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Equipment and Products Specification Catalog

Completion Products
Subsurface Flow Controls
Table of Contents
Subsurface Flow Control Preface Landing Nipples and Lock

Mandrels Lock System Accessory Equipment Bottomhole Pressure Equipment Flow Control Accessory Equipment Circulation/Production Sleeves Through-Flowline Techniques Subsurface Slickline Tools Optional Toolstring Connection Auxiliary Tools for Use with Slickline Toolstring Running Tools Pulling Tools Test Tools Positioning Tools Tubing Perforators and Bailers Slickline Service Equipment

6/98
CP3TOC

Equipment and Products Specification Catalog

Completion Products
Subsurface Flow Controls
Subsurface Flow Control Preface
Table of Contents
Subsurface Flow Control Systems Landing Nipple/Lock Mandrel Selection Guide

6/98
CP3A

Subsurface Flow Control Systems
Halliburton subsurface flow control equipment is designed to simplify completion programs and help maintain production control for the life of the well. Before a well is completed, well maintenance requirements should be anticipated as accurately as possible, and proper flow control equipment should be installed for efficient well maintenance operations. Halliburton is dedicated to providing top quality equipment. Halliburton maintains strict standards to help ensure excellence and dependability in our subsurface flow control equipment: ? all subsurface flow control products manufactured in accordance with ISO 9000-series quality standards ? more than 50 years of success in design and material selection ? strict tolerances to meet our latest design criteria ? use of the API monogram ? total traceability of each assembly by serial number and/or component job number ? functional testing of every lock mandrel by installing it into a nipple profile ? API class of service for API equipment; operating manual and shipping report furnished with each lock mandrel indicating serial number, design specification, repairs, repair limitations, assembly and disassembly procedures with precautions included ? full documentation available for landing nipples and lock mandrels, including dimensional and visual inspection results and job history file Subsurface flow control equipment includes both tubular flow control equipment and production tool equipment. Tubular flow control equipment is made up as part of the production tubing string and includes landing nipples, circulation/ production sleeves, blast joints, and flow couplings. Production tool equipment includes lock mandrels, plugs, equalizing devices, flow regulators, tubing stops, packoffs, pressure and temperature gauge hangers, plus other associated equipment. This equipment is normally installed with conventional slickline methods. Circulating equipment, gas lift mandrels, selective landing nipples, and safety valve nipples can be serviced by slickline methods as required.

Flow Coupling Safety Valve Landing Nipple Wireline-Retrievable Safety Valve Flow Coupling

Flow Coupling X? or R? Landing Nipple

Hydraulic-Set Packer

Circulation/Production Sleeve Blast Joint

Permanent Packer

X? or R? Landing Nipple

CN00755

XN? or RN? No-Go Landing Nipple

Typical Equipment Installation
6/98 Page 1 of 2

Landing Nipple/Lock Mandrel Selection Guide
Landing Nipple Features and Applications
Profile Available in Noted Tools Series of Nipples Can Be Used in Single Tubing String Safety Valve Landing Nipple Wellhead Plug Applications SAFETYSET? Compatible Selective By Running Tool Tubing-Retrievable Safety Valve Part Number Prefix for Applicable Tools

Landing Nipple

X? XN
?

l l l l l l l l l

l

l l

l l l l l l l l

l

l

10XO 710XO 10XN 710XN 10RO 710RO 10RN 710RN 10RQ 710SS 10FBN 710FBN 10RPT 710RPT 710SRP

l l l l l l l l

41XO

40GR

20XO

Equalizing Sub

Bottom No-Go

Lock Mandrel

Running Tool

Nipple Profile

Sliding Side-Door?

24 PXX

m
l l

41XO

40GR

20XO

24 PXX

R

?

l

l l l

l l

41RO

40GR

20RO

24 PRR

RN?

m
l l l

41RO

40GR

20RO

24 PRR

RQ

l l l l l l l

m
l l

41RXN 41SS 41FBN

40GR

20RO

FBN?
?

l l l

l l l

40GR 20FBN

24 FBN

RPT

l l l

41RXN

40GR 20RPT 24 RPT

l m

SRP

41SRP

40GR

m

= Standard Feature = Non-Standard Capability

Footnotes: 1. Part number prefix 710 or 711 indicates API monogrammed assembly; items with a prefix 10 or 11 are not API monogrammed.

6/98

Page 2 of 2

Equalizing Prong/Plug Assembly

Heavy Weight Tubing Applications

API Monogrammed1

API Monogrammed1

Tubing Seal Divider

Pulling Tool

Top No-Go

m

m

Equipment and Products Specification Catalog

Completion Products
Subsurface Flow Controls
Landing Nipples and Lock Mandrels
Table of Contents Selective by Running Tool Selective by No-Go

6/98
CP3BTOC

Equipment and Products Specification Catalog

Completion Products
Subsurface Flow Controls
Landing Nipples and Lock Mandrels
Selective by Running Tool
Table of Contents
Introduction to Selective by Running Tool X and R? Landing Nipples and Lock Mandrels XN? and RN? No-Go Landing Nipples and Lock Mandrels FBN?, Full Bore Landing Nipple/Lock Mandrel System
?

6/98
CP3B1

Introduction to Selective by Running Tool
The Halliburton landing nipples and lock mandrels that are selective by running tool consist of X?, R?, and FBN series landing nipples and lock mandrels. The XN? and RN? No-Go landing nipples and No-Go lock mandrels are no-go equipment compatible with the X and R line of equipment.

6/98

Page 1 of 1

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 landing nipple is used in standard weight tubing; the R landing 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 versatility results in an unlimited number of positions for setting 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. The slickline operator using the selective running tool can set the flow control in any one of the landing nipples at the desired 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.
Fishing Neck Expander Mandrel DoubleActing Spring Locking Keys
CN03539

CN03542

Packing

X? Landing Nipple and Lock Mandrel

Fishing Neck Expander Mandrel DoubleActing Spring

CN03540

Locking Keys

R? Landing Nipple and Lock Mandrel

XN? and RN? No-Go Landing Nipples and Lock Mandrels
This equipment is designed for use in single nipple installations or as the bottom nipple in a series of X? or R? landing nipples. These landing nipples have the same packing bore ID for a particular tubing size and weight. X and XN landing nipples are designed for use with standard weight tubing; R and RN landing nipples are designed for use with heavyweight tubing. (The N designates no-go nipples.)
Fishing Neck Expander Mandrel DoubleActing Spring
Fishing Neck

CN03541

Packing

Expander Mandrel DoubleActing Spring

CN03542

Locking Keys Packing No-Go Equalizing Sub

CN03544

Locking Keys Packing No-Go Equalizing Sub

CN03543

XN? No-Go Landing Nipple and Lock Mandrel

RN? No-Go Landing Nipple and Lock Mandrel

6/98

CN03545

Page 1 of 3

X?, XN?, R?, and RN? Landing Nipples and Lock Mandrels
Applications
? plugging under pressure ? almost unlimited locations for setting and locking subsurface flow controls ? 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.

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

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 ? extra large ID for higher flow volumes

X and XN Landing Nipples and Lock Mandrels Specifications
Tubing Size mm in. 1.050 26.67 1.315 33.40 1.660 Weight lb/ft kg/m 1.20 1.79 1.80 2.68 2.30 3.42 2.40 3.57 2.40 2.76 2.90 3.25 4.60 4.70 6.40 6.50 9.30 10.20 11.00 12.75 13.00 17.00 ID in. 0.824 1.049 1.380 1.660 1.610 1.751 1.995 2.441 For Standard Tubing Weights ? ? X Profile XN Profile Packing Bore Packing Bore No-Go ID mm mm mm in. in. in. Available on Request 1.250 31.75 1.250 Lock Mandrel ID in.

?

?

mm 20.93 26.64 35.05 42.16 40.89 44.48 50.67 62.00

Drift mm in. 0.730 18.54 0.955 24.26 1.286

mm

42.16

32.66

31.75

1.135

28.83

0.62

15.75

1.900 2.063 2 3/8 2 7/8 3 1/2 4 4 1/2 5 5 1/2

48.26 52.40 60.33 73.03 88.90 101.60 114.30 127.00 139.70

3.57 4.11 4.32 4.84 6.85 6.99 9.52 9.67 13.84 15.18 16.37 18.97 19.35 25.30

1.516 1.657 1.901 2.347

38.51 42.09 48.29 59.61

1.500 1.625 1.875 2.313

38.10 41.28 47.63 58.75

1.500 1.625 1.875 2.313

38.10 41.28 47.63 58.75

1.448 1.536 1.791 2.205

36.78 39.01 45.49 56.01

0.75

19.05

1.00 1.38 1.75 2.12 2.62 3.12

25.40 35.05 44.45 53.85 66.55 79.25

2.992 76.00 2.922 74.22 3.476 88.29 3.958 100.53 4.494 114.14 4.892 124.26

2.867 72.82 2.797 71.04 3.351 85.10 3.833 97.36 4.369 110.97 4.767 121.08

2.813 71.45 2.750 69.85 3.313 84.15 3.813 96.85 4.313 109.55 4.562 115.87

2.813 71.45 2.750 69.85 3.313 84.15 3.813 96.85 4.313 109.55 4.562 115.87

2.666 67.72 2.635 66.93 3.135 79.63 3.725 94.62 3.987 101.27 4.455 113.16

6/98

Page 2 of 3

Landing Nipples and Lock Mandrels Selective by Running Tool R? and RN? Landing Nipples and Lock Mandrels Specifications
Tubing Size in. 1.660 1.900 Weight lb/f t 3.02 3.64 5.30 2 3/8 5.95 6.20 7.90 8.70 8.90 9.50 10.40 11.00 11.65 ID in. Drif t For Heavy Tubing Weights R? Profile RN? Prof ile Packing Bore in. Packing Bore in. No-Go ID in. Lock Mandrel ID

mm 42.16 48.26

kg/m 4.49 5.42 7.89 8.85 9.23 11.76 12.95 13.24 14.14 15.48 16.37 17.34

mm

in. 1.184 1.406 1.845 1.773 1.759 1.609 2.229 2.165 2.149 2.101 2.057 1.971 1.901

mm 30.07 35.71 46.86 45.03 44.68 40.87 56.62 54.99 54.58 53.37 52.25 50.06 48.29

mm

mm

mm

in. 0.62 0.88 0.75 0.62 1.12 0.88 0.88 0.88 1.38 1.12 1.12 1.94 1.94 2.12 2.38 1.94 2.75 2.38 2.85 2.62 3.50 3.50

mm 15.75 22.35 19.05 15.75 28.45 22.35 22.35 22.35 35.05 28.45 28.45 49.28 49.28 53.85 60.45 49.28 69.85 60.45 72.39 66.55 88.90 88.90

1.278 32.46 1.500 38.10 1.939 49.25 1.867 47.42 1.853 47.07 2.323 2.259 2.243 2.195 2.151 2.065 1.995

