PRODUCT CATALOGUE · • NORSOK D-010 compliant Benefits • Enhances well integrity • Can be...

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PRODUCT CATALOGUE

Petroleum Technology Company ...........................................................................................................4Wellhead Solutions .................................................................................................................................5

MSAS Master Surface Annulus Safety Valve .........................................................................................6VR Sensor - Wired & Wireless ...............................................................................................................8A-Pro Annulus Pressure Management System ....................................................................................10MSAS-E Surface Safety Valve for Control and Chemical injection Lines .............................................12VR Lubricator Tool ................................................................................................................................14

Gas Lift Solutions ..................................................................................................................................16SafeLift & IsoLift Orifice Gas Lift Valves ...............................................................................................18SafeLift & IsoLift Injection Pressure Operated Gas Lift Valves.............................................................20ShearLift-T Tubing pressure activated Gas Lift Valve ..........................................................................22ShearLift-A Annulus pressure activated Gas Lift Valve ........................................................................24DuraLift Scale Resistant Gas Lift Valve ................................................................................................26GoLift Retrievable Gas Lift Straddle .....................................................................................................28Life of Field Gas Lift Design Tool ..........................................................................................................29NexLift Unwelded Gas Lift Mandrel ......................................................................................................30

Chemical Injection Solutions ...............................................................................................................32SureFlo Chemical Injection Sub ...........................................................................................................34SureFlo Chemical Injection Valve .........................................................................................................36

Completion Solutions ...........................................................................................................................38SaveFlo Bleed Off Valve .......................................................................................................................40Annulus Safety Valve Packer ...............................................................................................................42Water Injection Valve ............................................................................................................................44JetLift Retrievable Jet Pump ................................................................................................................46

Contacts .................................................................................................................................................47

Table of Contents

Innovation

Petroleum Technology Company (PTC) was founded in 2002 by a group of ex-perienced and innovative oilfield professionals, who were determined to improve the existing technologies and methods in response to specific client requests. Today PTC has grown to become an international oilfield service company with of-fices in Norway (Head Office), UK, UAE, US and Brazil. PTC is committed to provid-ing value adding and cost effective solutions to Oil and Gas Companies worldwide.

We specialize in providing

• Unique double barrier monitoring and surface annulus safety valve systems for wellheads

• Autonomous and/or remote controlled systems for annulus pressure man-agement

• Unrivalled solutions for Gas Lift design and equipment, including harsh en-vironment applications

• Reliable Chemical Injection design and equipment• Annulus bleed off subs and valves

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Wellhead Solutions

Solutions for wellhead integrity challenges today. Well integrity assurance is a fundamental need throughout the lifecycle of all wells. Definitions vary, but the universally adopted rule to facilitate this is: “At least two tested independent (primary and secondary) barriers between a hydrocarbon source and the environment shall exist at all times” Well Integrity Management

It has been reported that Sustained Annulus Pressure (SAP) is a challenge in over 40% of today’s global well stock. Many wells are prematurely shut in as a result Most commonly the SAP is un-planned, and a result of down-hole completion, casing or cementation failure. In other cases, where lift gas is being injected or vent gas is being produced via the annulus, the SAP is planned. Irrespective, both scenarios pose a significant risk to personnel and facilities as the double barrier rule has been compromised in these wells. Specifically, the annulus line gate valves, ring gaskets, instrument flanges and pressure gauges provide only a single barrier between the hydrocarbon source and the environment. Continuous monitoring of the annulus with SAP and its outer counterpart is critical for safe opera-tions. A method for the safe management and bleed off of pressure in the event that it approaches the casing or tubing design limits is also necessary. Historically there was no optimum solution to these challenges. PTC have now developed unique technologies, which fully address the issues. These are now field proven and increasingly adopted by OPCO’s worldwide. Annulus Pressure Monitoring

Continuous annulus pressure and temperature (P&T) monitoring, with enhanced well integrity using PTC’s unique VR Sensor system. The system eliminates the need for wellhead gate valves and in-strument flanges. It is also designed to maintain well integrity even upon impact or collision. Annulus Pressure Management

PTC’s Master Surface Annulus Safety Valve (MSAS) is installed in the wellhead VR profile. It can be used as an actuated (fail-safe closed) barrier valve in gas lift applications, or safety / bleed valve in wells where SAP or annulus production needs to be managed. Autonomous Annulus Pressure Management

The integration of PTC's VR sensor, Master Surface Annulus Safety Valve (MSAS) and Hydraulic Control & Power Unit (HCPU) provides a system for autonomous and controlled annulus pressure management. The system, called A-Pro, can be configured to both autonomous and human interven-tion modes. The system can be self-sustained or connected to an external power source.

