing
installations or as the bottom Fishing
Neck Neck

nipple in a series of Otis X or R

Expander
landing nipples. These landing Mandrel Expander
Mandrel
Double-
nipples have the same packing Acting Double-
Spring
bore ID for a particular tubing Acting
Spring
size and weight. X and XN Locking
CN03544
CN03542

Keys Locking
landing nipples are designed Keys
Packing
for use with standard weight Packing
No-Go
tubing; R and RN landing
CN03543

Equalizing No-Go
Sub
CN03545

Equalizing
nipples are designed for use Sub
with heavyweight tubing. (The
N designates no-go nipples.) XN® No-Go Landing
RN® No-Go Landing
Nipple and Lock Mandrel
Nipple and Lock Mandrel

April 26, 2020 Halliburton Company (Dallas, Texas) 4-112

Slickline Operations Manual SL 4.50: X and R® Nipple Selection Chart

Otis X, XN, R, and RN Landing Nipples and Lock Mandrels

Applications
• plugging under pressure
• almost unlimited locations for setting and locking subsurface flow controls

Features and Benefits

Landing Nipples
• large bore for minimum restriction
• universal nipple with one internal profile
• versatility helps reduce completion and production maintenance costs
• simple operation
• multiple options when running, setting, or retrieving subsurface flow controls

Lock Mandrels
• retractable locking keys
• locks designed to hold pressure from above or below or from sudden reversals

April 26, 2020 Halliburton Company (Dallas, Texas) 4-113

Slickline Operations Manual SL 4.50: X and R® Nipple Selection Chart

• extra large ID for higher flow volumes

• faster slickline service because of the retractable keys
• operator control of locating, landing, and locking in the selected nipple
• inside fishing neck provides large ID to maximize production
• optional hold-down feature for high flow rates and safety valve installations

Optional Hold-down
• interference hold-down for smaller locks
• shear pin hold-down for larger locks

Note The optional hold-down feature is recommended for SSSV installations. Both features provide
additional locking integrity to withstand rigorous well conditions.

April 26, 2020 Halliburton Company (Dallas, Texas) 4-114

Slickline Operations Manual SL 4.50: X and R® Nipple Selection Chart

Ordering Information
Specify: X or XN; R or RN; packing bore; tubing size, weight, grade, and thread; service environment
(standard, %H2S, %CO2, amines/other chemicals, chloride content, temperatures, pressures, etc.); API
monogramming or other certification requirements; special hold-down (interference or shear pin on lock
mandrel); special material and elastomer requirements, if applicable

Part number prefixes: 11X, XN—landing nipple; 711X, XN—API/monogrammed landing nipple;
10XO, XN—lock mandrel; 710XO, XN—API/monogrammed lock mandrel; 11R, RN—landing nipple;
711R, RN—API/monogrammed landing nipple; 10RO, RN—lock mandrel; 710RO, RN—API/
monogrammed lock mandrel

Otis X and XN Landing Nipples and Lock Mandrels Specifications
For Standard Tubing Weights
Tubing X® Prof ile XN Prof ile Lock Mandrel ID
Size Weight ID Drif t Packing Bore Packing Bore No-Go ID
in. mm lb/ft kg/m in. mm in. mm in. mm in. mm in. mm in. mm
1.050 26.67 1.20 1.79 0.824 20.93 0.730 18.54
Available on Request
1.315 33.40 1.80 2.68 1.049 26.64 0.955 24.26
2.30 3.42
1.660 42.16 1.380 35.05 1.286 32.66 1.250 31.75 1.250 31.75 1.135 28.83 0.62 15.75
2.40 3.57
2.40 3.57 1.660 42.16
1.900 48.26 2.76 4.11 1.610 40.89 1.516 38.51 1.500 38.10 1.500 38.10 1.448 36.78
0.75 19.05
2.90 4.32
2.063 52.40 3.25 4.84 1.751 44.48 1.657 42.09 1.625 41.28 1.625 41.28 1.536 39.01
4.60 6.85
2 3/8 60.33 1.995 50.67 1.901 48.29 1.875 47.63 1.875 47.63 1.791 45.49 1.00 25.40
4.70 6.99
2 7/8 73.03 6.40 9.52
2.441 62.00 2.347 59.61 2.313 58.75 2.313 58.75 2.205 56.01 1.38 35.05
6.50 9.67
9.30 13.84 2.992 76.00 2.867 72.82 2.813 71.45 2.813 71.45 2.666 67.72
3 1/2 88.90 1.75 44.45
10.20 15.18 2.922 74.22 2.797 71.04 2.750 69.85 2.750 69.85 2.635 66.93
4 101.60 11.00 16.37 3.476 88.29 3.351 85.10 3.313 84.15 3.313 84.15 3.135 79.63 2.12 53.85
4 1/2 114.30 12.75 18.97 3.958 100.53 3.833 97.36 3.813 96.85 3.813 96.85 3.725 94.62
2.62 66.55
5 127.00 13.00 19.35 4.494 114.14 4.369 110.97 4.313 109.55 4.313 109.55 3.987 101.27
5 1/2 139.70 17.00 25.30 4.892 124.26 4.767 121.08 4.562 115.87 4.562 115.87 4.455 113.16 3.12 79.25

