03 intelligent completions hlb

7/24/2019 03 Intelligent Completions HLB

1/54Intelligent Completions 3-1

Intelligent CompletionsHalliburton Intelligent Completions is the world's leading

provider of intelligent technology to the upstream oilindustry. First introduced in 1997, SmartWell systemtechnology was the industry's first intelligent well completionsystem and was designed specifically to remotely control andmonitor specific reservoir zones.

Today, Halliburton Intelligent Completions offers a broadcomplement of products and services that range fromreservoir engineering studies to advanced completion design,zonal isolation and flow control, reservoir monitoring, andsurface digital infrastructure solutions.

SmartWell Systems

A SmartWell completion system optimizes productionby collecting, transmitting, and analyzing completion,production, and reservoir data; allowing remote selectivezonal control and ultimately maximizing reservoirefficiency by:

Helping increase production Commingling ofproduction from different reservoir zones increases andaccelerates production and shortens field life.

Helping increase ultimate recovery Selective zonalcontrol enables effective management of water injection,gas and water breakthrough, and individual zoneproductivity.

Helping reduce capital expenditure The ability toproduce from multiple reservoirs through a singlewellbore reduces the number of wells required for fielddevelopment, thereby lowering drilling and completioncosts. Size and complexity of surface handling facilitiesare reduced by managing water through remotezonal control.

Helping reduce operating expenditure Remoteconfiguration of wells optimizes production withoutcostly well intervention. In addition, commingling ofproduction from different reservoir zones shortens fieldlife, thereby reducing operating expenditures.

SmartWell systems are designed to meet the demands of

every intelligent completion in all global areas andenvironments. Halliburton Intelligent Completions hasdesigned its product lines and solutions accordingly.

Flow control solutions include interval control valves(ICV), lubricator valves (LV), packers, and downholecontrol systems.

Permanent monitoring solutions include downholegauges and flowmeters.

Digital infrastructure solutions include a supervisorycontrol and systems designed for manual, automatic, andintegrated operation and electro-hydraulic control andmonitoring systems.

Optical fiber solutions include distributed temperaturesensing (DTS) tools and software.

Reliability

Reliability is essential for intelligent completion systems, andHalliburton engineers reliability into all of its equipment.The company is ISO 9001 application certified and hasdeveloped processes to guide, monitor, and optimize systemdelivery and performance. In addition, Halliburton has adedicated Reliability Assurance department that managesreliability tools and processes.

Halliburton maintains a detailed database to track the fieldperformance of each SmartWell system installation. Theknowledge gleaned from this data is used to calibrate designpredictions and optimize the design and production process.


2/543-2 Intelligent Completions

Flow Control Valves

Halliburton Intelligent Completions offers interval control valves (ICV) both with and without shrouds and deflectors: HS-ICV Interval control valve for deepwater and high-

pressure/high-temperature applications MCC-ICV Cost-effective valve with choking capability LV-ICV Lubricator valve

HS-ICV Valve

The HS interval control valve is the next-generationdownhole control valve designed for Halliburtons industry-leading SmartWell intelligent completion systems. The HS-

ICV is designed for deepwater and high-pressure/high-temperature (HP/HT) applications in which operatingconditions are extremely severe.

The HS-ICV's eight-position standard gas/liquid flow trimshave been characterized to provide optimum production/injection at various positions. Optional onboard sensorstrack the movement of the flow trim. These position sensorsprovide the operator with real-time feedback to confirm valve movements.

Features

Proprietary, debris-tolerant, metal-to-metal seal Customizable gas/liquid flow trim

Can be used in simple on/off intervention avoidanceapplications or in more versatile advanced reservoirmanagement choking applications with theAccu-Pulse module

Benefits Remotely control flow into or out of the reservoir in

challenging environments such as deepwater and HP/HT

Eliminate the potential for wellbore debris to be trappedinside the tool and consequently prevent valvemovement or impact sealing integrity

Obtain real-time confirmation of remotely actuated valve movements using optional position sensors

Unload at a maximum differential pressure of 5,000 psiwithout the threat of any valve damagethe highestunloading capacity in the industry

H A L 3 0 6 4 2



OperationHydraulically actuated, the HS-ICV is operated remotelyfrom surface using Halliburton Intelligent Completionsreliable Direct Hydraulics, Digital Hydraulics, or SmartPlex

downhole control system. The premium thermoplastichydraulic chamber seals are designed to operate under highactuation pressures and temperatures. The valve has also beensubjected to a stringent qualification program, includingtemperature, pressure, debris, and erosion tests.

The HS-ICV body has slots to accommodate two 1/4-in.dedicated instrument wires for position sensors and allowsbypass of up to six 1/4-in. bare hydraulic control lines orinstrument wiresall without compromising valve bodyrating or working envelope.

Debris-Tolerant DesignThe HS-ICV has been designed and tested such that the flowtrim will ensure complete metal-to-metal (MTM) sealintegrity even when exposed to heavy wellbore debris. A one-piece valve mandrel design eliminates the potential forwellbore debris to be trapped inside the tool and consequentlyprevent valve movement.

Proprietary MTM SealThe HS-ICV houses a proprietary metal-to-metal flank sealthat enables the valve to unload at a maximum differentialpressure of 5,000 psi without the threat of any valve damage.Any additional tubing or annulus pressure acts on the MTMseal to further ensure seal integrity, which has beenrigorously tested and qualified at low and high-pressure (upto 10,000 psi) differentials.

Pressure-Balanced Valve MandrelA pressure-balanced valve mandrel design eliminates theneed for a latch mechanism to hold trim closed or the need tomaintain hydraulic pressure on the close chamber to keep theflow trim shut. This balanced sleeve design also preventsdrifting of the sleeve in the incrementally open position.

Mandrel design also includes a shifting profile that allows thesleeve to be mechanically shifted in the event hydraulic

control has been compromised or if sleeve momentum is notachievable due to scale buildup inside the ICV.

Available in Three Variants HSP Premium Choking ICV designed for more

advanced reservoir management when used inconjunction with SCRAMS Surface Controlled

Reservoir Analysis downhole control system HSB Base Choking ICV designed for more versatile

choking applications when used in conjunction with theAccu-Pulse incremental positioning module

HSO designed for simple on/off applications

The flow trims on the HSB and HSP ICV can be customizedto suit a particular wells injection or production philosophy.Tungsten carbide is the material of choice for these flow trimsto combat the threat of erosion due to high flow rates.

Shrouded Versions

A shrouded configuration of the HS-ICV is availableprimarily for a two-zone stacked gravel pack application. Theshrouds can also be shrink-fitted with a carbide insert whenthe valve is used in a stacked gravel pack injection application.

Deflector VersionThis configuration of the HS-ICV is available primarily forhigh rate gas or water injection applications. The deflectorsare lined with tungsten carbide inserts to prevent erosionaleffects as a result of impingement from high flow velocityexiting the valve flow trim.



MC-ICV Valve

The MCC-ICV multi-position valve provides incrementalflow control over individual reservoir zones, allowing

optimization of reservoir architecture down hole andmaximizing recovery.

Halliburton Intelligent Completions surface control systemsprovide accurate incremental control over the MC-ICVchoke trim and can be tailored to fit the operator's needs.

The MCC-ICV is fitted with a tungsten carbide flow trim tocontrol erosion from aggressive downhole conditions.

The valve is available in a range of sizes and threadconfigurations and can be coupled with either an automaticor manual control system to accommodate specific

operational requirements.

Nominal Well ConditionsMC-ICVs have been specifically designed for use in wellswith the following normal conditions:

5,000 psi maximum differential pressure

Negligible H2S and CO2 BHT < 275F

Moderate duty cycle (open/close with pressuredifferential)

Features Simple cost-effective design

Bonded nitrile seals

Open/close functionality in the MC0-ICV

Multi-position functionality with tungsten carbide flowtrim in the MCC-ICV

Manual override

Benefits Cost-effective SmartWell system functionality in

moderate service conditions

Remote control of reservoir intervals without the needfor well intervention

MC-ICVValve

H A L 3 0 6 4 9



Interval Control Valves

T y p e

S i z e

i n .

M a x

i m u m

W o r

k i n g

P r e s s u r e

A v a

i l a b l e p s

i

M a x

i m u m

H y d r u a l

i c C h a m

b e r

R a t i n g p s

i

M a x

i m u m

T e m p e r a

t u r e

R a t

i n g

A v a

i l a b l e

F

M a x

i m u m

O D A v a

i l a b l e

i n .

M i n i m u m

I D A v a

i l a b l e

i n .

M i n i m u m

I n t e r n a l

F l o w

A r e a

i n .

P i s t o n

A r e a

i n .

T o t a l S t r o k e

i n .

H y d r a u l

i c C h a m

b e r

D i s p l a c e m e n t

i n .

V e r s i o n

A v a

i l a b l e

A v a

i l a b i l i t y

M a x

i m u m

D i f f e r e n

t i a l U n l o a

d i n g

P r e s s u r e p s

i

S h r o u

d S i z e

i n . /

W e i g h

t l b

S h r o u

d O D A v a

i l a b l e

i n .

F l o w

A r e a ,

I D o f

S h r o u

d - I C V O D i n

.

