subsurface prong and plug assemblies

Subsurface Flow C

ontrol SystemsSubsurface Flow Control SystemsHalliburton subsurface flow control systems are 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 and maintains strict standards to help ensure excellence and dependability in our subsurface flow control systems.

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, chokes, tubing stops, packoffs, pressure and temperature gauge hangers, and other associated equipment.

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.

HA

L397

54Subsurface Flow Control Systems 8-1

Typical Equipment Installation

API Certification 14L-00018-2 Subsurface Flow Control Systems

Landing Nipple/Lock Mandrel Selection Guide

Nipple Profile

Landing Nipple Features and Applications

Profile Available in Noted Tools Part Number Prefix for Applicable Tools

Sel

ectiv

e B

y R

unni

ng T

ool

Top

No-

Go

Bot

tom

No-

Go

Ser

ies

of N

ippl

es C

an B

e U

sed

in S

ingl

e Tu

bing

Stri

ng

Wel

lhea

d Pl

ug A

pplic

atio

ns

Hea

vy-W

eigh

t Tu

bing

App

licat

ions

SAF

ETY

SE

T C

ompa

tible

Land

ing

Nip

ple

Saf

ety

Valv

e La

ndin

g N

ippl

e

Slid

ing

Sid

e-D

oor

Circ

ulat

ing

Dev

ice

Tubi

ng-R

etrie

vabl

e S

afet

y Va

lve

Tubi

ng S

eal D

ivid

er

AP

I Mon

ogra

mm

ed*

Land

ing

Nip

ple

Lock

Man

drel

Run

ning

Too

l

Pulli

ng T

ool

Equ

aliz

ing

Sub

Equa

lizin

g P

rong

/Plu

g A

ssem

bly

X 11X 10XO

41XO 40GR 20XO 24PXX 711X 710XO

XN 11XN 10XN

41XO 40GR 20XO 24PXX 711XN 710XN

R 11R 10RO

41RO 40GR 20RO 24PRR 711R 710RO

RN 11RN 10RN

41RO 40GR 20RO 24PRR 711RN 710RN

RQ

SVLN or TRSV

710RQ 41RXN 40GR

710SS 41SS/41UP40GR w/144SS

FBN 11FBN 10FBN

41FBN 40GR 20FBN 24FBN 711FBN 710FBN

RPT

11RPT 10RPT

41RXN 40GR 20RPT24RPT

711RPT 710RPT

SVLN or TRSV

710RPV

710SSA 41SS/41UP40GR w/144SS 20RO

SRH 711SRH 710SRH/21SRH 41SRH 40GR

SRP Wellhead 710SRP21SRP 41SRP 40GR

= Standard Feature = Non-Standard Capability*Part Number Prefix 710 or 711 indicates API monogrammed assembly; items with a prefix 10 or 11 are not API monogrammed.Subsurface Flow Control Systems 8-3

Landing Nipples and Lock Mandrels

This section describes Halliburton landing nipples and lock mandrels as well as lock mandrels for wells without landing nipples.

Selective by Running Tool

Halliburton selective by running tool landing nipples and lock mandrels consist of Otis X and R series landing nipples and lock mandrels. Otis XN and RN no-go landing nipples and no-go lock mandrels are also available.

Otis X and R Landing Nipples and Lock Mandrels

Halliburton Otis 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. These landing nipples feature common internal profiles making them universal. The Otis X landing nipple is used in standard weight tubing. The Otis R landing nipple is typically used with heavyweight tubing.

The completion can include 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 Otis 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.

Otis 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 Otis X or R landing nipples. These landing nipples have the same packing bore ID for a particular tubing size and weight. Otis X and XN landing nipples are designed for use with standard weight tubing. Otis R and RN landing nipples are designed for use with heavyweight tubing. (The N designates no-go nipples.)

Otis X Landing Nipple and Lock Mandrel

HA

L397

53H

AL39

7528-4 Subsurface Flow Control Systems

Otis R Landing Nipple and Lock Mandrel

Applications Gauge hangers for bottomhole pressure/temperature

surveys Positive locator for straddle systems Plugging under pressure Almost unlimited locations for setting and locking

subsurface flow controls

Features Landing Nipples

Large bore for minimum restriction Universal nipple with one internal profile

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

Optional Holddown* Interference holddown for smaller locks Shear pin holddown for larger locks

*The optional holddown feature is recommended for subsurface safety valve installations. Both features provide additional locking integrity to withstand rigorous well conditions.

Otis X and XN Landing Nipples and Lock Mandrels

TubingFor Standard Tubing Weights

Lock Mandrel IDX

Profile XNProfileSize Weight ID Drift Packing Bore Packing Bore No-Go ID

in. mm lb/ft kg/m in. mm in. mm in. mm in. mm in. mm in. mm

1.660 42.162.3 3.42

1.380 35.05 1.286 32.66 1.250 31.75 1.250 31.75 1.135 28.83 0.62 15.752.4 3.57

1.900 48.26

2.4 3.57 1.660 42.16

1.516 38.51 1.500 38.10 1.500 38.10 1.448 36.78 0.75 19.052.76 4.111.610 40.89

2.9 4.32

2.063 52.40 3.25 4.84 1.751 44.48 1.657 42.09 1.625 41.28 1.625 41.28 1.536 39.01 0.75 19.05

2 3/8 60.334.6 6.85

1.995 50.67 1.901 48.29 1.875 47.63 1.875 47.63 1.791 45.49 1.00 25.404.7 6.99

2 7/8 73.036.4 9.52

2.441 62.00 2.347 59.61 2.313 58.75 2.313 58.75 2.205 56.01 1.38 35.056.5 9.67

3 1/2 88.909.3 13.84 2.992 76.00 2.867 72.82 2.813 71.45 2.813 71.45 2.666 67.72

1.75 44.4510.2 15.18 2.922 74.22 2.797 71.04 2.750 69.85 2.750 69.85 2.635 66.93

4 101.60 11 16.37 3.476 88.29 3.351 85.10 3.313 84.15 3.313 84.15 3.135 79.63 2.12 53.85

4 1/2 114.30 12.75 18.97 3.958 100.53 3.833 97.36 3.813 96.85 3.813 96.85 3.725 94.62 2.62 66.55

5 127.00 13 19.35 4.494 114.14 4.369 110.97 4.313 109.55 4.313 109.55 3.987 101.27 2.62 66.55

5 1/2 139.70 17 25.30 4.892 124.26 4.767 121.08 4.562 115.87 4.562 115.87 4.455 113.16 3.12 79.25Subsurface Flow Control Systems 8-5

Benefits Landing Nipples

Versatility helps reduce completion and production maintenance costs

Simple operation Multiple options when running, setting, or

retrieving subsurface flow controls

Lock Mandrels 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 holddown feature for high flow rates and

safety valve installations

Fishing Neck

Expander Mandrel

Double-Acting Spring

Locking Keys

Packing

No-Go Equalizing Sub

Otis RN No-Go Landing

HAL

3975

7

Otis XN Landing Nipple and Lock Mandrel

Fishing Neck

Expander Mandrel


Locking Keys

Packing

No-Go Equalizing Sub

HA

L397


Nipple and Lock Mandrel

Otis R and RN Landing Nipples and Lock Mandrels

TubingFor Heavy Tubing Weights

Lock MandrelIDR

ProfileBore

RN Profile

Size Weight ID Drift Packing Bore No-Go ID

in. mm lb/ft kg/m in. mm in. mm in. mm in. mm in. mm in. mm

1.900 48.26 3.64 5.42 1.500 38.10 1.406 35.71 1.375 34.93 1.375 34.93 1.250 31.75 0.62 15.75

2 3/8 60.33

5.3 7.89 1.939 49.25 1.845 46.86 1.781 45.24 1.781 45.24 1.640 41.66 0.88 22.35

5.95 8.85 1.867 47.42 1.773 45.031.710 43.43 1.710 43.43 1.560 39.62 0.75 19.05

6.2 9.23 1.853 47.07 1.759 44.68

7.7 11.46 1.703 43.26 1.609 40.87 1.500 38.10 1.500 38.10 1.345 34.16 0.62 15.75

2 7/8 73.03

7.9 11.76 2.323 59.00 2.229 56.62 2.188 55.58 2.188 55.58 2.010 51.05 1.12 28.45

8.7 12.95 2.259 57.38 2.165 54.992.125 53.98 2.125 53.98 1.937 49.20 0.88 22.35

8.9 13.24 2.243 56.97 2.149 54.58

9.5 14.14 2.195 55.75 2.101 53.372.000 50.80 2.000 50.80 1.881 47.78 0.88 22.35

10.4 15.48 2.151 54.64 2.057 52.25

11 16.37 2.065 52.45 1.971 50.061.875 47.03 1.875 47.03 1.716 43.59 0.88 22.35

11.65 17.34 1.995 50.67 1.901 48.29

3 1/2 88.90

12.95 19.27 2.750 69.85 2.625 66.68 2.562 65.07 2.562 65.07 2.329 59.16 1.38 35.05