April 26, 2020 Halliburton Company (Dallas, Texas) 4-115

Slickline Operations Manual SL 4.50: X and R® Nipple Selection Chart

® ® ®
Otis R And RN Landing Nipples And Lock Mandrels Specifications
For Heavy Tubing Weights
Tubing
R® Profile RN® Profile Lock Mandrel ID
Size Weight ID Drift Packing Bore Bore ID
in. mm lb/ft kg/m in. mm in. mm in. mm in. mm in. mm in. mm
1.660 42.16 3.02 4.49 1.278 32.46 1.184 30.07 1.125 28.58 1.125 28.58 1.012 25.70 Avail. on Request
1.900 48.26 3.64 5.42 1.500 38.10 1.406 35.71 1.375 34.93 1.375 34.93 1.250 31.75 0.62 15.75
5.3 7.89 1.939 49.25 1.845 46.86 1.781 45.24 1.781 45.24 1.640 41.66 0.88 22.35
5.95 8.85 1.867 47.42 1.773 45.03
2 3/8 60.33 1.710 43.43 1.710 43.43 1.560 39.62 0.75 19.05
6.2 9.23 1.853 47.07 1.759 44.68
7.7 11.46 1.703 43.26 1.609 40.87 1.500 38.10 1.500 38.10 1.345 34.16 0.62 15.75
7.9 11.76 2.323 59.00 2.229 56.62 2.188 55.58 2.188 55.58 2.010 51.05 1.12 28.45
8.7 12.95 2.259 57.38 2.165 54.99
2.125 53.98 2.125 53.98 1.937 49.20 0.88 22.35
8.9 13.24 2.243 56.97 2.149 54.58
2 7/8 73.03 9.5 14.14 2.195 55.75 2.101 53.37
2.000 50.80 2.000 50.80 1.881 47.78 0.88 22.35
10.4 15.48 2.151 54.64 2.057 52.25
11 16.37 2.065 52.45 1.971 50.06
1.875 47.03 1.875 47.03 1.716 43.59 0.88 22.35
11.65 17.34 1.995 50.67 1.901 48.29
12.95 19.27 2.750 69.85 2.625 66.68 2.562 65.07 2.562 65.07 2.329 59.16 1.38 35.05
15.8 23.51 2.548 64.72 2.423 61.54
3 1/2 88.90 2.313 58.75 2.313 58.75 2.131 54.13 1.12 28.45
16.7 24.85 2.480 62.99 2.355 59.82
17.05 25.37 2.440 61.98 2.315 58.80 2.188 55.58 2.188 55.58 2.010 51.05 1.12 28.45
11.6 17.26 3.428 87.08 3.303 83.90 3.250 82.55 3.250 82.55 3.088 78.44 1.94 49.28
4 101.60
13.4 19.94 3.340 84.84 3.215 81.66 3.125 79.38 3.125 79.38 2.907 73.84 1.94 49.28
12.75 18.97 3.958 100.53 3.833 97.36 3.813 96.85 3.813 96.85 3.725 94.62 2.12 53.85
13.5 20.09 3.920 99.57 3.795 96.39
3.688 93.68 3.688 93.68 3.456 87.78 2.38 60.45
4 1/2 114.30 15.5 23.07 3.826 97.18 3.701 94.01
16.9 25.50 3.754 95.35 3.629 92.18
3.437 87.30 3.437 87.30 3.260 82.80 1.94 49.28
19.2 28.57 3.640 92.46 3.515 89.28
15 22.32 4.408 111.96 4.283 108.79 4.125 104.78 4.125 104.78 3.912 99.39 2.75 69.85
5 127.00
18 26.79 4.276 108.61 4.151 105.44 4.000 101.60 4.000 101.60 3.748 95.20 2.38 60.45
17 25.30 4.892 124.26 4.767 121.08
4.562 115.87 4.562 115.87 4.445 113.16 2.85 72.39
5 1/2 139.70 20 29.76 4.778 121.36 4.653 118.19
23 34.23 4.670 118.62 4.545 115.44 4.313 109.55 4.313 109.55 3.987 101.27 2.62 66.55
15 22.32 5.524 140.31 5.399 137.13
6 152.40 5.250 133.35 5.250 133.35 5.018 127.51 3.50 88.90
18 26.79 5.424 137.77 5.299 134.59
6 5/8 168.28 24 35.72 5.921 150.39 5.795 147.22
5.625 142.88 5.625 142.88 5.500 139.70 3.50 88.90
28 41.67 5.791 147.09 5.666 143.92
17 25.30 6.538 166.07 6.431 163.35
20 29.76 6.456 163.98 6.331 160.81
23 34.23 6.366 161.70 6.241 158.52
5.963 151.46 5.963 151.46 5.770 146.05 3.75 95.25
7 177.80 26 38.69 6.276 159.41 6.151 156.24
29 43.16 6.184 157.07 6.059 153.90
32 47.62 6.094 154.79 5.969 151.61
35 52.09 6.004 152.50 5.879 149.33 5.875 149.23 5.875 149.23 5.750 146.05 3.75 95.25
7.050 179.07 7.050 179.07 6.925 175.90 5.25 133.35
8 5/8 219.08 36 53.57 7.825 198.76 7.700 195.58 7.250 184.15 7.250 184.15 7.125 180.98 5.25 133.35
7.450 189.23 7.450 189.23 7.325 186.06 5.25 133.35

