03 Intelligent Completions HLB

Halliburton Intelligent Completions is the world's leading provider of intelligent technology to the upstream oil industry. First introduced in 1997, SmartWell® system technology was the industry's first intelligent well completion system and was designed specifically to remotely control and monitor specific reservoir zones. Today, Halliburton Intelligent Completions offers a broad complement of products and services that range from reservoir engineering studies to advanced completion design, zonal isolation and flow control, reservoir monitoring, and surface digital infrastructure solutions.

SmartWell® Systems A SmartWell completion system optimizes production by collecting, transmitting, and analyzing completion, production, and reservoir data; allowing remote selective zonal control and ultimately maximizing reservoir efficiency by: • Helping increase production – Commingling of production from different reservoir zones increases and accelerates production and shortens field life. • Helping increase ultimate recovery – Selective zonal control enables effective management of water injection, gas and water breakthrough, and individual zone productivity. • Helping reduce capital expenditure – The ability to produce from multiple reservoirs through a single wellbore reduces the number of wells required for field development, thereby lowering drilling and completion costs. Size and complexity of surface handling facilities are reduced by managing water through remote zonal control.

SmartWell systems are designed to meet the demands of every intelligent completion in all global areas and environments. Halliburton Intelligent Completions has designed its product lines and solutions accordingly. • Flow control solutions include interval control valves (ICV), lubricator valves (LV), packers, and downhole control systems. • Permanent monitoring solutions include downhole gauges and flowmeters. • Digital infrastructure solutions include a supervisory control and systems designed for manual, automatic, and integrated operation and electro-hydraulic control and monitoring systems. • Optical fiber solutions include distributed temperature sensing (DTS) tools and software.

Reliability Reliability is essential for intelligent completion systems, and Halliburton engineers reliability into all of its equipment. The company is ISO 9001 application certified and has developed processes to guide, monitor, and optimize system delivery and performance. In addition, Halliburton has a dedicated Reliability Assurance department that manages reliability tools and processes. Halliburton maintains a detailed database to track the field performance of each SmartWell system installation. The knowledge gleaned from this data is used to calibrate design predictions and optimize the design and production process.

• Helping reduce operating expenditure – Remote configuration of wells optimizes production without costly well intervention. In addition, commingling of production from different reservoir zones shortens field life, thereby reducing operating expenditures.

Intelligent Completions

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Flow Control Valves Halliburton Intelligent Completions offers interval control valves (ICV) both with and without shrouds and deflectors:

Features • Proprietary, debris-tolerant, metal-to-metal seal

• HS-ICV – Interval control valve for deepwater and highpressure/high-temperature applications • MCC-ICV – Cost-effective valve with choking capability • LV-ICV – Lubricator valve

• Customizable gas/liquid flow trim

HS-ICV Valve

Benefits • Remotely control flow into or out of the reservoir in challenging environments such as deepwater and HP/HT

The HS interval control valve is the next-generation downhole control valve designed for Halliburton’s industryleading SmartWell® intelligent completion systems. The HSICV is designed for deepwater and high-pressure/hightemperature (HP/HT) applications in which operating conditions are extremely severe.

• Eliminate the potential for wellbore debris to be trapped inside the tool and consequently prevent valve movement 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 psi without the threat of any valve damage—the highest unloading capacity in the industry

HAL30642

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

• Can be used in simple on/off intervention avoidance applications or in more versatile advanced reservoir management choking applications with the Accu-Pulse™module

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Operation Hydraulically actuated, the HS-ICV is operated remotely from surface using Halliburton Intelligent Completions’ reliable Direct Hydraulics, Digital Hydraulics™, or SmartPlex™ downhole control system. The premium thermoplastic hydraulic chamber seals are designed to operate under high actuation pressures and temperatures. The valve has also been subjected to a stringent qualification program, including temperature, pressure, debris, and erosion tests. The HS-ICV body has slots to accommodate two 1/4-in. dedicated instrument wires for position sensors and allows bypass of up to six 1/4-in. bare hydraulic control lines or instrument wires—all without compromising valve body rating or working envelope. Debris-Tolerant Design The HS-ICV has been designed and tested such that the flow trim will ensure complete metal-to-metal (MTM) seal integrity even when exposed to heavy wellbore debris. A onepiece valve mandrel design eliminates the potential for wellbore debris to be trapped inside the tool and consequently prevent valve movement. Proprietary MTM Seal The HS-ICV houses a proprietary metal-to-metal flank seal that enables the valve to unload at a maximum differential pressure of 5,000 psi without the threat of any valve damage. Any additional tubing or annulus pressure acts on the MTM seal to further ensure seal integrity, which has been rigorously tested and qualified at low and high-pressure (up to 10,000 psi) differentials.

Available in Three Variants • HSP Premium Choking ICV designed for more advanced reservoir management when used in conjunction with SCRAMS® Surface Controlled Reservoir Analysis downhole control system • HSB Base Choking ICV designed for more versatile choking applications when used in conjunction with the Accu-Pulse™ incremental positioning module • HSO designed for simple on/off applications The flow trims on the HSB and HSP ICV can be customized to suit a particular well’s injection or production philosophy. Tungsten carbide is the material of choice for these flow trims to combat the threat of erosion due to high flow rates. Shrouded Versions A shrouded configuration of the HS-ICV is available primarily for a two-zone stacked gravel pack application. The shrouds can also be shrink-fitted with a carbide insert when the valve is used in a stacked gravel pack injection application. Deflector Version This configuration of the HS-ICV is available primarily for high rate gas or water injection applications. The deflectors are lined with tungsten carbide inserts to prevent erosional effects as a result of impingement from high flow velocity exiting the valve flow trim.

Pressure-Balanced Valve Mandrel A pressure-balanced valve mandrel design eliminates the need for a latch mechanism to hold trim closed or the need to maintain hydraulic pressure on the close chamber to keep the flow trim shut. This balanced sleeve design also prevents drifting of the sleeve in the incrementally open position. Mandrel design also includes a shifting profile that allows the sleeve to be mechanically shifted in the event hydraulic control has been compromised or if sleeve momentum is not achievable due to scale buildup inside the ICV.


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MC-ICV Valve The MCC-ICV multi-position valve provides incremental flow control over individual reservoir zones, allowing optimization of reservoir architecture down hole and maximizing recovery. Halliburton Intelligent Completions surface control systems provide accurate incremental control over the MC-ICV choke trim and can be tailored to fit the operator's needs.

The valve is available in a range of sizes and thread configurations and can be coupled with either an automatic or manual control system to accommodate specific operational requirements. Nominal Well Conditions MC-ICVs have been specifically designed for use in wells with the following normal conditions: • 5,000 psi maximum differential pressure

HAL30649

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

MC-ICV Valve

Benefits • Cost-effective SmartWell®system functionality in moderate service conditions • Remote control of reservoir intervals without the need for well intervention

• Negligible H2S and CO2 • BHT < 275°F • Moderate duty cycle (open/close with pressure differential) Features • Simple cost-effective design • Bonded nitrile seals • Open/close functionality in the MC0-ICV • Multi-position functionality with tungsten carbide flow trim in the MCC-ICV • Manual override

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5 1/2

10,000

15,000

13,500

40 - 235

7,500 10,000*

10,000

275

7,500

10,000

330 5.850

40 - 275

7.125

8.279

2.750

3.750

4.562

5.62

11.04

16.38

Choke

Yes

5.62

On/Off

TBA

6.00

11.94

Choke

Yes

3.28

6.53

On/Off

Yes

6.00

16.68

Choke

Yes

3.28

9.11

On/Off

Yes

6.00

25.44

Choke

TBA

3.28

13.90

On/Off

TBA

1.990

2.780

4.240

Flow Area, OD of HS - ID of Deflector in. ²

4 1/2

7,500 10,000

10.29

Deflector OD Available in.

3 1/2

6.00 3.28

Deflector Available

Piston Area in.² 1.716

Flow Area, ID of Shroud-ICV OD in.²

Minimum Internal Flow Area in.² 4.20

Shroud OD Available in.

Minimum ID Available in. 2.313

Shroud Size in. / Weight lb

Maximum OD Available in. 4.660

Maximum Differential Unloading Pressure psi

Maximum Temperature Rating Available °F 275

Availability

Maximum Hydrualic Chamber Rating psi 10,000

Version Available

Maximum Working Pressure Available psi 7,500

Hydraulic Chamber Displacement in.³

Size in. 2 7/8

Total Stroke in.

HS-Series

Type

Interval Control Valves

5,000

5 1/2 / 20

5.800

5.030

Yes

5.995

2.58

5,000

7/ 29

7.070

7.980

Yes

7.685

6.38

5,000

7 5/8 / 39

8.535

9.300

Yes

8.315

5.32

5,000

No

N/A

N/A

Yes

9.330

12.49

Notes: a) Chemraz® seals are standard on HS-series valves. Cold array seal stacks MSE seals (40 to 275°F) 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.


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HS Circulating Valve The HS Circulating Valve is designed for use in SmartWell® and conventional completion systems. Based on the proven HS interval control valve (ICV) design technology, the HS circulating valve is designed for safe and efficient circulation of completion fluids after landing the completion and setting the HF-1 and completion packer. The HS circulating valve is a bi-directional hydraulically operated balanced piston valve with a gas tight redundant sealing mechanism. The sealing mechanism consists of a debris tolerant metal-to-metal (MTM) primary seal and a secondary thermoplastic seal array. The valve mandrel incorporates a carbide nose to prevent erosion of the sealing surface 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

For a SmartWell® completion, once on depth, the HF-1 production packer is set via pressure down the production tubing. Element packoff integrity is then determined by applying pressure down the annulus. The open line of the valve is pressured up via the surface control unit to open the sleeve. Circulation down the annulus or tubing begins. Higher circulation rates can be attained as fluid is not circulated past the packer element. Once the desired volumes have been circulated, the close line of the valve is pressured up to move the sleeve into the closed position. The tubing is then pressured up to a maximum of 7,500 psi to test the sleeve integrity. A zero leak rate should be observed. On completion of a successful pressure test, the completion program can progress to the next step. Field-Proven MTM Seal The HS circulating valve houses a proprietary MTM seal from the proven HS-ICV design. Any additional tubing or annulus pressure acts on the seal to further ensure its integrity. The seal has been rigorously tested and qualified at low and high-pressure (up to 10,000 psi) differentials.