D e f

l e c t o r

A v a

i l a b l e

D e f

l e c t o r

O D A v a

i l a b l e

i n .

F l o w

A r e a ,

O D o f

H S -

I D o f

D e f

l e c t o r

i n .

H S - S e r i e s

2 7/8 7,500 10,000 275 4.660 2.313 4.20 1.7166.00 10.29 Choke Yes

5,000 5 1/2 /20 5.800 5.030 Yes 5.995 2.583.28 5.62 On/Off TBA

3 1/2

7,50010,000 10,000 330 5.850 2.750 5.62 1.990

6.00 11.94 Choke Yes

5,000 7 /29 7.070 7.980 Yes 7.685 6.383.28 6.53 On/Off Yes15,000 13,500 40 - 235

4 1/27,500

10,000* 10,000 275 7.125 3.750 11.04 2.7806.00 16.68 Choke Yes

5,000 7 5/8 /39 8.535 9.300 Yes 8.315 5.323.28 9.11 On/Off Yes

5 1/2 7,500 10,000 40 - 275 8.279 4.562 16.38 4.2406.00 25.44 Choke TBA

5,000 No N/A N/A Yes 9.330 12.493.28 13.90 On/Off TBA

Notes:a) Chemraz seals are standard on HS-series valves. Cold array seal stacks MSE seals (40 to 275F) under development.b) HS-series valves are available in various metallurgy to suit well conditions.c) HS-series provides incremental positioning only in conjunction with an Accu-Pulse control module.d) HS-series choke trims can be customized to suit clients needs.e) HS-series 2 7/8-in. size choking valve is eccentric in design.f) Please consult ICV data sheet for exact specification.*) Pending qualification testing

Please contact Halliburton for more details.

Chemraz is a registered trademark of Greene, Tweed & Co.



HS Circulating Valve

The HS Circulating Valve is designed for use in SmartWelland conventional completion systems. Based on the provenHS interval control valve (ICV) design technology, the HScirculating valve is designed for safe and efficient circulationof completion fluids after landing the completion and settingthe HF-1 and completion packer.

The HS circulating valve is a bi-directional hydraulicallyoperated balanced piston valve with a gas tight redundantsealing mechanism. The sealing mechanism consists of adebris tolerant metal-to-metal (MTM) primary seal and asecondary thermoplastic seal array. The valve mandrelincorporates a carbide nose to prevent erosion of the sealingsurface areas.

Features Proprietary, debris-tolerant metal-to-metal seal Redundant thermoplastic seal ensures gas tight seal

integrity Erosion resistant carbide nose seal High circulation rates Remotely activated without intervention Manual override shift profile Bypass slots for 12 1/4-in. control lines

Benefits

Run above the production packer, operated after packeris set, providing improved well control Helps eliminate need to circulate across packer element,

reducing risk of damage to element Prevents circulation pressures from impacting reservoir Faster circulation rates reducing rig time Allows for circulating well kill fluid during workover

operations without need to perforating tubing

OperationThe HS circulating valve is placed above the productionpacker in the completion string and is run into the well.

For a SmartWell completion, once on depth, the HF-1production packer is set via pressure down the productiontubing. Element packoff integrity is then determined byapplying pressure down the annulus. The open line of the valve is pressured up via the surface control unit to open thesleeve. Circulation down the annulus or tubing begins.Higher circulation rates can be attained as fluid is notcirculated past the packer element. Once the desired volumeshave been circulated, the close line of the valve is pressuredup to move the sleeve into the closed position. The tubing isthen pressured up to a maximum of 7,500 psi to test thesleeve integrity. A zero leak rate should be observed. Oncompletion of a successful pressure test, the completionprogram can progress to the next step.

Field-Proven MTM SealThe HS circulating valve houses a proprietary MTM sealfrom the proven HS-ICV design. Any additional tubing orannulus pressure acts on the seal to further ensure itsintegrity. The seal has been rigorously tested and qualified atlow and high-pressure (up to 10,000 psi) differentials.

Redundant Thermoplastic SealThe MTM seal is backed up by a redundant thermoplasticseal to achieve gas tight sealing integrity. These field-proventhermoplastic metal energized (MSE) seals are designed forredundancy in low and high-pressure applications.

The MTM along with the redundant thermoplastic seal havebeen qualified to provide a gas tight (zero leak) seal integrity.

Pressure-Balanced Valve MandrelA pressure-balanced valve mandrel design eliminates theneed for a latch mechanism to hold the trim closed or theneed to maintain hydraulic pressure on the close chamber tokeep the flow trim shut. This balanced sleeve design preventsdrifting of the sleeve in the open position. The valve mandreldesign also includes a shifting profile that allows the sleeve tobe mechanically shifted in the event hydraulic control hasbeen compromised, or if sleeve movement is not achievabledue to scale buildup inside the ICV.

HS Circulating Valve

TubingSize

ValveODin.

ValveIDin.

MinimumInternal

Flow Areain.

HydraulicChamber

Displacementin.

Piston Area

in.

PistonStroke

in.

MaximumWorkingPressure

psi

Maximum ActuationPressure

psi

TemperatureRange

F

MaximumUnloadingDifferential

psi

5.5 8.279 4.562 16.346 23.438 4.246 5.52 7,500 10,000 40 - 330 5,000



eRED-HS Remotely Operated Circulating Valve

The eRED-HS valve is a computer-controlled, gas-tight(V0 rated) circulating valve that can be repeatedly opened or

closed by remote command. No surface connections orinterventions are required to communicate with or operatethe valve.

Permanently deployed above the production packer as partof the tubing string, the eRED-HS valve controls the flow ofwell fluids between the tubing and annulus without the needfor any interventions or surface control linessaving rig-time, costs, and helping to reduce risk.

ApplicationThe eRED-HS valve has been designed specifically to offer asafe and highly efficient method of circulating well fluids

during a well completion operation.

It is deployed as an integrated part of the tubing string,positioned above the main production packer. Thisconfiguration eliminates the need to circulate across theunset packer, reducing the risk of damaging the elements andpreventing circulation pressure from impacting the reservoir.

Normally, the eRED-HS valve is run-in-hole in the closedposition and subsequently opened by remote command afterthe packer has been set. The valve is commanded to open byapplying pressure at surface (for example, 2,000 psi for10 minutes) against a deep-set barrier such as a reservoirisolation barrier.

When open, well fluids can be circulated to underbalance thewell ready for production, and the large flow ports allowfaster pump rates to be used, saving rig-time.

With the circulation successfully completed, the eRED-HS valve is commanded to re-close and/or permanently lockusing another pressure window trigger. Each time the valve isoperated this way, an intervention is eliminated from theoperation, saving rig-time, costs, and helping to reduce risk.

Features Remotely operated time-after-time

Large tubing to annulus ports

Run open or closed

No dedicated personnel required

Metal-to-metal carbide seal

Benefits Eliminates multiple interventions during completion

operationssaving time, money, and helping reduce risk

Allows for faster pump rates, providing safer and moreefficient circulation of well fluids

Provides flexible deployment options and well controlwhile running-in-hole

Reduces the number of operations personnelsavingcosts and helping reduce risk

Debris tolerant, V0 rated seal capable of withstanding

high circulation rates

H A L 3 9 0 6 1



OperationThe eRED-HS valve is an integrated assembly of two existingdevices. The first is the eMotion electronic control unit. Thisis used to provide surface communication and the motive

force to operate the second devicea Halliburton HS-ICVcirculating valve.

The assembly has integrated pressure and temperaturesensors which it uses to monitor the well conditions and ispreprogrammed to either open or close whenever a specifiedcondition (known as a trigger) is detected.

The triggers use a variety of well parameters includingambient pressure, temperature, time or surface appliedpressure. Each time a trigger is detected the valve will eitheropen or close as per its instructions. This process can berepeated time-and-time again without the need for any formof intervention or any control lines to surface.

Controlling the eRED-HS Valve RemotelyBy applying a defined pressure for a defined time at surface,the operator can activate the pressure window trigger. Thisallows direct communication to the eRED-HS valve so it canbe remotely operated. For example, applying between 1,000and 1,500 psi for 10 minutes could instruct it to open.

Any pressure applied outside the defined values will beignored. This means pressure can be applied to the tubing(for tubing integrity tests or packer setting, etc.) without anyrisk of inadvertent activation.

Onboard data analysis allows the eRED-HS valve todistinguish its own commands from other external factorssuch as naturally fluctuating hydrostatic or reservoirpressure. This enables the valve to behave as planned even ifthe downhole conditions change unexpectedly.

A range of other triggers consisting of ambient well pressure,ambient well temperature and a timer are also available.These triggers are used to provide a pre-programmedsequence for the eRED-HS valve to follow without any input

from the surface.

Each trigger can be used independently or combined to buildmore elaborate instructions. For example, the eRED-HS valve could be set to close when it detects pressure below2,000 psi, but only after 100 hours downhole. The pressurewindow trigger can also be used to manually cancel oroverride any trigger or permanently lock the valve in itscurrent position.

Opening

One of the Four eRED -HS ValveFlow Ports

H A L 3 9 0 8 0

eRED-HS Valve

Size(to suit thread size)

in.