April 26, 2020 Halliburton Company (Dallas, Texas) 4-116

Slickline Operations Manual SL 4.51: API Tubing Tables

SL 4.51: API Tubing Tables

Nominal Weight Threaded Coupling Joint Yield Capacity
Tubing Size T&C Wall Coupling Outside Dia. Col- Internal Strength Table
Non- T&C Thick- Inside Drift Non- Upset Upset lapse Yield T&C Barrels Linear
Nom. OD Upset Upset ness Dia. Dia. Upset Reg. Spec. Resis- Pres- Non- T&C per ft
in. in. lb/ft lb/ft Grade in. in. in. in. in. in. tance sure Upset Upset Linear per
psi psi lb lb ft Barrel
H-40 7,200 7,530 6,360 13,300
J-55 9,370 10,360 8,740 18,290
3/4 1.05 1.14 1.20 0.113 0.824 0.730 1.313 1.660 0.0007 1516.13
C-75 12,250 14,120 11,920 24,940
N-80 12,710 15,070 12,710 26,610
H-40 6,820 7,080 10,960 19,760
J-55 8,860 9,730 15,060 27,160
1 1.315 1.700 1.800 0.113 1.049 0.955 1.660 1.900 0.0011 935.49
C-75 11,590 13,270 20,540 37,040
N-80 12,270 14,160 21,910 39,510
H-40 0.125 1.410 5,220 5,270 0.0019 517.79
H-40 0.140 1.380 5,790 5,900 15,530 26,740 0.0018 540.55
J-55 0.125 1.410 6,790 7,250 0.0019 517.79
1 1/4 1.660 2.300 2.400 1.286 2.054 2.200
J-55 0.140 1.380 7,530 8,120 21,360 36,770 0.0018 540.55
C-75 0.140 1.380 9,840 11,070 29,120 50,140 0.0018 540.55
N-80 0.140 1.380 10,420 11,810 31,060 53,480 0.0018 540.55
H-40 0.125 1.650 4,450 0.0026 378.11
H-40 0.145 1.610 5,290 19,090 31,980 0.0025 397.14
J-55 0.125 1.650 5,790 0.0026 378.11
1 1/2 1.900 2.750 2.900 1.516 2.200 2.500
J-55 0.145 1.610 6,870 26,250 43,970 0.0025 397.14
C-75 0.145 1.610 8,990 10,020 35,800 59,960 0.0025 397.14
N-80 0.145 1.610 9,520 10,680 38,180 63,960 0.0025 397.14
H-40 5,240 5,290
J-55 6,820 7,280
2 1/16 2.063 0.156 1.751 0.0030 335.75
C-75 8,910 9,920
N-80 9,440 10,590
4.00 H-40 0.167 2.041 1.947 4,880 4,920 30,130 0.0040 247.12
4.60 4.70 H-40 0.190 1.995 1.901 5,520 5,600 35,960 52,170 0.0039 258.65
4.00 J-55 0.167 2.041 1.947 6,340 6,770 41,430 0.0040 247.12
4.60 4.70 J-55 0.190 1.995 1.901 7,180 7,700 49,450 71,730 0.0039 258.65
4.00 C-75 0.167 2.041 1.947 8,150 9,230 56,500 0.0040 247.12
4.60 4.70 C-75 0.190 1.995 1.901 9,380 10,500 67,430 97,820 0.0039 258.65
2 3/8 2.375 2.875 3.063 2.910
5.80 5.95 C-75 0.254 1.867 1.773 12,180 14,040 96,560 126,940 0.0034 295.33
4.00 N-80 0.167 2.041 1.947 8,660 9,840 60,260 0.0040 247.12
4.60 4.70 N-80 0.190 1.995 1.901 9,940 11,200 71,930 104,340 0.0039 258.65
5.80 5.95 N-80 0.254 1.867 1.773 12,890 14,970 102,990 135,400 0.0034 295.33
4.60 4.70 P-105 0.190 1.995 1.901 13,250 14,700 94,410 136,940 0.0039 258.65