15.8 23.51 2.548 64.72 2.423 61.542.313 58.75 2.313 58.75 2.131 54.13 1.12 28.45

16.7 24.85 2.480 62.99 2.355 59.82

17.05 25.37 2.440 61.98 2.315 58.80 2.188 55.58 2.188 55.58 2.010 51.05 1.12 28.45

4 101.6011.6 17.26 3.428 87.08 3.303 83.90 3.250 82.55 3.250 82.55 3.088 78.44 1.94 49.28

13.4 19.94 3.340 84.84 3.215 81.66 3.125 79.38 3.125 79.38 2.907 73.84 1.94 49.28

4 1/2 114.30

12.6 18.75 3.958 100.53 3.833 97.36 3.813 96.85 3.813 96.85 3.725 94.62 2.12 53.85

13.5 20.09 3.920 99.57 3.795 96.393.688 93.68 3.688 93.68 3.456 87.78 2.38 60.45

3.750 95.25 3.750 95.25 N/A 2.12 53.85

15.5 23.07 3.826 97.18 3.701 94.01 3.688 93.68 3.688 93.68 3.456 87.78 2.38 60.45

16.9 25.50 3.754 95.35 3.629 92.18 3.437 87.30 3.437 87.30 3.260 82.80 1.94 49.28

17 25.30 3.740 95.00 3.615 91.82 3.63 92.20 3.63 92.20 N/A 1.94 49.28

19.2 28.57 3.640 92.46 3.515 89.28 3.437 87.30 3.437 87.30 3.260 82.80 1.94 49.28

5 127.0015 22.32 4.408 111.96 4.283 108.79 4.125 104.78 4.125 104.78 3.912 99.39 2.75 69.85

18 26.79 4.276 108.61 4.151 105.44 4.000 101.60 4.000 101.60 3.748 95.20 2.38 60.45

5 1/2 139.70

17 25.30 4.892 124.26 4.767 121.084.562 115.87 4.562 115.87 4.445 113.16 2.85 72.39

20 29.76 4.778 121.36 4.653 118.19

23 34.23 4.670 118.62 4.545 115.44 4.313 109.55 4.313 109.55 3.987 101.27 2.62 66.55

6 152.4015 22.32 5.524 140.31 5.399 137.13

5.250 133.35 5.250 133.35 5.018 127.51 3.50 88.9018 26.79 5.424 137.77 5.299 134.59

6 5/8 168.2824 35.72 5.921 150.39 5.795 147.22

5.625 142.88 5.625 142.88 5.500 139.70 3.50 88.9028 41.67 5.791 147.09 5.666 143.92

7 177.80

17 25.30 6.538 166.07 6.431 163.35

5.963 151.46 5.963 151.46 5.770 146.553.75 95.25

20 29.76 6.456 163.98 6.331 160.81

23 34.23 6.366 161.70 6.241 158.52

26 38.69 6.276 159.41 6.151 156.24

29 43.16 6.184 157.07 6.059 153.90

32 47.62 6.094 154.79 5.969 151.61

35 52.09 6.004 152.50 5.879 149.33 5.875 149.23 5.875 149.23 5.750 146.05

Ordering InformationSpecify: 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 holddown (interference or shear pin on lock Subsurface Flow Control Systems 8-7

mandrel); special material and elastomer requirements, if applicable.Part Number Prefixes: 11X, XNlanding nipple; 711X, XNAPI/monogrammed landing nipple; 10XO, XNlock mandrel; 710XO, XNAPI/monogrammed lock mandrel; 11R, RNlanding nipple; 711R, RNAPI/monogrammed landing nipple; 10RO, RNlock mandrel; 710RO, RNAPI/monogrammed lock mandrel

FBN Full Bore Landing Nipple and Lock Mandrel System

The FBN full bore landing nipple and lock mandrel system allows an indefinite number of identical landing nipples to be installed in a tubing string. 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 mandrels expanding seal element and the landing nipples 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 preset in higher profiles because of the interference fit packing.

Applications Monobore well completions Wells/fields/conditions in which problems exist for

interference-type seals High-angle/horizontal wells

Features 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 Selective lock location Element above keys

Fishing Neck

Full Bore Nipple

Expandable Element


No-Go Locking Keys

Equalizing Sub

Plug Cap

HA

L823

8

FBN Full Bore Landing Nipple and 8-8 Subsurface Flow Control Systems

Lock Mandrel System

Benefits Field-proven Any number of the identical nipples can be run 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 sealbore landing nipples incompatible with some completion designs

Expandable element creates a seal downhole Keys provide positive location in nipple

FBN Full Bore Landing Nipple and Lock Mandrel System

Tubing/Casing Size

Casing Weight Nominal ID Drift

Standard Nipple ID

Minimum FBN Nipple ID

FBN Nipple Hone Bore

Lock Mandrel OD

Pressure from

Above

Pressure from

Below

Max. Temp

in. mm lb/ft kg/m in. mm in. mm in. mm in. mm in. mm in. mm psi psi F

3 1/2 88.909.30 13.84 2.992 76.00 2.867 72.82 2.813 71.45 2.880 73.15 2.900 73.66 2.78 70.61 6,730 6,730 300

10.2 15.18 2.922 74.22 2.797 71.04 2.750 69.85 2.810 71.37 2.830 71.88 2.73 69.34 10,000 10,000 300

4 1/2 114.30

12.60 18.75 3.958 100.53 3.833 97.36 3.813 96.85 3.840 97.54 3.920 99.57 3.79 96.27 6,400 6,400 300

13.5 20.09 3.922 99.62 3.795 96.39 3.750 95.25 3.810 96.77 3.830 97.28 3.73 94.74 10,000 10,000 300

16.90 25.15 3.740 95.00 3.615 91.82 3.688 93.688 3.630 92.20 3.710 94.23 3.60 91.44 10,000 6,400 300

5 1/2 139.7020.00 29.76 4.788 121.36 4.653 118.19 4.562 115.87 4.665 118.49 4.685 119.00 4.54 115.32 9,290 9,190 300

23.00 34.23 4.670 118.62 4.545 115.44 4.437 112.70 4.562 115.87 4.582 116.38 4.42 112.27 6,400 8,360 300

7 177.8029.00 43.16 6.184 157.01 6.059 153.90 5.963 151.46 6.070 154.18 6.120 155.45 5.94 150.88 9,780 7,500 300

32.00 47.62 6.094 154.79 5.969 151.61 5.963 151.46 5.980 151.89 6.000 152.40 5.86 148.84 8,529 7,526 300

Ordering InformationSpecify: tubing size, weight, grade, and thread connections; service environment (standard, %H2S, %CO2); temperature; pressure rating.Part Number Prefixes: 10FBNlock mandrels, 710FBNlock mandrels, 11FBNlanding nipples, 711FBNlanding nipples, 20FBNequalizing valves, 24FBNequalizing prong/plug assemblySubsurface Flow Control Systems 8-9

No-Go Locks and Nipples

Otis RPT No-Go Landing Nipple and Lock Mandrel SystemsThe Halliburton Otis RPT no-go landing nipple system provides a means of running a series of positive location landing nipples in a tubing string with minimum restriction. Otis RPT no-go landing nipples are designed to accept Otis RPT and RPTS lock mandrels with a rated working pressure of 10,000 psi (690 bar) differential and greater from above and below.

The Otis RPT and RPTS no-go lock mandrels locate on top of the nipples polished bore; therefore, there are no secondary restrictions normally associated with bottom no-go profiles. This feature makes Otis RPT systems well suited for high-pressure, high-volume large bore completions. Otis RPT and RPTS lock mandrels in any given size range are designed to use the same running tool and pulling tool.

Some of the original RPT series lock mandrels were designed with large no-go profiles that were not compatible with the 1/16-in. sealbore ID reductions between nipples that are currently available. For these sizes, the RPTS series of locks was developed. All RPTS lock mandrels incorporate no-go profiles that allow a 1/16-in. sealbore stagger in the completion design. The reduction in no-go OD on theRPTS lock mandrel does not have any affect on theirpressure rating.