Benefits • Run above the production packer, operated after packer is 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 Operation The HS circulating valve is placed above the production packer in the completion string and is run into the well.

Redundant Thermoplastic Seal The MTM seal is backed up by a redundant thermoplastic seal to achieve gas tight sealing integrity. These field-proven thermoplastic metal energized (MSE) seals are designed for redundancy in low and high-pressure applications. The MTM along with the redundant thermoplastic seal have been qualified to provide a gas tight (zero leak) seal integrity. Pressure-Balanced Valve Mandrel A pressure-balanced valve mandrel design eliminates the need for a latch mechanism to hold the trim closed or the need to maintain hydraulic pressure on the close chamber to keep the flow trim shut. This balanced sleeve design prevents drifting of the sleeve in the open position. The valve mandrel design also includes a shifting profile that allows the sleeve to be mechanically shifted in the event hydraulic control has been compromised, or if sleeve movement is not achievable due to scale buildup inside the ICV.

HS Circulating Valve Tubing Size

Valve OD in.

Valve ID in.

Minimum Internal Flow Area in.²


Piston Area in.³

Piston Stroke in.

Maximum Working Pressure psi

Maximum Actuation Pressure psi

Temperature Range °F

Maximum Unloading Differential psi

5.5

8.279

4.562

16.346

23.438

4.246

5.52

7,500

10,000

40 - 330

5,000

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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 or interventions are required to communicate with or operate the valve. Permanently deployed above the production packer as part of the tubing string, the eRED-HS valve controls the flow of well fluids between the tubing and annulus without the need for any interventions or surface control lines—saving rigtime, costs, and helping to reduce risk. Application The eRED-HS valve has been designed specifically to offer a safe 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. This configuration eliminates the need to circulate across the unset packer, reducing the risk of damaging the elements and preventing circulation pressure from impacting the reservoir.

With the circulation successfully completed, the eRED-HS valve is commanded to re-close and/or permanently lock using another pressure window trigger. Each time the valve is operated this way, an intervention is eliminated from the operation, 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 operations—saving time, money, and helping reduce risk • Allows for faster pump rates, providing safer and more efficient circulation of well fluids • Provides flexible deployment options and well control while running-in-hole • Reduces the number of operations personnel—saving costs and helping reduce risk • Debris tolerant, V0 rated seal capable of withstanding high circulation rates

HAL39061

Normally, the eRED-HS valve is run-in-hole in the closed position and subsequently opened by remote command after the packer has been set. The valve is commanded to open by applying pressure at surface (for example, 2,000 psi for 10 minutes) against a deep-set barrier such as a reservoir isolation barrier.

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


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The assembly has integrated pressure and temperature sensors which it uses to monitor the well conditions and is preprogrammed to either open or close whenever a specified condition (known as a trigger) is detected. The triggers use a variety of well parameters including ambient pressure, temperature, time or surface applied pressure. Each time a trigger is detected the valve will either open or close as per its instructions. This process can be repeated time-and-time again without the need for any form of intervention or any control lines to surface. Controlling the eRED-HS Valve Remotely By applying a defined pressure for a defined time at surface, the operator can activate the pressure window trigger. This allows direct communication to the eRED-HS valve so it can be remotely operated. For example, applying between 1,000 and 1,500 psi for 10 minutes could instruct it to open.

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-programmed sequence for the eRED-HS valve to follow without any input from the surface. Each trigger can be used independently or combined to build more elaborate instructions. For example, the eRED-HS valve could be set to close when it detects pressure below 2,000 psi, but only after 100 hours downhole. The pressure window trigger can also be used to manually cancel or override any trigger or permanently lock the valve in its current position.

HAL39080

Operation The eRED-HS valve is an integrated assembly of two existing devices. The first is the eMotion® electronic control unit. This is used to provide surface communication and the motive force to operate the second device—a Halliburton HS-ICV circulating valve.

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

One of the Four eRED® -HS Valve Flow Ports

Onboard data analysis allows the eRED-HS valve to distinguish its own commands from other external factors such as naturally fluctuating hydrostatic or reservoir pressure. This enables the valve to behave as planned even if the downhole conditions change unexpectedly.

Opening

eRED®-HS Valve Size (to suit thread size) in.

Temperature Range °F (°C)

Maximum Differential Pressure While Opening psi (bar)

5.5

39 - 284 (4 - 140)

5,000 (345)

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

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LV-ICV Lubricator Valve The Lubricator Interval Control Valve (LV-ICV) is a highperformance, remotely controlled, tubing-conveyed downhole lubricator system. The LV-ICV isolates pressure or flow above or below its position in the tubing string.

Benefits • Helps ensure pressure integrity from above and below • Helps control reservoir intervals without well intervention

The LV-ICV can be used in any completion where pressure or flow isolation in the tubing string is required. When included in a SmartWell® intelligent completion system, the LV-ICV can be used to control flow into or out of reservoir intervals. The LV-ICV can be controlled by any of Halliburton Intelligent Completions’ Direct Hydraulics, Digital Hydraulics™ systems, or SCRAMS® control systems.

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

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

HAL33641

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

LV-ICV Lubricator Valve

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

LV-ICV Valves Size

OD in.

ID in.

Maximum Temperature °F

Maximum Pressure (Ball Open) psi

Maximum Pressure (Ball Closed) psi

Maximum Hydraulic Chamber Pressure psi

Maximum Unloading Differential Pressure psi

Piston Area in.²

Total Stroke in.

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


Internal Flow Area in.²

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 registered trademark of DuPont Dow Elastomers, LLC-Fluorocarbon.


3-9

sSteam™ Valve Cyclic Steam Stimulation (CSS) and Steam Assisted Gravity Drainage (SAGD) are widely used enhanced oil recovery (EOR) methods for extracting bitumen or hydrocarbons in heavy oil reservoirs. To help optimize production in CSS and SAGD applications, Halliburton has developed the sSteam™ valve. The sSteam valve allows uniform or selective steam placement along the entire length of the horizontal section of the wellbore.

Splice Protection Sleeve

This robust downhole technology is designed to handle high temperatures (500°F) and moderate pressures associated with steam injection. The sSteam valve can be deployed as part of the production liner with or without zonal isolations. Features • 500°F temperature rating

Open Line

• 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

Metal-to-Metal Closure Seal

• Places uniform steam chamber under variant reservoir and steam quality conditions

Tubing Equivalent Flow Area Ports

• Prevents steam breakthrough by selectively shutting off a valve

Common Close Line

HAL31791

Common Close Line

sSteam™ Valve

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Operation The reliable Direct Hydraulics downhole control system uses hydraulic lines connected directly from the surface to remotely actuate the sSteam™ valve. Each of the two control lines required to operate the valve is connected to the open or close side of the valve respectively. If multiple valves are present, the close side is networked to a common close line, and the open side of each valve has a dedicated open line. A specially developed hydraulic control fluid is used to operate the valve.

This hydraulic control fluid retains its desired viscosity when subjected to the extreme temperatures of the CSS/SAGD environment. In the event of steam breakthrough, the sSteam valve can be selectively shut off, thus allowing efficient hydrocarbon recovery without the threat of injected steam being produced or the need to shut down production to cool the reservoir.

sSteam™ Valve Tubing Size in.

3.5

Maximum OD in.

5.430

Minimum ID in.

2.735

Length in.

53.5

Top and Bottom Connection

3.5-in. 8 rd 9.3-lb EUE Box × Box

Service

Steam

Maximum Working Temperature °F

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 Area in.²

5.15

Total Stroke Open-Close in.

4.419

Tensile Rating* lbf

207,000

Compressive Rating* lbf

207,000

Minimum Internal Flow Area in.²

5.87

Control-Line Bypass

6 ×.25-in. lines

Variations

2 Position / Open-Close

*Based on 9.3-lb tubing


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Zonal Isolation Packers HF-1 Packer The HF-1 packer is a single-string, retrievable, cased-hole packer that features a facility for bypass of multiple electrical and/or hydraulic control lines. Available for use as both the top production packer or as one of many lower packers isolating adjacent zones, the HF-1 packer includes a specialized slip configuration and additional body lock ring, which allow it to operate under higher loads and greater pressures 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 Mechanisms The HF-1 packer has two setting and three release mechanisms. • Setting Mechanisms – Tubing pressure set – Control-line set • Release Mechanisms

Connections The packer is made up directly to the tubing string via integral premium thread connections. The internal mandrel also uses premium thread connections for continuity. • Anti-pre-set mechanisms – incorporates a hydraulically activated interlock system and can be adjusted prior to running in the hole. The interlock system allows the packer 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 with tailpipe in tension, compression, or neutral. Setting mechanism is independent of tubing movement or pressure induced tubing forces. Setting action will not impart loads on or damage any penetrations or lines. Penetrations Provision is made for the passage of multiple hydraulic and/or electrical control lines. All connections are sealed using Halliburton proprietary FMJ connectors. Elastomeric Seals Material for setting chamber seals and tubing to lower annulus is chosen based on application conditions. Integral Element Anti-Extrusion System The packing element is multi-piece with NBR sealing elements. It incorporates an anti-extrusion system that provides high resistance to swab off, which permits increased running speeds and high annular circulation rates (up to 8 bbl/min) prior to setting. The system has been qualified through multiple thermal cycles using both water and nitrogen as test media. Load and Functional Performance All HF-series packers are ISO-14310 V0 or V3 rated.

– Punch and pressure release – Shift and pressure release – Mechanical shift release The release mechanism is recessed and selective, allowing for passage of other toolstrings. Axial loads are supported in both directions so the tool cannot be released by tubing forces.

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Retrievable Feed-Through HF Packer Casing Type

OD in.

Weight lb/ft 23 26

7

Mandrel Size in.

Maximum OD in.

Bore ID in.