5.80 5.95 P-105 0.254 1.867 1.773 17,190 19,650 135,180 177,710 0.0034 295.33
6.40 6.50 H-40 0.217 2.441 2.347 5,230 5,280 52,780 72,480 0.0058 172.76
6.40 6.50 J-55 0.217 2.441 2.347 6,800 7,260 72,580 99,660 0.0058 172.76
6.40 6.50 C-75 0.217 2.441 2.347 8,900 9,910 98,970 135,900 0.0058 172.76
8.60 8.70 C-75 0.308 2.259 2.165 12,200 14,060 149,360 185,290 0.0050 201.72
2 7/8 2.875 3.500 3.668 3.460
6.40 6.50 N-80 0.217 2.441 2.347 9,420 10,570 105,570 144,960 0.0058 172.76
8.60 8.70 N-80 0.308 2.259 2.165 12,920 15,000 159,310 198,710 0.0050 201.72
6.40 6.50 P-105 0.217 2.441 2.347 12,560 13,870 138,560 190,260 0.0058 172.76
8.60 8.70 P-105 0.308 2.259 2.165 17,220 19,690 209,100 260,810 0.0050 201.72
7.70 H-40 0.216 3.068 2.943 4,070 4,320 65,070 0.0091 109.37
9.20 9.30 H-40 0.254 2.992 2.867 5,050 5,080 79,540 103,610 0.0087 114.99
10.20 H-40 0.289 2.922 2.797 5,680 5,780 92,550 0.0083 120.57
7.70 J-55 0.216 3.068 2.943 5,290 5,940 89,470 0.0091 109.37
9.20 9.30 J-55 0.254 2.992 2.867 6,560 6,980 109,370 142,460 0.0087 114.99
10.20 J-55 0.289 2.922 2.797 7,390 7,950 127,250 0.0083 120.57
7.70 C-75 0.216 3.068 2.943 6,690 8,100 122,010 0.0091 109.37
9.20 9.30 C-75 0.254 2.992 2.867 8,530 9,520 149,140 194,260 0.0087 114.99
3 1/2 3.500 4.250 4.500 4.180
10.20 C-75 0.289 2.922 2.797 9,660 10,840 173,530 0.0083 120.57
12.70 12.95 C-75 0.375 2.750 2.625 12,200 14,060 230,990 276,120 0.0073 136.12
7.70 N-80 0.216 3.068 2.943 7,080 8,640 130,140 0.0091 109.37
9.20 9.30 N-80 0.254 2.992 2.867 9,080 10,160 159,090 207,220 0.0087 114.99
10.20 N-80 0.289 2.922 2.797 10,230 11,560 185,100 0.0083 120.57
12.70 12.95 N-80 0.375 2.750 2.625 12,920 15,000 246,390 294,530 0.0073 136.12
9.20 9.30 P-105 0.254 2.992 2.867 12,110 13,330 208,800 271,970 0.0087 114.99
12.70 12.95 P-105 0.375 2.750 2.625 17,200 19,690 323,390 386,570 0.0073 136.12
H-40 0.226 3.548 3.423 3,580 3,960 72,000 0.0122 81.78
H-40 0.262 3.476 3.351 4,420 4,580 123,070 0.0117 85.20
J-55 0.226 3.548 3.423 4,650 5,440 99,010 0.0122 81.78
J-55 0.262 3.476 3.351 5,750 6,300 169,220 0.0117 85.20
4 4.000 9.500 11.000 4.750 5.000
C-75 0.226 3.548 3.423 5,800 7,420 135,010 0.0122 81.78
C-75 0.262 3.476 3.351 7,330 8,600 230,750 0.0117 85.20
N-80 0.226 3.548 3.423 6,120 7,910 144,010 0.0122 81.78
N-80 0.262 3.476 3.351 7,780 9,170 246,140 0.0117 85.20
H-40 3,930 4,220 104,360 144,020
J-55 5,100 5,800 143,500 198,030
4 1/2 4.500 12.600 12.750 0.271 3.958 3.833 5.200 5.563 0.0152 65.71
C-75 6,430 7,900 195,680 270,240
N-80 6,810 8,430 208,730 288,040