1.125 28.58 1.375 34.93 1.781 1.710

1.125 28.58 1.375 34.93 1.781 45.24 1.710

1.012 25.70 Avail. on Request 1.250 31.75 1.640 41.66 1.560 39.62 1.345 34.16 2.010 51.05 1.937 1.881

45.24 43.43

60.33

43.43

7.70 11.46 1.703 43.26

1.500 38.10 2.188 55.58 2.125 2.000

1.500 38.10 2.188 55.58 2.125 53.98 2.000 50.80 1.875 47.03 2.562 65.07 2.313

2 7/8

73.03

59.00 57.38 56.97 55.75 54.64 52.45 50.67

53.98 50.80

49.20 47.78

1.875 47.03 2.562 65.07 2.313 58.75 2.188 55.58 3.250 82.55 3.125 79.38 3.813 96.85 3.688

1.716 43.59 2.329 59.16 2.131

3 1/2

88.90

12.95 19.27 2.750 69.85 15.80 23.51 2.548 64.72 16.70 24.85 2.480 62.99 17.05 25.37 2.440 61.98 11.60 17.26 3.428 87.08 13.40 19.94 3.340 84.84 12.75 13.50 15.50 16.90 19.20 15.00 18.00 17.00 20.00 23.00 15.00 18.00 24.00 28.00 17.00 20.00 23.00 26.00 29.00 32.00

2.625 66.68 2.423 61.54 2.355 59.82 2.315 58.80 3.303 83.90 3.215 81.66 3.833 3.795 3.701 3.629 3.515 4.283 4.151 4.767 4.653 4.545 5.399 5.299 5.795 5.666 6.431 6.331 6.241 6.151 6.059 5.969

58.75

54.13

4

101.60

2.188 55.58 3.250 82.55 3.125 79.38 3.813 96.85 3.688 93.68 3.437

2.010 51.05 3.088 78.44 2.907 73.84 3.725 94.62 3.456 87.78 3.260 82.80

4 1/2

114.30

5

127.00

5 1/2

139.70

18.97 20.09 23.07 25.50 28.57 22.32 26.79 25.30 29.76 34.23 22.32 26.79 35.72 41.67 25.30 29.76 34.23 38.69 43.16 47.62

3.958 3.920 3.826 3.754 3.640 4.408 4.276 4.892 4.778 4.670 5.524 5.424 5.921 5.791 6.538 6.456 6.366 6.276 6.184 6.094

100.53 99.57 97.18 95.35 92.46 111.96 108.61 124.26 121.36 118.62 140.31 137.77 150.39 147.09 166.07 163.98 161.70 159.41 157.07 154.79

97.36 96.39 94.01 92.18 89.28 108.79 105.44 121.08 118.19 115.44 137.13 134.59 147.22 143.92 163.35 160.81 158.52 156.24 153.90 151.61

93.68

3.437 87.30

87.30

4.125 104.78 4.125 104.78 3.912 4.000 101.60 4.000 101.60 3.748

99.39 95.20

4.562 115.87 4.562 115.87 4.445 113.16 4.313 109.55 4.313 109.55 5.250 133.35 3.987 101.27

6 6 5/8

152.40 168.28

5.250 133.35 5.018 127.51 5.500 139.70

5.625 142.88 5.625 142.88

7

177.80

5.963 151.46 5.963 151.46

5.770 146.05

3.75

95.25

8 5/8

219.08

35.00 52.09 6.004 152.50 5.879 149.33 5.875 149.23 5.875 7.450 36.00 53.57 7.825 198.76 7.700 195.58 7.250 7.050

149.23 189.23 184.15 179.07

5.750 7.325 7.125 6.925

146.05 186.06 180.98 175.90

3.75 5.25 5.25 5.25

95.25 133.35 133.35 133.35

6/98

Page 3 of 3

FBN?, Full Bore Landing Nipple/Lock Mandrel System
Halliburton’s FBN Landing Nipple/Lock Mandrel System allows an indefinite number of identical landing nipples to be installed in a tubing string designed for monobore with no restrictions. The FBN lock mandrel can be selectively set in any one of its associated landing nipples and, when locked in place, will withstand a differential pressure of up to 10,000 psi (690 bar) from either direction. The lock mandrel’s expanding seal element and the landing nipple’s full-opening bore allow the lock to be run through any number of profiles before reaching the intended depth without the tendency to “hang up” in the higher profiles. This feature is particularly significant for large tubing and highly deviated well applications in which conventional selective locks will tend to preset in higher profiles due to the interference fit packing.

Features and Benefits
? pressure ratings up to 10,000 psi (690 bar) ? seals protected during installation and retrieval of the lock ? can be run and retrieved on slickline or coiled tubing ? keys no-go in nipple profile ? field proven ? smooth installation ? reduces time in the well with slickline ? seals on the locking mandrel protected from damage ? running/pulling with no interference ? no need for restrictive seal bore landing nipples incompatible with some completion designs ? expandable element creates a seal downhole

Fishing Neck

Full-Bore Nipple Expandable Element DoubleActing Spring No-Go Locking Keys

Ordering Information
Specify: tubing size, weight, grade, and thread connections; service environment (standard, %H2S, %CO2); temperature; pressure rating Part number prefixes: 10FBN— lock mandrels, 710FBN—API/lock mandrels, 11FBN—landing nipples, 711FBN—API/landing nipples, 20FBN—equalizing valves, 24FBN—equalizing prong/plug assembly
Equalizing Sub Plug Cap

Applications
? monobore well completions ? wells/fields/conditions in which problems exist for interference type seals ? high angle/horizontal wells

CN02695

Full-Bore Nipple Landing Nipple Lock Mandrel System

6/98

Page 1 of 2

Full Bore Nipple and Lock Mandrel System
Tubing/Casing Tubing/Casing Size in. 3 1/2 Casing Weight lb/ft 9.30 Standard Nipple ID in. 2.813 3.813 3.688 FBN? Minimum FBN Maximum OD Nipple ID in. FBN Ratings (1) Pressure Pressure Max. from from Temp Above Below

Nominal ID

Drift

Hone Bore

mm 88.90

kg/m 13.84

in. 2.992

mm 76.00

in.

mm

mm 71.45 96.85 93.68

mm.

in. 2.79 3.79 3.66

mm 70.87 96.27 92.96

in. 2.880 3.840 3.710

mm 73.15 97.54 94.23
6730 6400 10000 6400 9780 6730 6400 10000 6400 10000 300° 300° 300° 300° 250°(2)

2.867 72.82

2.880 73.15 3.840 97.54 3.630 94.23

4 1/2 114.30

12.60 18.75 16.90 23.07

3.958 100.53 3.833 97.36 3.826

97.18

3.701 94.01

5 1/2 139.70 23.00 34.23 7

4.670 118.62 4.545 115.44 4.437 112.70 4.562 115.82 4.42 112.27 4.560 115.82 6.184 157.01 6.059 153.90 5.963 149.23 6.070 154.18 5.86 148.84 6.070 154.18

177.80 29.00 43.16

NOTES: 1. All pressure ratings based on 80 ksi lock and 80ksi landing nipple 2. Based on maximum testing pressure

6/98

Page 2 of 2

Equipment and Products Specification Catalog

Completion Products
Subsurface Flow Controls
Selective by No-Go
Table of Contents
Selective by No-Go Introduction RQ No-Go Lock Mandrels SAFETYSET? Lock Mandrel System RPT? No-Go Landing Nipple and Lock Mandrel Systems SRP Wellhead Plug

6/98
CP3B2

Selective by No-Go Introduction
The no-go nipple system allows positive placement of specific flow controls in predetermined nipples used in the completion. This section outlines the RQ, RPT?, SAFETYSET? No-Go lock mandrel/nipple system, and the SRP wellhead plug.

6/98

Page 1 of 1

RQ No-Go Lock Mandrels
Halliburton RQ lock mandrels are top no-go lock mandrels designed to land and lock subsurface flow controls in RQ landing nipples.

Options
? antivibration features are available

Fishing Neck

Applications
? used only with RQ landing nipples ? designed for SSSV applications

Ordering Information
Specify: packer 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: 11RQ— landing nipple; 711RQ—API/ monogrammed landing nipple; 10RQ—lock mandrel: 710RQ—API/ monogrammed lock mandrel
CN03546

Features and Benefits
? matching nonhelical teeth inside the keys and on OD of expander sleeve provide primary holddown ? removable no-go ring allows press from above ? positive no-go location prevents wireline misruns ? installed and retrieved by standard slickline methods ? redundant holddown features

DoubleActing Spring Locking Keys No-Go Shoulder Packing

RQ No-Go Lock Mandrel

6/98

Page 1 of 1

SAFETYSET? Lock Mandrel System
Halliburton’s SAFETYSET lock mandrel system is a drivedown, jarup-to-set, no-go-type system designed specifically for surfacecontrolled subsurface safety valve (SCSSV) applications. This patented system consists of a SAFETYSET lock mandrel, running tool, and unlocking tool. The SAFETYSET lock mandrel system is designed to help ensure valve-set integrity and hydraulic control communication to the safety valve. The design features a locking sleeve that moves upward in the direction of flow to establish a locked safety valve. This locking allows unlimited drivedown action without the possibility of presetting the lock while it travels downhole. A no-go shoulder on the lock mandrel provides positive locating within the landing nipple. This system is designed to minimize operator guesswork at the surface by requiring two independent conditions to exist before the running tool will release. The SCSSV must be pressured open for the lock keys to expand. Only when the locking sleeve is locked in place will the running tool release. A running tool retrieved to the surface without the lock and valve indicates a functional valve securely locked into the landing nipple.

Applications
? specifically for slickline-retrievable, surface-controlled subsurface safety valve (SCSSV) applications ? high flow rates
Fishing Neck

Features and Benefits
? helps avoid a possible flow-out of the subsurface safety valves to surface ? running tool can be released only after lock mandrel locks and SCSSV is operable ? no shear pins in the running tool ? lock mandrel can only lock in the nipple after control line integrity is established ? large ID ? locking sleeve locks in the direction of flow ? optimum pressure rating design on lock mandrel ? minimal metal-to-metal abrasion from vibration ? helps eliminate the possibility of subsurface safety valves being left downhole when improperly installed without control line pressure integrity ? no shear pin damage to safety equipment, seals, and sealing bores ? no presetting and false set indications from premature pin shearing ? antivibration ring in lock mandrel ? lock system is protected from unintentional unlocking by slickline tools passing up through the ID
Anti-Vibration Ring Locking Keys Locking Sleeve No-Go Shoulder
CN03547

Packing

SAFETYSET? Lock Mandrel

6/98

Page 1 of 2

Operation
The mechanical locking mechanism of the running tool cannot be activated until hydraulic control pressure has opened the safety valve. Opening the safety valve shifts the running tool in to the locking mode. Upward strain on the slickline toolstring props the keys of the lock mandrel into position. Upward jarring completes the locking operation. The running tool is designed to release automatically only when the safety valve has been opened and the lock mandrel is securely locked in position.

