horizontal completion systems - halliburton · horizontal completion systems ... the frac balls and...

$: Horizontal Completion Systems - Halliburton · Horizontal Completion Systems ... the frac balls and landing baffles can be milled out to provide ... opening and stimulation of the$
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Horizontal Completion SystemsNo two formations are alike. In fact, there are often

significant variations even within a given formation. These

variations create many demands on the completion for

stimulation and production purposes. Halliburton's

RapidSuite™ sleeve technology includes hydraulic fracturing

sleeves for a wide range of options to create the most effective

and efficient hydraulic stimulation completion system for

your application.

A vital part of the completion used for hydraulic fracturing of

horizontal/highly deviated wells is the system used to

annularly isolate the sleeves to help create transverse

fractures. RapidSuite sleeve systems have been used

successfully with all types of annular isolation products

including swellable packers, hydraulic-set packers, and

cement. And, Halliburton is able to offer industry-leading

technology for each of these isolation methods.

From the many baffle sizes offered with the RapidStage™sleeve system to the time-saving multi-entry sleeve

RapidFrac™ system, Halliburton's RapidSuite frac sleeve

portfolio provides the right completion solution for the most

challenging of frac stimulation applications.

Halliburton is set apart from other frac sleeve providers by its

ability to test various sleeve systems during development and

sustaining using specialized testing facilities such as the

5,200 ft (1600 m) horizontal flow loop in Duncan,

Oklahoma, or the Mike Adams horizontal well test facility

located at the Technology Center in Carrollton, Texas. This

translates into more robust, field-ready systems that lead the

way in frac sleeve technology.

Halliburton offers complete horizontal hydraulic fracturing

solutions from frac design to completion selection for the

most effective treatments. Frac fluid selection, pumping

design and surface hardware, cementing programs—

completion systems all working together to provide a

coordinated and optimized well treatment program for

maximum well performance.

Specialized testing facilities such as the horizontal flow loop (left) and the Mike Adams Test Well (right) have helped make Halliburton an industry leader in frac sleeve technology.

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Horizontal Completion Systems 4-1

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RapidStage™ Sleeve System

The RapidStage™ sleeve system optimizes the completion of

multi-interval wellbores by enabling highly accurate

placement of stimulation treatments without intervention.

This helps ensure the stimulation treatment covers targeted

areas in the wellbore and maximizes the stimulated reservoir

area. The RapidStage system can be run into a wellbore using

a casing string to surface or the VersaFlex® liner hanger

system to help enable a reliable, trouble-free installation.

The RapidStage system incorporates the proven RapidStage

sleeve, RapidStart™ Initiator sleeve, and a means of sleeve

isolation. Halliburton offers several isolation options for a

variety of reservoir conditions. Isolation in an openhole

completion can be achieved with either the versatile

Swellpacker® isolation system or ZoneGuard®SR packer.

Cemented applications are also an option for the majority

of the available sizes using Halliburton SoluCem™ acid-

soluble cement.

To activate the RapidStage sleeves, frac balls are dropped in

sequence, smallest to largest, from surface using the

Halliburton pneumatic ball launcher. The frac balls seal on a

corresponding millable baffle shifting the sleeve open,

diverting flow through ports in the sleeve, and providing

isolation from previous stages. After stimulation, cleanup is

assisted by flowing all lower zones simultaneously. If desired,

the frac balls and landing baffles can be milled out to provide

full open ID through the sleeves.

The RapidStart Initiator sleeve allows for interventionless

opening and stimulation of the toe stage. This provides a

means to pump down the frac balls to actuate the RapidStage

sleeves.

The RapidStart Initiator sleeve is an air-chambered tool that

is shear pinned prior to running in the hole based on the

wellbore conditions and is activated using applied pressure.

RapidStage™ Sleeve

RapidStart™ Initiator Sleeve

Swellpacker® Isolation System

RapidStage™ Sleeve System for Openhole Completions

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4-2 Horizontal Completion Systems

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Features• Up to 41 individual intervals

• Can be used with cement isolation

• Positive locking engagement when sleeve is opened

• 10,000 psi in 350°F rated standard service

• HPHT and sour service available

Benefits• Enables continuous pumping of multi-interval stimulation

treatments

• Requires no intervention

• Reduces completion cycle time

• Provides positive stimulation treatment placement

RapidStart™ Initiator SleeveThe RapidStart™ Initiator sleeve allows for an

interventionless stimulation treatment and serves as the toe

opening sleeve in a frac sleeve completion. This sleeve is

activated using tubing/casing pressure that exceeds a

predetermined shear pinned value. The Initiator sleeve uses

an air-chambered sleeve that operates solely off of absolute

tubing pressure. Once opened, the Initiator sleeve can be

used for stimulation of the first zone and/or as the flow path

to pump the first ball down to the lowest zone comprising the

RapidFrac™ and RapidStage™ sleeves.