April 26, 2020 Halliburton Company (Dallas, Texas) 4-117

Slickline Operations Manual SL 4.51: API Tubing Tables

Common Tubing/Nipple sizes

STD
OD wt./ft ID Drift Seal Bore No-Go Nipple
V-Packing

2 1/8 4.6-4.7 1.995 1.901 1.875 1.791 X STD 91V310

2 1/8 6.4-6.5 2.441 2.347 2.313 2.205 X STD 91V318

3 1/2 10.3 2.922 2.797 2.750 2.635 X STD 91V3376

3 1/2 10.3 2.922 2.867 2.813 2.760 X OPT 91V1330

4 109.11 3.476 3.351 3.313 3.135 X STD 91V3317

4 13.4 3.40 3.215 3.125 2.907 R SDT

4 1/2 12.75 3.958 3.833 3.813 3.725 X and R 91V320

4 1/2 13.5 3.920 3.795 3.688 3.456 R STD 91V3334

5 13 4.494 4
4.413 X STD 91V3422

5 13 4.494 4.369 .
4.125 3.913 R STD 91V375

5 13 4.408 4.283 3
4.125 3.912 R STD 91V375
6
5 1/2 17 4.892 4.767 4.562 4.455 X and R 91V3309
9
5 1/2 23 6.670 4.545 4.313 3.987 R STD 91V3422