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Hydraulically activated barrier valve installed in the wellhead VR profile

Assures well integrity even upon impact or collision.

Fail safe close barrier valve provides an independent primary barrier for gas lifted, gas vented or for wells with sustained annulus pressure.

ChallengeGas lifted, gas vented or wells with sustained annulus pressure pose a considerable risk to personnel and facilities. In these applications annulus gate valves and ring gaskets are the primary well barrier. Gate valves provide only a single barrier, which can be breached upon impact or collision.

Regulatory and/or company requirements may demand mitigation for the risk that high gas volume poses.

SolutionPetroleum Technology Company’s MSAS, provides an additional independent barrier in the wellhead VR pro-file. The MSAS is hydraulically operated and connected to ESD. Should an impact or collision take place, the API 6FD/FB fire tested fail safe safety valve locked in the VR profile will close and remain within the wellhead, thus securing the annular volume of hydrocarbons.

The MSAS system can be integrated in an API gate valve (MSAS-G) and has a smaller footprint as the valve actuator is installed within the gate valve bore (see illustration on next page).

Features• Based on API 6A• Fire tested to API 6FD & 6FB• Bi-directional flow• For gas injection and annulus venting applications• Fail safe close barrier valve• Independent barrier• NORSOK D-010 compliant

Benefits• Enhances well integrity• Can be used to substitute the annular safety valve

or downhole gas vent valve, or similar down hole barrier

• Eliminates the need for an ESD gate valve• Easy installation and service, even in live wells• No piping modification required (MSAS-G)

Wellhead gate valve knocked off, no MSAS installed. Entire Annulus volume can be vented to atmosphere.

PTC’s Dual Barrier MSAS and VR Sensors installed in a wellhead.

www.ptc.as

MSAS Master Surface Annulus Safety Va ve l

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Hydraulically activated barrier valve installed in the wellhead VR profile

Specifications

Size Range, in. 2-1/6 to 3-1/8

Valve/ Actuator Material Alloy K500

Seals Material FKM/PEEK/PTFE

Pressure Rating, psi [Mpa] 10 000 [69]

Temperature Class, L-U °F [°C] -51 to 250 [-46 to 121]

Flow Area Range, in² [cm²] 0.15 - 1 [0.97 to 6.45]

Min. Hydr. Pressure, psi [Mpa] 2 500 over inj. pressure [10.3]

Flow Rate Range (fluid), bbls/min [l/min] 1 - 5 [159 to 795]

Applicable Standard API 6A

MSAS-G System with the hydraulic actuator installed in-side the API gate valve bore. MSAS-G is designed for applications where piping modifications are not desired or possible to perform. Cost effective and safe instal-lations are provided by simply replacing the excising gate valve with PTC's gate valve and MSAS-G system.

www.ptc.as

Assures well integrity even upon impact or collision.

MSAS Master Surface Annulus Safety Valve

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Double Barrier Wellhead P&T Sensor

Continuous annulus monitoring, with enhanced well integrity.

Robust real-time pressure and temperature sensor system that eliminates the need for gate valves and instrument flanges. The system is designed to maintain well integrity even upon impact or collision.

ChallengeWells with sustained annulus pressure pose a considerable risk to personnel and facilities. Continuous monitoring of this pressure is critical for safe operations. Conventional monitoring systems often contain a gauge downstream gate valves/flanges.

Gate valves provide only a single barrier. Impact or collision can breach this barrier. Blockage by valve lubricant can impair pressure gauge operation. Regulatory and/or company requirements may demand continuous monitoring and alarms.

SolutionPetroleum Technology Company’s VR Sensor system, provides continuous monitoring, even during ESD shut downs. The VR Sensor is designed with two independent metal-to-metal barriers. Should an impact or collision take place, the API 6FD/FB fire tested gas tight VR sensor plug will remain within the wellhead.