TemperatureRangeF (C)

Maximum DifferentialPressure While Opening

psi (bar)

5.5 39 - 284(4 - 140)5,000(345)

These specifications are for guidance only. Contact your local Halliburton representative foradditional design variables.



LV-ICV Lubricator Valve

The Lubricator Interval Control Valve (LV-ICV) is a high-performance, remotely controlled, tubing-conveyeddownhole lubricator system. The LV-ICV isolates pressure orflow above or below its position in the tubing string.

The LV-ICV can be used in any completion where pressure orflow isolation in the tubing string is required. When includedin a SmartWell intelligent completion system, the LV-ICVcan be used to control flow into or out of reservoir intervals.The LV-ICV can be controlled by any of HalliburtonIntelligent Completions Direct Hydraulics, DigitalHydraulics systems, or SCRAMS control systems.

The LV-ICV incorporates a ball with full open bore ID. Twocontrol lines are connected to the LV-ICV, one at each side ofthe operating piston. Pressure applied to one control lineopens the LV-ICV, allowing pressure or flow to pass throughthe ball. Pressure applied to the other control line closes theLV-ICV on the valve sealing surface for pressure integrity.

Because the ball seals on the same surface for flow/pressurefrom above and below, the LV-ICV pressure integrity is fullytestable from surface.

Features Full bore ID Deep set capability Minimal moving parts High force actuation for both open and close operations

Benefits Helps ensure pressure integrity from above and below

Helps control reservoir intervals without wellintervention

The LV-ICV is available in different sizes and materials to suitspecific well configurations.

H A L 3 3 6 4 1

LV-ICV Lubricator Valve

LV-ICV Valves

Size ODin.IDin.

MaximumTemperature

F

MaximumPressure

(Ball Open)psi

MaximumPressure

(Ball Closed)psi

MaximumHydraulicChamber Pressure

psi

MaximumUnloadingDifferentialPressure

psi

Piston Area

in.

TotalStroke

in.

HydraulicChamber

Displacementin.

InternalFlow

Areain.

3 1/2 5.705 2.890 280 7,500 5,000 7,500 1,000 3.360 2.100 7.050 6.560

4 1/2 7.155 3.813 280 7,500 5,000 7,500 1,000 3.980 2.510 10.000 11.420

5 1/2 8.015 4.620 280 7,500 5,000 7,500 1,000 4.670 3.080 14.400 16.800

Notes:Valve OD will increase if a control-line bypass is required.Valve is available in various metallurgy.Valves use Chemraz , PEEK , and Viton seals.Please contact Halliburton Intelligent Completions for additional information.

Chemraz is a registered trademark of Greene Tweed & Co., Inc. PEEK is a trademark of ICI Americas, Inc. Poly-Ether-Ether-Ketone. Viton is a registeredtrademark of DuPont Dow Elastomers, LLC-Fluorocarbon.



sSteam Valve

Cyclic Steam Stimulation (CSS) and Steam Assisted GravityDrainage (SAGD) are widely used enhanced oil recovery

(EOR) methods for extracting bitumen or hydrocarbons inheavy oil reservoirs. To help optimize production in CSS andSAGD applications, Halliburton has developed the sSteam valve. The sSteam valve allows uniform or selective steamplacement along the entire length of the horizontal section ofthe wellbore.

This robust downhole technology is designed to handle hightemperatures (500F) and moderate pressures associatedwith steam injection. The sSteam valve can be deployed aspart of the production liner with or without zonal isolations.

Features

500F temperature rating 3,000 psi working pressure

High-temperature control-line fluid

Metal-to-metal closure seal

Remotely operated

Benefits Permits uniform or selective placement of steam across

the wellbore

Places uniform steam chamber under variant reservoirand steam quality conditions

Prevents steam breakthrough by selectively shutting off a valve

Open Line

Splice ProtectionSleeve

Metal-to-MetalClosure Seal

TubingEquivalent

Flow AreaPorts

CommonClose Line

CommonClose Line

H A L 3 1 7 9 1

sSteamValve



OperationThe reliable Direct Hydraulics downhole control system useshydraulic lines connected directly from the surface toremotely actuate the sSteam valve. Each of the two control

lines required to operate the valve is connected to the open orclose side of the valve respectively. If multiple valves arepresent, the close side is networked to a common close line,and the open side of each valve has a dedicated open line. Aspecially developed hydraulic control fluid is used to operatethe valve.

This hydraulic control fluid retains its desired viscosity whensubjected to the extreme temperatures of the CSS/SAGDenvironment.

In the event of steam breakthrough, the sSteam valve can beselectively shut off, thus allowing efficient hydrocarbonrecovery without the threat of injected steam being producedor the need to shut down production to cool the reservoir.

sSteam Valve

Tubing Sizein. 3.5

Maximum ODin. 5.430

Minimum IDin. 2.735

Lengthin. 53.5

Top and Bottom Connection 3.5-in. 8 rd 9.3-lb EUE Box Box

Service Steam

Maximum Working TemperatureF 500

Working Pressure (Internal and External)psi 3,000

Test Pressure (Internal and External)psi 3,000

Base Metallurgy A005 (4140)

Fastener Metallurgy Stainless Steel

Piston Areain. 5.15

Total Stroke Open-Closein. 4.419

Tensile Rating*lbf 207,000

Compressive Rating*lbf 207,000

Minimum Internal Flow Areain. 5.87

Control-Line Bypass 6 .25-in. lines

Variations 2 Position / Open-Close

*Based on 9.3-lb tubing



Zonal Isolation Packers

HF-1 Packer

The HF-1 packer is a single-string, retrievable, cased-holepacker that features a facility for bypass of multiple electricaland/or hydraulic control lines. Available for use as both thetop production packer or as one of many lower packersisolating adjacent zones, the HF-1 packer includes aspecialized slip configuration and additional body lock ring,which allow it to operate under higher loads and greaterpressures than standard production packers.

Features Hydraulically activated interlock mechanism prevents

premature setting

No body movement during setting Premium thread connections NBR and HNBR element with anti-extrusion system Tailpipe can be left in tension or compression

Benefits Less damage to casing using a multi-cone, full coverage

slip system Fully retrievable after installation Can be deployed with SmartWell systems May be used as both top production packer and lower

isolation packer Avoid damage to control line during setting

Setting MechanismsThe HF-1 packer has two setting and three releasemechanisms.

Setting Mechanisms

Tubing pressure set Control-line set

Release Mechanisms

Punch and pressure release

Shift and pressure release Mechanical shift release

The release mechanism is recessed and selective, allowing forpassage of other toolstrings. Axial loads are supported in bothdirections so the tool cannot be released by tubing forces.

ConnectionsThe packer is made up directly to the tubing string viaintegral premium thread connections. The internal mandrelalso uses premium thread connections for continuity.

Anti-pre-set mechanisms incorporates a hydraulicallyactivated interlock system and can be adjusted prior torunning in the hole. The interlock system allows thepacker to be run in highly deviated or horizontal wells,eliminating the risk of pre-setting due to casing drag.

Tandem setting designed for tandem setting withtailpipe in tension, compression, or neutral. Settingmechanism is independent of tubing movement orpressure induced tubing forces. Setting action will notimpart loads on or damage any penetrations or lines.

PenetrationsProvision is made for the passage of multiple hydraulic and/orelectrical control lines. All connections are sealed usingHalliburton proprietary FMJ connectors.

Elastomeric SealsMaterial for setting chamber seals and tubing to lowerannulus is chosen based on application conditions.

Integral Element Anti-Extrusion SystemThe packing element is multi-piece with NBR sealingelements. It incorporates an anti-extrusion system thatprovides high resistance to swab off, which permits increasedrunning speeds and high annular circulation rates (up to8 bbl/min) prior to setting. The system has been qualifiedthrough multiple thermal cycles using both water andnitrogen as test media.

Load and Functional PerformanceAll HF-series packers are ISO-14310 V0 or V3 rated.



Retrievable Feed-Through HF Packer

Type

CasingMandrel

Size

in.

MaximumOD

in.

Bore IDin.

MaximumFeedthrough

MaximumDifferential

Across

Elementpsi

WorkingPressure

psi

WorkingTemperature

F

RequiredSetting

Pressurepsi

ElementType

ISO14310

RatingODin.