7 17-32 5.926 5.750 R STD 91V322

April 26, 2020 Halliburton Company (Dallas, Texas) 4-118

Slickline Operations Manual SL 4.52: English to Metric Conversion Chart

SL 4.52: English to Metric Conversion Chart

Acre = 43,560 square feet Foot per second = 0.68182 mile per hour Mile per hour = 1.4667 feet per second
Acre = 4.047 square meters Foot pound = 0.001286 British Thermal Unit Ounce (Avoirdupois) = 28.3495 grams
Acre foot = 7,758 barrels Foot pound per second = 0.001818 horsepower Part per million = 0.05835 grain per gallon
Atmosphere = 33.94 feet of water Gallon (U.S.) = 0.02381 barrel Part per million = 8.345 pounds per million gal
Atmosphere = 29.92 inches of mercury Gallon (U.S.) = 0.1337 cubic feet Pascal (Pa) = 0.000145 pound per square inch
Atmosphere = 760 millimeters of mercury Gallon (U.S.) = 231.000 cubic inches Pound = 7000 grains
Atmosphere = 14.70 pounds per square inch Gallon (U.S.) = 3.785 liters Pound = 0.4536 kilogram
Bar = 14.504 pounds per square inch Gallon (U.S.) = 0.83267 gallon (Imperial) Pound per square inch = 2.309 feet of water @ 60oF
Barrel = 5.6146 cubic feet Gallon (U.S.) = 0.003785 cubic meters Pound per square inch = 2.0353 inches of mercury
Barrel = 42 gallons Gallon (Imperial) = 1.20095 gallons (U.S.) Pound per square inch = 51.697 millimeters of mercury
Barrel of water @60o F = 0.1588 metric ton Gallon (imperial) = 277.274 cubic inches Pound per square inch = 0.0703 kilograms per sq. cm
Barrel (36o A.P.I) = 0.1342 metric ton Gallon per minute = 1.429 barrels per hour Pound per square inch = 0.0689 bar
Barrel per hour = 0.0936 cubic feet per minute Gallon per minute = 0.1337 cubic feet per minute Pound per square inch = 0.006895 Mega Pascal (MPa)
Barrel per hour = 0.700 gallon per minute Gallon per minute = 34.286 barrels per day Pound per square inch = 6.895 Kilo Pascal (KPa)
Barrel per hour = 2.695 cubic inches per second Gram = 0.03527 ounce Pound per square inch = 6895 Pascal (Pa)
Barrel per day = 0.02917 gallon per minute Horsepower = 42.44 B.T.U.'s per minute Pound per million gals. = 0.00700 grain per gallon
British Thermal Unit = 0.2520 kilogram calorie Horsepower = 33 foot-pounds per minute Pound per million gals. = 0.11982 parts per million
British Thermal Unit = 0.2928 watt hour Horsepower = 550 foot-pounds per second Quart (Liquid) = 0.946 liter
B.T.U. per minute = 0.02356 horse power Horsepower = 1.014 horsepower (metric) Sack cement (set) = 1.1 cubic feet
Centimeter = 0.3937 inch Horsepower = 0.7457 kilowatt Square centimeter = 0.1550 square inch
Centimeter of mercury = 0.1934 pound per square inch Horsepower hour = 2.547 British Thermal Units Square foot = 0.0929 square meter
Cubic centimeter = 0.06102 cubic inch Inch = 2.540 centimeters Square inch = 6.452 square centimeters
Cubic foot = 0.1781 barrel Inch of mercury = 1.134 feet of water Square kilometer = 0.3861 square mile
Cubic foot = 7.4805 gallons (U.S.) Inch of mercury = 0.4912 pound per square inch Square meter = 10.76 square feet
Cubic foot = 0.02832 cubic meter Inch of water @60oF = 0.0361 pound per square inch Square mile = 2.590 square kilometers
o
Cubic foot = 0.9091 sacks cement (set) Kilogram = 2.2046 pounds Temp. Centigrade = 5/9 (Temp. F) -32
Cubic foot per minute = 10.686 barrels per hour Kilogram Calorie = 3.968 British Thermal Units Temp. Fahrenheit = 9/5 (Temp. oC)+32
Cubic foot per minute = 28.80 cubic inches per second Kiologram per square cm = 14.223 pounds per square inch Temp. Absolute (Kelvin) = Temp. oC +273
Cubic foot per minute = 7.481 gallons per minute Kilometer = 3.281 feet Temp. Absolute (Rankine) = Temp. oF +460
Cubic inch = 16.387 cubic centimeters Kilometer = 0.6214 mile Ton (Long) = 2.24 pounds
Cubic meter = 6.2897 barrels Kilo Pascal (KPa) = 0.145 pounds per square inch Ton (Metric) = 2.205 pounds
Cubic meter = 35.314 cubic feet Kilowatt = 1.341 horsepower Ton (Short or Net) = 2,000 pounds
Cubic meter = 1.308 cubic yards Liter = 0.2642 gallon Ton (Metric) = 1.102 tons (short or net)
Cubic meter = 264.20 gallon U.S. Liter = 1.0567 quarts Ton (Metric) = 1,000 kilograms
o
Cubic yard = 4.8089 barrels Mega Pascal (MPa) = 145.03 pound per square inch Ton (Metric) = 6.297 barrels of water @ 60 F
Cubic yard = 46,656 cubic inches Meter = 3.281 feet Ton (Short or Net) = 7.454 barrels (36o A.P.I.)
Cubic yard = 0.7646 cubic meter Meter = 39.37 inches Watt-hour = 0.907 ton (metric)
Foot = 30.48 centimeters Mile = 5280.000 feet Watt-hour = 3.415 British Thermal Units
Foot = 0.3048 meter Mile = 1.609 kilometers Yard = 0.9144 meter
o
Foot of water @ 60 F = 0.4331 pound per square inch

Conversion Factors

Multiply By To Obtain

Centimeter 0.3937 Inches

Foot 0.3048 Meters

Gallon 0.0238 Barrels

Gallon 3.785 Liters

Inch 2.54 Centimeters

Mere 3.281 Feet

Kilogram 2.2046 Pounds

Kilometer 0.6214 Miles

PSI 6.895 Kilopascal

Kilopascal 0.1451 PSI

Gallon US 0.8327 Gallon (Imperial)

PSI 0.0703 Kgs/sq. cm.

Kgs/sq. cm. 14.22 PSI

April 26, 2020 Halliburton Company (Dallas, Texas) 4-119

Slickline Operations Manual SL 4.52: English to Metric Conversion Chart

Downhole Pressures
To find the downhole pressure, multiply the surface pressure by the Correction Factor
corresponding to the well depth and the Gravity of the gas.