Options
? designs are available for all RQ and RPT? landing nipple profiles ? models are designed to land and lock in any safety valve landing nipple if there is a no-go ? optional "UP" running tool allows setting safety valve assemblies that have staggered seal diameters

Ordering Information
Specify: type nipple profile or part number of nipple, if known; packing bore of nipple; special material requirements, if applicable; service environment (standard, %H2S, %CO2, amines); necessity of API monogramming or other certification requirements; pressure rating Part number prefixes: 711RQ— safety valve landing nipple, 710SS—API monogrammed lock mandrel

SAFETYSET Lock Mandrels
Size mm in. 2 7/8 73.03 3 1/2 Weight kg/m lb/ft 9.67 6.50 13.84 9.30 15.34 10.30 19.29 12.95 18.97 12.75 20.11 13.50 23.09 15.50 19.36 13.00 22.34 15.00 23.07 15.50 25.3 17.00 29.76 20.00 29.76 20.00 thru thru 47.62 32.00 ID in. 2.441 2.992 2.922 2.750 3.958 3.920 3.826 4.494 4.408 4.950 4.892 4.778 6.456 thru 6.034

?

88.90

4 1/2 5 5 1/2

114.30
127.00

139.70

7

177.80

mm 62.00 76.00 74.22 69.85 100.53 99.57 97.18 114.15 111.96 125.73 124.26 121.36 163.98 thru 153.26

Drift mm in. 2.347 59.61 2.867 72.82 2.797 71.04 2.625 66.68 3.833 97.36 3.795 96.39 3.701 94.01 4.369 110.97 4.283 108.79 4.825 122.56 4.767 121.08 4.653 118.19 6.331 160.81 thru thru 5.969 151.61

Nipple Seal Bore mm in. 58.75 2.313 71.45 2.813 69.85 2.750 65.07 2.562 96.85 3.813 3.688 4.313 4.125 4.562 6.000 5.963 5.875

No-Go OD mm in. 60.02 2.363 72.64 2.860 70.99 2.795 66.68 2.625 98.04 3.860 3.745 4.395 4.170 4.655 6.100 6.033 5.950

ID in. 1.25 1.58 1.58 1.25 2.20 2.080 2.20 2.50 2.92

mm 31.75 40.13 40.13 31.75 55.88 52.83 55.88 63.50 74.17

93.68 109.55 104.78 115.87 152.40 151.46 149.23

95.12 111.63 105.92 118.24 154.94 153.24 151.13

4.125 104.78

6/98

Page 2 of 2

RPTTM No-Go Landing Nipple and Lock Mandrel Systems
The Halliburton RPT No-Go landing nipple system allows a series of positive location landing nipples to be run in a tubing string while providing minimum restrictions. RPT No-Go landing nipples are designed to accept RPT lock mandrels with a rated working pressure of 10,000 psi (690 bar) differential from above and below. The RPT No-Go lock mandrel locates on top of the nipple’s polished bore; therefore, there are no secondary restrictions normally associated with bottom no-go profiles. This feature makes RPT systems well suited for highpressure, high-volume, large-bore completions. RPT lock mandrels in any given size range are designed to use the same running tool and pulling tool.

Features and Benefits
? large bore ? lock mandrel locates on top of the nipples’ polished bore ? landing nipples can accept RPT lock mandrels with a rated working pressure of 10,000 psi (690 bar) differential from above and below ? minimum stepdown between nipple IDs ? locks designed with one ID for each tubing size, allowing use of one running and pulling tool
Fishing Neck RPT? Landing Nipple HighPressure Locking Keys No-Go

Ordering Information
Specify: tubing size, weight, grade, and thread connections; device environment (standard, %H2S, %CO2, amines/other chemicals, chloride content, temperatures, pressures, etc.); number of landing nipples in tubing string Part number prefixes: 11RPT— landing nipple, 711RPT—API monogrammed landing nipple, 10RPT—lock mandrel, 710RPT—API monogrammed lock mandrel

HighTemperature Packing Stack Equalizing Valve
CN03207

Plug Cap

Applications
? high-pressure, high-temperature, large-bore completions ? for running a series of no-go nipples in a tubing string when positive location and minimal ID reduction are required

RPT? No-Go Landing Nipple with RPT? Plug

6/98

Page 1 of 2

RPTTM No-Go Landing Nipple and Lock Mandrel Systems
RPT? Profile and Lock Dimensions
Nipple Profile Tubing Size Seal Bore (Minimum ID) in. 2 3/8 ID in. 0.750 OD Lock Mandrel

mm 60.33

in. 1.500 1.625 1.781 1.875 2.000

mm 38.10 41.28 45.24 47.63 50.80 55.58 58.75 65.07 69.85 73.03 76.20 79.38 84.15 87.30 90.47 93.68 95.25 96.85 101.60 106.38 109.55 112.70 114.30 115.87 119.08 139.70 142.88 146.05 149.23 151.46 158.75

mm 19.05

in. 1.560 1.685 1.841 1.935 2.060

mm 39.62 42.80 46.76 49.15 52.32 57.10 60.27 52.32 57.10 60.27 77.72 81.53 86.23 89.41 92.71 95.76 96.70 98.93 103.89 108.46 111.63 114.81 115.57 118.11 120.90 141.86 145.03 148.34 150.88 153.04 160.78

2 7/8

73.03

2.188 2.313 2.562

1.120

28.45

2.248 2.060 2.060

3 1/2

88.90

2.750 2.875 3.000

1.500

38.10

2.248 2.373 3.060 3.210 3.395 3.520 3.650

4 - 4 1/2

101.6-114.3

3.125 3.313 3.437 3.562

1.750 1.94

44.45 49.28

4 1/2 - 5

114.3-127

3.688 3.750 3.813 4.000 4.188 4.313

1.940

49.28

3.770 3.807 3.895 4.090 4.270 4.395

5 1/2

139.70

4.437 4.500 4.562 4.688 5.500 5.625

2.750

69.85

4.520 4.550 4.650 4.760 5.585 5.710

7

177.80

5.750 5.875 5.963 6.250

3.680

93.472

5.840 5.940 6.025 6.330

6/98

Page 2 of 2

SRP Wellhead Plug
Halliburton’s SRP Plug System is designed primarily for use in horizontal subsea trees. Its compact size allows the tree to be shorter, allowing smaller, less costly wellhead equipment. The top no-go design provides a positive locating means to simplify running procedures and eliminate misruns. Because the SRP plug is a dedicated wellhead plug, it can be used for any tree or tubing hanger plugging application.

Applications
? conventional tubing hangers ? platform horizontal trees ? subsea horizontal trees

Features and Benefits
? dedicated wellhead design ? internal fish neck ? available with top or bottom no-go locator ? single or multiple seal stacks ? equalizing option ? high pressure seal stack ? reduces cost of tubing hanger, tree housing, and services ? minimizes service riser dimension/ cost ? saves time and money using slickline to install ? requires no special tools ? field-proven technology

CN03152

"SRP" Wellhead Plug

Subsea Horizontal Tree

Ordering Information
Specify: packing bore, pressure rating, special material requirements, service environment Part number prefixes: 10SRP + plug, 710SRP/API monogrammed plug

6/98

CN03153

Platform Horizontal Tree

CN03154

Equipment and Products Specification Catalog

Completion Products
Subsurface Flow Controls
Lock Mandrels for Wells Without Landing Nipples
Table of Contents
Monolock?

6/98
CP3B3

Monolock?
The Halliburton Monolock is designed to be set anywhere in a given size of tubing, casing, or liner. The Monolock differs from a conventional lock mandrel because it does not require either a profile or seal bore in the tubing string and is retained in its set position by slips rather than keys. The Monolock may be used in association with the Halliburton Full Bore Nipple system or any other selective or nipple and lock system. The lock is set and retrieved with Halliburton-type DPU? (Downhole Power Unit) Running/ Retrieving Tools, which can be run on slickline, braided line, or coiled tubing. When used for plugging applications, the lock is designed to withstand differential pressure of up to 10,000 psi (690 bar) from either direction. ? because element returns to original shape, assembly can be recovered back through restrictions ? run and retrieved on same DPU ? run on slickline, braided line, or coiled tubing ? element located above slips, preventing any debris accumulation around slip area ? barrel-slip design provides maximum slip engagement while minimizing tubing deformation ? equalizing feature provided in standard assembly ? can be set anywhere in tubing, casing, or liner ? quick running and retrieval ? use of slickline rather than conductor line lowers installation and retrieval costs ? redressable in field, reducing downtime ? slip configuration ensures centralized setting of the lock, even in high angle or horizontal wells ? provides same reliability as production packers

Fishing Neck Lock Ring

Single-Piece Element

Barrel Slip

Applications
? as a retrievable bridge plug ? can be adapted to install BHP gauges and other flow control devices ? plug tubing below hanger for well repairs

Ordering Information
Specify: tubing size, weight, and grade; service environment (standard, %H2S, %CO2, amines/other chemicals, etc.); temperature; pressure rating; special material requirements
CN01998

Energy Storage Springs

Features and Benefits
? pressure ratings up to 10,000 psi (690 bar) ? requires no landing receptacle ? seals against pipe ID ? slip-type anchor system ? element is retracted during retrieval ? Belleville Spring Energy Storage System provides positive sealing during pressure reversals

Equalizing Valve

Part number prefix: 21ML

Plug Cap

Monolock?