Applications High-pressure, high-temperature large bore completions Running a series of no-go nipples in a tubing string when

positive location and minimal ID reduction are required

Features Large bore All RPTS locks and most RPT locks will allow a 1/16-in.

stagger in nipple bore sizes Lock mandrel locates on top of the nipples polished bore Landing nipples can accept Otis RPT and RPTS lock

mandrels with a rated working pressure of 10,000 psi (690 bar) differential from above and below

A series of profile IDs are established for common tubing strings by size and weight

The reduction in no-go OD on the RPTS lock mandrel does not have any effect on their pressure rating

Benefits No secondary restrictions normally associated with

bottom no-go profiles Lock mandrels in a particular size range use the same

running tool and pulling tool

Fishing Neck

Otis RPTLanding Nipple

High-PressureLocking Keys

No-Go

High-PressurePacking Stack

Equalizing Valve

Plug Cap

HA

L121

81

Otis RPT No-Go Landing Nipple With RPT Plug8-10 Subsurface Flow Control Systems

Otis RPT Profile and Lock Dimensions

Tubing SizeNipple Profile Lock Mandrel

Sealbore (Minimum ID) ID OD

in. mm in. mm in. mm in. mm

2 3/8 60.33

1.500 38.10

0.75 19.05

1.560 39.621.625 41.28 1.685 42.801.781 45.24 1.841 46.761.875 47.63 1.935 49.152.000 50.80 2.060 52.322.125 53.98 2.185 55.5

2 7/8 73.03

2.000 50.80

1.12 28.45

2.060 52.322.125 53.98 2.185 55.52.188 55.58 2.248 57.102.313 58.75 2.373 60.272.482 63.04 2.542 64.57

3 1/2 88.90

2.562 65.07

1.50 38.10

2.622 66.62.650 67.31 2.710 68.832.750 69.85 2.810 71.372.810 71.45 2.860 72.642.875 73.03 2.935 74.55

4 - 4 1/2 101.6-114.3

3.000 76.201.75 44.45

3.060 77.723.125 79.38 3.210 81.533.125 79.38

1.94 49.283.210 81.53

3.313 84.15 3.395 86.23

4 1/2 - 5 114.3-127

3.437 87.30

1.94 49.28

3.520 89.413.562 90.47 3.650 92.713.688 93.68 3.770* 95.763.750 95.25 3.807 96.703.813 96.85 3.895 98.934.000 101.60 4.090 103.89

5 1/2 139.70

4.188 106.38

2.75 69.85

4.270* 108.464.250 107.95 4.332* 110.034.313 109.55 4.395 111.634.437 112.70 4.520* 114.814.500 114.30 4.550 115.574.562 115.87 4.650 118.114.688 119.08 4.760* 120.904.688 119.08

3.12 79.254.760* 120.90

4.750 120.65 4.825 122.564.813 122.25 4.890 124.21

7 177.80

5.250 133.35

3.68 93.47

5.334 135.485.500 139.70 5.585 141.865.625 142.88 5.710 145.035.750 146.05 5.840* 148.345.813 147.65 5.890* 149.615.875 149.23 5.940 150.885.963 151.46 6.025 153.046.125 155.58 6.180 156.976.250 158.75 6.330 160.78

*No-go OD for these RPT lock sizes may not be compatible with next larger size nipple. Special OD tools are available. These use part number prefix 10RPTS and 710RPTS.Ordering InformationSpecify: 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: 11RPTlanding nipple, 711RPTAPI monogrammed landing nipple, 10RPTlock mandrel, 710RPTAPI monogrammed lock mandrel. 10RPTS-lock mandrel, 710RPTS-API monogrammed lock mandrelSubsurface Flow Control Systems 8-11

No-Go Locks for Safety Valves

The no-go nipple system allows positive placement of wireline safety valves, retrievable in predetermined nipples used in the completion. This section outlines the Halliburton Otis RQ, Otis RPV, and Otis SAFETYSET no-go lock mandrel/nipple system.

Otis RQ No-Go Lock Mandrels

RQ lock mandrels are top no-go lock mandrels designed to land and lock in Otis RQ profiles in safety valve landing nipples and tubing retrievable safety valves.

Otis RPV No-Go Lock MandrelRPV lock mandrels are top no-go lock mandrels designed to land and lock in Otis RPT landing nipple profiles.

Applications Designed for subsurface safety valve (SSSV) applications RQ mandrels are only used with Otis RQ landing nipple

profiles in SSSV equipment RPV mandrels are only used with Otis RPT landing

nipple profiles

Features Matching nonhelical teeth inside the keys and on OD of

expander sleeve provide primary holddown. Shear pin or interference fit secondary holddown assures

the lock will remain in place under extreme flowing conditions.

RQ mandrel features removable no-go ring RPV mandrel no-go takes all the load

Benefits Positive no-go location prevents wireline misruns Installed and retrieved by standard slickline methods Redundant holddown features Teeth engage and become primary holddown when lock

has pressure differential from below

Options Anti-vibration feature available

Fishing Neck

Double-ActingSpring

Locking Keys

Removable No-GoShoulder

Packing

Otis RQ No-Go Lock Mandrel

HAL

8490

Otis RPV No-Go Lock Mandrel

HAL

3926


ngOtis SAFETYSET Lock Mandrel SystemThe Halliburton Otis SAFETYSET lock mandrel system is a drive-down, jar-up-to-set, no-go-type system designed specifically for surface-controlled subsurface safety valve (SCSSV) applications. This system consists of an Otis 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 drive-down 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 surface by requiring two independent conditions to exist before the running tool will release. The SCSSV must be pressured open for lock keys to expand. Only when the locking sleeve is locked in place will the running tool release. A running tool retrieved to surface without the lock and valve indicates a functional valve securely locked into the landing nipple.

Applications Specifically designed for slickline-

retrievable, SCSSV applications High flow rates

Features No shear pins in the running tool Running tool can be released only

after lock mandrel locks (locking keys fully extended into the profile) and SCSSV is operable

Large ID Locking sleeve locks in the direction

Optimum pressure rating design on lock mandrel

Anti-vibration ring in lock mandrel

Benefits 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

Helps avoid possible flow-out of the subsurface safety valves to surface

Minimal metal-to-metal abrasion from vibration

Lock system protected from unintentional unlocking by slickline tools passing through the ID

Options Designs available for all Otis RQ

and Otis RPT landing nipple profiles.

Models designed to land and lock in any safety valve landing nipple if there is a no-go

UP running tool allows setting staggered and non-staggered sealbore safety valves

Ordering InformationSpecify: 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: 710SSAPI monogrammed lock mandrel to fit RQ profile, 710SSAto fit RPT profile

Fishing Neck

Anti-Vibration Ri

Locking KeysLocking Sleeve

No-Go Shoulder

Packing

Otis SAFETYSETNo-Go Lock Mandrel

HA

L220


of flow

SRH PlugHalliburton SRH high-pressure plugs are designed for use in extreme temperature and pressure environments. The SRH plug uses the top no-go location and is designed such that pressure from above and below is held by key/nipple engagement. Special non-elastomer V-packing stacks are gas-tight qualified up to 25,000 psi at 450F.

Features Robust and simple uni-body style plug with one moving

part (key expander) HP/HT non-elastomer seal stack V0 qualified 3 45 loading surfaces on key above and below,

maximizing key bearing area Up to 25,000 psi pressure rating at 450F Metal-to-metal (MTM) shear plug for equalizing in

pump-through type Holddown feature locks plug in the set position

Benefits Uni-body design eliminates internal leak paths Bubble-tight seal performance at ultra-high pressures

and temperatures Key/nipple profile configuration provides ultra-high

pressure capability while minimizing component stress levels

All seals are inert to all known well fluids and are unaffected by rapid gas decompression

Pump-through plug type allows for well kill while installed in the nipple profile

Pre-install capabilities of the positive type plug in the completion helps eliminate the need to run wireline to set the plug body

Running tool does not release until lock is correctly and fully set

Pulling tool will not engage unless pressure equalizes across plug

SRH plugs are available in pump-through and positive type. The pump-through type incorporates a poppet which has a metal-to-metal seal backed up by a HP/HT non-elastomer V-packing stack. A MTM knockout plug is provided for equalization. A test prong can be run to convert the pump-through plug into a positive plug for testing from above.

The two-trip prong-type plug is a positive plug with no pump-through feature. The packing on the prong uses the

The prong is pressure balanced for easy removal under high-pressure differential to allow for equalizing prior to retrieving the plug.

HA

L365

60

SRHPositive Plug

SRH Pump-Through Plugwith Positive Prong Installed

HAL

3782


same type HP/HT V-packing stacks as used on the plug body.

Wellhead Plugs and Backpressure Valves

SRP Wellhead PlugsHalliburtons 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.

SRP Wellhead Backpressure ValvesThe SRP wellhead backpressure valve provides pump-in well kill capability while providing complete well control. It features the same compact design and multiple seal backup available in the SRP wellhead plug. A test prong is also available to allow testing of the hanger and tree from above. The SRP backpressure valve incorporates two equalizing methods and cannot be released prior to full equalization of pressure. Both the SRP wellhead backpressure valve and the SRP wellhead plug utilize the same service tools for running and retrieving.

SSP Wellhead PlugsHalliburton SSP wellhead plugs feature a primary metal-to-metal seal and a composite packing stack. These plugs are typically rated for 10,000 psi (15,000 psi test) pressures from above and below. The wellhead plug features demonstrate the benefits of Halliburton design expertise and field experience.