Maximum Feedthrough

Maximum Differential Across Element psi

Working Working Pressure Temperature psi °F

Element Type

ISO 14310 Rating

2 7/8

6.180

2.315

5,000

5,000

Nitrile

V3

3 1/2

6.180

2.750

7,500

7,500

Nitrile

V3

3 1/2

6.090

2.750

7,500

7,500

Nitrile

V3

2 7/8

5.995

2.315

7,500

7,500

Nitrile HNBR

V3 V3

3 1/2

5.995

2.750

7,500

7,500

Nitrile HNBR

V0 V3

5

75 - 275

29

7 5/8

Required Setting Pressure psi

4,500 Tubing 6,500 Control line

32

3 1/2

5.905

2.750

7,500

7,500

Nitrile

V3

33.7

3 1/2

6.570

2.750

7,500

7,500

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

Nitrile HNBR

V3

43.5

5

75 - 275


4 1/2

8.515

3.812

7,500

7,500

75 - 275 70 - 285

5 1/2

8.515

4.562

7,500

7,500

75 - 275

Nitrile

V3

3 1/2

8.440

2.750

7,500

7,500 10,000

75 - 275

Nitrile HNBR

V3

(a) 7,500 (b) 10,000 (c) 12,500

7,500 10,000 12,500

75 - 275 40 - 300 55 - 235

Nitrile HNBR

V0 V3

7,500

7,500

75 - 275

Nitrile

V0

Nitrile

V0

40 - 275

HNBR

V0

75 - 275

Nitrile HNBR

V0

HF1 Series (722HF1) Production/Isolation

3.525 47

4 1/2

8.440

5 1/2

8.440

3.788 3.813 3.954

9 5/8

3 1/2

8.300

4.560

7

2.750

7,500

3.525 53.5

4 1/2

8.300

71.8 9 7/8

62.8

8.300

4 1/2

7.890

4 1/2

60.7 10 3/4

65.7

HFP Series (722HFP) Production/Isolation

71.8

5 1/2

9.330

62.8

4.625 3.525 3.813

4.562

9.175 4 1/2

10.550

3 1/2

9 7/8

4.560

9.430

73.2 11 7/8

8.440

4 1/2

7,500

7,500

40 - 275

HNBR

V0

10,000

10,000

40 - 275

HNBR

V3

7,500

7,500

75 - 275 40 - 275

Nitrile HNBR

V0 V0

7,500

7,500

75 - 275

3.788 3.813

5 1/2

7,500

3.688

75 - 275


12,500

12,500

55 - 235 40 - 275

7,500

7,500

6

(a) 7,500 (b) 5,000

7,500 5,000

40 - 275

5

8,000

8,000

140 - 260

Nitrile

V0


HNBR

V3


Nitrile

V0

Nitrile HNBR

V0 V3

5

5,000

5,000

75 - 275


5

10,000

10,000

100 - 220

6,500

HNBR

V0

Nitrile

V3

AFLAS®*

V3

2.755

8.440

3.788

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


3-13

MC Packers

Both MC production and isolation packers have the facility to feed through up to eight hydraulic or electrical control lines, allowing communication with other SmartWell equipment without compromising the integrity of the isolated zones. In some instances, the MC production packer has been used as an isolation packer below the primary HF-1 production packer. Features • Simple, cost-effective design

HAL30649

MC packers, available for both production (MC-1) and isolation (MC-0) applications (no slips), are single-string, cased-hole, retrievable packers primarily designed for use in SmartWell® completions in marginal or mature assets.

MC Packer

• 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 Mechanism Both MC production and isolation packers are tubing pressure set. Incorporating a hydraulically activated interlock system, the MC packers can be adjusted externally prior to running in the hole. The interlock system allows the packers to be run in highly deviated wells, helping eliminate the risk of presetting due to casing.

Packing Element The MC packer is fitted with a state-of-the-art nitrile and HNBR packing element similar to those used in the highperformance HF-1 packer. This element offers robustness and excellent sealing properties. Nominal Conditions The MC production and MC isolation packers are designed for use in wells with the following normal conditions: • BHP < 5,000 psi • Negligible H2S and CO2 BHT < 275°F • P 5,000 psi Reliability The MC production and isolation packers have been qualified to an ISO 14310 V3 rating.

Release Mechanism The MC production packer is released by the “shift-and-pull” method. Once the primary packer is released, the MC isolation packer can be retrieved simply by pulling it straight out of the well.

3-14


Retrievable Feed-Through MC Packers Casing Type

OD in.

722MC Production Packer

7

Weight lb/ft

Mandrel Size in.

Maximum OD in.

23

3 1/2

6.180

26 - 29

3 1/2

5.992

26

3 1/2

5.992

29

3 1/2

5.992

40 43

5 1/2

8.614

Maximum Feedthrough

Maximum Differential Across Element psi

9 5/8

47

2.817

8

5,000

8.515

3.820

3 1/2

8.440

2.750

4 1/2

8.460

3.810

5 1/2 *

8.455

4.590

4 1/2

5,000

75 - 275

4.580

4 1/2

3 1/2

Required Working Working Setting Pressure Temperature Pressure psi °F psi

Element Type

ISO 14310 Rating

HNBR

V3

Nitrile

V3

2,400

Viton

V3

Viton

V3

2,500

HNBR

V3

4,000

HNBR

V3

Nitrile

V3

4,000

4,000 5,000

53.5 *

HNBR

V3

4,000

HNBR

V3

3,500

Nitrile

V3

4,000

Nitrile

V3

Nitrile

V3

Nitrile

V3

5,000

8

75 - 275

2.825 8.297

5 1/2 Isolation Packer

Bore ID in.

3.820

5,000

5,000

4,000

4.590

Nitrile

V3

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 method c) Thread connections: VAM® TOP d) 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


3-15

Seal Stack Assembly Halliburton Intelligent Completions’ seal stack assembly isolates individual zones in SmartWell® intelligent completion systems in applications where it is not possible or desirable to use packers for isolation. The seal stack assembly enables bypass of control lines to communicate with equipment installed lower in the completion string. Typical applications are gravel pack or ESS completions where the seal stack assembly will stab into a polished bore to provide isolation between different reservoir intervals in the sandface completion. This ability is based on the use of a stack of robust bonded seal rings arranged along the assembly length.

The device is capable of isolating zones with a differential pressure 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

HAL30650

The seal stack assembly allows up to six independent control lines to bypass, enabling control and monitoring of equipment below, such as interval control valves (ICV) and permanent downhole gauges.

Seal Stack Assembly

3-16


Seal Stack Assembly Size in.

Maximum Body OD in.

Seal OD in.

Minimum ID in.

Length in.

Maximum Temperature °F

Maximum Pressure (Burst and Collapse) psi

Maximum Differential Pressure psi

Hydraulic Port Pressure Rating psi

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 lb VAM® 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 lb New VAM

5.00

5.076

4.945

2.313

80.000

275

10,000

7,500

10,000


5.80

5.770

5.876

2.945

88.923

275

10,000

7,500

10,000


6.10

6.050

6.176

2.945

72.220

275

10,000

7,500

10,000

3 1/2 in. 9.2 lb VAM TOP

7.125

7.075

7.201

2.945

72.210

275

10,000

7,500

10,000


7.20

7.150

7.276

3.813

107.210

275

10,000

7,500

10,000


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


3-17

Downhole Control Systems Downhole control systems provide a method of integrating the surface control system (either manual or automated) with downhole SmartWell® equipment.

SCRAMS® Surface Controlled Reservoir Analysis and Management System The SCRAMS® system is a fully integrated control and data acquisition system that allows the operator to remotely control the wellbore and obtain real-time pressure/temperature data for each zone. This data feedback and accurate flow control capability allow the operator to optimize reservoir performance and enhance reservoir management. The SCRAMS system is ideal for onshore, platform, and subsea applications and is typically used to control the HS-ICV valve for 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-drop functionality

Auxiliary Flat-Pack Consisting of 1x Electrical Line 1x Hydraulic Line

Primary Flat-Pack Consisting of 1x Electrical Line 1x Hydraulic Line

SAM Unit Infinitely Variable Interval Control Valve

Electrical Line Hydraulic Line Broken/Damaged Line

Damaged or Broken Line Damaged or Broken Line

HAL30655

Connection Re-established via SAM™ Unit

Connection Re-established via SAM™ Unit

SCRAMS® Surface Controlled Reservoir Analysis and Management System

3-18


Operation The link from the control equipment located outside the well to the downhole tools includes redundant hydraulic and electrical buses in the form of control lines and electrical conductors enclosed in a flatpack. The hydraulic control line provides the hydraulic locomotive force to the SAM™ sensoractuated module tool, which in turn, using solenoid valves, distributes this force to each side of the ICV piston. The electrical conductor allows transmission of power and communication signals from the well controller to all of the downhole tools by means of the multi-drop telemetry system. To simplify and increase the reliability of the cable to the downhole tool interface, the SCRAMS® system adopts a signal-on power telemetry system. To further enhance the downhole system survivability, the redundant electric and hydraulic network is segmented (SegNet™communications protocol). If any failure, either electric or hydraulic, develops in any section of the network between surface and the downhole tools, the SegNet communications protocol provides the ability to steer around the failure, retaining full functionality of the complete SmartWell® completion system.


SAM™ Sensor Actuation Module The SAM™ tool provides the control and data acquisition functionality for the SCRAMS system. The SAM tool contains redundant electronics, each separately connected to individual flatpacks, a hydraulic manifold to distribute hydraulic power, and sensors for pressure/temperature measurement. The SAM tool is the active component of the SegNet infrastructure. Incoming electrical and hydraulic buses are terminated into the SAM tool and exit to provide communication to other SAM tools further down the completion string. Solenoid valve and electrical switches incorporated in the SAM tool allow isolation of any potentially faulty sections of the network connecting the next tool in the completion.

3-19

SmartPlex™ Downhole Control System The SmartPlex™ downhole control system is an electrohydraulic multi-drop system that provides simple and reliable zonal control of multiple valves in a single wellbore with a minimum number of control lines. The SmartPlex downhole control system uses two hydraulic and one electric line from the surface to remotely and selectively actuate multiple downhole flow control devices such as interval control valves (ICV). This makes a large number of tubing hanger penetrations unnecessary and reduces operational complexity and risk.

Electric In

Hydraulic In

Three-Line Flatpack

SmartPlex™ Manifold

The SmartPlex system can control any flow control tool in the field-proven Halliburton portfolio. SmartPlex Clamp

Features • Three control lines for up to 12 downhole devices or four control lines for up to 24 downhole devices • Minimal use of only passive and no active electrical components • System can remain pressured when operating any of the ICVs in the same direction, significantly decreasing ICV actuation times • Can be deployed with non-integrated systems and fiber optics • Supports “fail-as-is” device types • Independent of tubing or annulus pressure • Can be used to position ICVs in choking applications

3-20

Hydraulic Out

Interval Control Valve or sFrac™ Valve

HAL32214

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

Electric Out

Three-Line Flatpack

Control Module with Clamp Assembly


Application The SmartPlex™ downhole control system is applicable for any 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 an intelligent completion, but also reduces the complexity involved by minimizing the number of control lines required.