6/98

Page 1 of 2

Monolock?
Tubing/Casing Tubing/ Casing Size 4 1/2 4 1/2 4 1/2 5 4 1/2 4 1/2 5 5 1/2 5 1/2 5 1/2 5 1/2 5 1/2 7 7 7 7 7 7 7 7 7 7 7 7 NOTES: 1. Pressure ratings shown are for 80,000 minimum yield material. 2. Pressure ratings are based on monolock rating itself or 70% of API internal rating. Induced stresses on the element and slips may cause the tubing/casing to swell at pressures higher than the 70% value. 3. Temperature rating for all Monolocks are 72° F to 250° F. 4. Part numbers shown are for existing designs. Weight 11.6 12.6 13.5 23.2 13.5 15.5 18.0 15.5 17.0 17.0 20.0 23.0 23.0 26.0 29.0 26.0 29.0 32.0 29.0 32.0 35.0 32.0 35.0 38.0 Nominal ID 4.000 3.958 3.920 4.044 3.920 3.826 4.276 4.950 4.892 4.892 4.778 4.670 6.366 6.276 6.184 6.276 6.184 6.094 6.184 6.094 6.004 6.094 6.004 5.920 Drift 3.875 3.833 3.795 3.919 3.795 3.701 4.151 4.825 4.767 4.767 4.653 4.545 6.241 6.151 6.059 6.151 6.059 5.969 6.059 5.969 5.879 5.969 5.879 5.795 Minimum Nipple ID 3.813 3.813 – 3.813 3.688 3.688 4.000 4.688 4.688 4.562 4.562 – 6.000 6.000 6.000 5.963 5.963 5.963 5.875 5.875 5.875 5.750 5.750 5.750 Maximum OD 3.78 3.78 3.78 3.78 3.66 3.66 3.97 4.66 4.66 4.53 4.53 4.53 5.97 5.97 5.97 5.92 5.92 5.92 5.84 5.84 5.84 5.72 5.72 5.72 Fish Neck 1.380 1.380 1.380 1.380 1.380 1.380 1.380 1.810 1.810 1.810 1.810 1.810 2.310 2.310 2.310 2.310 2.310 2.310 2.310 2.310 2.310 2.620 2.620 2.620 Monolock
TM

Pressure Rating 80K Minimum Yield 6,200 6,740 7,200 8,200 7,730 8,990 8,200 5,600 6,190 6,190 7,350 8,450 5,080 5,790 6,500 5,790 6,530 7,200 6,530 7,200 7,200 7,200 7,200 7,200

Part Number

21ML37800 21ML37810

21ML36610

21ML39710

21ML55012

21ML55000 21ML55001 21ML55011

21ML59710 21ML59770

21ML59200 21ML59201 21ML59210

21ML58410

21ML1 21ML2 21ML3 (Not standard)

6/98

Page 2 of 2

Equipment and Products Specification Catalog

Completion Products
Subsurface Flow Controls
Lock System Accessory Equipment
Table of Contents Plug Choke Assemblies Pump-Through Plug Assemblies X? Bottomhole Choke Beans Hot Plug? System Pump Open Plugs Equalizing Subs

6/98
CP3CTOC

Equipment and Products Specification Catalog

Completion Products
Subsurface Flow Controls
Lock System Accessory Equipment
Plug Choke Assemblies
Table of Contents

Introduction to Plug Choke Assemblies PXX, PRR, and PRT Plug Choke Assemblies XX, RR, and RPT? Plug Choke Assemblies

6/98
CP3C1

Introduction to Plug Choke Assemblies
Halliburton offers several plug choke assemblies including the PXX, PRR, and PRT plug choke assemblies.

6/98

Page 1 of 1

PXX, PRR, and PRT Plug Choke Assemblies
These Halliburton plug choke assemblies consist of a lock mandrel, a prong-and-valve equalizing assembly, and a plug cap. The plug chokes are run and pulled on slickline and used to plug the tubing for various operations, including setting and testing packers and testing tubing. PXX plug chokes are made up on X? or XN? lock mandrels and installed in X? or XN? landing nipples. PRR plug chokes are made up on R? or RN? lock mandrels and installed in Halliburton R? or RN? landing nipples. PRT plug choke assemblies make up an RPT lock mandrel. PXX, PRR, or PRT plug choke assemblies with equalizing prongs are used to plug the wellbore in either direction. They are designed for use where sediment might collect on the plug. Before the plug is retrieved from the wellbore on slickline, the prong is removed from the plug housing, providing an equalization path across the plug choke. Two slickline trips are required to run or pull the plug.

Features and Benefits
? balanced equalizing prongs with seals for either standard or H2S service ? fluid bypass during running or retrieving operations ? extended-length prongs for use in completions with side pocket mandrels or when a large amount of sediment is expected ? Vee-packing seals on equalizing prong ? set and retrieved on slickline ? holds pressure from below or above ? more dependable sealing in extreme environments

Ordering Information
Specify: lock type and size or part number, if known; plug type (onetrip, two-trip, pump through); sesrvice environment (standard, %H2S, %CO2, amines); temperature and pressure rating requirements; special material requirements, if applicable Part number prefixes: 24PXX, PRR, PRT—two-trip plugs require lock mandrel and plug choke assembly, each ordered separately

Applications
? setting and testing packers ? removing the wellhead ? separating zones during production tests or data-gathering ? for use where sediment might collect on the plug ? PXX used with X or XN lock mandrels and landing nipples ? PRR used with R or RN lock mandrels and landing nipples ? PRT used with RPT lock mandrels and landing nipples

PXX Plug Choke Assembly

6/98

CN01923

Page 1 of 1

XX, RR, and RPT? Plug Choke Assemblies
Halliburton’s plug choke assemblies consist of a lock mandrel, an equalizing sub assembly, and a plug cap. These plug chokes are run and pulled on slickline to plug the tubing for various operations. XX plug chokes are made up on X or XN lock mandrels and installed in Halliburton X or XN landing nipples. RR plug chokes are made up on Halliburton R or RN lock mandrels and installed in Halliburton R or RN landing nipples. The RPT plug chokes are made up on RPT? lock mandrels and installed in Halliburton RPT? landing nipples. Halliburton’s XX and RR plug choke assemblies are designed to hold differential pressure from above or below for normal plugging operations. The equalizing sub provides an equalization path across the plug choke. Only one slickline trip is required to run or pull the plug.

Features and Benefits
? balanced equalizing system ? fluid bypass during running or retrieving operations ? variable size equalizing ports available ? requires only one slickline trip to run or pull ? holds pressure from below or above
Fishing Neck

Lock Mandrel

Ordering Information
Specify: lock type and size or part number, if known;plug type (one-trip, two-trip, pump through); service environment (standard, %H2S, %CO2, amines); temperature and pressure rating requirements; special material requirements, if applicable Part number prefixes: one-trip plugs require lock mandrel and plug choke assembly, each ordered separately; 20XO, RO, RPT— equalizing valve for one trip plug; 20X, R—valve cap for one-trip plug

Equalizing Sub

Applications
? ? ? ? ? normal plugging operations setting and testing packers removing the wellhead testing tubing separating zones during production tests or data-gathering

Valve Cap
CN03548

XX Plug Choke Assembly

6/98

Page 1 of 1

Equipment and Products Specification Catalog

Completion Products
Subsurface Flow Controls
Lock System Accessory Equipment
Pump-Through Plug Assemblies
Table of Contents
XR Pump-Through Plug Assemblies

6/98
CP3C2

XR Pump-Through Plug Assemblies
XR pump-through plug assemblies are designed to hold pressure differential only from below. They can be pumped through by applying tubing pressure above the plug until it overcomes the well pressure, allowing fluids to be pumped through the plug, to equalize across the plug, or to kill the well. One slickline trip is required to run or pull the plug. These plug chokes are run and pulled on slickline to plug the tubing for various operations. XR pump-through plugs are made up on X?, XN?, R?, or RN? lock mandrels and installed in X?, XN?, R?, or RN? landing nipples.

Features and Benefits
? holds pressure differential from below only ? uses a ball-and-seat assembly ? requires only one slickline trip to run or pull the plug ? allows kill fluids to be pumped through the plug

Fishing Neck

Lock Mandrel Expander Mandrel

Ordering Information
Specify: lock type and size or part number, if known; service environment (standard, %H2S, %CO2, amines); temperature and pressure rating requirements; special material requirements, if applicable Part number prefixes: 21XR— pump-through plug; 20XO, RO— equalizing valve

Applications
? killing the well ? removing the wellhead ? isolating high-pressure zones from lower pressure zones

Equalizing Sub

Ball and Seat
CN03549

Spring Valve Housing

XR Pump-Through Plug Assembly

6/98

Page 1 of 1

X? Bottomhole Choke Beans
Halliburton X Bottomhole choke beans are designed to reduce the possibility of freezing surface controls by moving the point of pressure and temperature reduction to the lower portion of the wellbore. They are connected to Halliburton X? and R? lock mandrels. Halliburton X choke beans are designed to prolong the flowing life of wells by liberating gas from solution at the bottom of the hole. This liberation lightens the oil column and increases flow velocity. These choke beans also help prevent water encroachment by maintaining a consistent bottomhole pressure. Reducing water encroachment helps to stabilize and keep the formation oil/water contact constant.

Applications
? to help reduce the possibility of freezing surface controls
CN03550

Bean Holder O-ring Choke Bean

Features and Benefits
? can be connected to X and R lock mandrels ? are available in various sizes ? minimize water encroachment ? lighten the oil column ? increase flow velocity ? prolong the life of the well

X? Bottomhole Choke Bean

Ordering Information
Specify: lock type and size or part number, if known; service environment (standard, %H2S, %CO2, amines); temperature and pressure rating requirements; bean size for X bottomhole choke Note: Beanholder supplied with blank bean for custom sizing. Alternate beans available under prefix 21X. Part number prefix: 21XO— beanholder for bottomhole choke

6/98
CP3C3

Page 1 of 1

Hot PlugTM System
Halliburton’s Hot Plug system is an integrated plug system designed to be installed near the end of the completion string. This system was developed to provide a method to plug tubing in difficult conditions. The Hot Plug system consists of an integral plug and equalizing valve assembly and a dedicated landing nipple and running tool. It is retrieved with a standard pulling tool. The plug is designed for high pressure, such as 10,000 psi (690 bar) from above or below. It can be run and retrieved in a single trip.

Features
? packing section located above the keys so plug can be used in wells with debris or sand ? locking key is designed to prevent premature setting of plug in collar recess ? equalizing feature prevents plug from unlocking until equalization is complete ? emergency shear-out feature ? one-piece design does not require accessory equalizing devices, prongs, caps, etc.
Fishing Neck

Packing

Benefits
? designed for use in wells where debris or sand may be present ? designed to prevent the possibility of premature setting of the plug in a collar recess ? can be equalized in sandy conditions ? can be run and retrieved in one trip

Applications
? installing plugs for snubbing, pressure testing tubing, installing BOPs, or wellhead repairs ? testing tubing ? packer setting

Locking Keys No-Go Shoulder

Ordering Information
Specify: service environment (standard, %H2S, %CO2, amines); size of packing/polished bore; temperature rating; special material, if required Part number prefixes: 21HOT— hot plug assembly, 11HOT—hot landing nipple, 41HOT—hot running tool

AntiBlowout Equalizing Valve

CN00619

Hot Plug? System

6/98
CP3C3

Page 1 of 1

Pump Open Plugs
The Halliburton pump open plug is a positive plug that holds pressure from either direction but can be pumped open by applying excess surface pressure. Pump open plugs serve as temporary tubing plugs that can be pumped open and used for production without retrieving by slickline. Pump open plugs consist of a plug body, plug cap, and pump open valve. They are designed to be run with Halliburton’s equalizing valves and lock mandrels, although they can also be run on other compatible lock mandrels.