Weightlb/ft

H F 1 S e r

i e s

( 7 2 2 H F 1 )

P r o

d u c t

i o n /

I s o l a t

i o n

7

232 7/8 6.180 2.315

5

5,000 5,000

75 - 275

4,500Tubing6,500

Control line

Nitrile V3

3 1/2 6.180 2.750 7,500 7,500 Nitrile V3

26 3 1/2 6.090 2.750 7,500 7,500 Nitrile V3

292 7/8 5.995 2.315 7,500 7,500 NitrileHNBR

V3V3

3 1/2 5.995 2.750 7,500 7,500 NitrileHNBRV0V3

32 3 1/2 5.905 2.750 7,500 7,500 Nitrile V3

7 5/8

33.7 3 1/2 6.570 2.750

5

7,500 7,50075 - 275 4,500

Tubing6,500

Control line

Nitrile V3

39 3 1/2 6.430 2.750 10,000 10,000 Nitrile V0

45.3 3 1/2 6.240 2.750 7,500 7,500 140 - 260 HNBR V0

47 3 1/2 6.180 2.750 10,000 10,000 70 - 275 HNBR V0

9 5/8

43.5 4 1/2 8.515 3.812

7

7,500 7,50075 - 27570 - 285

4,500Tubing6,500

Control line

NitrileHNBR V3

5 1/2 8.515 4.562 7,500 7,500 75 - 275 Nitrile V3

47

3 1/2 8.440 2.750 7,500 7,50010,000 75 - 275NitrileHNBR V3

4 1/2 8.440

3.525(a) 7,500

(b) 10,000(c) 12,500

7,50010,00012,500

75 - 27540 - 30055 - 235

NitrileHNBR

V0V3

3.788

3.813

3.954

5 1/2 8.440 4.560 7,500 7,500 75 - 275 Nitrile V0

53.5

3 1/2 8.300 2.750 7,500 7,50075 - 275 Nitrile V0

40 - 275 HNBR V0

4 1/2 8.300

3.5257,500 7,500

75 - 275 NitrileHNBR V0

3.788 40 - 275 HNBR V0

3.813 10,000 10,000 40 - 275 HNBR V3

5 1/2 8.3004.560

7,500 7,500 75 - 27540 - 275NitrileHNBR

V0V04.625

71.8 4 1/2 7.890 3.525 7,500 7,500 75 - 275 Nitrile V0

9 7/8 62.8 4 1/2 8.440 3.813 12,500 12,500 55 - 235

4,500Tubing6,500

Control line

HNBR V3

10 3/4

60.7

5 1/2

9.430

4.5626

7,500 7,500 40 - 275 4,500Tubing6,500

Control line

Nitrile V0

65.7 9.330 (a) 7,500(b) 5,0007,5005,000 40 - 275

NitrileHNBR

V0V3

73.2 9.175 5 8,000 8,000 140 - 260 HNBR V0

11 7/8 71.8 4 1/2 10.550 3.688 5 5,000 5,000 75 - 275

4,500Tubing6,500

Control line

Nitrile V3

H F P S e r

i e s

( 7 2 2 H F P )

P r o

d u c t

i o n /

I s o l a t

i o n

9 7/8 62.8

3 1/2

8.440

2.755

5 10,000 10,000 100 - 220 6,500 AFLAS * V34 1/2 3.788

Notes:a) Available in two setting options: tubing set or control-line setb) Available in three releasing options: straight shift and pull method, knock-out plug and pump method, punch and pump methodc) Available in various metallurgy, elastomers, and thread connections to suit well conditionsd) Refer to individual specification sheets for additional details.Contact Halliburton for additional information.*AFLAS is a registered trademark of the Asahi Glass Co., Ltd.



MC Packers

MC packers, available for both production (MC-1) andisolation (MC-0) applications (no slips), are single-string,

cased-hole, retrievable packers primarily designed for use inSmartWell completions in marginal or mature assets.

Both MC production and isolation packers have the facility tofeed through up to eight hydraulic or electrical control lines,allowing communication with other SmartWell equipmentwithout compromising the integrity of the isolated zones. Insome instances, the MC production packer has been used asan isolation packer below the primary HF-1 productionpacker.

Features Simple, cost-effective design

Feed through for up to eight control lines Tubing set

Nitrile and HNBR packing element

Benefits Apply SmartWell technology in marginal or mature

assets

Maintain zonal integrity

Perform high pressure/tubing pressure testing

Achieve communication with laser tools

Setting MechanismBoth MC production and isolation packers are tubingpressure set. Incorporating a hydraulically activated interlocksystem, the MC packers can be adjusted externally prior torunning in the hole. The interlock system allows the packersto be run in highly deviated wells, helping eliminate the riskof presetting due to casing.

Release MechanismThe MC production packer is released by the shift-and-pullmethod. Once the primary packer is released, the MCisolation packer can be retrieved simply by pulling it straight

out of the well.

Packing ElementThe MC packer is fitted with a state-of-the-art nitrile andHNBR packing element similar to those used in the high-performance HF-1 packer. This element offers robustness andexcellent sealing properties.

Nominal ConditionsThe MC production and MC isolation packers are designedfor use in wells with the following normal conditions:

BHP < 5,000 psi

Negligible H2S and CO2BHT < 275F

P 5,000 psi

ReliabilityThe MC production and isolation packers have been qualifiedto an ISO 14310 V3 rating.

MCPacker

H A L 3 0 6 4 9



Retrievable Feed-Through MC Packers

Type

CasingMandrel

Sizein.

Maximum

ODin.

Bore IDin.

MaximumFeedthrough

MaximumDifferential

AcrossElement

psi

Working

Pressurepsi

Working

TemperatureF

RequiredSetting

Pressurepsi

ElementType

ISO

14310RatingOD

in.Weight

lb/ft

7 2 2 M C P r o

d u c t

i o n

P a c

k e r

7

23 3 1/2 6.180

2.817 8 5,000 5,000 75 - 275

4,000 HNBR V3

26 - 29 3 1/2 5.992

2,400

Nitrile V3

26 3 1/2 5.992 Viton V3

29 3 1/2 5.992Viton V3

2,500 HNBR V3

9 5/8

40 5 1/2 8.614 4.580

8

5,000 5,000

75 - 275

4,000 HNBR V3

43 4 1/2 8.515 3.820 4,000Nitrile V3

HNBR V3

47

3 1/2 8.440 2.750 4,000 HNBR V3

4 1/2 8.460 3.810 3,500 Nitrile V3

5 1/2 * 8.455 4.590 4,000 Nitrile V3

53.5 *

3 1/2

8.297

2.825

5,000 5,000 4,000

Nitrile V3

4 1/2 3.820 Nitrile V3

5 1/2 4.590 Nitrile V3

I s o l a t

i o n

P a c

k e r 5 1/2 13 - 17 2 7/8 4.700 2.373 8 2,500 5,000 75 - 275 2,400 Nitrile V3

7 26 - 29 3 1/2 5.980 2.885 8 2,500 5,000 75 - 275 2,400 Nitrile V3

Notes:a) Packer is set only via the tubing.b) Packer is released via straight shift and pull methodc) Thread connections: VAM TOPd) Refer to individual specification sheets for additional details.

*Pending qualification testing

Contact Halliburton for additional information.

VAM is registered Trademark of Vallourec Oil and Gas France



Seal Stack Assembly

Halliburton Intelligent Completions seal stack assemblyisolates individual zones in SmartWell intelligent completion

systems in applications where it is not possible or desirable touse packers for isolation.

The seal stack assembly enables bypass of control lines tocommunicate with equipment installed lower in thecompletion string.

Typical applications are gravel pack or ESS completions wherethe seal stack assembly will stab into a polished bore toprovide isolation between different reservoir intervals in thesandface completion. This ability is based on the use of a stackof robust bonded seal rings arranged along the assemblylength.

The seal stack assembly allows up to six independent controllines to bypass, enabling control and monitoring ofequipment below, such as interval control valves (ICV) andpermanent downhole gauges.

The device is capable of isolating zones with a differentialpressure of up to 7,500 psi but, unlike the HF-1 packer range,

has no load bearing capability.Features Simple effective design

Multiple sets of bonded seals

Bypass for up to six control lines

Field proven

Benefits Installs above ICVs and permanent downhole gauges

Isolates reservoir intervals without requiring a packer

Helps eliminate need for setting/release system

Seal Stack Assembly H A L 3 0 6 5 0



Seal Stack Assembly

Sizein.

Maximum

Body ODin.

Seal ODin.

Minimum

IDin.

Lengthin.

Maximum

TemperatureF

MaximumPressure

(Burst andCollapse)psi

MaximumDifferentialPressure

psi

HydraulicPort

PressureRatingpsi

Thread Size and

Type(B x P)

4.75(ECC) 4.695 4.826 2.382 83.640 275 10,000 7,500 10,000

2 7/8 in. 6.4 lbVAM TOP

4.80(ECC) 4.740 4.870 2.340 92.420 275 10,000 7,500 10,000

2 7/8 in. 6.4 lbNew VAM

5.00 5.076 4.945 2.313 80.000 275 10,000 7,500 10,000 2 7/8 in. 6.4 lbNew VAM

5.80 5.770 5.876 2.945 88.923 275 10,000 7,500 10,000 3 1/2 in. 9.2 lbNew VAM

6.10 6.050 6.176 2.945 72.220 275 10,000 7,500 10,000 3 1/2 in. 9.2 lbVAM TOP

7.125 7.075 7.201 2.945 72.210 275 10,000 7,500 10,000 3 1/2 in. 9.2 lbVAM TOP

7.20 7.150 7.276 3.813 107.210 275 10,000 7,500 10,000 4 1/2 in. 12.6 lbVAM TOP

Control lines are normally hydraulically spliced above and below the seal stack assembly. Control-line feed throughs are also available.Number of feed throughs or hydraulic splices or both depends on the size of mandrel.Seals are nitrile bonded 90 duro.Contact Halliburton for additional information.VAM is registered Trademark of Vallourec Oil and Gas France



Downhole Control Systems

Downhole control systems provide a method of integrating

the surface control system (either manual or automated) withdownhole SmartWell equipment.