Qualification Testing The SmartPlex control system has successfully passed extensive in-house deep well simulation testing. The tool has been cycled more than 10,000 times at 300°F (150°C) at 10,000 psi internally and 15,000 psi externally. A three-valve system integration test with 10,000-ft control line was also successfully conducted.

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. Typically this can be advantageous for selective stimulation control in tight gas applications or in combination with a choking ICV for drawdown optimization in production applications.

HAL31805

HAL32215

Operation The SmartPlex system is a design that uses a simple passive electrical switching method. Each valve is coupled with a SmartPlex actuator module which allows selective and remote control of each valve. Control lines consisting of one electrical and two hydraulic lines run from surface and are networked to each SmartPlex module. A signal down the electrical line switches a solenoid at the desired module, allowing hydraulic communication between the surface control unit and the valve. By regulating the fluid volume in combination with a time-domain control method, valves can be incrementally positioned (choking) to allow for advanced reservoir management.

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


3-21

Digital Hydraulics™ Downhole Control System The Digital Hydraulics™ system is an all-hydraulic, multidrop intelligent completion system that can direct any flow control tool in the Halliburton portfolio, providing simple and reliable zonal control for even the most complex reservoirs. The Digital Hydraulics system allows up to six flow control devices to be controlled from only three hydraulic control lines, making a large number of tubing hanger 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 and fiber optics • No setting depth limitations • All-hydraulic system • Supports “fail as is” devices • Field-proven • Independent of tubing or annular pressure

The Digital Hydraulics system controls simple open/close interval control valves (ICV) and lubricator valves (LV) to provide on/off flow control from each zone. Surface Control The surface equipment for the Digital Hydraulics™ system, Halliburton SmartWell® Master™ supervisory application, is designed as part of the Digital Infrastructure system. A fully automated surface hydraulic system (SHS), controlled from a central location allows control of the Digital Hydraulics system from a local or remote control station. The SmartWell Master application translates Digital Hydraulics system logic into standard central control room operations. This translation allows the operator to easily monitor and control multiple Digital Hydraulics completion systems as well as an individual zone within an intelligent well completion.

Pressure

Control Lines From Surface

Benefits • Helps reduce control line costs • Helps reduce rig time through greater facilitation of completion installation and retrieval • Fewer connections through tubing hanger

No Pressure

Decoder 1

ICV 1

Operation The Digital Hydraulics system design uses the logical absence or presence of pressure (hydraulic code) to communicate between a surface controller and the downhole tools.

Decoder 2

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

3-22

HAL30644

Each flow control device is paired with a decoder that is designed to respond to its own unique code and rejects all other codes or sequences. Using this method, the communication between the surface controller and the downhole tools maintains its integrity—even when conditions such as temperature changes, long control lines, fluids, and leaks can cause other hydraulic communication methods to fail.

ICV 2

To More Decoders

Digital Hydraulics™ System


Direct Hydraulics Downhole Control System The Direct Hydraulics downhole control system uses direct hydraulic 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 and can 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

Operation A typical Direct Hydraulics system includes an ICV, an Accu-Pulse™ hydraulic positioning module, and a zonal isolation packer such as the HF-1 packer. The ICV is a remotely operated control valve used to control flow into or out of an isolated reservoir interval. Hydraulic control lines are installed at the surface and are fed directly into the ICV piston. For control of a single ICV, two control lines are run from surface with one attached to the open side of the piston and the other attached to the close side. Pressure applied to one line, rather than to the other, drives the piston to the corresponding position. Because the piston is rigidly attached to the ICV opening mechanism, movement of the piston operates the valve. This feature can dramatically improve the ability to shift a sleeve which has been stuck due to scale buildup.

HAL30640

Benefits • Controls reservoir intervals without costly intervention • Helps eliminate dependence on mechanical or pneumatic spring-return mechanism to open and close ICV • Use in onshore, platform, or subsea applications

Direct Hydraulics System


3-23

Accu-Pulse™ Incremental Positioning Module

The Accu-Pulse module works in tandem with either Halliburton Digital Hydraulics™ or Direct Hydraulics downhole control systems and with the HS-ICV multiposition valve. Applications The Accu-Pulse module provides effective incremental control 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

HAL30629

Halliburton Accu-Pulse™ incremental positioning module is a complementary control module that provides incremental opening of a multi-position interval control valve (ICV). The Accu-Pulse control module allows the operator to control produced or injected fluid rates to the desired quantity, greatly enhancing reservoir management capabilities.

Accu-Pulse™ Module

Reliability Testing Extensive reliability and integration testing is performed on the Accu-Pulse module to ensure accuracy and long-term performance. Long-Term Testing The Accu-Pulse module has been long-term tested for: • High temperature – up to 330°F (165°C) • High pressure – 10,000 psi • Flow-induced vibration

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 Operation The Accu-Pulse module provides incremental movement of a suitable ICV flow trim by exhausting a predetermined amount of control fluid from the ICV piston. The capability to recharge and exhaust the same amount of fluid repeatedly allows the ICV flow trim to be accurately moved through up to 11 predetermined positions. The Accu-Pulse module can communicate with either side of the ICV piston. It can drive the ICV open or closed. This ability provides incremental positioning in one direction with the ICV being driven to a fully open or closed position when pressure is applied from the other direction.

3-24


Auxiliary Components Control-Line Cut Sub The Halliburton Intelligent Completions control-line cut sub (CLCS) incorporates reliable and field-proven methods for effective removal of the tubing string and control lines in contingency situations. The CLCS helps ensure proper retrieval of complex upper completions, ensuring a clean tubing stub for subsequent fishing operations. The CLCS is used in SmartWell® completions where hydraulic line and electric line flatpacks are used, and where removal of the complex upper completion is necessary.

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

Clamp

Cutter

HAL39093

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

TEC

Operation The CLCS provides the possibility to chemically or physically cut the tubing string above a tubing packer. A nipple profile below the CLCS will straddle the targeted cut zone. Hydraulic lines are successfully disconnected by pulling on the tubing string, and overcoming the ratings of the FMJ fittings. In addition, the electrical line gets severed during the pulling motion of the string. Tension on the electrical line drives it against a cutting blade that swiftly severs the line.


3-25

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

The device also includes provision for bypassing at least one bare 1/4-in electrical line. This line is retained in a special section of the body clamp that contains a line severing blade for electrical connections.

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

The splice sub connector is available in 4 1/2 in. and 5-in. configurations. 3 FMJ 1/4 Connection with HF1 Packer HF1 Feed-Through Packer

3 FMJ Splice Bodies at This Level

Flat Pack 3 x 1/4 Hydraulic CL 1 x 1/4 Electric CL Anchored at This Level

Electric Line Position Anchor Sub Assembly

Bottom of Completion

L3 HA

909

4

Hydraulic Control Lines

Splice Sub Assembly Hydraulic Control Lines

Top of Completion

3-26


Splice Subs The Halliburton Intelligent Completions’ splice sub connector is a reliable, field-proven method of splicing two ends of flatpack to facilitate repairs or lengthening. The splice sub also helps protect the flatpack by securing it to the tubing. The splice sub incorporates a two-piece robust splice clamp with a key profile that locates into a groove machined in a specially designed crossover. This arrangement ensures no vertical or rotational slippage of the clamp occurs during installation or retrieval of the tubing string. The crossover is made up directly to the tubing string. Application The splice sub is used in all SmartWell® completion systems where a flatpack is deployed, including wells with chemical injection, fiber optics, and surface-controlled subsurface safety valves (SCSSV). Features • Fully compatible with standard Halliburton FMJ metalto-metal sealing fittings • FMJs fitted to the splice sub are fully testable using a standard FMJ test kit

Benefits • Enables the splicing of up to four lines within a single splice sub • Allows free bypass of at least one bare control line

HAL30652

• All splice connections are set within the sub body for protection

Splice Subs

• Ease of assembly in the field Connections FMJ connections are used to make the splice connection, and these are retained within the clamp body to protect the splices, flatpack, and control lines from damage. By using these metal-to-metal FMJ connectors, completed connections can be pressure tested to ensure integrity. The device also includes provision for bypassing at least one additional bare 1/4-in. control line for operation of a chemical injection valve or SCSSV. The splice sub is available to suit different tubing specifications and applications.


3-27

SmartWell® Hydraulic Disconnect Tool The SmartWell® Hydraulic Disconnect tool facilitates the removal of the upper completion from the lower completion without any destructive or mechanical intervention, leaving the intelligent completion lower assemblies such as packers and interval control valves (ICV) in place. Compact in design, the hydraulic disconnect tool enables reconnection and isolation of the tubing and hydraulic umbilicals to the lower completion when the upper completion is redeployed. Applications • ESP pump applications • Safety valve replacement • Deepwater plug and abandonment • Two-trip completions

3-28

HAL36922

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 highperformance seals maintain isolation between hydraulic control lines and the tubing and annulus • Verify control line integrity during workover – protective sleeve allows for low pressure test • Prevent control line contamination while disconnected – poppets prevent well ingress into hydraulic system

HAL36873

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)

Hydraulic Disconnect Tool


Operation The Hydraulic Disconnect tool features six hydraulic control line channels that provide communication in a SmartWell® completion. All six channels are independent of each other, using concentric seal channels that eliminate the need for special orientation. While running the upper assembly, a protective sleeve covers the seals, preventing damage and providing a means to verify hydraulic control line integrity. The sleeve is engaged during stab-in, sliding up the seal assembly to safely present the seals in the receptacle.

While disconnected, spring-loaded poppets provide a debris barrier for the control line channels. The poppets are lifted off seat by the seal mandrel during stab-in, establishing hydraulic communication from the surface. The secure latching mechanism can be configured on location to complement the customer well plan. Three modes of 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

135°C

Body Working Pressure

5,000 psi

Control Line Pressure

7,500 psi

Maximum Differential Unloading 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.