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RapidStage™ Sleeve System for Cemented Applications

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RapidStage™ System

Casing Sizein.

Tool ODin.

NominalTool ID

in.

Minimum OpenHole Size

in.

Maximum Baffle ID

in.

MinimumBaffle ID

in.

MaximumTemperature

Rating°F

Maximum Pressure Rating

psi

2 7/8 3.95 2.40 4.25 2.192 1.04 350 10,000

3 1/2 4.40 2.99 4.75 2.628 1.04 350 10,000

4 1/25.60 3.83 5.875 3.556 0.96 350 10,000

5.75 3.83 5.875 3.556 0.96 400 15,000

5 1/2 6.50 4.67 7.875 4.400 0.96 350 10,000

7 7.95 6.004 8.375 4.400 1.04 350 10,000

5000 Series RapidStage™ System Balls and Baffles, RapidFrac™ Sleeve Rate

Zone Baffle ID

in.4 1/2-in. BafflePart Number

5 1/2-in. BafflePart Number

Ball ODin.

BallPart Number

Maximum Rate bbl/min

5000 Series RapidFrac™

1 1.040 101867812 101901825 1.125 101845696 17 –

2 1.165 101867813 101901826 1.250 101845697 22 –

3 1.290 101867814 101901827 1.375 101845698 26 –

4 1.415 101867815 101901828 1.500 101845699 32 –

5 1.540 101867816 101901829 1.625 101845700 37 –

6 1.665 101867817 101901830 1.750 101845702 44 40

7 1.790 101867818 101901831 1.875 101845703 50 46

8 1.915 101867819 101901832 2.000 101845331 58 53

9 2.040 101867820 101901833 2.125 101845704 65 60

10 2.165 101867821 101901834 2.250 101845705 74 67

11 2.290 101867822 101901835 2.375 101845707 83 75

12a 2.415 101867823 101901836 2.500 101845708 92 84

13 2.540 101867824 101901837 2.625 101845709 102 93

14 2.665 101867825 101901838 2.750 101845710 112 101

15 2.790 101867826 101901839 2.875 101845711 123 111

16 2.915 101867827 101901840 3.000 101845712 135 121

17 3.040 101867828 101901841 3.125 101845713 147 132

18 3.155 101898966 101901842 3.280 101898867 158 142

19 3.310 101898967 101901843 3.443 101898869 174 156

20 3.473 101898968 101901844 3.615 101898870 191 172

21 3.645 – 101901845 3.792 101901845 211 190

22 3.882 – 101901846 3.975 101901846 239 215

23 4.005 – 101901847 4.168 101901847 254 229

24 4.198 – 101901848 4.370 101901848 279 252

25 4.400 – 101901849 4.580 101901849 307 276aSmallest baffle used with 5 1/2-in. RapidFrac System cementing


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RapidFrac™ Sleeve System

The RapidFrac™ sleeve system provides operators new

options for completing horizontal multi-interval wellbores to

help enable highly accurate placement of fractures with

minimal or no intervention. This multi-entry sleeve system

allows access to multiple fracture points within an isolated

interval, and its unique ball activation feature helps enable a

totally interventionless completion.

The RapidFrac completion assembly can be run into the

wellbore using the VersaFlex® liner hanger system or

production casing to surface. Based on the reservoir

conditions, isolation can be achieved with either the

Swellpacker® isolation system or ZoneGuard® SR packers

for an openhole completion.

Cement isolation is also an option for larger casing size

sleeves.

The system uses RapidFrac sleeves and a RapidStage™ sleeve

within a single interval. This exposes the reservoir face to

multiple fracture points, similar to the “plug and perf”

process without the loss of time, waste of water resources, or

extended exposure of personnel. Numerous fracture points

can be used within an isolated interval in a given zone. Up to

20 intervals can be used for the completion.

RapidFrac™Sleeves

RapidStage™Sleeve



RapidFrac™ Sleeve System for Openhole Applications

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RapidFrac™ Sleeve

The RapidFrac™ sleeve uses a delayed opening mechanism

that enables a single ball to open multiple RapidFrac sleeves

before landing on the RapidStage™ sleeve, which is isolated

within an interval.

Once the ball lands on the RapidStage sleeve, increased

casing ID pressure will open the RapidStage sleeve during

which time the RapidFrac sleeves are metering to the open

position, allowing multiple fracture points (sub-intervals)

within the interval.

Each RapidFrac and RapidStage sleeve has ports that can be

modified to allow each sleeve within a sub-interval to be

tailored to specific flow requirements to maximize the

stimulation treatment. Each interval uses our proven

composite balls, which can be launched from the Halliburton

pneumatic ball launcher. After stimulation, cleanup is

assisted by flowing all lower zones simultaneously.