Applications Conventional tubing hangers Platform horizontal trees Subsea horizontal trees

Features Dedicated wellhead design Internal fish neck Top no-go locator Single or multiple seal stacks Equalizing option High-pressure seal stack

Benefits Helps reduce cost of tubing hanger, tree housing,

and services Minimizes service riser dimension/cost Helps save time and money using slickline to install Field-proven technology Compatible with other Halliburton downhole

landing nipples

Ordering InformationSpecify: packing bore, pressure rating, special material requirements, service

SRP WellheadPlug

SRP WellheadBackpressure Valve (with Test Prong)

SSP Wellhead Plug

Subsea Horizontal Tree

HA

L143

00

HA

L831

0

HAL

8308

HA

L140


environment. Part Number Prefixes: 10 and 710SRP for Wellhead Plugs; 21SRP for Backpressure Valve; 14 SRP for test prongs for BPV; 710SSP for MTM seal

Through-Tubing Plugging Equipment

Plugs Set in Nipples

Otis One-Trip Plug AssembliesNote: Not recommended for use where debris can build up in or above the plug system. Please refer to the prong-type plug systems for a debris-tolerant solution.

Otis one-trip plug assemblies consist of a lock mandrel, an equalizing sub-assembly, and a plug cap. These plugs are run and pulled on slickline to plug the tubing for various operations.

Otis one-trip plugs are available for all Otis key-type locks. This style plug is also available for FBN locks.

One-trip plug 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. Only one slickline trip is required to run or pull the plug.

Applications Normal plugging operations Setting and testing packers Removing the wellhead Testing tubing Separating zones during production tests or data

gathering Assemblies for X, XN, R, RX, RPT, and FBN locks

and nipples

Features Balanced equalizing system Fluid bypass during running or retrieving operations

Benefits Requires only one slickline trip to run or pull Holds pressure from below or above

Note: One-trip plug requires lock mandrel, equalizing valve, and valve cap, each ordered separately.

Ordering InformationSpecify: 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 Prefix: 20XO, RO, RPT, FBN-equalizing valve for one-time plug.

Fishing Neck

Lock Mandrel

Equalizing Sub

Valve Cap

Otis XX Plug Assembly

HA

L849


20X, R-valve cap for one-trip plug.

Otis Prong-Type Plug Assemblies

Otis prong-type plug assemblies consist of a lock mandrel and a prong equalizing housing. Plugs are run and pulled on slickline and used to plug the tubing for various operations, including setting and testing packers and testing tubing.

Otis prong-type plugs are made available for all Otis key-type lock mandrels.

Otis plug 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. Two slickline trips are required to run or pull the plug.

Applications Setting and testing packers High-pressure conditions Removing the wellhead Separating zones during production tests or data-

gathering For use where sediment might collect on the plug Available for X, XN, RN, RPT, and FBN locks

and nipples

Features 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

V-packing seals on equalizing prong

Benefits Set and retrieved on slickline Holds pressure from below or above Dependable sealing in extreme environments Compatible with other Halliburton downhole

landing nipples

Ordering InformationSpecify: 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 Prefix: 24PXX, PRR, RPT, FBN

Otis PRR Plug Assembly

HA

L392


Otis XR Pump-Through Plug Assemblies

Halliburton Otis 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. Otis XR pump-through plugs can be made up on Otis X, XN, R, RN, RPT or FBN lock mandrels and installed in Otis X, XN, R, RN, RPT, or FBN landing nipples.

Applications Killing the well Removing the wellhead Isolating high-pressure zones from lower pressure zones

Features Holds pressure differential from below only Uses a ball-and-seat assembly

Benefits Requires only one slickline trip to run or pull the plug Allows kill fluids to be pumped through the plug

Ordering InformationSpecify: 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,

Fishing Neck

Lock Mandrel

Expander Mandrel

Equalizing Sub

Ball and Seat

Spring

Valve Housing

Otis XR Pump-Through Plug

Assembly

HA

L849


if applicable.Part Number Prefix: 21XRpump-through plug

Pump-Open Plugs

The 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.

These plugs consist of a plug body, plug cap, and pump open valve. They are designed to be run with equalizing valves and are available for all Otis key-type lock mandrels.

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

Features Only one moving part Nontortuous flow path Balanced flow areas

Benefits Provides reliable, economical performance Can be used with virtually any lock mandrel 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, RPOpump open plug

O-ring Seal

Flow Ports

Release Pins

Pump-Open Valve

Plug Body

Plug Cap

Pump-OpenPlug

HA

L117


Equalizing Subs

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

Otis XH Equalizing Subs

Halliburton Otis XH equalizing subs feature button-type valves with a no-go OD that holds pressure from below only. They are designed to be used with Otis X lock mandrels to allow ambient and pressure-differential safety valves to be reopened against differential pressures without being pulled.

The Otis XH equalizing valve has a flow bore compatible with the subsurface flow control bore.

Applications Used with Otis X lock mandrels Allow ambient and pressure-

differential safety valves to be reopened against differential pressures without being pulled

Suitable for H2S and standard service

Features Button valve No-go OD Holds pressure from below only

Benefits Ambient and pressure-differential

safety valves can be reopened without being pulled

Otis X and R RPT and FBN Equalizing Subs

These Otis equalizing subs are used in one-trip plugs where pressure differentials are anticipated. They are designed to hold pressure from above or below.

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

Available for all Otis key-type lock mandrels

Features Holds pressure from above or below Valve is closed when running tool is

released and is opened when pulling tool is engaged

Pressure balanced

Benefits Ports opened during installation for

fluid bypass Can be adapted to numerous flow

control devices and Storm Choke safety valves

Ordering InformationSpecify: 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, XH, RO, RPT, FBNequalizing subs

ValveHousing

Valve

Spring

Valve HousingSeal

Valve

SealOtis X and R Equalizing Sub

Otis XH Equalizing Sub

HAL

8494

HA

L849


Otis Bottomhole Choke BeansHalliburton Otis 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 can be run on any Halliburton Otis lock mandrel.

Otis 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

Features Can be connected to all Otis lock mandrels Are available in various sizes

Benefits Minimize water encroachment Lighten the oil column Increase flow velocity Prolong the life of the well

Ordering InformationSpecify: 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: 21XObeanholder with choke

BeanHolder

O-ring

ChokeBeanHA

L849

3

Otis X Bottomhole Choke BeanSubsurface Flow Control Systems 8-21

HE3/HX4 Retrievable Bridge Plug

The HE3 and HX4 retrievable bridge plugs (RBP) provide a means of isolating the upper wellbore from production or the lower wellbore from a treatment in the upper wellbore.

They can be set at a predetermined depth anywhere in the tubing or casing and can be run and retrieved using conventional well intervention methods. The slip system on the tools outer body anchors the plug to the wellbore while a packing element provides the pressure seal.

The HE3 RBP incorporates a mid-mounted pressure equalization feature that offers single-trip run and retrieve. With an extensive run history, the HE3 RBP is available in sizes ranging from2 7/8-in. through 13 3/8-in.

The HX4 RBP is a two-trip run and retrieve version of the HE3 RBP facilitated by a prong and equalizing housing.

ApplicationsThe HE3 RBP is designed for deployment in any type of well, whether horizontal or vertical, oil, gas, or water. Typical applications include pressure testing of the production tubing, packer setting, and completion installation operations.

Additional applications include tree repair or installation, gas-lift valve change out, zonal isolation or treatment, temporary well suspension, and packer or annular safety valve punch release.

Incorporating a larger equalizing flow area, the HX4 RBP is ideal for pre-installation in the completion tailpipe and being run with the completion for packer setting operations.

Features One-piece dual modulus packing

element Compact, modular design Large footprint segmented slip

mechanism Slip mechanism located below

packing element Slips mechanically retained on

retrieval Controlled setting action Various slip options Field redressable May be set using conventional

slickline or electric line setting tools, on coiled tubing or workstring, and using the Halliburton DPU downhole power unit

Benefits Allows the tubing to be plugged

without the need for a nipple profile Removes the need for restrictions

caused by such nipple profiles Reduced risk of premature setting

while running in hole and hanging up on retrieval

Slip mechanism position offers protection from casing debris, thus improving reliability

Slip design and controlled setting action helps ensure the stresses exerted on the casing or tubing are evenly distributed, thus preventing damage