SCRAMS Surface Controlled ReservoirAnalysis and Management System

The SCRAMS system is a fully integrated control and dataacquisition system that allows the operator to remotely controlthe wellbore and obtain real-time pressure/temperature datafor each zone. This data feedback and accurate flow controlcapability allow the operator to optimize reservoirperformance and enhance reservoir management.

The SCRAMS system is ideal for onshore, platform, and subseaapplications and is typically used to control the HS-ICV valvefor precise control of flow into or out of a reservoir interval.

Features Can be used to control infinitely variable hydraulic flow

control valves Can be used for land, platform, or subsea applications

Capable of interfacing with multiple subsea control

vendors Infinitely variable control valve positioning Flow estimation derived from fundamental metrology

Benefits Optimize reservoir performance by controlling multiple

reservoirs without intervention Enhance reservoir management through real-time data

acquisition Remotely control the wellbore Obtain real-time pressure/temperature data for each

reservoir interval Steer around faults for continued functionality using full

redundancy capability Control multiple intervals from only one of the two

electro-hydraulic flatpacks through multi-dropfunctionality

Primary Flat-PackConsisting of 1x Electrical Line1x Hydraulic Line

Electrical LineHydraulic LineBroken/Damaged Line

Damaged or Broken Line

Connection Re-establishedvia SAM Unit

ConnectionRe-establishedvia SAM Unit

Damaged or Broken Line

Infinitely VariableInterval Control Valve

SAM Unit

Auxiliary Flat-PackConsisting of 1x Electrical Line1x Hydraulic Line

SCRAMS Surface Controlled Reservoir Analysis and Management System

H A L 3 0 6 5 5



OperationThe link from the control equipment located outside the wellto the downhole tools includes redundant hydraulic andelectrical buses in the form of control lines and electrical

conductors enclosed in a flatpack. The hydraulic control lineprovides the hydraulic locomotive force to the SAM sensor-actuated module tool, which in turn, using solenoid valves,distributes this force to each side of the ICV piston. Theelectrical conductor allows transmission of power andcommunication signals from the well controller to all of thedownhole tools by means of the multi-drop telemetry system.

To simplify and increase the reliability of the cable to thedownhole tool interface, the SCRAMS system adopts asignal-on power telemetry system. To further enhance thedownhole system survivability, the redundant electric andhydraulic network is segmented (SegNet communications

protocol) . If any failure, either electric or hydraulic, developsin any section of the network between surface and thedownhole tools, the SegNet communications protocolprovides the ability to steer around the failure, retaining fullfunctionality of the complete SmartWell completion system.

SAM Sensor Actuation ModuleThe SAM tool provides the control and data acquisitionfunctionality for the SCRAMS system. The SAM toolcontains redundant electronics, each separately connected to

individual flatpacks, a hydraulic manifold to distributehydraulic power, and sensors for pressure/temperaturemeasurement. The SAM tool is the active component of theSegNet infrastructure. Incoming electrical and hydraulicbuses are terminated into the SAM tool and exit to providecommunication to other SAM tools further down thecompletion string. Solenoid valve and electrical switchesincorporated in the SAM tool allow isolation of anypotentially faulty sections of the network connecting the nexttool in the completion.



SmartPlex Downhole Control System

The SmartPlex downhole control system is an electro-hydraulic multi-drop system that provides simple and

reliable zonal control of multiple valves in a single wellborewith a minimum number of control lines. The SmartPlexdownhole control system uses two hydraulic and one electricline from the surface to remotely and selectively actuatemultiple downhole flow control devices such as intervalcontrol valves (ICV). This makes a large number of tubinghanger penetrations unnecessary and reduces operationalcomplexity and risk.

The SmartPlex system can control any flow control tool inthe field-proven Halliburton portfolio.

Features

Three control lines for up to 12 downhole devices or fourcontrol lines for up to 24 downhole devices

Minimal use of only passive and no active electricalcomponents

System can remain pressured when operating any of theICVs in the same direction, significantly decreasing ICVactuation times

Can be deployed with non-integrated systems andfiber optics

Supports fail-as-is device types Independent of tubing or annulus pressure

Can be used to position ICVs in choking applications

Benefits Helps reduce cost in multi-valve completions Faster activation time for valves Reduces rig time through greater facilitation of

completion installation and retrieval Electro-hydraulic system provides high level of motive

power to operate ICVs Allows the ICV to be closed in a single step Provides the ability to move the ICV from closed to any

choking position in a single step

Three-LineFlatpack

Electric InHydraulic In

SmartPlexManifold

SmartPlexClamp

Electric OutHydraulic Out

Interval Control Valveor sFrac Valve

Three-LineFlatpack

Control Module withClamp Assembly

H A L 3 2 2 1 4



ApplicationThe SmartPlex downhole control system is applicable forany dry tree multi-zone completion requiring more than two valves. When compared to the Direct Hydraulics system, the

SmartPlex system not only helps reduce the overall cost of anintelligent completion, but also reduces the complexityinvolved by minimizing the number of control lines required.

The SmartPlex system is ideally suited for long horizontal,compartmentalized completions, in both cased or open hole,where selective control of each interval is desired. Typicallythis can be advantageous for selective stimulation control intight gas applications or in combination with a choking ICVfor drawdown optimization in production applications.

OperationThe SmartPlex system is a design that uses a simple passiveelectrical switching method. Each valve is coupled with aSmartPlex actuator module which allows selective andremote control of each valve. Control lines consisting of oneelectrical and two hydraulic lines run from surface and arenetworked to each SmartPlex module. A signal down theelectrical line switches a solenoid at the desired module,allowing hydraulic communication between the surfacecontrol unit and the valve. By regulating the f luid volume incombination with a time-domain control method, valves canbe incrementally positioned (choking) to allow for advancedreservoir management.

Qualification TestingThe SmartPlex control system has successfully passedextensive in-house deep well simulation testing. The tool hasbeen cycled more than 10,000 times at 300F (150C) at

10,000 psi internally and 15,000 psi externally. A three-valvesystem integration test with 10,000-ft control line was alsosuccessfully conducted.

H A L 3 2 2 1 5

The SmartPlex downhole control system provides a simple methodology for controlling up to 12 interval control valves.

H A L 3 1 8 0 5



Digital Hydraulics Downhole Control System

The Digital Hydraulics system is an all-hydraulic, multi-drop intelligent completion system that can direct any flow

control tool in the Halliburton portfolio, providing simpleand reliable zonal control for even the most complexreservoirs. The Digital Hydraulics system allows up to sixflow control devices to be controlled from only threehydraulic control lines, making a large number of tubinghanger penetrations unnecessary.

Features High activation forces for flow control devices in

both directions Three control lines for up to six downhole devices Four control lines for up to 12 downhole valves

Can be deployed with non-integrated systems andfiber optics No setting depth limitations All-hydraulic system Supports fail as is devices Field-proven Independent of tubing or annular pressure

Benefits Helps reduce control line costs Helps reduce rig time through greater facilitation of

completion installation and retrieval Fewer connections through tubing hanger

OperationThe Digital Hydraulics system design uses the logical absenceor presence of pressure (hydraulic code) to communicatebetween a surface controller and the downhole tools.

Existing pressure greater than 2,000 psi is represented by a 1and pressure less than 500 psi is represented by a 0.Depending on the pressure in the wellbore, a sequence of 1sand/or 0s is communicated to the flow control devices withinthe Digital Hydraulics system.

Each flow control device is paired with a decoder that isdesigned to respond to its own unique code and rejects allother codes or sequences. Using this method, thecommunication between the surface controller and thedownhole tools maintains its integrityeven whenconditions such as temperature changes, long control lines,fluids, and leaks can cause other hydraulic communicationmethods to fail.

The Digital Hydraulics system controls simple open/closeinterval control valves (ICV) and lubricator valves (LV) to

provide on/off flow control from each zone.Surface ControlThe surface equipment for the Digital Hydraulics system,Halliburton SmartWell Master supervisory application, isdesigned as part of the Digital Infrastructure system. A fullyautomated surface hydraulic system (SHS), controlled from acentral location allows control of the Digital Hydraulicssystem from a local or remote control station.

The SmartWell Master application translates DigitalHydraulics system logic into standard central control roomoperations. This translation allows the operator to easily

monitor and control multiple Digital Hydraulicscompletion systems as well as an individual zone within anintelligent well completion.

Control LinesFrom SurfaceControl LinesFrom Surface

To More

Decoders

Pressure

Decoder 1

Decoder 2

ICV 1

ICV 2

No Pressure

Digital HydraulicsSystem

H A L 3 0 6 4 4



Direct Hydraulics Downhole Control System

The Direct Hydraulics downhole control system uses directhydraulic control lines from the surface to remotely actuate

downhole flow control devices such as interval control valves(ICV). The Direct Hydraulics system also provides on/off variable control of flow into or out of reservoir intervals andcan be used in onshore, platform, or subsea applications.