3-29

SmartWell® Electro-Hydraulic Disconnect Tool The SmartWell® Electro-Hydraulic Disconnect tool facilitates removal of the upper completion from the lower completion without any destructive or mechanical intervention, leaving the intelligent completion lower assemblies such as packers, interval control valves (ICV), and gauges in place. Compact in design, the electrohydraulic disconnect tool enables reconnection and isolation of the tubing, electrical and hydraulic lines to the lower completion when the upper completion is redeployed. Applications • Multi-trip completions • ESP applications • Safety valve replacement • Deepwater plug and abandonment Features • Compact, concentric design • One electrical channel for use with up to eight permanent gauges

Benefits • Minimizes risk and costs associated with workovers – pull upper string, leaving lower intelligent completion undisturbed • No orienting mechanism or special alignment required – concentric design allows for straight stab installation • Reestablishes electrical integrity – qualified proprietary connector allows wet mates by reliably isolating completion fluid from electrical contacts during reconnection or after disconnection • Reestablishes hydraulic integrity – durable high-performance seals maintain isolation between hydraulic control lines and the tubing and annulus • Oil or water-based control line fluid compatibility • Prevents control line contamination in receptacle while disconnected – poppets prevent well ingress into hydraulic system

• Proven FFKM replaceable “T” seal technology • Protective sleeve over electrical assembly

HAL37362

• Pressure compensated electrical system allows reliable mating and de-mating

HAL37363

• Connection for six hydraulic channels for use with up to five valves using Direct Hydraulics and 12 valves using Digital Hydraulics™ downhole architecture system

SmartWell® Electro-Hydraulic Disconnect Tool

• Spring-loaded poppets in receptacle control-line channels • Multiple disconnect sub/receptacle latching configurations

3-30


Operation The electro-hydraulic disconnect tool features six hydraulic control-line channels that provide hydraulic communication, and one electrical channel that provides gauge communication in a SmartWell® system completion. All six hydraulic channels are independent of each other, using concentric FFKM “T” seal channels that help ensure compatibility across most wellbore and control-line fluids and which eliminate the need for special orientation. The disconnect sub is run to depth, remaining centralized as it enters the disconnect receptacle. The stabbing sequence results in the protective electrical sleeves moving out of the way. The sub shoulders out against the receptacle; in this state the electrical contacts are completely mated with each other. 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 the electrical connector. The electrical connector is pressure compensated to the annulus. Upon pulling out of the hole, the sub disengages from the receptacle, and the sleeves retract to their original position via springs, thus isolating the connectors from the environment.

In the disconnect receptacle, spring-loaded balls maintain a debris barrier to help prevent contamination of the lower completion hydraulic channels. As the disconnect sub enters the receptacle, it safely lifts the poppets off seat. The poppet springs are designed for an optimum force that prevents any damage to the seals. The sub continues into the disconnect receptacle until the latching mechanism is engaged, and the sub shoulders out on the receptacle. In this mated state, the hydraulic seals reliably isolate annulus to tubing and the hydraulic channels. The secure latching mechanism can be configured in the region to complement the customer well plan. Three modes of 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

257°F (125°C)

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


3-31

Permanent Monitoring Halliburton Intelligent Completions’ permanent monitoring solutions include the following: • ROC™ permanent downhole gauges • FloStream™ Venturi flowmeter system ROC™ Gauge and Cablehead Connection

HAL31448

ROC™ Permanent Downhole Gauges ROC permanent downhole gauges (PDG) help increase productivity through the life of the well or reservoir by providing reliable, real-time permanent monitoring of downhole conditions. Based on an industry-standard, fieldproven resonating quartz crystal sensor, ROC gauges can be used for single or multi-zone monitoring applications. In multi-zone applications, variations of the standard gauge are available, along with dual, triple, and quad splitter block assemblies for multi-drop capabilities. Halliburton Intelligent Completions has installed more than 1,000 ROC permanent gauge systems—both as standalone systems and as integrated components of a SmartWell® completion system—worldwide. Applications • Life of well production monitoring

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-theart testing ROC Gauge Designs • Quartz transducer • Hybrid technology • Maximum 200°C operating temperature • Multi-drop capability – up to seven gauges at 30,000 ft downhole cable • Dual sensor feed-through capability

• Life of field reservoir monitoring

• Improved shock and vibration performance

• SmartWell completion system optimization

• 0.75-in. OD slimline design available

• 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 sealing arrangement on both gauge and cable termination • Reduced OD gauge design

• Flow measurements for specific applications • Hermetically sealed electron beam-welded design

HAL32151

• Multi-drop capability on single tubing-encased conductor (TEC)

ROC™ Gauge Environmental Chart

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Mechanical Arrangement The ROC™ gauge mechanical arrangement consists of all “wetted” parts manufactured from high-performance, NACE-compliant corrosion resistant alloys (CRA). Cable Termination Cable termination is provided with a pressure-testable, dual metal-to-metal ferrule seal arrangement for isolating the downhole cable outer metal sheath from the well fluid. Testing The complete ROC gauge (sensor and electronic boards) is independently calibration-checked in our calibration facility. A calibration certificate is included with each gauge and is provided before each installation.

New gauge designs are subjected to a Highly Accelerated Lifetime Test (HALT) program. This program is a series of controlled environmental stresses designed to ensure stringent criteria are met for thermal shock, mechanical shock, vibration, and thermal aging. During manufacture, all ROC gauges are also subjected to Environmental Stress Screening (ESS) to highlight any defect in functionality prior to installation at the wellsite. This screening method has proven to be far more effective than “burn-in” techniques. All gauges are further subjected to pressure tests at elevated temperatures during Factory Acceptance Testing (FAT). For more information on any of the details featured here, please email us at [email protected].

ROC™ Gauge Family - Temperature Performance Accuracy

0.5°C

Typical Accuracy

0.15°C

Achievable Resolution

<0.005°C/sec

Repeatability

<0.01°C

Drift at 177ºC

<0.1°C/yr

ROC™ Gauge Family - Pressure Performance Pressure Range psi (bar)

0 - 10,000 (0 - 690)

0 - 16,000 (0 - 1100)

0 - 20,000 (0 - 1380)

0 - 25,000 (0 - 1725)

Accuracy (% FS)

0.015

0.02

0.02

0.02

Typical Accuracy (% FS)

0.012

0.015

0.015

0.015

Achievable Resolution

<0.006 psi/sec

<0.008 psi/sec

<0.008 psi/sec

<0.010 psi/sec

Repeatability (% FS)

<0.01

<0.01

<0.01

<0.01

Response Time to FS Step (for 99.5% FS)

<1 sec

<1 sec

<1 sec

<1 sec

Acceleration Sensitivity (psi/g – any axis)

<0.02

<0.02

<0.02

<0.02

Drift at 14 psi and 25°C (% FS/year)

Negligible

Negligible

Negligible

Negligible

Drift at Maximum Pressure and Temperature (% FS/year)

0.02

0.02

0.02

0.02


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ROC™ Gauge ROC-150

ROC-175

ROC-200

Configurations 10K

16K

20K

25K

20K

HAL32155

Single Pressure/ Temperature Sensor

 Single Pressure/ Temperature Sensor + Feed Through















HAL32157







Dual Pressure/ Temperature Sensor + Feed Through

HAL32158





Dual Pressure/ Temperature Sensor Fully Redundant

 HAL32159



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

HAL32156

Dual Pressure/ Temperature Sensor

Dual Pressure/ Temperature Sensor Fully Redundant + Feed Through

25K

 HAL32160






ROC™ Gauge Mandrels All Halliburton Intelligent Completions ROC™ gauge mandrels are sized to match the tubing string in which they are to be run in accordance with API 5CT. The gauge mandrel fully contains the ROC gauge assemblies within the mandrel body slots, protecting the gauges from damage. The gauge mandrels are machined from solid bar stock and are profiled to avoid snagging during run-in-hole operations. The gauge mandrels are also provided with premium threads to match that of the completion. The gauges communicate with the production bore through ports in the sidewall. The gauges are mounted in customprofiled locations on the mandrels, and a metal-to-metal seal with elastomeric backup seals provides a high-confidence permanent pressure seal between the mandrel and gauge.

Accuracy and Resolution • Accuracy of +5% can be achieved, provided the limits of the Venturi flowmeter principle are not exceeded • Resolution of <0.1% of full scale Operational Parameters The Venturi flowmeter mandrel can be machined to a specific profile or can incorporate a wireline-retrievable Venturi flowmeter section, which can allow for: • Changing of the Venturi flowmeter should the flow rate change significantly • Replacement should the Venturi profile become worn • Removal of the restriction imposed should it become necessary to carry out some well maintenance operation below the flowmeter

All gauge mandrels are fully tested prior to delivery. This testing 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 the tubing string • High-pressure external testing on completed assembly • Thread gauging and drift testing

FloStream™ Venturi Flowmeter The FloStream™ flowmeter incorporates a Venturi flowmeter profile and two high-accuracy ROC quartz pressure and temperature gauges. An optional third ROC gauge can be added to enable continuous calculation of downhole fluid density 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 in pressure measurement and a wide flow rate measurement window • Minimum pressure loss over whole system


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SmartLog™ Downhole Gauge System The SmartLog™ downhole gauge system provides reliable and economical downhole pressure, temperature, and vibration measurements for optimized reservoir and production management. The system allows an operator to monitor production status throughout the life of an asset allowing for critical adjustments as needed when downhole conditions change. The heart of the SmartLog system is a piezoresistive gauge technology. Other system components include proven cable termination, tubing encapsulated conductor (TEC), splitter for multi-drop gauge applications, economical mandrel configurations for common casing and tubing combinations, industry standard cross coupling protection, wellhead outlets, and an XPIO 2000™ data acquisition and communication system. Applications • Real-time production monitoring • Artificial lift optimization • Coalbed methane monitoring

Features • Piezoresistive gauge technology • Industry-proven FMJ metal-to-metal sealing arrangement on the cable termination • Multi-drop capability on single tubing-encapsulated conductor (TEC) • High accuracy, repeatability and reliability allows long life needed in downhole applications • 0.88-in. OD slimline design Qualification Testing The gauge is subjected to a Highly Accelerated Lifetime Test (HALT) and Quantitative Accelerated Lifetime Test (QALT) programs. HALT is a series of controlled environmental stresses designed to help ensure that stringent criteria are met for thermal shock, mechanical shock and vibration. QALT is thermal aging that is performed to help accurately determine the life of the gauges at maximum operating temperatures. Testing indicates the target reliability for the SmartLog system is estimated at approximately 90% for five years at 110°C operating environment.