HE3 Retrievable Bridge Plug

HX4 Retrievable Bridge Plug

HAL

3147

2

HA

L316

17

HAL

3161


HE3/HX4 Retrievable Bridge Plugs

Casing/Tubing Maximum OD

To Pass Restriction

Pressure Rating

Size Weight Above Below

in. mm lb/ft kg/m in. mm in. mm psi bar psi bar

2 7/8 73.036.4 9.52 2.120 53.85 2.187 55.55 10,000 689.00 10,000 689.00

8.7 12.94 2.280 57.91 2.310 58.67 5,000 344.50 5,000 344.50

3 1/2 88.90

9.2 13.69 2.710 68.83 2.750 69.85 7,500 516.75 7,500 516.75

10.2 15.70 2.710 68.83 2.750 69.85 7,500 516.75 7,500 516.75

12.7 18.89 2.600 66.04 2.625 66.68 7,500 516.75 7,500 516.75

4 101.609.5 14.13 3.250 82.55 3.220 81.79 5,000 344.50 5,000 344.50

11.6 17.26 3.250 82.55 3.220 81.79 5,000 344.50 5,000 344.50

4 1/2 114.30

11.6 17.263.600 91.44 3.625 92.08 6,000 413.40 6,000 413.40

3.600 91.44 3.625 92.08 6,000 413.40 6,000 413.40

12.6 18.75 3.750 95.30 3.812 96.85 10,000 689.00 10,000 689.00

14.5 21.58 3.600 91.44 3.625 92.08 6,000 413.40 6,000 413.40

15.1 22.46 3.600 91.44 3.625 92.08 6,000 413.40 6,000 413.40

5 127.00

15.0 21.31 4.220 107.19 4.250 107.95 5,000 344.50 5,000 344.50

18.0 26.784.090 103.89 4.125 104.78 6,000 413.40 6,000 413.40

3.970 100.84 4.000 101.60 3,000 206.70 3,000 206.70

5 1/2 139.70

17.0 25.29 4.470 113.54 4.500 114.30 5,000 344.50 5,000 344.50

20.0 29.75 4.410 112.01 4.437 112.70 4,000 275.76 4,000 275.76

23.0 34.214.410 112.01 4.437 112.70 4,000 275.76 4,000 275.76

4.280 108.71 4.313 109.55 5,000 344.50 5,000 344.50

26.0 38.68 4.280 108.71 4.313 109.55 5,000 344.50 5,000 344.50

6 5/8 168.30

28.0 41.65 5.560 141.22 5.625 142.88 6,500 447.85 6,500 447.85

32.0 47.60 5.470 138.94 5.500 139.70 5,000 344.50 5,000 344.50

33.0 49.09 5.470 138.94 5.500 139.70 5,000 344.50 5,000 344.50

7 177.80

23.0 34.21 5.970 151.64 6.000 152.40 3,500 241.15 3,500 241.15

26.0 38.68 5.890 149.61 5.937 150.80 5,000 344.50 5,000 344.50

29.0 43.15 5.750 146.05 5.720 145.29 6,500 447.85 6,000 413.40

32.0 47.60 5.750 146.05 5.720 145.29 6,500 447.85 6,000 413.40

35.0 52.06 5.600 142.24 5.625 142.88 6,000 413.40 6,000 413.40

38.0 56.55 5.600 142.24 5.625 142.88 6,000 413.40 6,000 413.40

41.0 60.99 5.600 142.24 5.625 142.88 6,000 413.40 6,000 413.40

7 5/8 193.6826.4 39.27 6.625 168.28 6.687 169.85 5,000 344.50 5,000 344.50

29.7 44.18 6.625 168.28 6.687 169.85 5,000 344.50 5,000 344.50

9 5/8 244.48

40.0 59.50 8.555 217.30 8.625 219.08 3,000 206.70 3,000 206.70

43.5 64.71 8.475 215.27 8.500 215.90 3,000 206.70 3,000 206.70

47.0 69.91 8.475 215.27 8.500 215.90 3,000 206.70 3,000 206.70

53.5 79.58 8.260 209.80 8.312 211.12 5,000 344.50 5,000 344.50

10 3/4 273.0560.7 90.29 9.375 238.13 9.437 239.70 5,000 344.50 5,000 344.50

65.7 97.73 9.375 238.13 9.437 239.70 5,000 344.50 5,000 344.50

11 3/4 298.45 54.0 80.33 10.600 269.24 10.660 270.76 5,500 379.17 3,500 241.15

13 3/8 339.7368.0 101.15 11.015 275.78 12.187 307.55 3,500 241.15 3,500 241.15

72.0 107.10 11.015 275.78 12.187 307.55 3,500 241.15 3,500 241.15

Part Number Prefixes: P.801HE3, P.801HX4Subsurface Flow Control Systems 8-23

Evo-Trieve Bridge Plug

The Evo-Trieve bridge plug is a high-performance retrievable monobore plugging device that does not require a predetermined setting restriction for locating or sealing within the production completion. Evolved from the industry-leading HE3, TR0 / TR1, and Monolock retrievable bridge plugs, the Evo-Trieve bridge plug blends past experience with future industry requirements.

The Evo-Trieve bridge plug is V0-qualified per ISO 14310 to 7,500 psi and up to 325F. Its robust design includes large slip and element footprints to provide improved pressure-holding capability in unsupported casing. Debris tolerance has been verified through a comprehensive flow loop testing program.

The Evo-Trieve bridge plug can be deployed using conventional slickline with the DPUdownhole power unit and can be retrieved with industry-standard GS pulling tools.

Applications Particularly suited to applications

requiring a qualified barrier-type plugging device located within the tubing string

Suitable for new completion installation and multiple well maintenance applications throughout the complete life ofwell cycle

Readily adapted to install pressure gauges or other associated flow control equipment for a full range of well service demands

Suited to shallow-set well plugging applications prior to Christmas tree removals and repairs to surface wellhead equipment

Features Supplied with H2S packing element

system as standard for critical well deployment and reduced inventory management

Superior debris tolerance provided by element positioned above slips complemented by a large ID pressure equalizing feature to resist plugging

Improved body lock ring system retains element pack-off force during pressure reversals across plug

Robust slip system permits no over expansion in set position while remaining mechanically locked in retracted position when plug is released

Time savings delivered through single-trip wireline equalization and plug retrieval operations

Easily adapted to existing modular extensions for extreme debris environments

Easy access top guide sub helps ensure retrieving tool engagement in highly deviated well profiles

Benefits Minimized tool diameter and

retained packing element offers improved running speeds and operational performance within deviated wellbores and access through tubing restrictions

Reduced operational costs as tool is retrieved by readily available industry-standard GS pulling tools

Simplified compact design requires no special assembly tools and is ideally suited for well site conversion and remote location operations

Suitable for deployment in all well types utilizing slickline, DPU unit, electric line, coiled tubing, tractor, and workstring operations

Evo-Trieve

HA

L246


Bridge Plug

Evo-Trieve Bridge Plugs

Casing/Tubing MaximumOD

MinimumOD

To Pass Restriction

Pressure RatingISO 14310 V0 Tested Temperature

Rating Size Weight Above Below

in. mm lb/ft kg/m in. mm in. mm in. mm psi bar psi bar F C

4 1/2 114.30

11.6 17.26

3.660 92.96 1.250 31.75 3.688 93.70 7,500 516.75 7,500 516.75 325 16312.6 18.79

13.5 20.09

5 1/2 139.70

17 25.30

4.470 113.54 1.750 44.45 4.500 114.30 7,500 516.75 7,500 516.75 325 16320 29.76

23 34.23

7 177.8029 43.16

5.720 145.29 2.310 58.67 5.750 146.05 7,500 516.75 7,500 516.75 325 16332 47.62

Part Number Prefix: P.801EV0Subsurface Flow Control Systems 8-25

Evo-RED Bridge Plug

The Evo-RED bridge plug provides a unique and highly efficient method of deploying and retrieving a downhole barrier. It incorporates a computer-controlled ball valve which can be remotely opened and closed multiple times without the need for any control lines or interventions. Each time the ball valve is activated, an intervention is eliminated from the operation saving rig-time while helping to reduce risk to both the operation and personnel.

The Evo-RED bridge plug can be used in a wide range of well operations and is particularly effective as a downhole barrier during workovers or completion operations keeping interventions and personnel-on-site to a minimum.

ApplicationsAny application where a wireline plug is used can be replaced by the Evo-RED bridge plug. The same results can be achieved but without repeated interventions, reducing personnel on board while saving on rig time and the associated costs and risks. Multiple assemblies can be used in a single operation maximizing benefits.

Packer setting device Deep-set barrier in extended reach or horizontal wells Shallow-set for tree testing and change out Liner deployment with external swellable elastomer Barrier in temporary abandonments or light well

intervention operations Barrier in tubing conveyed perforating gun firing and

stimulation operations Self-actuating flow control device Shut-in tool for pressure build-up tests with reduced

interventions

Features Reduced personnel on board Reduced interventions Remotely operated time-after-time Extensive run history Reliable deployment Debris tolerant Integrated backup

Benefits Can be pre-installed onshore; no dedicated offshore

personnel are required during the operation. Wellsite installations use multi-skilled service engineers reducing personnel on-site; saving substantial costs and helping reduce risk.

Can be retrieved with the tubing during a workover operation. This reduces the number of interventions for the entire operation to just one.

Remote activation of the ball valve minimizes the number of interventions required to set and remove a downhole barrier for almost any well operation.

Incorporates field-proven technology and is currently in worldwide use by many of the major oil operators.