Features• 10,000 psi pressure rating

• 350°F

• High fracturing rates

• Used with a variety of isolation methods

• 90 to 180 sec delay on initial opening for each

RapidFrac sleeve

• Single ball activates all sleeves in a given interval

• Maximum of 20 intervals per well

• Composite ball activated

• Standard service

Benefits• Alternative to “plug and perforate” process

• Need for wireline intervention and its associated risks

eliminated

• Stimulation cycle time reduced from weeks to days or from

days to hours with continuous pumping

• Over displacement of proppant reduced

• Water requirements reduced when compared to pumping

plugs and guns on depth

• Number of flow ports on each RapidFrac and RapidStage

sleeve may be tailored for a specific treatment regimen

RapidFrac™ Sleeve

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RapidFrac™ Sleeve

Zone Tool Sizein.

CompositeBall Size

in.

BaffleSizein.

MaximumRate

bbl/min

1 4 1/2 1.750 1.665 40

2 4 1/2 1.875 1.790 46

3 4 1/2 2.000 1.915 53

4 4 1/2 2.125 2.040 60

5 4 1/2 2.250 2.165 67

6 4 1/2 2.375 2.290 75

7 4 1/2 2.500 2.415 84

8 4 1/2 2.625 2.540 93

9 4 1/2 2.750 2.665 100

10 4 1/2 2.875 2.790 100

11 4 1/2 3.000 2.915 100

12 4 1/2 3.125 3.040 100

13 4 1/2 3.280 3.155 100

14 4 1/2 3.443 3.310 100

15 4 1/2 3.615 3.473 100

16 5 1/2 3.792 3.645 100

17 5 1/2 3.975 3.822 100

18 5 1/2 4.168 4.005 100

19 5 1/2 4.370 4.198 100

20 5 1/2 4.580 4.400 100


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The RapidStart™ Initiator sleeve provides an interventionless

means of establishing an initial flow path from the tubing/

casing ID to the OD during multi-zone fracturing or plug

and perf operations. Activation is achieved by using absolute

pressure on the sleeve ID that exceeds a predetermined shear

pinned value. Designed for extreme environments, the sleeve

can be cemented in place without losing functionality.

The RapidStart Initiator sleeve uses an air-chambered

mechanism that operates solely off absolute tubing pressure.

Prior to running the completion, the sleeve is pinned

according to opening requirements dictated by the

hydrostatics of the well, other tubing pressure-operated tools,

and casing pressure ratings. Opening the internal sleeve

allows flow to be diverted through ports in the outer case

from the ID. Once opened, the sleeve can be used for

stimulation of the first zone in a “plug and perf” type

completion, thereby eliminating the need for coiled tubing to

establish circulation. Additionally, the sleeve may be used as

the first zone in a frac sleeve completion system, such as the

RapidStage™ or RapidFrac™ systems.

The rugged construction and debris-tolerant design allows

the RapidStart Initiator sleeve to be successfully run in

cemented applications in both horizontal and vertical wells.

Features• Interventionless completion compatibility

• Tubing/casing internal pressure activation

• Available with 10,000 psi and 15,000 psi differential ratings

or 15,000 psi and 20,000 psi absolute pressure ratings

(HPHT)

• Positive locking engagement when sleeve is opened

• Available in standard service and CO2 (S13Cr)

Benefits• Allows for interventionless opening of cemented

completion string toe, eliminating coiled tubing

perforating

• Provides flow path to pump first frac stage and displace

first stage ball


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CasingSizein.

Tool ODin. (mm)

Tool IDin. (mm)

MinimumOpenhole Size

in. (mm)

MaximumTemperature

°F (°C)

MaximumAbsolute Pressure

psi (kPa)

MaximumDifferential Pressure

psi (kPa)

MaximumPump Rate

bbl/min

4 1/2 5.60(142.24)

3.00(76.20)

5.875 (149.23)

350 (177)

15,000(103.421)

10,000(68.948) 100

4 1/2 HPHT

5.75(146.15)

3.00(76.20)

6.00(152.40)

400(204)

20,000(137.880)

15,000(103.410) 100

4 1/2 S13Cr

5.60(142.24)

3.00 (76.20)

5.875(149.23)

350(177)

15,000 (103.421)

10,000 (68.948) 100

5 1/2 6.50(165.10)

4.00(101.60)

6.875 (174.63)

350(177)

15,000 (103.421)

10,000(68.948) 100


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RapidShift™ Sleeve System

The RapidShift™ stimulation and production sleeve system

allows selective multi-zone stimulation treatment through

the production string. This versatile sleeve can be operated

by either a mechanical hydraulic shifting tool run on either

coiled tubing or jointed tubing or by using a ball-drop

system. Opening the sleeve permits zonal stimulation

through the selected tool and diverts the flow through the

ports in the RapidShift sleeve. After stimulation, cleanup is

assisted by flowing all lower zones simultaneously.