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

SmartLog™ Gauge Performance Calibrated Pressure Range

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Atmospheric 5,000 psi

Pressure Accuracy

< 0.1%FS

Pressure Resolution

< 0.05 psi/sec

Pressure Drift at Maximum Pressure and Temperature

< 0.1%FS/yr

Maximum Operating Pressure

6,000 psi

Calibrated Temperature Range

Ambient - 125°C

Temperature Accuracy

< 0.5°C

Operating Temperature Range

-20°C to 125°C

Vibration Sensing

± 17g axis accelerometer


Chemical Injection System Halliburton Intelligent Completions chemical injection applications 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 machined design utilizing the same design criteria as the permanent downhole gauge mandrel for use in deepwater or critical applications • Welded pup nipple mandrel – Designed for use in shallow set, non-deviated wells, or land applications Features • Dual check valve (burst disk option available) • Externally testable connections

Dual Check Valve The 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 primary and backup ferrules to provide improved sealing and physical strength. The check valve body is a welded construction to further reduce the possibility of tubing/annular leak. The check valve is available in a variety of materials to best suit well conditions with externally testable connections to reduce makeup time. Control Line, Chemical Injection Lines, and Clamps Multi-line conveyance is supplied as a standard service and includes all necessary spooler units, hydraulic slip rings, pumps, filters, and sheave wheels. Intelligent Completions can provide full pump capability for operations during tripping in hole and for commissioning the well. Control lines and chemical injection lines are available in all common materials with 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 are supplied fluid filled, flushed, and filtered to the required NAS standard. Cast steel or press steel clamps are used to protect the control lines.

• Welded construction check valve body • Check valve material to suit application Benefits • Subsea, platform, and land applications • Cost effective • Multi-line conveyance


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CheckStream® Chemical Injection System The CheckStream® downhole chemical injection system features a dual redundant check valve installed and protected by an industry-standard mandrel chassis. The CheckStream system provides precise wellbore chemistry management, optimizing flow assurance and enhancing production. The dual redundant check valve allows delivery of chemical fluids to the wellbore while simultaneously preventing wellbore fluids and gas from entering the control line and migrating to the surface.

CheckStream Mandrel The mandrel includes a profile for burst disk installation. Two types of chemical injection mandrels are available. • Deep-set nipple mandrel features a one-piece machined design for use in deep water or critical applications. The deep-set nipple mandrel uses the same design criteria as the permanent downhole gauge mandrel. • Welded pup joint nipple mandrel is designed for use in low pressure, shallow set, non-deviated well applications.

Applications Completions where chemicals will be injected downhole to prevent: • Scale • Emulsions • Hydrates

HAL37643

• Asphaltines

• Foaming

CheckStream® One-Piece Mandrel

• 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

CheckStream Check Valve The dual redundant check valve configurations include a wide range of flow, variable cracking pressures, and different connection sizes providing a variety of options to best suit well conditions. Connections to the check valve are pressure testable, dual MTM seal FMJ connectors delivering added protection compared to standard single MTM seal connections.

• 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 of 15,000 psi differential and 200°C for HP/HT applications

• Extensive qualification testing performed to achieve highest reliability

HAL37647

• Configurable for multi-point, single control-line injection applications

CheckStream® Check Valve

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HAL37646

Installation Services Multi-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 for commissioning the well. A fluid particle counting service, which is carried out by certified technicians, is also supplied as required.

Multi-Line Spooling Operations

HAL37645

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.)

CheckStream valves endured tens of thousands of pressure and 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.

HAL37644

CheckStream® System Qualification Extensive qualification testing has been performed on CheckStream® mandrels, valves and connectors to achieve the highest reliability in the industry.

Chemical Injection Offshore Pumping Unit

CheckStream Lines and Cable Protectors Hydraulic control lines and chemical injection lines are available in 316 SS and Inconel® 825 alloy as standard with tubing sizes and wall thicknesses to suit all applications. The control lines can be provided bare, encapsulated with other lines, or with tubing encapsulated conductor (TEC) line. Lines are supplied fluid-filled, flushed, and filtered to the required NAS standard. Standard cast or pressed steel cable protectors are used to secure the control lines while running in the hole. Inconel is a registered trademark of Huntington Alloys.


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CS1 Chemical Injection Sub The CS1 chemical injection sub is used to introduce chemicals, which are pumped from surface via dedicated injection lines in the annulus, into the tubing. The injection sub incorporates inline check valves that prevent tubing pressure from escaping back up the injection lines. A shearout plug allows the injection line to be run under pressure. Applications The CS1 chemical injection sub is used in chemical injection applications where it is not possible or desirable to run sidepocket 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

HAL31736

• Allows the introduction of non-compatible chemicals

CS1 Chemical Injection Sub

CS1 Chemical Injection Sub Casing Size

Tubing Size

Weight

Maximum OD

Pressure Rating

Minimum ID

Above

Below

in.

mm

in.

mm

lb/ft

kg/m

in.

mm

in.

mm

psi

bar

psi

bar

5 1/2

139.70

2 7/8

71.75

7.9

11.76

4.450

113.03

2.229

56.62

7,500

516.75

7,500

516.75

7

177.80

3 1/2

88.90

9.2

13.69

5.800

147.32

2.949

74.90

7,500

516.75

7,500

516.75

8.000

203.20

3.880

98.55

7,500

516.75

7,500

516.75

6.050

153.67

3.860

98.04

5,000

344.50

5,000

344.50

4 1/2

9 5/8

10 3/4

114.30

5

127.00

5 1/2

139.70

12.6

18.75

15.0

22.32

7.515

190.88

4.339

110.21

5,000

344.50

5,000

344.50

15.5

23.06

8.275

210.19

4.848

123.14

7,000

482.30

7,000

482.30

17.0

25.28

8.265

209.93

4.892

124.26

5,000

344.50

5,000

344.50

20.0

29.76

8.265

209.93

4.756

120.80

5,000

344.50

5,000

344.50

26.0

38.69

9.250

234.95

6.125

155.58

5,000

344.50

5,000

344.50

29.0

43.15

9.250

234.95

6.098

154.89

5,000

344.50

5,000

344.50

244.48

273.05

7

177.80

Part Number Prefix: P.220CS1

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Digital Infrastructure Halliburton Intelligent Completions’ digital infrastructure system enables operators to: • Monitor and control permanent downhole gauges (PDG) • Remotely control and configure downhole interval control valves (ICV) • Monitor and control surface sensors and instruments • Connect to distributed control systems and other thirdparty systems for monitoring and control • Provide remote power and communications for SmartWell® and permanent monitoring systems where no infrastructure is available • Interface with field controllers provided by a variety of vendors The digital infrastructure portfolio consists of the following electrical and hydraulic sub-systems and applications: • SmartWell® Master™ supervisory application – Provides a central point of control and monitoring for SmartWell and permanent monitoring systems • XPIO 2000™ data acquisition and control unit – Allows operators to monitor and control downhole gauges and topside instrumentation

• UACU+ system – Larger variant of XPIO 2000 system that enables monitoring of up to 20 wells/40 gauges • Surface hydraulic system – Designed to supply pressurized hydraulic fluid to downhole SmartWell systems and provide automatic and manual control of downhole ICVs • Subsea interface cards – Allow users to monitor PDGs and control Halliburton Intelligent Completions' SCRAMS® system completions in subsea applications. The cards reside in pods provided by subsea control system vendors • Remote power systems – Designed to support Halliburton Intelligent Completions' digital infrastructure data acquisition and control systems in areas where conventional power and, in some cases, communications are unavailable, unreliable, or cost-prohibitive • SoftFlow™ data analysis and calculation application – Provides well and zonal flow rate estimations • Surface positioning system – Provides control of downhole ICVs without downhole control devices

Distributed Control System

Supervisory Control (SmartWell® Master) Data from the Well Pressure/Temperature/Flow Interval Control Valve Positions

Downhole Data from SWM

Instructions to the Well Change ICV Positions

Other Field Data (Surface/Process)

Human Machine Interface

Human Machine Interface Interpretation & Decision Making

HAL39852

Instructions to Downhole Controls

Physical Asset Execute Plan & Decide

Acquire Data

Applications Data Validation Reservoir Modeling Optimization Remote Clients

Instructions to Surface Controls

Data

Options

Interpret Model

OPC

Modbus

TCP/IP

Other

Digital Infrastructure Portfolio


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SmartWell® Master™ Supervisory Application The SmartWell® Master™ supervisory application for the digital infrastructure product line provides a central point of control and monitoring for SmartWell and permanent monitoring systems. The SmartWell Master application is based on the ICONICS GENESIS32™ web-enabled human machine interface (HMI)/ supervisory control and data acquisition (SCADA) software running on the Microsoft® Windows® operating system. Features • Web-based HMI/SCADA visualization • Modular tool suite for visualization, HMI, and SCADA • GENESIS32 OPC-To-The-Core Technology™ system • Visual OPC alarming and event notification • OPC connectivity • Extensive diagnostics and analysis capabilities • Powerful data-mining technology • Custom configuration utility • International language switching and global aliasing • Visual control replay traceability playback Benefits • Control SmartWell downhole equipment from central location • Interfaces with external systems, including third-party computers and distributed control systems

External System Connectivity A custom external control module allows the SmartWell Master application to connect to an external system such as a third-party computer or DCS for control and data handoff. Resource locking is utilized to ensure control is available from either the SmartWell Master application or the external system. Both OPC and Modbus® versions are available. Displays The SmartWell Master application features standard displays specifically designed for: • • • • •

Hydraulic supply modules Well control modules Permanent downhole monitoring Alarming Trending

A well configuration panel, a standard feature on the lefthand side of the screen, shows which wells are configured for the project. A standard alarm banner, located at the bottom of the screen, displays the most recent real-time alarms which have been raised. Tabs at the top of the screen allow easy switching between displays. Various hardware configurations are available, including standalone PC and rack-mount server with retractable VDU/keyboard/mouse unit.

Hydraulic Supply Module Screen Modbus is a registered trademark of Schneider Automation, Inc.

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Modules The SmartWell® Master™ application features several modules that can be enabled according to the operator's specific needs, including: • • • • • •

HMI Historical data External OPC interface Remote client Alarms and events Microsoft .NET helper programs, such as calculation engines and external Modbus® data link modules

SmartWell® System Configuration A custom configuration utility allows project-specific SmartWell systems to be built up in the SmartWell Master application by dragging and dropping standard functional modules. Trending Trending can be carried out in real time or configured from historical data.