Minimized OD, retained packing element, anti-preset and anti-reset features aid deployment and retrieval. Ball valve can also be functioned to either the opened or closed position as the operation requires.

Large ID and the element positioned above the slips; the ball valve has a large flow area allowing debris to be washed through the assembly before retrieval.

Built-in mechanical equalization feature aids retrieval and can be used as a backup should the ball valve fail. It is activated by the pulling tool during the retrieval operation, keeping interventions to a minimum.


OperationThe Evo-RED bridge plug is run-in-hole with the ball valve normally in the open position and the slips and element relaxed. Typically the assembly is deployed on the electronically controlled DPU downhole power unit which will mechanically set the bridge plug when target depth has been reached. At this stage, the ball valve is still open and the flow of the well unrestricted. It can be commanded to close at any time using one of the pre-programmed triggerssuch as applying between 1,000 and 1,500 psi for 10 minutes.

With the ball valve closed, the device provides a testable downhole barrier (rated to ISO 14310 V1) capable of holding up to 7,500 psi from above and below. The well can be equalized at any time by commanding the Evo-RED bridge plug to open using another pre-programmed trigger. This process can be repeated up to 30 times in a single jobproviding operational flexibility and eliminating an intervention each time.

The assembly is retrieved in a single run using a standard GS pulling tool with PX0 anti-pre-shear adapter. This latches into the top of the Evo-RED bridge plug activating the internal equalizing mechanism which aids recovery and doubles as a backup should the electronics fail. The slips and element retract and are secured in place by the anti-reset mechanism.

The large flow ports on the ball valve and extensive bypass features aid recovery by allowing significant fluid to flow through the assembly, while the minimized OD helps prevent them from fouling on other equipment during the retrieval.

Evo-RED Bridge Plug

Available Sizes (to Suit Casing Size)

Maximum Differential Across Closed Assembly

Temperature Range

Maximum Differential Pressure While Opening

in. lb/ft psi bar F C psi bar

4 1/2 11.6, 12.6, 13.5 7,500 516 39 - 284 4 - 140 6,000 414

5 1/2 17, 20, 23 7,500 516 39 - 284 4 - 140 6,000 414

7 23, 26, 29, 32 7,500 516 39 - 284 4 - 140 6,000 414Subsurface Flow Control Systems 8-27

DPU Downhole Power Unit

Halliburtons DPU downhole power unit is an electro-mechanical downhole electric power supply device that produces a linear force for setting packers using downhole electric power. The tool is self-contained with a battery unit and an electrical timer to start the setting operation. The unit consists of three functioning sections: the pressure sensing actuator, the power source, and the linear drive section.

The slickline version of the DPU unit uses batteries to provide the energy to the motor and timing circuits. An electric line version without the timer, circuits, and batteries is also available.

Note: Both slickline and e-line DPU units include conversion kits to allow for the use of some existing Baker setting adapter kits.

The DPU unit and attached subsurface device are run into the well on slickline or braided line. The timer initiates the operation. The setting motion is gradual and controlled (about0.7 in./min) allowing the sealing element to conform against the casing/tubing wall and the slips to fully engage. The controlled setting motion allows the sealing element to be fully compressed. Once the setting force is reached, the DPU unit shears loose from the subsurface device and is free for removal from the well. The DPU unit is designed to help set and allow for dependable operation of downhole flow control devices, reduce well completion costs, and improve safety at the wellsite.

ApplicationsSets and Retrieves:

Packers Bridge plugs Whipstocks Subsea tree plugs

Sets:

Cement retainers Sump packers HE3 and HX4 retrievable bridge

plugs B-series wireline-retrievable packers Evo-Trieve products

Perforates: Retrievable intervention straddles Tubing Casing

Shifts:

Sliding Side-Door circulation/production devices

Internal control valves Releasing mechanisms/sleeves

DPU Downhole Power Unit

HAL

1400


Features Equipped with a timer/accelerometer/pressure actuation

system to help ensure tool setting at proper time and depth

Batteries for self-contained operation Slickline, e-line, or coiled tubing operation Sets and retrieves tools with optimal setting force Reduced cost for setting packers and bridge plugs using

traditional electric line Non-explosive operation helps improve safety Eliminates need for electric wireline Dependable operation Positive setting of slips and elements Optimized operating speed

AdvancedMeasuringSystem

InspectionCoil

Slickline Service Unit

Downhole Power Unit

Bridge Plug

HA

L117


Bottomhole Pressure and Temperature Equipment

Halliburton softset gauge hangers and LO shock absorbers are designed to attach to bottomhole pressure and temperature tools and allow them to be positioned downhole.

Softset Gauge HangerSoftset gauge hangers are designed to set instruments virtually anywhere Otis 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 monitoring.

Applications Wells with a highly corrosive

environment Field with several wells to be

surveyed Wells that require extended surveys

Features Soft mechanical release

Benefits Does not require jarring to set Allows data surveys using

conventional slickline methods 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: An Otis MR mechanical running tool is used to run the Otis softset bomb hanger. It is designed to carry weight in excess of the 140-lb (63.5 kg) weight limit of a hydraulic running tool. The Otis 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.

Shock AbsorbersThe 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 toolstring are absorbed by the shock absorbers.

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

Ordering InformationShock AbsorbersSpecify: lock type and size; service environment (standard, %H2S, %CO2, amines); special material requirements, if applicable; weight of instruments.Part Number Prefix: 33LOBomb hanger or shock absorberOrdering InformationSoftset Bomb HangerSpecify: 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: 33XN, RNS, 33RPT, 33FBNSoftset bomb hanger

Softset Gauge Hanger

LO Shock Absorber

HA

L849

6

HA

L104


Tubing-Installed Flow Control Equipment

DuraSleeve Sliding Side-Door Circulation and Production Sleeve

The DuraSleeve Sliding Side-Door circulation and production sleeve is a full opening device that can be operated using standard slickline methods. It incorporates an internal sleeve that when open enables communication between the tubing and tubing/casing annulus. A nipple profile in the top sub and a polished bore in the bottom sub are standard features and allow accessory tools such as a Side-Door choke or separation tool to be set across the DuraSleeve device.

The DuraSleeve device incorporates Halliburton DURATEF engineered composite material (ECM) seals completely eliminating any elastomers from the tool. These seals provide a more easily shifted sleeve while providing reliable service for the life of the well.

Applications Single string selective completions Provide path for circulating heavier or lighter fluids Secondary recovery

Features Otis X, R, RPT, or FBN profiles available Polished sealbores in both top and bottom subs All seals are non-elastomer Circulation/production flow area is equal to DuraSleeve

device ID Packing does not move when sleeve is shifted Collet provides positive sleeve location in the closed,

equalizing, and open position Open up and open down versions available Equalizing ports in the inner sleeve allow opening under

high differential pressures B profile provides automatic positioning tool release

when sleeve is completely shifted

Benefits Reliable operation over the life of the well Can be opened repeatedly against high differential

pressures Can be shifted in high debris or sandy environments Multiple devices can be run in a single tubing string Several sleeves can be shifted in a single slickline trip Individual sleeves can be opened or closed selectively Slickline-run accessory tools can be set within the

DuraSleeve device

Landing NippleProfile

Closing Sleeve

Equalizing Ports

Flow PortsBuffer SealECM Seal StackHigh-Strength BodyJoints

Lower PolishedBore

DuraSleeve Sliding Side-Door Circulation/Production Sleeve

HA

L849


DuraSleeve Sliding Side-Door Circulation and Production Sleeve

Tubing Size SSD ID Nipple Profile

in. mm in. mm X R RPT

2 3/8 60.33

1.875 47.63 1.781 45.24 1.710 43.43

2 7/8 73.03

2.313 58.75 2.188 55.58 2.125 53.98 1.875 47.63 1.710 43.43

3 1/2 88.90

2.813 71.45 2.750 69.85 2.562 65.07 2.313 58.75

4 101.603.313 84.15 3.125 79.38

4 1/2 114.30

3.813 96.85 3.750 95.25 3.688 93.68 3.562 90.47 3.500 88.90 3.437 87.30

5 127.00

4.000 101.60 3.813 96.85 3.688 93.68 3.562 90.47 3.437 87.30

5 1/2 139.70

4.688 119.08 4.562 115.87 4.500 114.30 4.437 112.70 4.313 109.55

7 177.80

5.960 151.38 5.875 149.23 5.625 142.88 5.500 139.70

= currently available = available on request8-32 Subsurface Flow Control Systems

Slimline DuraSleeve Sliding Side-Door Circulation and Production Device

Slimline DuraSleeve Sliding Side-Door circulation and production devices are available in 2 3/8 through 4-in. sizes. These Sliding Side-Door circulation devices retain all the

features of the regular Halliburton circulation devices but have reduced pressure and tensile ratings.