Features and Benefits
? ? ? ? only one moving part nontortuous flow path balanced flow areas provides reliable, economical performance ? can be used with virtually any lock mandrel

O-ring Seal

Ordering Information
Specify: lock/equalizing valve size and type or part number, if known; service environment (standard, %H2S, %CO2, amines, etc.); temperature rating; special material requirements, if applicable Part number prefix: 21XPO, RPO—pump open plug

Flow Ports

Release Pins

Applications
? as a temporary tubing plug that can be pumped open and used for production without running slickline ? for conventional plugging applications in sandy conditions where equalizing through small bore equalizing devices might be difficult ? to isolate perforations when run below packer completion assembly

Pump Open Valve

Plug Body

CN01737

Plug Cap

Pump Open Plug

6/98
CP3C3

Page 1 of 1

Equipment and Products Specification Catalog

Completion Products
Subsurface Flow Controls
Lock System Accessory Equipment
Equalizing Subs
Table of Contents

Introduction to Equalizing Subs X?, R?, and RPT Equalizing Subs XH Subs

6/98
CP3C4

Introduction to Equalizing Subs
Halliburton features many different equalizing subs to accompany the various lock mandrel models available. The various sub models differ in the ID size, pressure-holding capabilities, equalizing valve design, lock mandrel compatibility, tubing weight, and service environment.

6/98

Page 1 of 1

X?, R?, and RPT Equalizing Subs
Halliburton X, R, and RPT equalizing subs are used in the XX, RR, XXN, RRN, and RPT plugs where pressure differentials are anticipated. They are designed to hold pressure from above or below and are used with the large-bore Halliburton X? lock mandrels for standard weight tubing, Halliburton R? lock mandrels for heavyweight tubing, and RPT lock mandrels for stepped no-go systems. These subs are run in the open position, and the running prong shifts the sleeve to the closed position during the setting procedure. The pulling prong shifts the sleeve downward to the open position for equalization before pulling.

Applications
? when pressure differentials are anticipated across a flow control device ? used with Halliburton X lock mandrels for standard weight tubing, R mandrels for heavyweight tubing, and RPT lock mandrels for stepped no-go systems

Valve Housing

Valve

CN03552

Ordering Information
Specify: lock type and size or part number, if known; service environment (standard, %H2S, %CO2, amines); temperature and pressure rating requirements; special material requirements, if applicable Part number prefix: 20XO, RO, RPT—equalizing subs

Seal

Equalizing Sub

6/98

Page 1 of 1

XH Subs
Halliburton XH equalizing subs feature button-type valves that hold pressure from below only. They are designed to be used with X? and XN lock mandrels to allow ambient and velocity-type safety valves to be reopened against differential pressures without being pulled. The XH equalizing valve has a flow bore compatible with the subsurface flow control bore.

Features and Benefits
? button valve ? no-go OD to allow setting in XN landing nipples ? holds pressure from below only ? ambient and pressure-differential safety valves can be reopened without being pulled

Valve Housing

Valve

Ordering Information
Specify: lock type and size or part number, if known; service environment (standard, %H2S, %CO2, amines); temperature and pressure rating requirements; special material requirements, if applicable Part number prefix: 20XH— equalizing subs

Spring

Applications
? used with X or XN lock mandrels ? allow ambient and velocity-type safety valves to be reopened against differential pressures without being pulled ? suitable for H2S and standard service

CN03551

XH Equalizing Sub

6/98

Page 1 of 1

Equipment and Products Specification Catalog

Completion Products
Subsurface Flow Controls
Bottomhole Pressure Equipment
Table of Contents
Bottomhole Pressure Equipment Introduction Softset Bomb Hanger LO Shock Absorbers

6/98
CP3D

Bottomhole Pressure Equipment Introduction
Halliburton’s Softset bomb hangers and LO shock absorbers are described in this section.

6/98

Page 1 of 1

Softset Bomb Hanger
Description
Halliburton Softset bomb hangers are designed to set instruments virtually anywhere Halliburton X?, XN?, R?, and RN? landing nipples have been installed. Data surveys can be collected downhole using conventional slickline methods. This practice provides significant savings (1) when several wells in a field are to be surveyed and (2) in fields where a highly corrosive environment requires the slickline to be removed from the well during prolonged testing. ? allows for accurate charts rather than recording jarring effects ? can be set in one of many landing nipples to run surveys at known locations downhole Note: A Halliburton MR mechanical running tool is used to run the XNS or RNS Softset bomb hanger. It is designed to carry weight in excess of the 140-lb weight limit of a hydraulic running tool. The MR mechanical running tool features an emergency shear ring designed to release the core from the fishing neck if the bomb hanger becomes stuck and needs to be freed.

Applications
? wells with a highly corrosive environment ? field with several wells to be surveyed ? wells that require extended surveys

Ordering Information
Specify: type (Softset or lug); tubing size, weight, and thread; nipple profile and ID; service environment (standard, %H2S, %CO2, amines); special material requirements, if applicable; weight of instruments Part number prefix: 33XNS, RNS—Softset bomb hanger

Features and Benefits
? has a soft mechanical release ? does not require jarring to set ? allows data surveys using conventional slickline methods

Softset Bomb Hanger
6/98 Page 1 of 1

CN03554

LO Shock Absorbers
Description
Halliburton LO shock absorbers are designed to help prevent instrument damage caused by jarring and impacts during slickline operation. The assemblies suspended below the shock absorbers are supported by springs within the absorber. Any shocks transmitted from the slickline tool string are absorbed by the shock absorbers.

Ordering Information
Specify: lock type and size; service environment (standard, %H2S, %CO2, amines); special material requirements, if applicable; weight of instruments Part number prefix: 33LO—shock absorber

Applications
The absorbers should be used only when the weight of the instruments attached below does not compress the spring to its stacked length.

LO Shock Absorber

6/98

CN01881

Page 1 of 1

Equipment and Products Specification Catalog

Completion Products
Subsurface Flow Controls
Accessory Equipment
Table of Contents
Mirage? Disappearing Plug Fill Sub Flow Couplings Blast Joints

6/98
CP3E

Mirage? Disappearing Plug
Description
The Halliburton Mirage? Disappearing Plug is a plugging device designed to run as an integral part of the tubing. The plug can be used to set a hydraulic-set packer or to test the tubing string. It is activated by hydraulic pressure, eliminating the need to use wireline or coiled tubing to run and retrieve the plugging device. Once the plug has been expended, the plug material will dissolve and disintegrate leaving full tubing ID through the plug. A fill sub is run above the mirage plug when tubing autofill is required. ? water used to dissolve plug is carried with the tool ? a diaphragm is run in the top of the tool to keep debris off plug matrix ? full nonrestrictive ID after expending plug ? maximum particle size after the plug material has disintegrated is 1 mm, eliminating any well debris ? can be mechanically activated by wireline as a backup ? multiple pressure cycle capability ? hold differential pressure from above and below ? automatic expend after last pressure cycle ? reduces well risk, reduces number of slickline or CTU trips in the hole, allows multiple pressure tests prior to expending

Applications
? horizontal and high angle wells where slickline or CTU intervention after completion is undesirable ? setting production and isolation packers ? testing tubing ? wells where retrievable plug after use is undesirable

Ordering Information
Specify: tubing size, weight, and grade; thread connection; material; service environment; pressure rating Part number prefix: 21MPA Mirage plug

Features and Benefits
? testing tubing can be accomplished without delay or problems associated with other plugging methods ? soft expend feature minimizes shock damage to formation ? reduces completion costs by eliminating trips to install and retrieve plugging device

Mirage? Disappearing Plug
Mirage ? Disappea ring Plug
Nominal Size in. 3 1 /2 4 1 /2 5 1 /2 7 OD in. 5.40 5.88 6.87 8.26 ID (A f ter Expend) Length in. 44.00 54.11 56.60 56.60 Pressure Rating From A bove From Below psi 2500 2500 2500 2500

mm 88.90 114.30 139.70 177.80

mm 139.70 152.40 174.50 209.80

in. 2.88 3.88 4.77 6.08

mm 72.64 98.04 118.87 154.43

mm 1117.60 1374.39 1437.64 1437.64

psi 7500 5000 5000 5000

kPa 51710.67 34473.79 34473.79 34473.79

CN04196a

kPa 17236.89 17236.89 17236.89 17236.89

6/98

Page 1 of 1

Fill Sub
Description
The fill sub is run above the Mirage? Plug when automatic filling of the tubing is required. The unique bladder design of the fill sub allows debris-laden annulus fluids to enter the tubing, while providing a reliable seal from the tubing side. The tubing can be tested any number of times providing the sheer pressure of the lockout piston is not exceeded. Once the lockout pins are sheared due to tubing pressure, the piston drives the ports in the isolation sleeve past the o-rings, locking the fill sub out of service. Since the isolation sleeve is balanced and the lockout piston is not connected, a simple interference fit retains the fill sub in the locked out condition.

Features and Benefits
? fill valve automatically fills the tubing from below, eliminating manual fill from the surface while keeping pressures balanced ? allows tubing fill-up when used with Mirage Plug ? prevents fluid flow from tubing to casing ? can be locked closed at any time by pressure ? rubber sealing sleeve provides positive sealing in debris-laden fluid

Ordering Information
Specify: tubing size, weight and grade; thread connection material; service environment; pressure rating Part number prefix: 21FS - fill sub

CN04197

Fill Sub

6/98

Page 1 of 1

Flow Couplings
Description
Halliburton flow couplings in the tubing are an important part of lifeof-the-well completion planning. Flow couplings, which have a wall thickness greater than the corresponding tubing, are designed to inhibit erosion caused by flow turbulence. Field experience indicates that flow couplings should be a minimum of 3 ft (.91 m) long. Halliburton recommends flow couplings be installed above and below landing nipples or any other restriction that may cause turbulent flow.

Features and Benefits
? are a minimum of 3 ft (.91 m) long ? used with landing nipples and flow controls ? have wall thickness greater than tubing ? help extend the life of the well completion

Ordering Information
Part number prefixes: 11FN, FNC, FNM—flow coupling, standard length 3, 4, 6 ft (.915, 1.22, 1.83 m)

Flow Coupling

Applications
? to help inhibit erosion caused by flow turbulence ? to be installed above and below landing nipples or any other restriction that may cause turbulent flow

Landing Nipple and Flow Control Device Flow Coupling

CN03555

Flow Coupling

6/98

Page 1 of 1

Blast Joints
Description
Halliburton blast joints are installed in the tubing opposite perforations in wells with two or more zones. Halliburton blast joints are sized to help prevent tubing damage from the jetting action of the zone perforations.