There is no limit to the number of RapidShift sleeves that can

be run in a single string when using the mechanical/

hydraulic shifting device. Once completed, the RapidShift

sleeve will function as a standard production device, allowing

full wellbore access.

Features• 10,000 psi pressure rating

• Can be shifted with coiled tubing or jointed-pipe methods

• Allows sleeve to be opened or closed in a single coiled

tubing or jointed-pipe trip

• Available in standard service

• Can be mechanically shifted with a mechanical/hydraulic

shifting tool

• Ball-activated version available for interventionless

completion

Benefits• Stimulates multiple zones and helps maintain wellbore

integrity during completion

• Eliminates restrictions during production, allowing full

wellbore access

• Functions as a conventional sliding sleeve during

production

RapidShiftSleeve Mechanical Shift

RapidShift Sleeve Ball Drop

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RapidShift SleeveMechanical Shifting Tool

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30 Plus RapidStage™ Balls and Baffles

ZoneBaffle ID

in.3 1/2-in. Baffle Part Number

4 1/2-in. BafflePart Number

5 1/2-in. Baffle Part Number

Ball ODin.

Ball Part Number

Maximum Ratebbl/min

1 0.965 102181666 102054013 102098607 1.000 102067554 19

2 1.025 102181667 102054014 102098608 1.060 102067691 21

3 1.085 102181668 102054015 102098609 1.120 102067692 24

4 1.145 102181669 102054016 102098610 1.180 102067693 27

5 1.205 102181670 102054017 102098611 1.240 102067694 30

6 1.265 102181671 102054018 102098612 1.300 102067695 33

7 1.325 102181672 102054019 102098613 1.360 102067696 36

8 1.385 102181673 102054020 102098614 1.420 102067697 39

9 1.445 102181674 102054021 102098617 1.480 102067698 43

10 1.505 102181675 102058592 102098618 1.540 102067699 46

11a 1.565 102181676 102058593 102098619 1.600 102067700 50

12 1.625 102181677 102058594 102098620 1.660 102067701 54

13 1.685 102181678 102058595 102098621 1.720 102067702 58

14 1.745 102181679 102058596 102098622 1.780 102067703 62

15b 1.805 102181680 102058597 102098623 1.841 102067704 66

16 1.866 102181681 102058598 102098624 1.904 102067705 71

17 1.929 102181682 102058599 102098625 1.968 102067706 76

18 1.993 102181683 102058600 102098626 2.033 102067707 81

19 2.058 102181684 102058601 102098639 2.099 102067708 86

20 2.124 102181685 102058602 102098640 2.167 102067709 92

21 2.192 102181686 102058603 102098641 2.236 102067710 98

22 2.261 102181687 102058604 102098642 2.307 102067711 104

23 2.332 102181688 102058605 102098643 2.379 102067712 111

24 2.404 102181689 102058606 102098644 2.452 102067713 117

25 2.477 102181690 102058607 102098645 2.527 102067714 125

26 2.552 – 102058608 102098646 2.603 102067715 132

27 2.628 – 102058609 102098647 2.681 102067716 140

28 2.706 – 102058610 102098648 2.761 102067717 149

29 2.786 – 102058611 102098650 2.842 102067718 158

30 2.867 – 102058612 102098651 2.925 102067719 167

31 2.950 – 102058613 102098652 3.009 102067720 177

32 3.034 – 102058614 102098653 3.104 102067721 187

33 3.129 – 102058615 102098654 3.201 102067722 199

34 3.226 – 102058616 102098655 3.301 102067723 212

35 3.326 – 102072103 102098656 3.414 102067724 225

36 3.439 – 102072104 102098657 3.531 102067725 241

37 3.556 – 102072105 102098658 3.650 102067726 257

38 3.882 – – 102098662 3.975 101901846 307

39 4.005 – – 102098663 4.168 101901847 327

40 4.198 – – 102098664 4.370 101901848 359

41 4.400 – – 102098665 4.580 101901849 394aSmallest baffle used with 4 1/2-in. RapidStage cementingbSmallest baffle used with 5 1/2-in. RapidStage cementing3 1/2-in. size not qualified for cemented applications


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RapidShift™ Sleeve(Ball Drop and Mechanical Shift Versions)

Casing Size in. Material

Tool ODin. (mm)

Tool IDin. (mm)

Minimum Openhole Size

in. (mm)

Maximum Temperature*

°F (°C)