Features Can be used to control all Halliburton hydraulic flow

control equipment Provides all-hydraulic control Networking option helps reduce number of control lines

required Operates as a closed-loop system

Requires no setting depth

Benefits Controls reservoir intervals without costly intervention Helps eliminate dependence on mechanical or

pneumatic spring-return mechanism to open andclose ICV

Use in onshore, platform, or subsea applications

OperationA typical Direct Hydraulics system includes an ICV, anAccu-Pulse hydraulic positioning module, and a zonal

isolation packer such as the HF-1 packer. The ICV is aremotely operated control valve used to control flow into orout of an isolated reservoir interval. Hydraulic control linesare installed at the surface and are fed directly into the ICVpiston. For control of a single ICV, two control lines are runfrom surface with one attached to the open side of the pistonand the other attached to the close side. Pressure applied toone line, rather than to the other, drives the piston to thecorresponding position. Because the piston is rigidlyattached to the ICV opening mechanism, movement of thepiston operates the valve. This feature can dramaticallyimprove the ability to shift a sleeve which has been stuck dueto scale buildup.

H A L 3 0 6 4 0

Direct HydraulicsSystem



Accu-Pulse Incremental Positioning Module

Halliburton Accu-Pulse incremental positioning module is acomplementary control module that provides incremental

opening of a multi-position interval control valve (ICV). TheAccu-Pulse control module allows the operator to controlproduced or injected fluid rates to the desired quantity,greatly enhancing reservoir management capabilities.

The Accu-Pulse module works in tandem with eitherHalliburton Digital Hydraulics or Direct Hydraulicsdownhole control systems and with the HS-ICV multi-position valve.

ApplicationsThe Accu-Pulse module provides effective incrementalcontrol of an ICV in a range of applications, such as:

Internal gas lift Waterflood Gas injection Commingled production

Features Hydraulic, incremental control Ability to close valve from any position in one press cycle Provides up to 11 discrete positions with the appropriate

interval control valve

Benefits Enhanced reservoir management through control of

produced or injected fluids Helps provide accurate flow estimation and allocation Avoidance of reservoir drawdown High level of well control for internal gas lift, waterflood,

and commingled flow

OperationThe Accu-Pulse module provides incremental movement of asuitable ICV flow trim by exhausting a predeterminedamount of control fluid from the ICV piston. The capability torecharge and exhaust the same amount of fluid repeatedlyallows the ICV flow trim to be accurately moved through upto 11 predetermined positions.

The Accu-Pulse module can communicate with either side ofthe ICV piston. It can drive the ICV open or closed. Thisability provides incremental positioning in one direction withthe ICV being driven to a fully open or closed position whenpressure is applied from the other direction.

Reliability TestingExtensive reliability and integration testing is performed onthe Accu-Pulse module to ensure accuracy and long-termperformance.

Long-Term TestingThe Accu-Pulse module has been long-term tested for:

High temperature up to 330F (165C) High pressure 10,000 psi Flow-induced vibration

Accu-Pulse Module

H A L 3 0 6 2 9



Auxiliary Components

Control-Line Cut SubThe Halliburton Intelligent Completions control-line cutsub (CLCS) incorporates reliable and field-proven methodsfor effective removal of the tubing string and control lines incontingency situations. The CLCS helps ensure properretrieval of complex upper completions, ensuring a cleantubing stub for subsequent fishing operations.

The CLCS is used in SmartWell completions wherehydraulic line and electric line flatpacks are used, and whereremoval of the complex upper completion is necessary.

Features Fully compatible with standard Halliburton Intelligent

Completions FMJ metal-to-metal sealing fittings FMJ connectors fitted to the splice sub are fully

testable, using a standard FMJ connector test kit All splice connections are set within the body of the

sub for protection Easily disconnects the hydraulic FMJs by over pulling Easily severs the electrical line for successful removal

of a complex upper completion

Benefits Splice multiple hydraulic lines with a single splice sub

connector Freely bypass one bare E-line Easily assemble in the field Minimize workover operations

OperationThe CLCS provides the possibility to chemically orphysically cut the tubing string above a tubing packer. Anipple profile below the CLCS will straddle the targeted cutzone. Hydraulic lines are successfully disconnected bypulling on the tubing string, and overcoming the ratings ofthe FMJ fittings. In addition, the electrical line gets severedduring the pulling motion of the string. Tension on theelectrical line drives it against a cutting blade that swiftlysevers the line.

Clamp

TEC

Cutter

H A L 3 9 0 9 3



ConnectionsFMJ connectors are used to make the splice connection andretained within the body of the clamp to protect the splices,flatpack and control lines from damage.

By using the metal-to-metal FMJ connectors, completedconnections can be pressure tested to ensure integrity.

The device also includes provision for bypassing at least onebare 1/4-in electrical line. This line is retained in a specialsection of the body clamp that contains a line severing bladefor electrical connections.

The splice sub connector is available in 4 1/2 in. and 5-in.configurations.

Electric LinePosition

Anchor Sub Assembly

3 FMJ Splice Bodiesat This Level

Splice Sub Assembly

Hydraulic Control Lines

Hydraulic Control Lines

3 FMJ 1/4 Connectionwith HF1 Packer

Bottom of Completion

Top of Completion

HF1Feed-Through Packer

Flat Pack3 x 1/4 Hydraulic CL1 x 1/4 Electric CL

Anchored at This Level

HA L 3 9 0 9

4



Splice Subs

The Halliburton Intelligent Completions splice subconnector is a reliable, field-proven method of splicing two

ends of flatpack to facilitate repairs or lengthening. The splicesub also helps protect the flatpack by securing it to the tubing.

The splice sub incorporates a two-piece robust splice clampwith a key profile that locates into a groove machined in aspecially designed crossover. This arrangement ensures no vertical or rotational slippage of the clamp occurs duringinstallation or retrieval of the tubing string. The crossover ismade up directly to the tubing string.

ApplicationThe splice sub is used in all SmartWell completion systemswhere a flatpack is deployed, including wells with chemical

injection, fiber optics, and surface-controlled subsurfacesafety valves (SCSSV).

Features Fully compatible with standard Halliburton FMJ metal-

to-metal sealing fittings

FMJs fitted to the splice sub are fully testable using astandard FMJ test kit

All splice connections are set within the sub body forprotection

Benefits

Enables the splicing of up to four lines within a singlesplice sub

Allows free bypass of at least one bare control line

Ease of assembly in the field

ConnectionsFMJ connections are used to make the splice connection, andthese are retained within the clamp body to protect thesplices, flatpack, and control lines from damage.

By using these metal-to-metal FMJ connectors, completedconnections can be pressure tested to ensure integrity.

The device also includes provision for bypassing at least oneadditional bare 1/4-in. control line for operation of a chemicalinjection valve or SCSSV.

The splice sub is available to suit different tubingspecifications and applications.

SpliceSubs

H A L 3 0 6 5 2



SmartWell Hydraulic Disconnect Tool

The SmartWell Hydraulic Disconnect tool facilitates theremoval of the upper completion from the lower completion

without any destructive or mechanical intervention, leavingthe intelligent completion lower assemblies such as packersand interval control valves (ICV) in place.

Compact in design, the hydraulic disconnect tool enablesreconnection and isolation of the tubing and hydraulicumbilicals to the lower completion when the uppercompletion is redeployed.

Applications ESP pump applications Safety valve replacement Deepwater plug and abandonment Two-trip completions

Features Compact, concentric design Up to six hydraulic control line channels Proven bonded seal technology Protective sleeve over seal assembly Spring-loaded poppets in receptacle control line

channels Adjustable shear-to-release, straight stab-in to reconnect

(typical)

Benefits Minimize risk and costs associated with workovers pull

upper string, leaving lower completion undisturbed No orienting mechanism or special alignment required

concentric design allows for straight stab installation Reestablish hydraulic integrity durable high-

performance seals maintain isolation between hydrauliccontrol lines and the tubing and annulus

Verify control line integrity during workover protectivesleeve allows for low pressure test

Prevent control line contamination while disconnected poppets prevent well ingress into hydraulic system

HydraulicDisconnect Tool

H A L 3 6 9 2 2

H A L 3 6 8 7 3



OperationThe Hydraulic Disconnect tool features six hydraulic controlline channels that provide communication in a SmartWellcompletion.

All six channels are independent of each other, usingconcentric seal channels that eliminate the need for specialorientation.

While running the upper assembly, a protective sleeve coversthe seals, preventing damage and providing a means to verifyhydraulic control line integrity. The sleeve is engaged duringstab-in, sliding up the seal assembly to safely present the sealsin the receptacle.

While disconnected, spring-loaded poppets provide a debrisbarrier for the control line channels. The poppets are liftedoff seat by the seal mandrel during stab-in, establishing

hydraulic communication from the surface.

The secure latching mechanism can be configured onlocation to complement the customer well plan. Three modesof operation are available:

Snap Latch: Snap In/Snap Out

Anchor: Snap In/Rotate Out to Release

Shear Anchor: Snap In/Shear to Release

SmartWell Hydraulic Disconnect Tool

Tubing Size 4 1/2 in.

Maximum OD 8.300 in.

Minimum ID 3.788 in.

Seal Bore Diameter 5.35 in.