Gas Table

Well Depth Correction Factors

ft m 0.6 Gravity 0.7 Gravity 0.8 Gravity

4,500 1371.60 1.099 1.116 1.132

5,000 1524.00 1.110 1.130 1.149

5,500 1676.40 1.120 1.141 1.163

6,000 1828.80 1.132 1.155 1.181

6,500 1981.20 1.143 1.175 1.195

7,000 2133.60 1.155 1.184 1.211

7,500 2286.00 1.171 1.195 1.227

8,000 2438.40 1.181 1.210 1.241

8,500 2590.80 1.190 1.230 1.260

9,000 2743.20 1.202 1.240 1.273

9,500 2895.60 1.215 1.250 2.285

10,000 3048.00 1.225 1.265 1.305

To find the pressure at the bottom of a column of fluid, multiply the depth of fluid by the
Pressure Gradient and add the result to the pressure at the surface of the fluid.

API Conversion Table

Density Pressure Gradient

Specific*
API Gravity
Gravity
lb/gal kg/m3 psi/ft bar/m kPa/m

15% HCl 1.0750 8.962 1075.00 0.4654 0.1055 10.547

10 (water) 1.0000 8.337 1000.00 0.4330 0.0981 9.807

12 0.9861 8.221 986.10 0.4270 0.0967 9.670

15 0.9659 8.053 965.90 0.4182 0.0947 9.472

18 0.9465 7.891 946.50 0.4098 0.0928 9.282

20 0.9340 7.787 934.00 0.4044 0.0916 9.159

22 0.9218 7.685 921.80 0.3991 0.0944 9.044

24 0.9100 7.587 910.00 0.3940 0.0892 8.924

26 0.8984 7.490 898.40 0.3890 0.0881 8.810

28 0.8871 7.396 887.10 0.3841 0.0870 8.700

Halliburton Company (Dallas, Texas) 4-120

Slickline Operations Manual SL 4.52: English to Metric Conversion Chart

API Conversion Table

Density Pressure Gradient

Specific*
API Gravity
Gravity
lb/gal kg/m3 psi/ft bar/m kPa/m

30 0.8762 7.305 876.20 0.3794 0.0859 8.592

31 0.8708 7.260 870.80 0.3771 0.0854 8.539

32 0.8654 7.215 865.40 0.3747 0.0849 8.487

33 0.8602 7.171 860.20 0.3725 0.0844 8.436

34 0.8550 7.128 855.00 0.3702 0.0836 8.385

35 0.8498 7.085 849.80 0.3680 0.0833 8.334

36 0.8448 7.043 844.80 0.3658 0.0828 8.284

37 0.8398 7.001 839.80 0.3638 0.0824 8.235

38 0.8348 6.960 834.80 0.3615 0.0819 8.187

39 0.8299 6.919 829.90 0.3593 0.0814 8.139

40 0.8251 6.879 825.10 0.3573 0.0809 8.091

41 0.8203 6.839 820.30 0.3552 0.0804 8.044

42 (diesel) 0.8156 6.800 815.60 0.3532 0.0800 7.998

43 0.8109 6.760 810.90 0.3511 0.0795 7.952

44 0.8063 6.722 806.30 0.3491 0.0791 7.907

46 0.7972 6.646 797.20 0.3452 0.0782 7.818

48 0.7883 6.572 788.30 0.3413 0.0773 7.731

50 0.7796 6.500 779.60 0.3376 0.0765 7.645

55 0.7587 6.325 758.70 0.3285 0.0744 7.440

60 0.7389 6.160 738.90 0.3200 0.0725 7.246

*For heavier fluid weights, pressure gradient in psi/ft = 0.05195 x density (lb/gal) or
pressure gradient in kPa/m = 22.626 x density (kg/m3), 1 lb/gal = 119.841 kg/m3

Halliburton Company (Dallas, Texas) 4-121

Slickline Operations Manual SL 4.53: Handy Formulas and Data

SL 4.53: Handy Formulas and Data

Amount Wireline Will Fall Back When Broken

The following table originated with measurements during fishing exercises in a 3000-ft.
well. While it cannot be totally accurate under all conditions, field experience has proven
the table to be a reasonable guide in calculating the depth of the top of the broken wire.

Table 4.53 - 1: Amount Wireline Will Fallback (per 1,000 ft.)