Maximum Pressure*psi (MPa)

Number of Interventionless Zones

(Ball Drop Only)**

Uncemented Cemented

3 1/2125 ksi

Minimum Yield Alloy Steel

4.4(111.76)

2.88(73.15)

4.75(120.65)

350(177)

10,000(68.95) 25 Not Qualified

4 1/2125 ksi


5.7(144.78)

3.75(95.25)

6.125(155.58)

350(177)

11,000(75.84) 37 27

4 1/2110 ksi

Minimum Yield Super 13 Chrome

5.7(144.78)

3.75(95.25)

6.125(155.58)

350(177)

10,000(68.95) 37 27

5 1/2125 ksi


7.5(190.50)

4.67(118.62)

7.875(200.03)

350(177)

10,000(68.95) 41 27

*All ratings for the material and maximum tool OD listed above. Contact your local Halliburton representative for tools made from materials or dimensions other than those listed.**This is the maximum number of zones available using the 30 plus ball/baffle combinations; 5000-series ball/baffle combinations are more limited.The maximum pump rates are limited by the baffle size. Refer to literature on the ball/baffle combinations.

Hydraulically Activated Shifting Tools For RapidShift™ Sleeves

Tool Size

in.Part

Number

Tool OD at Maximum Key Expansion*

in. (mm)

Tool OD Retracted in. (mm)

TopThread

in.

Maximum Temperature

°F (°C)

Minimum Pressure to Expand Keys

psi (Mpa)

3.5 101975062 3.52(89.41) 2.72 1 1/2 AMMT 350

(177)600

(4.14)

4.5 101930910 4.158(105.61) 3.61 2 3/8 - 5.95

API EU350

(177)500

(3.45)

4.5 102112937 4.23(107.44) 3.36 2 3/8 - 5.95

API EU350

(177)500

(3.45)

5.5-in. sizes are also available; request 142DSS7.*Key expansion will only expand until it contacts the ID it is being passed through. The maximum expansion is limited by key hard stops in the tool itself.This table lists the standard bi-directional shifting tools.Other shifters are available. Contact your local Halliburton representative for more information.


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ZoneGuard® SR Packer

Halliburton’s ZoneGuard® SR (Short Radius) packer is

designed for situations where tight radius well conditions are

anticipated. The packer uses a multi-durometer element

package with a unique backup and deployment system to

deliver unsurpassed sealing performance in a wide range of

openhole conditions. The design features an anti-preset

feature to help protect against premature setting of the packer

during running operations. The packer can be used for zonal

isolation in formation control, selective stimulation, and

fracturing applications.

The ZoneGuard SR packer is run as an integral part of the

production casing or casing string. The packer is set with

hydraulic pressure either by setting a plug beneath the tool,

or when plugging the completion string is not possible, by

running a isolation straddle tool across the packer.

Applications• Horizontal or vertical completions

• Openhole isolation

• Stimulation

• Stage cementing

• Water shutoff

• Gas shutoff

• Production testing

• Selective production

Features• Long-term isolation reliability

• Small running OD

• Compact length for short radius well conditions

• Anti-preset feature

• Multi-piece/multi-durometer element package

• Adjustable setting shear value

• Internal locking system

• Multiple hydraulic setting methods

Benefits• Ideally suited for short radius and higher differentials

• Enables selective production management in horizontal

wellbores

• Offers the ability to reliably control inflow or injection

within selected sections of the wellbore

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Part Number

Tool Connection

in.

MaximumMetal OD

in.

MinimumIDin.

MinimumBore Hole

in.

MaximumBore Hole

in.Length

Temperature

Rating °F

Pressure Rating psi

102053962 4 1/2Blank 5.65 3.850 5 7/8 6 1/4 70.48 325 up to 10,000

102053960 4 1/213.5 lb API-LC 5.65 3.850 5 7/8 6 1/4 60.01 325 up to 10,000

102053961 4 1/213.5 lb API-BC 5.65 3.850 5 7/8 6 1/4 63.98 325 up to 10,000

102123418 5 1/2 23.0 lb API-LC 7.25 4.670 7 1/2 7 7/8 80.24 325 up to 10,000

102123419 5 1/2 23.0 lb API-BC 7.25 4.670 7 1/2 7 7/8 80.24 325 up to 10,000

102123420 5 1/2 Blank 7.25 4.670 7 1/2 7 7/8 80.24 325 up to 10,000

102107206 5 1/2 20.0 lb API-LC 8.00 4.670 8 1/2 8 3/4 80.36 325 up to 10,000

102148005 5 1/2 23.0 lb API-BC 8.00 4.670 8 1/2 8 3/4 80.36 325 up to 10,000

102148006 5 1/2 Blank 8.00 4.670 8 1/2 8 3/4 80.36 325 up to 10,000


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Today’s oilfield requires operators to find simpler, safer, and

more stable downhole technologies. The Swellpacker®

isolation system is an innovation that meets all of these

criteria. The technology is based on the swelling properties of

rubber in hydrocarbons or water, or in both. It swells up to

200%, sealing the annulus around the pipe to achieve

effective zonal isolation. Once deployed, the rubber retains

its flexibility, allowing the Swellpacker isolation system to

adapt to shifts in the formation over time, retaining the

integrity of the seal. Its self-healing properties make this a

truly innovative technology for all zonal isolation

applications. This bonded-to-pipe product can be delivered

with any element length depending on the basepipe length.