Slimline Circulation and Production Equipment

Tubing Size

Tubing Weight

Tubing ID

Tubing Drift

Standard Weight ID OD*

in. mm lb/ft kg/m in. mm in. mm in. mm in. mm

2 3/8 60.334.6 6.85 1.995 50.67 1.901 48.29

1.875 47.63 2.710 68.834.7 6.99 1.995 50.67 1.901 48.29

2 7/8 73.036.4 9.52 2.441 62.00 2.347 59.61

2.313 58.75 3.220 81.786.5 9.67 2.441 62.00 2.347 59.61

3 1/2 88.99.3 13.84 2.992 76.00 2.867 72.82 2.813 71.45 4.195 106.55

10.3 15.33 2.992 76.00 2.797 71.04 2.750 69.85 3.925 99.69

4 101.6 11 16.37 3.476 88.29 3.351 85.10 3.313 84.15 4.635 117.73

*ODs are based on 110 ksi minimum yield material.Ordering InformationSpecify: 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 Prefix: 621ooSubsurface Flow Control Systems 8-33

Zonemaster Injection System

The Zonemaster injection system provides the ability to control injection for any interval in a well. When run with isolation packers, the Zonemaster mandrels provide a positive and reliable method to shut off well segments. The Zonemaster system consists of two separate components. The ported landing nipple is generally run as part of the tubing string or liner and is used as the injection point into the production tubing. Zonemaster isolation sleeves can be installed or retrieved depending on whether the adjacent interval should be injected into or shut off.

Applications Selective injection Formation isolation Individual interval stimulation

Features No-go positive positioning system Large isolation sleeve ID Collet holddown system simplifies setting Nipple accepts RPT lock mandrels Installation capability with:

Wireline Coiled tubing Sucker rod Pump down system

Available with sour service or premium service version

OperationZonemaster sleeves with blank beans can be installed via slickline or pre-installed in the nipple before running in the well. This allows for pressure setting of hydraulic-set packers or for pressure testing the tubing string during well completion. The isolation sleeves can then be removed and replaced with sleeves with choke beans installed to control injection in each zone. If injection requirements change during the life of the well, the Zonemaster sleeves can be retrieved and bean sizes changed as needed. Each time the sleeves are retrieved, the seals can be redressed.

The isolation sleeves utilize a top no-go positive positioning system to provide for certainty during installation. They are generally installed using wireline in vertical wells and can be installed using either coiled tubing or sucker rods in horizontal wells.

Ported Zonemaster Nipple

No-GoShoulder

Locking Collet

ChangeableBean Insert

ZonemasterInjection System

HA

L330


Zonemaster Injection System

Tubing OD Sealbore

Bottom No-Go

Minimum ZonemasterMandrel ID (Bottom No-Go)

in. mm in. mm in. mm

1.900 48.26 1.500 38.10 1.447 36.75

2 1/16 52.39 1.625 41.28 1.572 38.35

2 3/8 60.331.812 46.02 1.750 44.68

1.875 47.63 1.822 46.28

2 7/8 73.032.250 57.15 2.197 55.80

2.312 58.70 2.259 57.40

3 1/2 88.92.750 69.85 2.697 68.50

2.812 71.40 2.759 70.08

4 101.63.125 79.40 3.072 78.00

3.312 84.10 3.260 82.80

4 1/2 114.30

3.688 93.70 3.625 92.10

3.750 95.30 3.700 94.00

3.812 96.90 3.759 95.50

5 127.00

4.000 101.60 3.910 99.30

4.125 104.80 4.035 102.50

4.312 109.50 4.223 107.30

5 1/2 139.704.560 115.80 4.472 113.60

4.750 120.60 4.660 118.40

6 5/8 168.205.250 133.40 5.150 130.80

5.500 139.70 5.400 137.20

7 177.805.750 146.10 5.625 142.90

5.900 149.86 5.800 147.32

7 5/8 193.60 6.125 155.60 6.000 152.40

Ordering InformationSpecify: lock type and size or part number, if known; service environment (standard, %H2S, %CO2, amines); temperature and pressure rating requirements; bean size.Part Number Prefix: 10TPIA, 11TPLA Zonemaster Injection System. For ordering information, specify bean size.Subsurface Flow Control Systems 8-35

Velocity String Hangers

Many mature gas wells experience decreased production over time. This can lead to liquid loading which can eventually cause the well to cease production. Contributing factors are typically declining reservoir pressures which reduce gas velocity and increased water production. If gas velocity is not high enough to keep water entrained in the produced gas, the water will accumulate at the bottom of the well and the well may cease production.

An effective method to continue or restart production is to provide a smaller ID production string. The smaller ID increases the production velocity, preventing the well from loading with liquid. To do this, a means of suspending this smaller velocity string must be provided. Various types of velocity string hangers (VSH) have been used but these can prevent the use of the existing safety valve system but without incorporating a new safety valve system to protect the well.

Halliburton velocity string hangers are installed in an existing tubing retrievable safety valve (TRSV) or safety valve landing nipple (SVLN) to support the velocity string while using the existing hydraulic control system to operate a new subsurface safety valve. The new safety valve can be a wireline type safety valve or in some cases a tubing retrievable type. The VSH uses the nipple profile in the existing TRSV or SVLN to suspend the full weight of the velocity string. In addition, unique seals on the VSH pack off in the TRSV or SVLN sealbores preserve the integrity of the existing safety valve hydraulic system.

Application Wells with reduced production due

to liquid loading Wells that have ceased production

Features Available to fit most Halliburton

nipple profiles in SVLNs and TRSVs Can incorporate a wireline

retrievable or tubing retrievable safety valves

Unique seals provide pressure capability in damaged sealbores

Can carry loads up to 100,000 lb and more

Field proven

Benefits Adaptable to most landing nipple

profiles Maintains the use of a SSSV

operated by the original hydraulic control system

Can seal off in damaged sealbores Keyed type hanger allows high

tubing weights to be run Designs available to fit many well

architectures

HA

L387

63

HAL

3876

4

Velocity String Hangers8-36 Subsurface Flow Control Systems

Tubing-Installed Plugging Equipment

DP1 Anvil Plugging System

The DP1 Anvil plugging system is a temporary tubing plugging device that allows the operator to perform multiple production tubing pressure tests prior to packer setting and on command provides full bore, through-tubing access without the need for well intervention. The Anvil plug incorporates a solid metal mechanical barrier removed by applying tubing pressure a predetermined number of times. No special surface equipment is required for operation and no debris results after actuation. The plug comes complete with a range of accessories to accommodate pre-fill, circulation, and secondary override facility.

ApplicationsThis tool is ideally suited for deep, highly deviated, or horizontal wells that would normally require coiled tubing to run plugs to set hydraulically activated equipment.

Features Solid metal barrier Depth limited only by ratings of hydrostatic chamber

housings Low pressure differentials to activate Feedback at surface of tool activation No waiting on plug to open No debris No non-standard surface equipment required Mechanical override Easily millable

Benefits Totally interventionless completion installation Can be used as a deep, downhole barrier for wireline

valve removal Produces no residual debris after activation Requires no special surface equipment to occupy

premium space on the rig floor

Cutting Metal Barrier

RunPosition

Well Open Full Bore

DP1 AnvilPlugging System

HAL

1220

4

DP1 Anvil Plugging System

Casing Size

Thread Maximum OD

Minimum ID

Pressure Rating

Size Weight Above Below

in. mm in. mm lb/ft kg/m in. mm in. mm psi bar psi bar

7 177.80

3 1/2 88.90 9.2 13.695.890 149.61

2.890 73.416,000 413.40 2,000 137.80

6.000 152.404 101.60 10 14.88 5.875 149.23

4 1/2 114.3012 17.86

5.890 149.61 3.875 98.4313 19.35Subsurface Flow Control Systems 8-37

9 5/8 244.485 1/2 139.70 17 25.28 7.650 194.31 4.625 117.48

6,000 413.40 2,000 137.806 5/8 168.28 32 47.62 8.312 211.12 5.750 146.05

Part Number Prefix: P.208DP1

LA0 Liquid Spring-Actuated Anvil Plugging System

The LA0 liquid spring-actuated Anvil plugging system is a pressure cycle-operated device that allows the operator to perform tubing tests or set hydraulically activated tools and then have full tubing bore ID without wireline or coiled tubing intervention. The operation of the liquid spring device is carried out by a ratchet mechanism that travels each time pressure is applied for the predetermined number of cycles. When the predetermined number of pressure cycles has been applied, communication from the tubing to the control line is opened, allowing pressure to activate the Anvil plugging system.

ApplicationsThis tool is ideally suited for deep, highly deviated, or horizontal wells, which would normally require coiled tubing to run plugs for setting hydraulically activated equipment and where it is necessary to apply a number of tubing pressure tests before activation of hydraulically operated downhole tools.

Features Insensitive to changes in annulus

pressure Control fluid sealed within

actuation mechanism Solid metal barrier Surface indication of successful tool

activation No waiting on plug to open No debris Circulating sub Mechanical override Easily millable

Benefits Control fluid in the actuation

mechanism is sealed and therefore protected from contamination.