Connection 4 1/2-in, 15.1 lb/ft, VAM TOP box pin

Working Temperature 135C

Body Working Pressure 5,000 psi

Control Line Pressure 7,500 psi

Maximum DifferentialUnloading Pressure 500 psi

Snap-In Force 10,000 lb

Compression Rating 353,000 lb

Running Tool Tensile Rating 178,000 lb

Snap Latch Rating 40,000 - 50,000 lb

Shear Rating 70,000 up to 120,000 lb

Seals Bonded HNBR

Hydraulic Connections 6 1/4-in. FMJ

Control Line Fluids Oil-based (Red Oil)

Other sizes and metallurgy can be made available.



SmartWell Electro-Hydraulic Disconnect Tool

The SmartWell Electro-HydraulicDisconnect tool facilitates removal of

the upper completion from the lowercompletion without any destructive ormechanical intervention, leaving theintelligent completion lower assembliessuch as packers, interval control valves(ICV), and gauges in place.

Compact in design, the electro-hydraulic disconnect tool enablesreconnection and isolation of thetubing, electrical and hydraulic lines tothe lower completion when the uppercompletion is redeployed.

Applications Multi-trip completions

ESP applications

Safety valve replacement

Deepwater plug and abandonment

Features Compact, concentric design

One electrical channel for use withup to eight permanent gauges

Connection for six hydraulicchannels for use with up to five valves using Direct Hydraulics and12 valves using Digital Hydraulicsdownhole architecture system

Pressure compensated electricalsystem allows reliable mating andde-mating

Proven FFKM replaceable T sealtechnology

Protective sleeve over electricalassembly

Spring-loaded poppets in receptaclecontrol-line channels

Multiple disconnect sub/receptaclelatching configurations

Benefits Minimizes risk and costs associated

with workovers pull upper string,leaving lower intelligent completionundisturbed

No orienting mechanism or specialalignment required concentricdesign allows for straight stabinstallation

Reestablishes electrical integrity qualified proprietary connectorallows wet mates by reliablyisolating completion fluid fromelectrical contacts during

reconnection or after disconnection Reestablishes hydraulic integrity

durable high-performance sealsmaintain isolation betweenhydraulic control lines and thetubing and annulus

Oil or water-based control line fluidcompatibility

Prevents control line contaminationin receptacle while disconnected poppets prevent well ingress intohydraulic system

SmartWell Electro-HydraulicDisconnect Tool

H A L 3 7 3 6 2

H A L 3 7 3 6 3



OperationThe electro-hydraulic disconnect tool features six hydrauliccontrol-line channels that provide hydraulic communication,and one electrical channel that provides gaugecommunication in a SmartWell system completion. All sixhydraulic channels are independent of each other, usingconcentric FFKM T seal channels that help ensurecompatibility across most wellbore and control-line fluidsand which eliminate the need for special orientation.

The disconnect sub is run to depth, remaining centralized asit enters the disconnect receptacle. The stabbing sequenceresults in the protective electrical sleeves moving out of theway. The sub shoulders out against the receptacle; in thisstate the electrical contacts are completely mated with eachother. The electrical contact on the sub uses a canted spring

to ensure reliable mating regardless of radial tolerances.Elastomeric pillow seals isolate wellbore fluids from theelectrical connector. The electrical connector is pressurecompensated to the annulus. Upon pulling out of the hole,the sub disengages from the receptacle, and the sleevesretract to their original position via springs, thus isolating theconnectors from the environment.

In the disconnect receptacle, spring-loaded balls maintain adebris barrier to help prevent contamination of the lowercompletion hydraulic channels. As the disconnect sub entersthe receptacle, it safely lifts the poppets off seat. The poppetsprings are designed for an optimum force that prevents anydamage to the seals. The sub continues into the disconnectreceptacle until the latching mechanism is engaged, and thesub shoulders out on the receptacle. In this mated state, thehydraulic seals reliably isolate annulus to tubing and thehydraulic channels.

The secure latching mechanism can be configured in theregion to complement the customer well plan. Three modesof operation are available:

Snap Latch: Snap In/Snap Out Anchor: Snap In/Rotate Out to Release

Shear: Snap In/Shear to Release

SmartWell Electro-Hydraulic Disconnect

Tubing Size 3 1/2 in.

Maximum OD 5.950 in.

Minimum ID 2.890 in.

Connection 3 1/2-in. 10.2 lb/ft VAM TOP box pin

Working Temperature 257F (125C)

Working Pressure 5,000 psi

Control Line Pressure 7,500 psi

Maximum Differential Unloading Pressure 500 psi (Hydraulic channel to tubing or annulus)

Snap-In Force 7,500 lb

Maximum Compression Rating 233,000 lb

Maximum Tensile Rating 114,000 lb

Shear Rating 70,000 lb (standard); Other sizes available on request

Seals Open Gland T Seal (FFKM) - field replaceable

Electrical Connection 1 1/4-in. E-FMJ

Hydraulic Connections 6 1/8-in. NPT

Control-Line Fluids Oil or water-based fluids



Permanent Monitoring

Halliburton Intelligent Completions permanent monitoringsolutions include the following:

ROC permanent downhole gauges

FloStream Venturi flowmeter system

ROC Permanent Downhole Gauges

ROC permanent downhole gauges (PDG) help increaseproductivity through the life of the well or reservoir byproviding reliable, real-time permanent monitoring ofdownhole conditions. Based on an industry-standard, field-proven resonating quartz crystal sensor, ROC gauges can beused for single or multi-zone monitoring applications. Inmulti-zone applications, variations of the standard gauge areavailable, along with dual, triple, and quad splitter blockassemblies for multi-drop capabilities.

Halliburton Intelligent Completions has installed more than1,000 ROC permanent gauge systemsboth as standalonesystems and as integrated components of a SmartWellcompletion systemworldwide.

Applications Life of well production monitoring

Life of field reservoir monitoring

SmartWell completion system optimization

Artificial lift optimization

Features Incorporates the most advanced high-temperature

electronics available in the marketplace

Accurate quartz pressure/temperature sensor

Designed for harsh environments up to 25,000 psi

Dual-pressure testable metal-to-metal sealingarrangement on both gauge and cable termination

Reduced OD gauge design

Multi-drop capability on single tubing-encasedconductor (TEC)

Flow measurements for specific applications

Hermetically sealed electron beam-welded design

Benefits Obtains continuous pressure and temperature data

without the need for well intervention

Enhances reservoir management

Helps increase system reliability using stable pressure/temperature measurements gained from state-of-the-art testing

ROC Gauge Designs Quartz transducer

Hybrid technology

Maximum 200C operating temperature

Multi-drop capability up to seven gauges at 30,000 ftdownhole cable

Dual sensor feed-through capability

Improved shock and vibration performance

0.75-in. OD slimline design available

HAL31448ROC Gauge and Cablehead Connection

H A L 3 2 1 5 1

ROC Gauge Environmental Chart



Mechanical ArrangementThe ROC gauge mechanical arrangement consists of allwetted parts manufactured from high-performance,NACE-compliant corrosion resistant alloys (CRA).

Cable TerminationCable termination is provided with a pressure-testable, dualmetal-to-metal ferrule seal arrangement for isolating thedownhole cable outer metal sheath from the well fluid.

TestingThe complete ROC gauge (sensor and electronic boards) isindependently calibration-checked in our calibration facility.A calibration certificate is included with each gauge and isprovided before each installation.

New gauge designs are subjected to a Highly AcceleratedLifetime Test (HALT) program. This program is a series ofcontrolled environmental stresses designed to ensurestringent criteria are met for thermal shock, mechanical

shock, vibration, and thermal aging.

During manufacture, all ROC gauges are also subjected toEnvironmental Stress Screening (ESS) to highlight any defectin functionality prior to installation at the wellsite. Thisscreening method has proven to be far more effective thanburn-in techniques. All gauges are further subjected topressure tests at elevated temperatures during FactoryAcceptance Testing (FAT).

For more information on any of the details featured here,please email us at [email protected].

ROC Gauge Family - Temperature Performance

Accuracy 0.5C

Typical Accuracy 0.15C

Achievable Resolution



ROC Gauge

ConfigurationsROC-150 ROC-175 ROC-200

10K 16K 20K 25K 20K 25K

Single Pressure/Temperature Sensor

Single Pressure/Temperature Sensor +

Feed Through

Dual Pressure/

Temperature Sensor

Dual Pressure/Temperature Sensor +

Feed Through

Dual Pressure/Temperature Sensor

Fully Redundant

Dual Pressure/Temperature Sensor

Fully Redundant + FeedThrough

HAL32155

HAL32156

HAL32157

HAL32158

HAL32159

HAL32160



ROC Gauge Mandrels

All Halliburton Intelligent Completions ROC gaugemandrels are sized to match the tubing string in which they

are to be run in accordance with API 5CT. The gaugemandrel fully contains the ROC gauge assemblies within themandrel body slots, protecting the gauges from damage. Thegauge mandrels are machined from solid bar stock and areprofiled to avoid snagging during run-in-hole operations.The gauge mandrels are also provided with premium threadsto match that of the completion.

The gauges communicate with the production bore throughports in the sidewall. The gauges are mounted in custom-profiled locations on the mandrels, and a metal-to-metal sealwith elastomeric backup seals provides a high-confidencepermanent pressure seal between the mandrel and gauge.