Since the rubber is bonded to the basepipe, it is extremely

robust and can hold significant differential pressures.

The Swellpacker system can be used in cased or openhole

environments. In some openhole applications, operators may

be able to avoid cementing and perforating altogether,

reducing the expense associated with these operations. By

reducing well construction costs, saving rig time, and

isolating producing zones, the Swellpacker system helps

enable previously unachievable levels of oilfield performance.

Cementing Support

For well integrity issues, the Swellpacker isolation system can

also be used to complement the primary cement job. The

system provides comprehensive long-term zonal isolation,

increasing the productive life of the well and minimizing the

potential for an expensive workover operation. This

combination of proven technologies provides an effective

means to address both micro-annulus concerns and

incomplete cement sheath issues.


Swelling Delay Systems

To ensure that the oil or water contained within the well fluid

does not affect the packer while it is run into the hole,

Halliburton has engineered several systems that can delay the

swelling process. These systems enable control of the

elastomer swelling process as the setting time can be tailored

according to the customer’s needs, mitigating the risk of

premature setting while optimizing the operating envelope.

The swelling delay systems include polymers with built-in

slower swelling properties and a variety of applied diffusion

barriers. Customizing a design with either of these options,

or using in combination, allows for creation of a well-specific

engineered product.

End Ring Design

In addition to the elastomer compound development,

Halliburton continues to innovate in all areas of Swellpacker

isolation system design, including the end rings. These

important components assist in increasing the differential

pressure capability and guide the packer when run into the

hole. Depending on the application and metallurgy

requirements, the design can be anchored using set screws, a

crimping process, or welding.

Halliburton has developed the K2 end ring, which protects

the rubber element while running in hole and further

eliminates element extrusion once the packer is set. One of

the benefits of this unique end ring is the ability to shorten

tool length, while maintaining differential pressure. It also

increases absolute differential pressure performance of the

tools with testing performed to 15,000 psi across the packer.

K2 End Ring

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Swellpacker® Cable System

The Swellpacker® system can be delivered with a unique cable

feed-through option that enables the passage of single or

multiple control lines and flatpacks for downhole

monitoring, chemical injection, and SmartWell® completions

without the need to cut the cables or lines. This removes the

requirement for cable splices, control line cuts, and cable

stripping, greatly reducing the risk of failure. It provides an

annular seal in cased and open hole, and a seal around the

control lines or flatpacks capable of holding differential

pressure. Installation of the cables through the Swellpacker

system is performed on the rig floor at the time of running

the completion and requires no extra rig time.

Swellpacker® Cable System

InstallationTo install the systems, simply perform standard pre-job

checks, then run in hole as part of the reservoir completion

string or liner system. At that point, either produce the well

to begin the swelling process, allow the current well fluid to

swell the packer systems prior to operations, or circulate

down the designed swelling fluid. The simplicity of the

operation means that specialized installation personnel are

not required.

For the cable design, Halliburton provides the installation

tool that fits easily on the rotary cable and installs the control

cable or flatpack through the packer.

Applications• Open and cased hole isolations

• Stimulation placement

• Open and cased hole straddles

• SmartWell completion systems

• Monitoring and chemical injection

• Water control

• Multilaterals

• Stand-alone screen sand control

• Compartmentalization for screen/ICD completions

• Gravel pack isolation

• Well construction

Features• Manufactured on any oilfield tubular

• Suitable for cased and open holes

• Robust construction

• No moving parts

• Spliceless cable feed-through option

• Self-healing, interventionless technology

• Can be run in most all fluid environments

• Multiple polymers available to provide oil swelling, water

swelling, and hybrid swelling solutions

• Engineered swelling delay system

Benefits• No specialist operator required for installation

• Casing integrity is maintained

• Perfect seal for irregular borehole geometry

• Alternative solution to cementing and perforating in

certain applications

• Complements cement to resolve well integrity issues

• Helps reduce operational risk

• Isolates producing zones more effectively

• Helps reduce well costs and rig time

• Cable feature increases system reliability by eliminating

cable splicing and enables openhole SmartWell

completions

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Bonded-to-Pipe Tools

OperatingCondition Oil Swelling (OS) Water Swelling (WS) Hybrid Swelling (HS) Comments