Tubing Size Wireline OD Feet of Fall Back

(in.) (in.) (per1,000-ft. wire length)

2-3/8 .082 8

2-3/8 .092 10

2-7/8 .082 10

2-7/8 .092 12

3-1/2 .092 16

3-1/2 .108 15

3-1/2 3/16 20

4-1/2 .108 27

4-1/2 3/16 35

5-1/2 .108 40

5-1/2 3/16 50

7 .108 90

7 3/16 100

Other Formulas and Data

1. Circles
Circumference of a circle = 3.14 x Diameter (x D)
Diameter of a circle = Circumference 3.14
Radius of a circle = Diameter 2
Area of a circle = 3.14 x Radius x Radius (x R)
2. Force From Pressure on a Surface
Force (pounds) = Pressure (psi) x Area (sq. in.)

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Slickline Operations Manual SL 4.53: Handy Formulas and Data

3. Volume of Rectangular Tank

Volume = Length x Width x Depth (Height)
Use the same units (inches, etc.) for each dimension.
4. Volume of a Sphere
Volume = 3.14 x Radius x Radius x Radius (x R)
5. Volume of Circular Tank
Volume = Area of Round Base x Height
Use the same units (inches, etc.) for each dimension.
6. Fresh Water
Weight 8.33 Pounds per US gallon
Density 62.4 Pounds per cubic foot
1000 kilogram per cubic meter
1 kilogram per liter
Gradient 0.433 psi per foot
Specific Gravity 1
AP Gravity 10

7. Fill-up Volume of Any Size Pipe - Approximate

Inside pipe diameter squared = barrels per 1,000 ft of length
Example: Schedule-40 4-in pipe inside diameter = 3.826 in.
Barrels per 1,000 ft = 3.826 x 3.286 = approximately 10.8 barrels per 1,000 ft
8. Approximate Hydrostatic Head
Approximate Head = 0.052 x weight of fluid per gallon x depth in feet
(Annulus Calculation)
9. True Hydrostatic Head = Gradient x True Vertical Depth
10. Convert API Gravity to Specific Gravity
Specific Gravity = 141.5 / (131.5 + API)
11. Convert Specific Gravity to API Gravity
API Gravity = (141.5 / Specific Gravity) - 131.5
12. Convert Specific Gravity to Gradient
Gradient = Specific Gravity 0.433

Halliburton Company (Dallas, Texas) 4-123

Slickline Operations Manual SL 4.53: Handy Formulas and Data

13. Bottom Hole Pressure of Gas Column

Bottom Hole Pressure = Surface Pressure x Gas Correction Factor
14. Fahrenheit = (Centigrade x 1.8) + 32F
15. Centigrade = (Fahrenheit - 32F) x .5556
16. Drawdown = static BHP - flowing BHP
17. Productivity Index (PI) = BBLS per day / (static BHP - flowing BHP)
18. 1 Pascal = 1 Newton / Square meter
19. Using S.I. Units
Approximate Hydrostatic Head in kPa = kg/L x Depth in Meters x 9.81
20. Weight required to make a tool string fall - neglecting friction.
Weight Required = Area of Wire x Well Pressure
21. Approximate weight per foot of round bar stock or stem.
Approximate Weight = (Diameter squared x 8) / 3
22. Maximum working strength of wirelines.
Slow Pull - 75% of Breaking Strength
Fast Jarring - 50% of Breaking Strength
23. Wire areas and approximate wire strengths.

Min. Breaking
Area
Wire Size (in.) Strength,
(square in)
API 9A (lb)

.066 811 0.0034

.072 961 0.0041

.082 1239 0.0053

.092 1547 0.0066

.105 1966 0.0086

.108 2109 0.0092

.125 2794 0.0123

3/16 Galvanized 9/6/1 4960 0.0275

Halliburton Company (Dallas, Texas) 4-124

 Revision History
Revision Description Who Date
A Original Release Global Advisor 15-April-2013
Updated Section Global Advisor 29-May-2015
B 4.49 Shear Pin
Guide
Revised the requirement for
Stuffing Box Packing
selection, inspection and
C Global Advisor 26-April-2018
replacement frequency in
section - SL 4.21: Stuffing Box
Packing Stack
D Create a new individual D Technical Services 30-Apr-2018
number for the document

E Added details of a Slow Technical Services 29-Apr-2020

Speed Upgrade Kit for the
Single Piece Stainless Steel
Halliburton Unit 101474238.
HARD COPY UNCONTROLLED