Well Control Module Screen

SmartWell® Configuration Utility Screen


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SoftFlow™ Virtual Flowmeter Halliburton Intelligent Completions’ SoftFlow™ virtual flowmeter is a data analysis and calculation program that provides well and zonal flow rate estimation and allocation in real time. Traditional asset production information is often based on data acquired intermittently from individual well tests. The SoftFlow application provides real-time estimates for continuous reporting of daily production on a per-well and/ or per-zone basis. No additional equipment is required for a SmartWell® completion system. The SoftFlow application draws information from downhole sensors as well as attributes from interval control valves (ICV), such as HS-ICVs used in SmartWell completion systems. SoftFlow Application Requirements • Intelligent well completions with ICVs, annulus, and tubing sensors for every zone • Dynamic Field Data Management System (FDMS) interface to provide data and receive results from the SoftFlow application • Standard Human Machine Interface (HMI) to configure the SoftFlow flowmeter for real-time operations and a computer to use the SoftFlow application offline Features • Inputs can be configured for field and well levels including well completion architecture, fluid composition (PVT tables), and ICV attributes

Field/Project Information

– Choice of analytical or numerical choke models to estimate and allocate subsurface flow rates – Tubing performance, nodal analysis, and Inflow Performance Relationship (IPR) Benefits • Asset Management – Quickly helps identify wells with production problems and implements corrective actions to restore production – Real-time reservoir information for asset optimization – Helps improve production accounting and aids compliance with regulatory reporting requirements • Real-Time Operations – Enables production accounting in real time – Real-time monitoring of individual well and asset performance – Offers real-time well optimization (model, measure, and optimize) – Allows viewing of zonal flow for commingled wells in real time – Allows viewing of in-situ multi-phase flow estimates in real time – Calculation engine tolerates erratic or missing sensor data – Data analysis for back allocation (offline mode)

Well Information

1. Well type 2. Well properties and architecture 3. Depth of sensors and ICV’s 4. Well administration

Zone Information

1. Zone PVT 2. ICV Specification 3. Node definition

HAL32364

1. Field information (single or multiple) 2. Data management and quality 3. Define calculation parameters 4. Units of measurements

• Calculation engine incorporates:

• Data Management

• Calibration for unique well conditions using well test data (shown to calibrate to 90% accuracy of actual flow rate measurements) • Enables oil and water production scenarios (gas capability in future release)

• Configurable without well downtime or production interruption

Information Chart

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HAL32365 HAL32363

SoftFlow™ Screen Shot

SoftFlow™ Application Management System


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Surface Positioning System The surface positioning system provides a methodology to incrementally control downhole interval control valve (ICV) position in each zone through the Halliburton Intelligent Completions surface hydraulic system (SHS) without the need for downhole control devices. It is implemented by calibrating and moving ICVs from the surface with the help of an algorithm embedded into the SHS controller. With this method, a specific pressure is applied for a specific time to one side of the ICV to cause it to move the desired increment, thus exposing or closing a number of flow ports. At the same time, compensating pressure is applied to other ICVs to keep them at their current position. The surface positioning system is a reliable, cost-effective solution to move downhole ICVs to the desired choke open or close position without the need for reset. Features • Implemented through algorithms embedded into the SHS controller; no extra hardware is needed for the automated SHS • Can be integrated into the SmartWell® Master™ supervisory application • Maintains other ICVs in their current position by applying compensating pressures HAL32162

• Can be used for wells with ICVs up to 10,000 ft deep; applications out of this range can be reviewed on a project-by-project basis • Can be used for a well with a configurable number of ICVs

Surface Positioning of ICVs

• Can be used for completions with a common close line as well as independent open and close control-line configurations

HAL32219

• User-friendly interface

Surface Positioning Sequence

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Benefits • Provides incremental ICV position control from surface without the need for downhole control devices, thereby reducing system cost • Provides ability to incrementally position an ICV in either direction (open or close) without the need to close the ICV first • Requires less time to perform incremental moves than systems using downhole control devices for this purpose • Provides a flexible and configurable number of discrete choke positions for an ICV • Can be applied to new or existing direct hydraulics ICV installations controlled from an automated SHS

Surface positioning system calibration involves determination of downhole response delay through simulation software. Accuracy depends upon correct information about the well completion configuration and control fluid. Well condition changes require recalibration of the surface positioning system to maintain accuracy. The surface positioning method can provide incremental control of an ICV in a range of applications, such as: • • • •

Auto-gas lift Waterflood Gas injection Commingled production

SmartWell® Master Surface Positioning Screen


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Remote Power Systems For circumstances in which conventional power is unavailable, unreliable, or cost-prohibitive, Halliburton Intelligent Completions offers a wide variety of remote power systems. Each system is designed to support the Intelligent Completions digital infrastructure data acquisition and control systems, including: • XPIO 2000™ series of data acquisition and control units • Surface hydraulic system • OptoLog® DTS CE fiber-optic system Depending on site conditions and available resources, operators can choose from solar, wind, thermoelectric generator (TEG), engine generator-set (gen-set), or DC-UPS systems, either individually or in combination. Systems utilize existing local resources and enable wireless communication to remote locations. Offshore systems employ solar power with wind power backup. The remote power systems employed by Halliburton Intelligent Completions are completely self-contained, preassembled, and tested prior to shipment and are specifically tailored for the electrical load and climatic conditions of each particular site. Reliability Health and safety margins are built into each remote power system in order to ensure high reliability and continuous operation. Like all Halliburton Intelligent Completions equipment and electronics, the remote power systems are pre-wired inside custom enclosures and are fully factory-acceptance tested prior to shipment. Systems are warranted for five years.

Solar Photo Voltaic (SPV) Systems SPV systems convert sunlight to DC electricity and are the preferred choice in most circumstances. Solar power can be used in conjunction with wind, TEG, or gen-set systems. Wind Generators Modern electrical windmills harness wind power that can complement solar power in conditions with intermittent sunlight. Regular maintenance and repair are required. Thermoelectric Generators (TEG) TEGs burn natural gas and are extremely reliable when natural gas is readily available. They can also be a good supplement to solar power. A separator is normally required if the gas is “wet.” DC-UPS DC-UPS is recommended for situations in which power is dirty, intermittent, or unreliable. Additional filtering and surge suppression are offered in addition to backup. Engine-Generator Set (Gen-Set) Systems Gen-set systems use conventional fuel to charge a large battery bank. They can be used to supplant solar power and to charge batteries in temporary applications or in circumstances in which weather extremes make other options unattractive.

Choosing the Appropriate Remote Power System Among the most crucial considerations related to choosing an appropriate remote power system is the year-round availability of sunlight. Every remote power system must be able to perform reliably during even the most inclement weather. Accurate load information is also critical, particularly if communications equipment is included. In general, solar photo voltaic (SPV) cells are the preferred method for providing remote power because of their simplicity, reliability, and cost-effectiveness. The solar-panel/ battery combination is determined by accurately calculating the total power consumption of the data acquisition and control equipment and then sizing the system based on the worst weather conditions. A safety margin is included.

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XPIO 2000™ Data Acquisition and Control Unit Halliburton Intelligent Completions' XPIO 2000™ data acquisition and control system allows operators to monitor and control downhole gauges and topside instrumentation. Acquiring data at a rate of 0.5 seconds per gauge, the XPIO 2000 system is available in a range of capacities, from 1 well/4 gauges to 4 wells/8 gauges. A larger variant within the XPIO 2000 range is the UACU+, which extends capacity up to 20 wells/40 gauges for a single unit. The UACU+ is fitted with a permanent downhole gauge interface card (PDGIC) module for each downhole channel. Downhole cable inputs are independent and fully isolated. Features • Five channels of 4-20mA analog inputs (12-bit) • Four channels of 4-20mA analog outputs (16-bit) • 4MB of flash memory • Modbus® RTU protocol support via RS-485 or RS-232 port, or via TCP/IP port • Modem communications support via the RS-232 port • Two relay contacts • Communications programs that allow full configuration of the unit Benefits • Control Halliburton Intelligent Completions' permanent downhole gauges (PDG), including the ROC™ family, SmartLog™ gauges, and surface instruments • Store and display data from PDGs and surface sensors • Interface with external systems, including third-party computers and distributed control systems Analog Inputs The XPIO 2000 system features five channels of 4-20mA inputs (12-bit) that are fully configurable using the XPIO 2000 PC program. Users can set the offset, span, and units of measure, and then can choose to monitor them on the display or log them into memory. Analog Outputs The XPIO 2000 system features four channels of 4-20mA outputs (16-bit). Users can select the pressure, temperature, span, and offset of a permanent downhole gauge, and the XPIO 2000 system will drive the translated value onto an output as it is decoded from down hole.

Memory Logging The XPIO 2000 system comes standard with 4MB of flash memory. A SanDisk CompactFlash® card option extends the memory by 2GB. The 4MB memory can hold pressure and temperature data from one gauge at one-minute updates for more than three months. The 2GB option extends memory capacity to hold pressure and temperature data from two gauges at onesecond updates for more than a year. Data is retrieved via an RS-232 port using the supplied PC program or by file transfer protocol (FTP) over the TCP/IP link and can easily be imported to other applications such as a spreadsheet. Data is logged to memory at a maximum rate of once per second. Both the standard XPIO and UACU+ are available in NEMA4X enclosure and 19-in. rack mount versions. The 19-in. rack mount UACU+ has a 10-well/20-gauge capacity. Serial Communications The XPIO 2000 system supports Modbus® RTU protocol via its RS-485 or RS-232 port or via its TCP/IP port. These interfaces are fully configurable in terms of parity, baud rate, etc. As a slave device, the XPIO 2000 system provides gauge data (i.e., pressure and temperature) that can be polled as well as data from any of the 4-20mA inputs. Time and date are also available. Modem Support The XPIO 2000 system supports modem communications via the RS-232 port. Users may dial into the unit using the supplied PC program, or use the port to talk to the Modbus system over a radio modem, cellular modem, or regular modem. Pressure-Controlled Relay Contacts The XPIO 2000 system comes with two relay contacts (1/2A at 115VAC) which are controlled by software. When a selected gauge's pressure rises above or falls below a set pressure, the contact is closed. This feature is ideal for alarms and/or pump control. Web-Installed PC Application The XPIO 2000 system comes with a web-installed application that provides for full configuration of the unit as well as data memory retrieval, real-time logging of data to the computer hard drive, and real-time data trending.