Run in Hole Fluid:Oil-Based Mud

Design to suitapplications All fluid systems Design to suit applications Contact Halliburton for

engineered delay system

Run in Hole Fluid:Water-Based Mud All fluid systems Design to suit applications Design to suit applications Contact Halliburton for


Temperature Range 30 - 390°F (0 - 200°C) 30 - 390°F (0 - 200°C) OS: 30 - 390°F (0 - 200°C)WS: 265 - 390°F (130 - 200°C) —

Reservoir Fluid:Liquid Hydrocarbon

Wide range of crude oil tested; swelling rate is a function of

fluid viscosity

Does not swell in hydrocarbons

Wide range of crude oil tested. Swelling rate is a function of

fluid viscosity

Contact Halliburton fordesign and simulations

Reservoir Fluid:Oil with HighWater Cut

Swells in traces ofhydrocarbon fluid

All fluid systems; swelling depends on temperature

and salinity

Swells in traces of hydrocarbon fluid; water

swelling depends on temperature and salinity

Contact Halliburton for design and simulations

Reservoir Fluid:Water Does not swell Wide range of fresh and saline

water testedWide range of fresh and saline

water testedSalinity and temperature

affect swell time

Reservoir Fluid:Gas Condensate


Requires contact with water-based fluid for permanent seal



DifferentialPressure Capability

Up to 15,000 psi(1032 bar)

Up to 10,000 psi(690 bar)


Contact Halliburton forapplication-specific pressure ratings

Time to Set Varies based on designs and well conditionsCan be engineered for swelling delays of 1-20 days

Contact Halliburton forapplication-specific simulations

Chemical Resistance Common oilfield chemicals Contact Halliburton forapplication-specific questions

Element Length Application and basepipe dependent Contact Halliburton forlength requirement

BasepipeTensile/Burst/

Collapse/MetallurgyCustomer supplied or Halliburton purchased to match specifications Can be built on any oilfield tubulars


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Swellpacker® Slip-On Isolation System

The Swellpacker® slip-on isolation

system is based on the swelling

properties of rubber in hydrocarbons

and/or water, swelling up to 200% to

seal the annulus around the pipe for

effective zonal isolation. This unique

slip-on packer retains a full length

internal seal against the pipe. Once

deployed, the rubber retains its

flexibility, allowing the Swellpacker

system to adapt to formation shifts over

time to maintain seal integrity. Its self-

healing properties make it a truly

innovative technology for all zonal

isolation applications.

The Swellpacker slip-on isolation

system does not require basepipe to be

supplied up front in the manufacturing

process and is installed at the service

location or rig site by sliding over the

pin end of the casing or tubing joint.

This allows storing and stocking of the

tools, simplifying logistics, and

reducing cost significantly.

The system can be used in cased or

openhole environments. In some

openhole applications, operators may be

able to avoid cementing and perforating

altogether, reducing the expense

associated with these operations.

Cementing SupportFor well integrity issues, the

Swellpacker slip-on system can also be

used to complement the primary

cement job. The system provides

comprehensive long-term zonal

isolation, increasing the productive life

of the well and minimizing potential for

an expensive workover operation. This

combination of proven technologies

provides an effective means to address

both micro-annulus concerns and

incomplete cement sheath issues.

Slip-On ConvenienceTraditionally, swellable packers

achieved high differential pressure

ratings based on the area in contact

with the casing wall or borehole.

Element length is a key parameter for

the contact area. The resulting

differential pressure, and therefore the

shorter slip-on designs, traditionally

had lower pressure holding capabilities.

Halliburton has developed shorter slip-

on tools that can handle the higher

differential ratings previously only

achievable through a longer bonded-to-

pipe product. One of those designs, the

Swellpacker HPE (high performance

element) slip-on isolation system

incorporates the K2 end ring to protect

the rubber element while running in

hole and support the rubber during and

after the swelling process. In addition,

the next generation of the Lite family,

the Swellpacker Lite II slip-on isolation

system, has been redesigned to create a

step change in slip-on tool capability.

Swelling Delay SystemsTo ensure the oil or water contained

within the well fluid does not affect the

packer while it is run into the hole,

Halliburton has engineered several

systems that delay the swelling process.

These enable control of the elastomer

swelling process as the setting time can

be tailored according to customer

needs, mitigating premature setting risk

while optimizing the operating

envelope. The systems include

polymers with built-in slower swelling

properties and a variety of applied

diffusion barriers. Customizing a

design with either of these options,

or using them in combination, allows

for creation of a well-specific

engineered product.