Unlike nitrogen pre-charged systems, the liquid spring mechanism eliminates well-specific setup and enhances long-term suspension capability.

Fluid used to communicate with the hydraulically activated device is carried in with the liquid spring module and therefore remains separate from the tubing fluid at all times, reducing the chance of control line blockages.

Prior to activating the release mechanism, a solid metal plate is in place to form a downhole barrier that satisfies most operators' plugging policy.

Sudden pressure drop at the device at activation will be detectable at surface.

The Anvil plug completely opens at the time of actuation. Controlled metallurgical and dimensional properties help ensure consistent and reliable full opening.

After activation, the Anvil plug produces no residual debris to potentially cause problems during subsequent operations.

To allow the tubing to self-fill while running, a circulating sub or fill up sub can be run in conjunction with the Anvil plug.

In the event the plug does not activate normally, it can be mechanically overridden using a dedicated tool run on wireline or coiled tubing.

The Anvil plug can also be milled with no rotating parts and only the metal plate to be removed.

Part Number Prefix: P.208LA0

LA0 Liquid Spring-ActuatedAnvilPlugging System

HA

L124


LS0 Liquid Spring Actuation DeviceThe LS0 liquid spring actuation device is a pressure cycle-operated, self-contained tool used to initiate any hydraulically activated downhole device. The tool allows setting of equipment after the application of a predetermined number of pressure cycles. The operation of the tool is carried out by a ratchet mechanism that travels each time pressure is applied. When the predetermined number of pressure cycles have been applied, communication from the tubing to the control line is opened, allowing pressure to reach the target device.

ApplicationsThe liquid spring actuation device is used when it is necessary to apply a number of tubing pressure tests before activation of hydraulically operated downhole tools.

Features No atmospheric chamber or nitrogen-charged chamber

to limit time to actuation Actuation system is unaffected by changes in pressure in

the lower annulus Control fluid in the actuation mechanism is sealed and

therefore protected from contamination

Benefits Total interventionless actuation of hydraulically

operated tools. Unlike similar actuation devices, the liquid spring is not

affected by changes in pressure in the lower annulus. Unlike nitrogen pre-charged systems, the liquid spring

mechanism eliminates well-specific setup and enhances long term suspension capability.

Fluid used to communicate with the hydraulically activated device is carried within the liquid spring module and therefore remains separate from the tubing fluid at all times, reducing the chance of control-line blockages.

Part Number Prefix: P.224LS0

LS0 Liquid SpringActuation Device

HAL

1249


Mirage Disappearing Plug

The 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 plug when tubing autofill is required.

The Mirage plug is available in two versionsthe MPB multi-cycle version that allows six pressure cycles before expending and an MPR single-cycle type. The MPR Mirage plugs have no moving parts and use a rupture disk to select the expend pressure.

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 use is

undesirable Rupture disk available from 500 to

16,000 psi in 500 psi increments

Features Multiple pressure-cycle capability

(MPB version) Automatic expend after last

pressure cycle Maximum particle size after

expending is less than 1 mm Helps reduce well risk; reduces

number of slickline or CTU trips in the hole; allows multiple pressure tests before expending

Benefits Testing tubing can be accomplished

without delay or problems associated with other plugging methods

Helps reduce completion costs by eliminating trips to install and retrieve plugging device

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


(MPB)

MirageDisappearing Plug

(MPR)

HA

L330

61

HA

L882

7


Nominal Size OD

ID (After Expend) Length

Pressure Rating Temperature RatingFrom Above From Below

in. mm in. mm in. mm in. mm psi kPa psi kPa F C

3 1/2 88.90 5.40 139.70 2.88 72.64 62.34 1583.31 7,500 51 710.67 2,500 17 236.89 220 104.4

4 1/2 114.30 5.88 152.40 3.88 98.04 62.52 1587.88 5,000 34 473.79 2,500 17 236.89 220 104.4

5 1/2 139.70 7.02 178.31 4.77 118.87 64.33 1633.86 5,000 34 473.79 2,500 17 236.89 220 104.4

7 177.80 8.26 209.80 6.08 154.43 67.07 1703.45 5,000 34 473.79 2,500 17 236.89 220 104.48-40 Subsurface Flow Control Systems

Part Number Prefix: 21MPB or 21MPR

Autofill SubThe autofill sub is run above the Mirage or Anvil 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, provided the shear pressure of the lockout piston is not exceeded. Once the lockout pins are sheared resulting from tubing pressure, the piston drives the ports in the isolation sleeve past the o-rings, locking the fill sub out of service. A simple interference fit retains the fill sub in the locked-out condition.

Applications Used separately or in conjunction with Mirage and Anvil

plug systems Completions requiring automatic filling of tubing

Features Simple, robust design Prevents fluid flow from tubing to casing A mechanical override in the form of an isolation

sleeve can be used to permanently isolate the bladder if required

Benefits Autofill valve automatically fills the tubing from below,

eliminating manual fill from the surface. Rubber sealing sleeve provides positive sealing in debris-

laden fluid.

Ordering InformationSpecify: tubing size, weight, and grade; thread connection; material; service environment; pressure rating.Part Number Prefix: 21FS

Lockout ShearPins

Lockout Piston

Isolation Sleeve

Bladder Valve

Interference Bump

Autofill Sub

HA

L592


Fluid Loss Devices

Automatic Downhole Master Valve

The automatic downhole master valve (DHMV) is used in electric submersible pump (ESP) completions and eliminates the need for expensive well control fluids. This downhole pressure-operated fluid flow control valve is run with a packer, on-off tool, and wireline Otis XN lock.

The valve prevents fluid loss if the ESP shuts down and can be adjusted to hold up to 1,000 psi from below after it is latched closed. After the ESP is restarted, the DHMV will open when the hydrostatic pressure is reduced to the adjusted differential.

Applications ESP installations in which flow control without heavy kill

fluids is desired during remedial operations

Features Wireline or tubing-retrievable Holds pressure in both directions Variable opening and closing pressure adjustment

Benefits Eliminates the need for expensive well control fluids Prevents formation damage Automatic operationdoes not require control lines,

conductor cables, wireline operations, or tubing manipulation to operate

Ordering InformationSpecify: nipple size and type, special material requirements, service environment (standard, %H2S, %CO2, amines)Part Number Prefix: 14MV

Run-In Position

Open Position

Closed Position

HAL


FS2 Fluid Loss Isolation Barrier Valve

For efficient asset management, Halliburtons FS2 fluid loss isolation barrier valve provides a reliable, interventionless solution for fluid loss control during well completion, eliminating potential formation damage.

The FS2 valve isolates the formation below the uppermost gravel pack packer before the upper completion has been installed and can be utilized in frac pack, gravel pack, and standalone screen applications. The valve provides a reliable means of:

Preventing fluid loss to formations after completing initial gravel pack operations

Isolating formations during up-hole operations throughout life of the well

Helping to reduce costs on subsea or deep wells through the use of interventionless technology

Use as a barrier in a well suspension system

The closure device is a proven, high-performance ball mechanism that provides a positive bi-directional seal in brine and oil-based mud environments. The debris-tolerant, non-translating ball design eliminates unnecessary movement within the mechanism during opening and closing operations, allowing operation in debris-laden environments.

Optimum FS2 valve placement is normally below the gravel pack or liner hanger assembly. Washpipe, located on the bottom of the service tool, is extended through the valve. A collet shifting tool is attached to the end of the washpipe, which on retrieval closes the valve, immediately isolating the formation and allowing inflow or positive pressure-testing above the ball. Remote actuation in the form of hydraulic pressure cycles is then used to open the valve after upper completion installation.

FS2 Fluid LossIsolation Barrier Valve

HA

L308


Features and Benefits Initial valve closure achieved when washstring/collet is

retrieved through the valve. Bi-directional sealing mechanism provides a fully tested

downhole barrier. Unlike nitrogen pre-charged systems, the fluid spring

indexing mechanism eliminates well-specific setup and enhances long-term suspension capability.

One-time remote activation achieved by the application of pressure cycles, eliminating the need for well intervention.

Activation piston provides increased opening force (up to 200% increase over previous FS valve designs).

Improved fluid management helps ensure valve operation in debris.

Increased differential opening capability. Design provides unlimited mechanical opening/closing

of valve. Indexing system is unaffected by changes in hydrostatic pressure, making it suitable for use in wells with fluid loss.

Valve opens on pressure bleed down, minimizing the risk of surging the formation.

Full bore ID maximizes production and allows access to the formation.

Design incorporates enhanced debris exclusion features. Mechanical shifting profile incorporated within design. Sealed actuation mechanism helps prevent control

system contamination. Cycling mechanism isolated from debris in the wellbore.

Qualification TestingEach FS2 valve is subjected to extensive qualification testing during prototyping. In addition to rigorous discrete component level testing, a full valve

subsurface prong and plug assemblies

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