Features and Benefits
? available in lengths greater than 10 ft (3.048 m) ? has wall thickness that is greater than tubing ? increases production tubing life

Ordering Information
Part number prefix: 11BN—blast joints, standard length—10 to 20 ft (3.048 to 6.096 m); specify length required

Applications
? used to help prevent tubing damage from the jetting action of the zone perforations ? installed in the tubing opposite perforations in wells with two or more zones

Blast Joint

CN03556

Blast Joint

6/98

Page 1 of 1

Equipment and Products Specification Catalog

Completion Products
Subsurface Flow Controls
Circulation/Production Sleeves
Table of Contents
DURASLEEVE? Circulation/Production Sleeve

6/98
CP3F

DURASLEEVE? Circulation/Production Sleeve
Description
The Halliburton DURASLEEVE? Circulation/Production Sleeve incorporates the new DURATEF ECM seal, a nonelastomer engineered composite material (ECM) available only from Halliburton. DURATEF ECM is so advanced that temperature and pressure ranges for testing have been expanded dramatically, resulting in a new specification for sleeves. During testing, DURASLEEVE devices were repeatedly opened against 5,000 psi (345 bar) differential pressure with no seal damage. The Halliburton DURASLEEVE? Circulation/ Production Sleeve is a full-opening device with an inner sleeve that can be opened or closed using standard slickline methods. This sleeve enables communication between the tubing and tubing/casing annulus. A Halliburton X? or R? nipple profile is featured above the inner sliding sleeve and a polished packoff area below as an integral part of the assembly. This design provides for an additional landing nipple in the tubing string for a wide variety of Halliburton flow control equipment and the option to pack it off. A three-position collet lock helps keep the sleeve in full open, equalizing or full-closed position. Equalizing ports in the inner sleeve are designed to allow pressure differential between the tubing and casing annulus to equalize while shifting into the full-open or closed position. Any number of circulation equipment pieces may be run in a single tubing string and all opened or all closed on a single slickline trip. Individual sleeves may also be opened or closed selectively as needed. Compression, tensile, and burst strength of Halliburton circulation equipment are equal to or greater than N-80 tubing. Models are also available in strengths equal to or greater than P-110 tubing. The DURASLEEVE? Circulation/Production Sleeve is used for a variety of installations. It is available in two shifting versions: down to close and up to open or up to close and down to open. Models are also available for standard and heavyweight tubing and high-temperature service. All have a circulation/ production area equivalent to the tubing area.

Landing Nipple Profile

Applications
? ? ? ? single selective completions circulating kill fluids secondary recovery washing above packer Closing Sleeve

Features and Benefits
? X? or R? nipple profile is standard; other profiles available on request ? Duratef nonelastomer seals ? polished packoff area ? circulation/production area equals the tubing area ? packing does not move when the sleeve is shifted ? three-position collet lock ? equalizing ports in the inner sleeve allow equalizing at high differential pressure ? available in up or down opening versions ? reliable shifting for the life of the well ? can equalize against 5,000 psi (345 bar) differentials ? sleeve can be shifted even when outside of sleeve is packed with sand

Equalizing Ports Flow Ports Buffer Seal ECM Seal Stack High-Strength Body Joints

CN03557

Lower Polished Bore

DURASLEEVE? Circulation/ Production Sleeve
6/98 Page 1 of 2

? several DURASLEEVES? may be run in a single tubing string ? all the DURASLEEVES can be shifted on a single trip of the slickline ? individual sleeves may also be opened or closed selectively as desired ? Sleeve can be shifted repeatedly

Ordering Information
Specify: type (open up or down); tubing size, weight, grade, and thread; service environment (standard, %H2S, %CO2, amines); pressure and temperature requirements; dimensional constraints, if any; special material requirements Part number prefixes: 621 XU, RU—open up; 621 XD, RD—open down Note: Other profiles available on request

DURASLEEVE? Circulation/Production Equipment
Tubing Weight Tubing ID Tubing Drift Standard Weight* ID Heavyweight* ID lb/ft kg/m in. mm in. mm in. mm in. mm 6.85 4.60 1.995 50.67 1.901 48.29 1.875 47.63 6.99 4.70 1.995 50.67 1.901 48.29 3 2 /8 60.33 5.30 1.939 49.25 1.845 46.86 1.781 45.24 7.89 8.85 5.95 1.867 47.42 1.773 45.09 1.710 43.43 9.23 6.20 1.853 47.07 1.759 44.68 11.46 7.70 1.703 43.26 1.609 40.87 1.500 38.10 9.52 6.40 2.441 62.00 2.347 59.61 2.313 58.75 9.67 6.50 2.441 62.00 2.347 59.61 11.76 7.90 2.323 59.00 2.229 56.62 2.188 55.58 12.95 8.70 2.259 57.38 2.165 54.99 2.125 53.98 7 2 /8 73.03 8.90 2.243 56.97 2.149 54.58 13.24 14.14 9.50 2.195 55.75 2.101 53.37 2.000 50.80 15.48 10.40 2.151 54.64 2.057 52.25 16.37 11.00 2.065 52.45 1.971 50.06 1.875 47.63 17.34 11.65 1.995 50.67 1.901 48.29 13.84 9.30 2.992 76.00 2.867 72.82 2.813 71.45 15.33 10.30 2.992 76.00 2.797 71.04 2.750 69.85 1 3 /2 88.90 12.95 2.750 69.85 2.625 66.68 2.562 65.07 19.27 23.51 15.80 2.548 64.72 2.423 61.54 2.313 58.75 24.85 16.70 2.480 62.99 2.356 59.82 25.37 17.05 2.440 61.98 2.315 58.80 2.188 55.58 16.22 10.90 3.476 88.29 3.351 85.12 3.313 84.15 16.37 4 101.60 11.00 3.476 88.29 3.351 85.12 17.26 11.60 3.428 87.07 3.303 83.90 3.250 82.55 19.94 13.40 3.340 84.84 3.215 81.66 3.125 79.38 18.97 12.75 3.958 100.53 3.833 97.36 3.813 96.85 20.09 13.50 3.920 99.57 3.795 96.39 3.688 93.68 1 4 /2 114.30 15.50 3.826 97.18 3.701 94.01 23.07 25.15 16.90 3.754 95.35 3.629 92.18 87.30 3.437 28.57 19.20 3.640 92.46 3.515 89.28 *ODs will vary depending on threads, material, and desired pressure rating. If OD dimensional restrictions apply, consult your local Halliburton representative to confirm ODs available for your application. Tubing Size in. mm

6/98

Page 2 of 2

Equipment and Products Specification Catalog

Completion Products
Subsurface Flow Controls
Through-Flowline Techniques
Table of Contents
Through-Flowline Techniques

6/98
CP3G

Through-Flowline Techniques
Description
The first through-flowline (TFL) equipment was developed and installed by Halliburton in the mid1960s. TFL techniques are applicable to almost any type of completion. Many operators have found that Halliburton’s TFL techniques provide the extra power needed to cut extreme paraffin deposits, the jet-action needed to wash out stubborn sand bridges, and many other practical advantages to help solve downhole maintenance problems.

TFL Technique Requirements
? pump to provide power at the surface ? fluid to convert the pump power to work ? circulation member to provide a complete circulation path ? tool string to perform the needed transport and service ? suitable conduit to carry tools and fluids

H Crossover Control Lines Safety Valve Landing Nipples Tubing-Retrievable Safety Valves

Operation
TFL service refers to a method of conducting downhole maintenance using hydraulic pressure and flow to provide the force required for tool movement and manipulation. If the wellhead is located on a sea bed, the flowline is used to provide access for the service tools. The TFL service system requires a circulation path going from a central service station into a well as deeply as possible, through a communication port, and then returning to the service station. This path may be through the tubing/ casing annulus, dual tubing strings, or tubing side string in single-or multiple-zone completions.
Wye-Block Select 20? Landing Nipple Foot Valve w/Standing Valve Seal Unit w/Straight Slot Locator Polished Bore Receptacle Permanent Packer No-Go Landing Nipple Ball Catcher Sub

Applications
? subsea completions ? directional wells drilling from offshore platforms ? deep, deviated holes where wireline is extremely difficult

Benefits
? added power for difficult downhole cleaning jobs ? economical and efficient ? full line of compatible equipment for many maintenance needs ? does not recognize vertical access from a rig to service subsea wells

Single-Zone, Dual-String TFL

6/98

CN03558

Page 1 of 1

Equipment and Products Specification Catalog

Completion Products
Subsurface Flow Controls
Subsurface Slickline Tools
Table of Contents
Slickline Service Tools Introduction Slickline Toolstring Introduction Rope Sockets Stems Jars Accelerators Knuckle Joints B Blind Box

6/98
CP3H

Slickline Service Tools Introduction
The famous Otis?-designed and manufactured slickline service tools have been the benchmark for the industry and are a requirement for all tool boxes worldwide. Known for dependable performance and low maintenance costs, these service tools can help reduce your total operating costs. As the OEM (original equipment manufacturer), Halliburton continues to provide high quality slickline service tools.

Standard Wireline Toolstring
Normal Tool OD in.
3

Thread Connection*
5

Fishneck OD in.

mm 19.05 25.40 31.75 38.10 47.63 50.80 63.50
/8" - 11 UNC /8" -11 UNC
5 15 15

mm 19.05 25.40 30.18 34.93 44.45 44.45 58.75

/4
1 1 7

0.750 1.000 1.188 1.375 1.750 1.750 2.313

1 1 /4 1 /2 1 /8 2 2 /2
1

/16" - 10 UNS /16" - 10 UNS /16" - 10 UNS

11 11 11

/16" - 10 UNS /16" - 10 UNS

*Other thread connections available

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Page 1 of 1

Slickline Tool String
A Halliburton Wireline Tool String attached to a wireline is used to furnish the mechanical force necessary for setting, pulling, or servicing subsurface equipment under pressure without killing the well. Tool strings are available in various ODs and component lengths designed to be compatible with various tubing sizes.

Wireline Socket

Stem

Jars

Knuckle Joint

Typical string of wireline tools
6/98 Page 1 of 1

CN03559

Running or Pulling Tool

Rope Sockets
Description
Halliburton Rope Sockets provide a means for connecting the wireline to the toolstring. Rope sockets are available in several types including knot and no knot types.

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

CN03560

Rope Socket

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Page 1 of 1

Stems
Description
Halliburton 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, stem is made up by combining 2, 3, or 5 ft (.61, .91, 1.22 m) lengths of standard stem. For high-pressure applications when additional weight is needed, lead or mallory-filled stems are available.

Ordering Information
Specify: nominal size; length: 2, 3, 5 ft (.61, .91, 1.525 m); solid or filled (Y/N–lead, mallory) Part number prefixes: 44B—solid stem, 44AO—filled stem

CN03561

Stem

6/98

Page 1 of 1

Jars
Description
Halliburton 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 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 utilization in the toolstring. Jar operation is monitored by a weight indicator.

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

CN03564

Mechanical Jar
6/98

Hydraulic Jar
Page 1 of 1

CN03565

Accelerators
Description
Halliburton Accelerators are used with and just above hydraulic jars for shallow, heavy 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.

Ordering Information
Specify: nominal size, stroke: 20in. or 30-in. (50.8 - 76.2 cm) – mechanical only Part number prefixes: 44AC— accelerator

Accelerator

6/98

CN03566

Page 1 of 1

Knuckle Joints
Description
Halliburton 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 toolstring. 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.

Ordering Information
Specify: nominal size Part number prefix: 45BO— knuckle Joint

CN03562

Knuckle Joint

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Page 1 of 1

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

Ordering Information
Specify: nominal size and thread, maximum OD, tubing size and weight Part number prefix: 44B—blind box

CN03563

Blind Box

6/98

Page 1 of 1

Equipment and Products Specification Catalog

Completion Products
Subsurface Flow Controls
Optional Toolstring Connection
Table of Contents
Quick Connect Toolstring Connection

6/98
CP3I

Quick Connect Toolstring Connection
Description
Prior to its extensive field history, the Halliburton 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 ?-in. (38.1 cm) 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 Quick Connect had retained full strength throughout the operation. Now Halliburton toolstring components and wireline service tools are available with integral Halliburton Quick Connects.