All gauge mandrels are fully tested prior to delivery. Thistesting includes:

NDT - MPI to ASTM E709:94

UT wall to ASME V SA V88

Gauge-mount pressure testing

Bore burst testing as per API 5CT to match that of thetubing string

High-pressure external testing on completed assembly

Thread gauging and drift testing

FloStream Venturi Flowmeter

The FloStream flowmeter incorporates a Venturi flowmeterprofile and two high-accuracy ROC quartz pressure andtemperature gauges. An optional third ROC gauge can beadded to enable continuous calculation of downhole fluiddensity to be made.

Benefits Accurate downhole flow rate measurement

No moving parts mean high reliability

Based on proven ROC permanent gauge technology Wireline-retrievable Venturi section option allows

measurement of changing flow rates without a workover

Absolute pressure measurement allows redundancy inpressure measurement and a wide flow ratemeasurement window

Minimum pressure loss over whole system

Accuracy and Resolution Accuracy of +5% can be achieved, provided the limits of

the Venturi flowmeter principle are not exceeded

Resolution of



SmartLog Downhole Gauge System

The SmartLog downhole gauge system provides reliableand economical downhole pressure, temperature, and

vibration measurements for optimized reservoir andproduction management. The system allows an operator tomonitor production status throughout the life of an assetallowing for critical adjustments as needed when downholeconditions change.

The heart of the SmartLog system is a piezoresistive gaugetechnology. Other system components include proven cabletermination, tubing encapsulated conductor (TEC), splitterfor multi-drop gauge applications, economical mandrelconfigurations for common casing and tubing combinations,industry standard cross coupling protection, wellheadoutlets, and an XPIO 2000 data acquisition and

communication system.

Applications Real-time production monitoring

Artificial lift optimization

Coalbed methane monitoring

Benefits Enables adjustments as downhole conditions change

Optimize wells with commingled zones

Identify continuity and communication between wells

Can be used to plan well placement Provides accurate data to build reservoir model

Features Piezoresistive gauge technology

Industry-proven FMJ metal-to-metal sealingarrangement on the cable termination

Multi-drop capability on single tubing-encapsulatedconductor (TEC)

High accuracy, repeatability and reliability allows longlife needed in downhole applications

0.88-in. OD slimline design

Qualification TestingThe gauge is subjected to a Highly Accelerated Lifetime Test(HALT) and Quantitative Accelerated Lifetime Test (QALT)programs. HALT is a series of controlled environmentalstresses designed to help ensure that stringent criteria are metfor thermal shock, mechanical shock and vibration. QALT isthermal aging that is performed to help accurately determinethe life of the gauges at maximum operating temperatures.Testing indicates the target reliability for the SmartLogsystem is estimated at approximately 90% for five years at110C operating environment.

SmartLog Gauge Performance

Calibrated Pressure Range Atmospheric 5,000 psi

Pressure Accuracy < 0.1%FS

Pressure Resolution < 0.05 psi/sec

Pressure Drift at MaximumPressure and Temperature < 0.1%FS/yr

Maximum Operating Pressure 6,000 psi

Calibrated Temperature Range Ambient - 125C

Temperature Accuracy < 0.5C

Operating Temperature Range -20C to 125C

Vibration Sensing 17g axis accelerometer



Chemical Injection System

Halliburton Intelligent Completions chemical injectionapplications include:

Scale Asphaltines Emulsions Hydrates Defoaming Paraffin Scavengers Corrosion Demulsifiers

There are two variations of chemical injection mandrels:

Deep-set nipple mandrel A robust one-piece machineddesign utilizing the same design criteria as thepermanent downhole gauge mandrel for use indeepwater or critical applications

Welded pup nipple mandrel Designed for use inshallow set, non-deviated wells, or land applications

Features Dual check valve (burst disk option available)

Externally testable connections

Welded construction check valve body

Check valve material to suit application

Benefits Subsea, platform, and land applications

Cost effective

Multi-line conveyance

Dual Check ValveThe chemical injection systems include dual check valves,

providing redundant checks (one hard seat and one soft seat).The connection to the chemical injection line uses primaryand backup ferrules to provide improved sealing and physicalstrength. The check valve body is a welded construction tofurther reduce the possibility of tubing/annular leak.

The check valve is available in a variety of materials to bestsuit well conditions with externally testable connections toreduce makeup time.

Control Line, Chemical Injection Lines, and ClampsMulti-line conveyance is supplied as a standard service andincludes all necessary spooler units, hydraulic slip rings,

pumps, filters, and sheave wheels. Intelligent Completions canprovide full pump capability for operations during tripping inhole and for commissioning the well. Control lines andchemical injection lines are available in all common materialswith tubing sizes and wall thicknesses to suit all applications.

The lines can be provided bare, encapsulated with other lines,or with a tubing-encapsulated connector (TEC) line. Lines aresupplied fluid filled, flushed, and filtered to the required NASstandard. Cast steel or press steel clamps are used to protectthe control lines.



CheckStream Chemical Injection System

The CheckStream downhole chemical injection systemfeatures a dual redundant check valve installed and protected

by an industry-standard mandrel chassis.The CheckStream system provides precise wellbore chemistrymanagement, optimizing flow assurance and enhancingproduction. The dual redundant check valve allows deliveryof chemical fluids to the wellbore while simultaneouslypreventing wellbore fluids and gas from entering the controlline and migrating to the surface.

ApplicationsCompletions where chemicals will be injected downhole toprevent:

Scale

Asphaltines

Emulsions

Hydrates

Foaming

Paraffin

Stress corrosion

Cracking corrosion

Features Subsea, platform, and land applications

Dual redundant checks (hard and soft seats) Field-installable burst disk with selectable ranges

Variable cracking pressures available

Wide range of flow from 0.02 gpm up to 10 gpm

Industry-proven FMJ testable dual metal-to-metal(MTM) seal connectors

High-pressure/high-temperature (HP/HT) ratings of15,000 psi differential and 200C for HP/HT applications

Configurable for multi-point, single control-lineinjection applications

Extensive qualification testing performed to achievehighest reliability

CheckStream MandrelThe mandrel includes a profile for burst disk installation. Twotypes of chemical injection mandrels are available.

Deep-set nipple mandrel features a one-piece machineddesign for use in deep water or critical applications. Thedeep-set nipple mandrel uses the same design criteria asthe permanent downhole gauge mandrel.

Welded pup joint nipple mandrel is designed for use inlow pressure, shallow set, non-deviated well applications.

CheckStream Check ValveThe dual redundant check valve configurations include a widerange of flow, variable cracking pressures, and differentconnection sizes providing a variety of options to best suitwell conditions.

Connections to the check valve are pressure testable, dualMTM seal FMJ connectors delivering added protectioncompared to standard single MTM seal connections.

H A L 3 7 6 4 3

CheckStreamOne-Piece Mandrel

CheckStreamCheck Valve

H A L 3 7 6 4 7



CheckStream System QualificationExtensive qualification testing has been performed onCheckStream mandrels, valves and connectors to achieve thehighest reliability in the industry.

CheckStream valves endured tens of thousands of pressureand temperature cycles using liquid and gas test medians.Long-term endurance testing was also performed ensuring valve optimal performance throughout the life of the well.

CheckStream Lines and Cable ProtectorsHydraulic control lines and chemical injection lines areavailable in 316 SS and Inconel 825 alloy as standard withtubing sizes and wall thicknesses to suit all applications.

The control lines can be provided bare, encapsulated withother lines, or with tubing encapsulated conductor (TEC)line. Lines are supplied fluid-filled, flushed, and filtered to therequired NAS standard.

Standard cast or pressed steel cable protectors are used tosecure the control lines while running in the hole.

Inconel is a registered trademark of Huntington Alloys.

Installation ServicesMulti-line spooling is provided as a standard service,including all necessary spooler units, hydraulic slip rings,pumps, filters, and sheave wheels. Full pump capability for

operations is provided during running in hole and forcommissioning the well. A fluid particle counting service,which is carried out by certified technicians, is also suppliedas required.

First Letter - Flow Rate L, S, H (Low, Standard, High)Second Letter - Cracking Pressure L, H (50 psi and 500 psi)Third and Fourth Number - Connection Size 25, 38, 50 (1/4, 3/ 8, and 1/2 in.)

HAL37645 Multi-Line SpoolingOperations

H A L 3 7 6 4 6

Chemical InjectionOffshore Pumping Unit

H A L 3 7 6 4 4



CS1 Chemical Injection Sub

The CS1 chemical injection sub is used to introducechemicals, which are pumped from surface via dedicatedinjection lines in the annulus, into the tubing. The injectionsub incorporates inline check valves that prevent tubingpressure from escaping back up the injection lines. A shear-out plug allows the injection line to be run under pressure.

ApplicationsThe CS1 chemical injection sub is used in chemical injectionapplications where it is not possible or desirable to run side-pocket injection mandrels.

Features One-piece injection sub body

Dual chemical injection

Nitrogen-tested check valves

Metal-to-metal seals

Emergency shear-out

Control-line pressure test

Benefits Reliable chemical injection without complexity of a

chemical injection side-pocket mandrel

Allows the introduction of non-compatible chemicals

CS1Chemical Injection Sub

H A L 3 1

03 intelligent completions hlb

Documents