ApplicationsSwellpacker slip-on isolation systems

can be key components in gravel packs

for isolation and stand-alone screen

completions to reduce fines migration.

In reservoirs prone to sand production,

the slip-on tool helps enable increased

productivity and reduced well

construction costs since it can be

installed without specialized operating

personnel. In completions using inflow

control devices, slip-on tools are used

to create shorter compartments for

improved reservoir management.

Swellpacker® Slip-On Isolation System

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For many reservoirs using inflow control technology, the

Constrictor® slip-on isolation system can be an ideal device

due to its simple design and reliable performance.

One of the main applications for slip-on systems is with

hydraulic stimulation operations. Halliburton horizontal

completions provide operators with new options for

completing horizontal multi-zone wellbores and enable

highly accurate fracture placement with little to no

intervention. The service allows operators to selectively

access, isolate, and stimulate multiple payzones in a single

wellbore with the option to close off one or more zones at a

future date. This makes multi-zone stimulation possible in a

shorter time interval, leading to reduced overall well

completion costs.

Constrictor® Slip-On Isolation System

InstallationSlide the slip-on system onto the basepipe, securing in place

with Halliburton end rings. Run in hole with assembly. The

tool simplicity means installation does not require specialist

attention and can be fitted by personnel at the rig site.

Features• Suitable for cased and open holes

• Install on any non-upset basepipe

• Robust construction

• No moving parts

• Self-healing, interventionless technology

• Can be run in most all fluid environments

• Multiple polymers available to provide oil swelling, water

swelling, and hybrid swelling solutions

• Engineered swelling delay system

Benefits• No specialist operator required for installation

• Casing integrity is maintained

• Simplified logistics

• Permits last minute adjustments to placement

• Perfect seal for irregular borehole geometry

• Protect sand screens from plugging

• Alternative solution to cementing and perforating

• Helps reduce operational risk

• Isolates producing zones more effectively

• Helps reduce well costs and rig time

HAL32576

Slip-On ToolsOperating Condition Oil Swelling (OS) Water Swelling (WS) Hybrid Swelling (HS) Comments

Run in Hole Fluid:Oil-Based Mud Design to suit applications Does not swell in

hydrocarbons Design to suit applications Contact Halliburton for engineered delay system

Run in Hole Fluid:Water-Based Mud All fluid systems Design to suit applications Design to suit applications Contact Halliburton for


Temperature Range 30 - 390°F (0 - 200°C) 30 - 390°F (0 - 200°C) OS: 30 - 390°F (0 - 200°C)WS: 265 - 390°F (130 - 200°C) —

Reservoir Fluid:Liquid Hydrocarbon


fluid viscosity

Does not swell in hydrocarbons


fluid viscosity


Reservoir Fluid:Oil with HighWater Cut

Swells in traces of hydrocarbon fluid

All fluid systems; swelling depends on

temperature and salinity

Swells in traces of hydrocarbon fluid; water

swelling depends on temperature and salinity


Reservoir Fluid:Water Does not swell Wide range of fresh and

saline water testedWide range of fresh and

saline water testedSalinity and temperature

affect swell timeReservoir Fluid:Gas Condensate


Requires contact with water-based fluid for permanent seal



Differential Pressure Capability




Contact Halliburton forapplication-specific pressure ratings

Time to Set Varies based on designs and well conditionsCan be engineered for swelling delays of 1-20 days.

Contact Halliburton for application-specific simulations

Chemical Resistance Common oilfield chemicals Contact Halliburton for application-specific questions

Element Length Standard lengths are 0.3 m, 0.5 m, and 1 m Custom lengths available on request


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Pneumatic Ball Launcher

The Pneumatic Ball Launcher enables continuous pumping

during stimulation when using RapidSuite™ ball-actuated

stimulation sleeves. The ball-launching pods can be installed

on top of the wellhead isolation tool, directly on the

wellhead, or trailer mounted. The sleeve activation balls are

loaded into the launching pods in sequence of their

deployment. Each ball is launched individually by means

of a remote console that can be locked out to prevent

accidental deployment.

Features• Allows for interventionless stimulation through

continuous pumping

• Up to 15,000 psi pressure rating

• Each pod holds up to four balls

• Able to launch up to 4.5-in. diameter ball

• Pods are stackable for wellhead mounting

• Units can be trailer mounted for increased capacity

• Trailer-mounted units can be equipped with acoustic

verification of ball release

• Visual verification of ball release

Benefits• Eliminates the need to install balls manually

• Remote operation helps keep personnel away from

dangerous areas

• Promotes continuous pumping of frac treatments

PneumaticBall Launcher

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HA

L3

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Trailer-MountedBall Launcher


horizontal completion systems - halliburton · horizontal completion systems ... the frac balls and...

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