Features and Benefits
? spacing of load-bearing shoulders will not allow coupling to connect until full engagement of all shoulders occurs ? self washing feature minimizes sand buildup in the locking mechanism ? designed for manual operation; no special tools are required ? Quick Connect design ensures proper toolstring make-up ? reliable disconnect, even in sandy environment ? safe assembly/disassembly on location, no special tools required ? faster turnaround on location minimizes job time

Ordering Information
Specify: nominal size Part number prefixes: 44BQW— stem; 44AOQ—jars; 45BQ—knuckle joint
CN00756

Wireline Quick Connect Stem

CN00757

Mechanical Wireline Jar
6/98 Page 1 of 1

CN00757

Knuckle Joint Quick Connect

Equipment and Products Specification Catalog

Completion Products
Subsurface Flow Controls
Auxiliary Tools for Use with Slickline Toolstring
Table of Contents
Gauge Cutter and Swaging Tools Impression Tool Tubing Broach M Magnetic Fishing Tool G Fishing Socket P Wireline Grab Go-Devil

6/98
CP3J

Gauge Cutter and Swaging Tools
Description
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 gauge cutter knife (larger than OD of the control) is 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.

Ordering Information
Specify: nominal size and thread, maximum OD, tubing size and weight Part number prefixes: 65A— swaging tool, 65G—gauge cutter
CN03568 CN03567

Swaging Tool

Gauge Cutter

6/98

Page 1 of 1

Impression Tool
Description
Halliburton 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 indicate the type of tool necessary for the next operation.

Ordering Information
Specify: nominal size and thread, maximum OD, tubing size and weight Part number prefixes: 52C— impression tool

CN03569

Impression Tool

6/98

Page 1 of 1

Tubing Broach
Description
Halliburton Tubing Broach is made up of three major parts: (1) a mandrel; (2) a nut; and (3) a set of three spools. Spools are tapered and used to cut burrs in the tubing 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.

Ordering Information
Specify: nominal size and thread, maximum OD, tubing size and weight Part number prefixes: 65B— tubing broach

CN03570

Tubing Broach

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Page 1 of 1

M Magnetic Fishing Tool
Description
Halliburton M Magnetic Fishing Tool is designed to remove small particles of ferrous metals from the top of tools in the well.

Ordering Information
Specify: nominal size and thread Part number prefixes: 52MO— magnetic fishing tool

M Magnetic Fishing Tool

6/98

CN03571

Page 1 of 1

G Fishing Socket
Description
Halliburton G Fishing Socket was designed primarily to extract prongs with fishing necks from Halliburton subsurface equipment, such as the Halliburton PS Plug Choke.

Ordering Information
Specify: nominal size and thread Part number prefixes: 52GO—G Fishing Socket

6/98

CN03572

G Fishing Socket

Page 1 of 1

P Wireline Grab
Description
Halliburton P Wireline Grab is a fishing tool designed to extract broken wireline or cable from the tubing or casing.

Ordering Information
Specify: tubing size and weight, wireline toolstring nominal size and thread Part number prefixes: 52P— wireline grab

P Wireline Grab

6/98

CN03573

Page 1 of 1

Go-Devil
Description
Halliburton Go-Devil is a slotted stem with a fishing neck. A small strip of metal is pinned in the slot to inhibit the wireline from coming out. Its use is usually limited to fishing operations in which a wireline socket is inaccessible and the line must be cut. Go-Devils designed to cut the wireline at the wireline socket are also available.

Ordering Information
Specify: nominal size, length, style bottom (flat or angled) Part number prefix: 47AO

CN03574

Go-Devil

6/98

Page 1 of 1

Equipment and Products Specification Catalog

Completion Products
Subsurface Flow Controls
Running Tools
Table of Contents

X? and R? Running Tools RXN Running Tools SAFETYSET? Running Tools MR Running Tools

6/98
CP3K

X? and R? Running Tools
Description
Halliburton X? and R? Running Tools are used to set Halliburton X?, XN?, R?, RN?, and RQ Lock Mandrels in their respective Halliburton Landing Nipples. These tools are similar in design to a nipple locator, as dogs serve to locate the proper landing nipple and position the lock mandrel before locating and locking. By selecting the position of the running tool, the lock mandrel keys may be placed in the locating or retracted position.

Ordering Information
Specify: lock mandrel type and size, or running tool type and size (X?, R?) Part number prefix: all wireline running tools carry a numeric prefix 41 followed by the alpha characters defining the type of running tool as above; for example, 41XO is the prefix for X running tools

X? or R? Running Tool

6/98

CN03576

Page 1 of 1

RXN Running Tools
Description
Halliburton RXN Running Tools set Halliburton X, XN, R, RN, RPT?, and RQ Lock Mandrels in their respective landing nipples. This tool is generally used for installing tubing safety valves in the uppermost landing nipple. When a non-nogo lock is being run, the keys must be run in the locating position and the lock must be set in the first nipple in the bore of that lock size. The lock mandrel keys or no-go serve to locate the nipple. The tool gives a positive indication when the lock is fully set.

Ordering Information
Specify: lock mandrel type and size, or running tool type and size (RXN) Part number prefix: all wireline running tools carry a numeric prefix 41 followed by the alpha characters defining the type of running tool as above; for example, 41RXN is the prefix for RXN running tools

RXN Running Tool

6/98

CN03575

Page 1 of 1

SAFETYSET? Running Tools
Description
Halliburton SAFETYSET? Running Tools are used to set Halliburton Surface-Controlled, Wireline-Retrievable Safety Valves on Halliburton SAFETYSET Lock Mandrels. Two independent conditions must exist in sequence before the running tool will release the valve and lock. The SCSSV must be pressured open in order to activate the running tool. Only when the locking sleeve is locked in place will the running tool release. A running tool retrieved to the surface without the lock and valve indicates a functional valve securely locked in the landing nipple. For more information on Halliburton SAFETYSET lock systems, please refer to the Flow Control Completion Section of this catalog.

Ordering Information
Specify: lock mandrel type and size, or running tool type and size (SS) Part number prefix: all wireline running tools carry a numeric prefix 41 followed by the alpha characters defining the type of running tool as above; for example, 41SS is the prefix for SS running tools

SAFETYSET? Running Tool

CN03577

6/98

Page 1 of 1

MR Running Tools
Description
Halliburton MR Running Tools are used to run Halliburton XNS and RNS Soft Set Bomb Hangers. This running tool is designed to carry weight exceeding the 140-lb (63.50 kg) weight limit of hydraulic running tools as no preset force needs to be overcome. The lugs of the running tool hold the fish neck of the bomb hanger during the running of the bombs. The lugs are held in the expanded position by the core in the fully down position. When the bomb hanger locks into the nipple profile, the lock moves upward pushing the core up by means of the core extension. Once the core is pushed up, the lock-out lug can then be pushed into the core recess by the leaf spring, thus locking the core in the up position. In the up position, the core no longer holds the lugs out and the running tool is disengaged from the hanger. The bomb hanger and pressure gauges are left suspended in the well.

Ordering Information
Specify: lock mandrel type and size, or running tool type and size (MR) Part number prefix: all wireline running tools carry a numeric prefix 41 followed by the alpha characters defining the type of running tool as above; for example, 41MR is the prefix for MR running tools

MR Running Tool

6/98

CN03578

Page 1 of 1

Equipment and Products Specification Catalog

Completion Products
Subsurface Flow Controls
Pulling Tools
Table of Contents Internal Fishing Necks External Fishing Necks

6/98
CP3LTOC

Equipment and Products Specification Catalog

Completion Products
Subsurface Flow Controls
Pulling Tools
Internal Fishing Necks
Table of Contents
GS Pulling Tools GR Pulling Tools

6/98
CP3L1

GS Pulling Tools
Description
Halliburton GS Pulling Tools are used during wireline operations to unlock and pull a variety of subsurface controls with internal fishing necks, such as a Halliburton G Packoff Assembly. Designed to shear with a jarring down action, this pulling tool is utilized where excessive jarring upward is necessary to retrieve subsurface controls. In the running position, the dogs are designed to seat and lock in the internal recess of the mandrel being run until a pin is sheared by downward jarring. With this tool being a shear-down-to-release, it can be used in many cases as a running tool.

Fishing Neck

Shear Pin Cylinder Spring Spring Retainer Dog Spring Dog Retainer Cylinder Dogs

Ordering Information
Specify: lock mandrel type and size, pulling tool type and size (GS) Part number prefix: all wireline pulling tools carry a numeric prefix 40 followed by the alpha characters defining the type of pulling tool as above, for example, 40GS is the prefix for GS pulling tools

CN03580

Core

GS Pulling Tool

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Page 1 of 1

GR Pulling Tools
Description
Halliburton GR Pulling Tools are used during wireline operations to unlock and pull a variety of subsurface controls with internal fishing necks, including: Halliburton D Bridge Plugs, Halliburton X? and R? Lock Mandrels, Halliburton D Mandrels, and Halliburton D Collar Stops. Designed to shear with a jarring up action, this pulling tool is used during routine wireline operations on controls when shear-down is not possible. The Halliburton GR Pulling Tool is assembled by incorporating a Halliburton GS Pulling Tool with a Halliburton GU Shear-Up Adapter.

Ordering Information
Specify: lock mandrel type and size, pulling tool type and size (GR) Part number prefix: all wireline pulling tools carry a numeric prefix 40 followed by the alpha characters defining the type of pulling tool as above, for example, 40GR is the prefix for GR pulling tools

Fishing Neck

Shear PIn Dowel Pin Core Nut

Fishing Neck

Shear Pin Cylinder Spring Spring Retainer Dog Spring Dog Retainer Cylinder
CN03581

Dogs

Core

GR Pulling Tool

6/98

Page 1 of 1

Equipment and Products Specification Catalog

Completion Products
Subsurface Flow Controls
Pulling Tools
External Fishing Necks
Table of Contents
S Pulling Tools R Pulling Tools

6/98
CP3L2

S Pulling Tools
Description
Halliburton S Pulling Tools are designed for jobs in which extensive upward jarring is required to pull a bottomhole control. This tool is designed to pull any subsurface equipment with an external fishing neck. The core is manufactured in various lengths and may be changed in the field to accommodate the fishing necks of various controls. The tool is designed to shear and release by downward jarring. With this feature, the tool may also be used as a running tool to run collar stops, pack-off anchor stops, and various other Halliburton tools. Note: When used as a running tool, the core must be long enough to allow for upward travel after shearing the pin before the skirt is stopped by the equipment being run. It is this action that permits complete release of the running tool.