Modbus is a registered trademark of Schneider Automation, Inc.


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The application communicates with the XPIO 2000 system via a standard RS-232 port and runs on the Microsoft® Windows® 2000/XP/Vista operating system.

Variants • XPIO 1 well/4 gauges

Operating Information • 110/250 VAC

• XPIO-QT 4 wells/4 gauges

• 10-36 VDC unit available

• XPIO-DT+ 2 wells/8 gauges

• 14W power consumption plus 1W per gauge for XPIO

• XPIO-QT+ 4 wells/8 gauges

• 10W power consumption plus 2W per PDGIC plus 1W per gauge for UACU+

• UACU+ 20 wells/40 gauges

• XPIO-DT 2 wells/4 gauges • XPIO+ 1 well/8 gauges

• UACU+ 19-in. rack 10 wells/20 gauges

• -10°C to 85°C operation Gauges Supported • ROC™ family of permanent downhole gauges • SmartLog™ cost-effective gauges Communication Ports • 2 × RS-232 • 1 × RS-485 • 10-BASE-T option Port Usage Options • One RS-232 dedicated to XPIO PC program • Modbus® RTU • Modem support (radio/cell) • TCP/IP via ethernet (optional) Inputs • Five 4-20mA inputs (12-bit) • One 16-bit A/D (tool current) Outputs • Four 4-20mA outputs (16-bit) • Two pressure-controlled relays

XPIO Data Acquisition and Control Unit

Memory • 4MB flash for data logging • 2GB SanDisk CompactFlash® option (standard on UACU+) Enclosure • NEMA-4 type water resistant • Anodized aluminum • 19-in. rack-mount option Modbus is a registered trademark of Schneider Automation, Inc.

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Hydraulic Systems Halliburton Intelligent Completions’ surface hydraulic system (SHS) supplies pressurized hydraulic fluid to downhole interval control valves (ICV) located in the well. It also retrieves pressure and temperature data from Halliburton Intelligent Completions’ permanent downhole gauges (PDG). A standalone self-contained unit, the SHS consists of an electro-hydraulic unit capable of delivering pressurized fluid up to 10,000 psi to the SmartWell® equipment. It is housed in a single stainless steel enclosure which includes one main hydraulic supply module (HSM) and up to six well control modules (WCM) with expansion capabilities.

• The integrated system consists of the SmartWell® Master™ supervisory application and an SHS consisting of a hydraulic supply module and one well control module per well. Data acquisition and control can be managed either locally (by keypad or portable device such as a laptop computer or PDA) or remotely. • The automated system is an SHS which includes a hydraulic supply module and one well control module per well. Data acquisition and control can be managed either locally (by keypad or portable device such as a laptop computer or PDA) or remotely. • The manual system consists of the same basic hardware as the automated system but does not provide for automated or remote control. Manually operated valves are used throughout.

HAL31443

The digital infrastructure system features a range of surface hydraulic systems designed to meet every environment.

Hydraulic System

Modules The basic SHS contains the following modules: • Hydraulic supply module • Well control modules Automated systems, in addition to the hydraulic supply and well control modules, contain: • Hydraulic control unit

In subsea applications, SmartWell system control is provided by hydraulic functionality from the third-party subsea controls company. Features • A variety of physical configurations for well type, number of zones, and completion details • Modules that allow for remote control and monitoring by the SmartWell Master supervisory application Benefits • Supply pressurized hydraulic fluid to downhole interval control valves • Retrieve pressure and temperature data from PDGs

• Well control units The SHS is designed for hazardous area applications, including IEC/Cenelec Zone 1 (ATEX category 2). Automated systems can be controlled and monitored remotely by the SmartWell Master supervisory application or from a third-party computer by the Modbus® system over TCP/IP communications to the programming logic controllers (PLC) in the hydraulic control and well control units. In one-well cabinets, the HSM and WCMs are combined into a single unit. For automated systems, hydraulic control and well control units are also combined. Modbus is a registered trademark of Schneider Automation, Inc.


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The hydraulic control unit/well control unit firmware, developed in IEC 61131-3 standard language, automates the sequences and levels of pressure required to operate the SmartWell® completion, and receives feedback from the ICV movement from surface sensors. Surface Hydraulic System Enclosure Features • 316 SS, IP56/NEMA4X • Removable latching doors • Sloped drip pan • 4X lifting eyes, multi-lift capable • Ventilation louvers • Ergonomic design • Plexiglass doors • Durability for harsh environments Hydraulic Supply Module (HSM) The hydraulic supply module (HSM) provides control fluid to the well control module at the required pressure and cleanliness. Material selection for some HSM components may change according to the type of pressure and control fluid used. The HSM contains the tanks necessary to store and filter control fluid. For optimal performance of downhole equipment, all HSM designs are provided with a recirculation capability for managing control fluid cleanliness. Although the standard product contains two tanks and two pumps, several variations—including one tank and one pump—are available, depending on the number of wells and operational philosophy. The HSM provides all the electrical/hydraulic connections for connection to the well control modules. The HSM controls and manages system operation manually (switches) or automatically (pressure transmitters and PLC). In automated systems, the hydraulic control unit houses the PLC and its accessories.

Hydraulic Supply Module

Well Control Module (WCM) A well control module (WCM) provides a means of applying pressure sequences to hydraulic control lines and therefore a way of manipulating the downhole tools. Pressurization and venting of the control lines are achieved by manual or automatic supply/block/vent of directional control valves. Designed for both reliable performance in the target environment and for quick installation for future expansion, well control modules are interchangeable modules that can be combined with the same cabinet for multi-well applications, providing a flexible base for future expansion. In automated systems, each WCM is controlled by a dedicated well control unit which can be fitted with an optional permanent downhole gauge interface card (PDGIC) module for communication with downhole gauges in the well. The number of hydraulic lines required to operate a particular SmartWell completion system is dependent on the chosen control system (Halliburton Intelligent Completions’ Digital Hydraulics™ or Direct Hydraulics systems) and the number of downhole valves in the well.

The hydraulic supply module consists of: • • • • • • • • •

Clean supply reservoir (typically 95 L) Return reservoir (typically 220 L) Main hydraulic supply pump Recirculation pump Accumulator (up to 10,000 psi) Filters (1m, NAS1638, Class 6) Relief valves Tubing/fittings (up to 10,000 psi rated) Hydraulic control unit junction box

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• Solenoid directional control valves (DCV)

Physical Configurations The surface hydraulic system comes in various physical configurations, depending on well type, number of zones, and completion details. For example:

• Pressure transmitters (24VDC, 4-20mA)

• Six-well cabinet

• Hydraulic pressure gauges (up to 10,000 psi)

• Two-well cabinet

• Three-way manual control valves

• Four-well expansion cabinet

• Relief valves and bleed valves

• One-well cabinet

• External connection bulkhead

• Portable unit

• Well control unit junction box (with optional PDGIC)

Both automated and manual versions of the surface hydraulic system are available.

Additional external ports are included for connecting chart recorders and an external hydraulic supply. A well control module contains the following components:

Well Control Module


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Subsea Interface Cards Halliburton Intelligent Completions offers a range of subsea interface cards that enable users to monitor permanent downhole gauges (PDG) and control SCRAMS® surface controlled reservoir analysis and management system completions. Each subsea interface card resides in the pod provided by the respective subsea controls vendor. VetcoGray Dual Gauge Interface Card Halliburton Intelligent Completions' VetcoGray dual gauge interface card is compatible with the VetcoGray-type SEM2000 subsea control module, which features a single downhole channel that provides communications and power to the ROC™ family of gauges. It operates in either “Analog Gauge” or “Digital Gauge” mode. The card has been subjected to an extensive environmental qualification program, including tests for: • • • • •

Temperature soak Temperature cycling Sine swept vibration Random vibration Non-operational shock

Functional card integration testing in the SEM2000 pod was carried out at VetcoGray's premises in Nailsea, U.K. The card has been deployed in the VetcoGray pod on major projects for various operators, including Statoil and ENI. Cameron Dual Gauge Interface Card Halliburton Intelligent Completions' Cameron dual gauge interface card is compatible with the generic Cameron subsea pod. Featuring a single downhole channel that provides communications and power to the ROC™ gauge family, the card can operate in either “Analog Gauge” or “Digital Gauge” mode. Cameron dual gauge interface card firmware includes a timeout feature on the gauge communications, ensuring the card will disconnect power to the downhole gauges if the pod processor has not communicated with the card for more than the timeout period. This feature is important in Cameron dual-SEM pods, where gauge outputs from the interface card in each SEM are connected together. The card has been subjected to an extensive environmental qualification program, including tests for: • Temperature soak • Temperature cycling

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• Sine swept vibration • Random vibration • Non-operational shock The card underwent extensive integration testing to Cameron procedure X065418-07-01 at Cameron's premises in Celle, Germany. FMC Dual Gauge Interface Card The Halliburton Intelligent Completions' FMC dual gauge interface card is compatible with the FMC KS150 subsea electronics module. The card features a single downhole channel that provides communications and power to the ROC gauge family and can operate in either “Analog Gauge” or “Digital Gauge” mode. The FMC card was subjected to an extensive environmental qualification program, including tests for: • • • •

Sine swept vibration Shock Thermal cycling Thermal dwell

The card underwent extensive integration testing at the FMC premises in Kongsberg, Norway. An older card design, the FMC digital gauge interface card, is still used exclusively in Gulf of Mexico projects for a major customer. It has a single downhole channel providing communications and power to ROC digital gauges. Aker Solutions Dual Interface Card Halliburton Intelligent Completions' Aker Solutions dual gauge interface card is compatible with the Aker Solutions iCon (formerly 5th Generation) subsea control module. It has a single downhole channel, providing communications and power to the ROC family of gauges and can operate in either “Analog Gauge” or “Digital Gauge” mode. Unlike other interface cards, the Aker Solutions dual gauge interface card uses a Hypertac® edge connector rather than a DIN41612 Euro style connector. The card was subjected to electromagnetic compatibility qualification testing specific to Aker Solutions requirements, including: • Emissions • Immunity • Electrical fast transients/burst immunity Hypertac is a registered trademark of Smiths Interconnect.


03 Intelligent Completions HLB

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