Ordering Information
Specify: lock mandrel type and size, pulling tool type and size (SB, SM) Part number prefix: all wireline pulling tools carry a numeric prefix 40 followed by the alpha characters defining the type of pulling tool as above, for example, 40SB or SM is the prefix for S pulling tools

CN03582

S Pulling Tool

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Page 1 of 1

R Pulling Tools
Description
Halliburton R Pulling Tools are designed for jobs in which extensive downward jarring is required. Tools use upward jarring to release when necessary and use line pull to cause the dogs to securely engage the fishing neck, reducing the possibility of the dogs slipping off the bottomhole control. The R Pulling Tool can be modified as follows: ? Halliburton RB Pulling Tool (R body with a B core) pulls Halliburton B, C, and W Lock Mandrel Assemblies and mandrel assemblies with full relative motion. ? Halliburton RS Pulling Tool (R body with S core) pulls Halliburton S Mandrel Assemblies. ? Halliburton RJ Pulling Tool (R body with J core) pulls all controls that do not have full relative motion.

Ordering Information
Specify: lock mandrel type and size, pulling tool type and size (RB, RS, RJ) Part number prefix: all wireline pulling tools carry a numeric prefix 40 followed by the alpha characters defining the type of pulling tool as above, for example, 40RB, RS, or RJ is the prefix for R pulling tools

CN03603

R Pulling Tool

6/98

Page 1 of 1

Equipment and Products Specification Catalog

Completion Products
Subsurface Flow Controls
Test Tools
Table of Contents
Selective Test Tools Non-Selective Test Tools

6/98
CP3M

Selective Test Tools
Description
Halliburton Selective Test Tools are used to test tubing, locate leaks, or set hydraulic-set packers. Designed to hold pressure from above, selective test tools may be set in compatible Halliburton X?, XN?, R?, or RN? Landing Nipples in the tubing string. Keys retracted, the tool is run to a point below the desired nipple; pulling up through the nipple releases the locking keys to set the tool. Pressure from above may then be applied.

Features and Benefits
? designed for high working pressure ? located in the lowest nipple, these tools move up the tubing with the test tool, reducing wireline trips

Ordering Information
Specify: nipple type and size Part number prefixes: 14XO—X test tool-selective, 14RO—R selective test tool

Selective Test Tool
6/98 Page 1 of 1

CN03584

Non-Selective Test Tools
Description
Halliburton Non-Selective Test Tools are designed to test the tubing string, set hydraulic packers and protect lower zones when circulating above perforations or through a Sliding Side-Door? circulating device. Designed to hold pressure from above by employing the use of a drop valve equalizing assembly, the nonselective test tools land in Halliburton No-Go landing nipples with compatible packing bores. When landed in the landing nipple, pressure from above is sealed by the drop, seal ring, and Veepacking. In order to retrieve by wireline, the drop is moved off seat with a pulling tool. This equalizes the pressure across the test tool, allowing it to be retrieved.

Features and Benefits
? ease of running, setting, and retrieving ? no-go OD on bottom of tool for positive location in landing nipple ? may be pumped into the well ? may be pumped out of the nipple with a sufficient flow from below the test tool ? designed for high-pressure ratings

Ordering Information
Specify: nipple type and size Part number prefixes: 14NO—N test tool-non selective

Non-Selective Test Tool

6/98

CN03583

Page 1 of 1

Equipment and Products Specification Catalog

Completion Products
Subsurface Flow Controls
Positioning Tools
Table of Contents
BO Positioning Tools BO Selective Positioning Tools X? Suspension Tools

6/98
CP3N

BO Positioning Tools
Description
Halliburton BO Positioning Tools are used to move the inner sleeve to its open or closed position in Halliburton Sliding Side-Door? Circulating Devices. Note: The Halliburton B Positioning Tool is not to be used for shifting Halliburton XXO or RRO Surface-Controlled Safety Valve Nipples. For these nipples, use the Halliburton XL or RL Shifting Tool. The positioning tool engages the recess in the upper (or lower) end of the inner sleeve to permit the sleeve to be shifted by a jarring action. The tool is designed to release itself only after the sleeve reaches its fully open or closed position. This automatic-releasing feature incorporates a releasing profile on the key itself that acts to compress the key spring and release the positioning tool. A shear pin is an added feature designed to release the tool in the event well conditions make it impossible to shift the sleeve. A set of positive keys is available for this tool to permit upward movement of the inner sleeve of one among several Sliding SideDoor circulating devices in one well bore. These keys do not have a releasing profile. The positioning tool pin must be sheared to release. Note: The Halliburton BO Positioning Tool will not pass through position number 1 of Halliburton S Landing Nipples.

Ordering Information
Specify: type and size of tool containing sleeve to be shifted, selective shifting required (Y/N) Part number prefixes: 42BO— standard BO shifting tool

BO Positioning Tool

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CN03585

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BO Selective Positioning Tools
Description
Halliburton BO Selective Positioning Tools are designed to selectively position Halliburton Sliding Side-Door inner sleeves only to the down position. These tools are designed so that one sleeve can be shifted to the down position at any level in the tubing string without shifting any other sleeve. This positioning tool is designed with dogs that serve to locate the proper Sliding Side-Door circulating device and release the springloaded keys to engage the profile in the inner sleeve. The tool is designed to release itself only after the sleeve reaches the full-down position. This automatic-release feature incorporates a releasing profile on the key that acts to compress the key spring and release the positioning tool. The tool can then be raised to the next Sliding Side-Door circulating device to position its sleeve down or return to the surface.

Ordering Information
Specify: type and size of tool containing sleeve to be shifted, selective shifting required (Y/N) Part number prefixes: 142BO— selective BO shifting tool

BO Selective Positioning Tool

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CN03586

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X? Suspension Tools
Description
Halliburton X? Suspension Tools are designed to hold Halliburton Positioning Tools in the shifting profile of the inner sleeve. When the inner sleeve is being shifted, the suspension tool is used to prevent the positioning tool from dropping out of the inner sleeve while the jars are being opened or closed. The suspension tool is designed to hold the entire weight of the toolstring.

Ordering Information
Specify: type and size of tool containing sleeve to be shifted, selective shifting required (Y/N) Part number prefixes: 42XO—X? suspension tool

X? Suspension Tool

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CN03587

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Equipment and Products Specification Catalog

Completion Products
Subsurface Flow Controls
Tubing Perforators and Bailers
Table of Contents
A Perforators M Sand Pump Bailers B Hydrostatic Bailers

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CP3O

A Perforators
Description
Halliburton A Perforators are mechanically operated and can be used with wireline (under pressure) to perforate both standard and heavyweight tubing.

Features and Benefits
? no explosives used, minimizing the possibility of perforating the casing ? safety-release mechanism designed to permit removing of perforator without perforating ? greater tubing penetration ? perforator designed to retract the punch and release automatically after perforating ? service performed by Halliburtontrained personnel

Applications
? to provide access to casing annulus to circulate or kill a well ? to bring in additional productive zones ? to install pack-off gas lift assemblies ? to permit production through tail pipe that has been plugged and cannot be opened by regular methods

Ordering Information
Specify: tubing size, weight, and grade; ID restrictions Part number prefix: 62AO

A Perforator

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CN03589

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M Sand Pump Bailers
Description
Halliburton M Sand Pump Bailers may be used to remove a sand bridge if one is encountered during normal wireline operations. The sand bailer consists of a piston encased in an outer cylinder. By working the wireline in the same manner as used to set certain subsurface controls (lightly jarring up and down), the bailer acts to pull sand into the cylinder to remove the sand bridge.

Ordering Information
Specify: nominal size, type (pump or hydrostatic), type bottom (ball or flapper–pump type only) Part number prefixes: 50MB— sand pump bailer

Features and Benefits
An assortment of bailer bottoms are available: ? flat bottom for soft, easy to bail sand ? chisel bottom for hard packed sand ? flapper bottom for bailing metal particles which are too large to pass the ball and seat

M Sand Pump Bailer
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CN03590

B Hydrostatic Bailers
Description
Halliburton B Hydrostatic Bailers are designed for use when the substance to be bailed cannot be removed by a pump-type bailer. This is sometimes the case when small metallic particles become lodged on top of the locking mandrel dogs of a subsurface control. The Halliburton B Hydrostatic Bailer is sealed at the surface and run into the tubing bore with the internal bailer chamber at atmospheric pressure. When the bailer reaches the object to be bailed, a few downward strokes of the wireline jars act to shear a small sealing disc and admit the well pressure and/or hydrostatic head (as well as the junk) into the bailer cylinder. A ball check valve acts to contain the junk as well as the well pressure until the bailer is retrieved. For large pieces of junk, a flapper bottom and junk basket are available. Note: The internal chamber pressure should always be bled off through the bailer release valve before the bailer bottom is broken off.

Ordering Information
Specify: nominal size, type (pump or hydrostatic), type bottom (ball or flapper–pump type only) Part number prefixes: 50BO— hydrostatic bailer

B Hydrostatic Bailer
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CN03591

Equipment and Products Specification Catalog

Completion Products
Subsurface Flow Controls
Slickline Service Equipment
Table of Contents
Slickline Service Equipment Introduction Slickline Skid Units and Trucks Surface Service Equipment

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CP3P

Slickline Service Equipment Introduction
The high quality of Halliburton's slickline services depends upon the capabilities of its service tools and equipment; therefore, we are committed to designing and manufacturing the most sophisticated tools in the industry. Our success in this endeavor has allowed us to remain the leader of the slickline service industry. Though our decades of experience and global presence, Halliburton has continued to offer the industry the most complete line of slickline service equipment and tools.

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Slickline Skid Units and Trucks
Halliburton designs and manufactures top quality skid-based units for offshore operations and trucks for land operations. The units are known worldwide for their user-focused design, providing the right mix of operator-friendly components to make both specialized and standard operations more productive. For more detailed information, please contact your local Halliburton representative.

Advanced Slickline Skid Unit

Slickline truck

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Surface Service Equipment
Halliburton's wellhead pressurecontrol equipment provides a safe and highly productive service operation. Unmatched equipment quality backed by extensive training and maintenance instruction has made Halliburton the industry's premier provider of this type of equipment. For more detailed information, please contact your local Halliburton representative.
Options: ? Slickline Grease Head ? Liquid Chamber ? Lubricator Control (Purge) Valve Hydraulic Stuffing Box (16-in. Sheave) Quick Union

Upper Lubricator Section

Quick Union Option: ? Middle Lubricator Middle Lubricator Section Lubricator Pick Up Clamp

Quick Union

Lower Lubricator Section Option: ? Pump-In Sub Quick Union Options: ? Wireline Valve Dual (Manual) ? Wireline Valve Single (Hydraulic) ? Wireline Valve Dual (Hydraulic) Wireline Valve Single (Manual)

Options: ? Lubricator Safety Valve ? Pin End Assembly Flanged Tree Connection

Wellhead Pressure-Control Equipment
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CN03594


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