The VR sensor removes potential issues related to viscous valve lubricant and can substantially lower installation and maintenance costs.

Features• Wired and wireless versions• Based on API 6A• Atex certified for Zone 0• Fire tested to API 6FD & 6FB• Dual independent barriers• NORSOK D-010 compliant• Short and lightweight

Benefits• Enhances well integrity• Continuous annulus monitoring with alarms• Saves cost• Small footprint

Wireless VR Sensor

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Double Barrier Wellhead P&T Sensor

PTC VR Sensor System vs conventional monitoring rig up.

Specifications

Pressure Rating, psi [Mpa] Up to 10,000 [69]

Temperature Class U (standard material) °F [°C] 0 to 250 [-18 to 121]

Flange Size According to Wellhead Spec.

Plug Size According to Wellhead Spec.

Accuracy 0.5% F.S (Pressure) | 1,5% °C(Temperature)

Output Signals Analog 4-20mA, HART® or WirelessHART®

Power module lifetime (Wireless) Depending on transmission rate and network configuration

Material Class (standard) EE - Sour Service

Flange Material Super Duplex/4130/4140

Sensor Plug Material Alloy 718

Secondary Metal to Metal Seals Material S165M/4130/4140

Applicable Standard API 6A/ISO 10432 PSL3G PR2

VR Sensor ExitBlock is designed to monitor the cavity above the tubing hanger.

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A-Pro

Real time autonomous monitoring control of annular pressure

Time savings and enhanced well integrity.

The integration of Petroleum Technology Company’s (PTC) field proven technolo-gies provide a system for autonomous and controlled annulus pressure monitoring and bleed off.

ChallengeSustained annulus pressure (SAP) pose a considerable risk to personell, well infrastructure and facilities, espe-cially for remote and unmanned locations. Monitoring and bleed off operations typically require human intervention.

SolutionThe integration of PTC’s VR Sensor, Master Surface An-nulus Safety Valve (MSAS) and Hydralic Control Power unit (HCPU) allows operators to perform both monitoring and bleed off of annulus pressure in a reliable and safe manner.

The system can be configured to:

1) Acquire the signals provided by the VR Sensor in the Local Control Panel (LCP). Field Technicians can decide when to actuate the MSAS system,

2) In autonomous mode, the HCPU local unit acquires the pressure readings, provided by the VR Sensor, and based on the pre-defined set points automatically opens or clos-es the MSAS system (Alarm signals for process monitor-ing can be implemented).

As the system is modular several options can be included with varying levels of redundancy and ATEX classifica-tions.

Features

• Remote control and monitoring of annulus pressure• Wellhead mounted equipment based on API 6A• VR profile mounted barrier equipment fire tested to

API 6FD and 6FB• Fail safe close barrier valve (MSAS)• Independent barriers (MSAS and VR Sensor)• Autonomous or manual control modes• Supplied with a dedicated power unit or connected to

an existing power source.• Permanent or temporary installation.

Benefits• Enhanced well integrity• Time savings• Can be installed on live wells• No piping modification required (MSAS-G)

www.ptc.as10

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Specifications (HCPU)

5, 000P psi HPU

Redundant HPU available

SIL (1,2) capable PLC’s available

Redundant I/O cards available

ATEX zone 1 & 2 certification available

Solar & Battery power sources available

Solar, Wind & Battery power sources available

Diesel & Battery power sources available

Please see MSAS and VR Sensor product flyers for product specification

www.ptc.as

A-Pro

MSAS-G and VR Sensor ccontrolled by HCPU

Surface Safety Valve for Control and Chemical Injection Lines

Enhanced well integrity for wellhead exit blocks

Fail safe close barrier valve provides an independent primary barrier for control and chemical injection lines

ChallengeWells with chemical injection, surface controlled hydraulic downhole smart well valves and similar systems require control lines all the way to the surface. A compromised barrier downhole may allow hydrocarbons to enter the line(s) and subsequently the surface control system, pos-ing considerable risk to personnel and facilities.

Most of the current exit block valves are manually operat-ed and not part of the ESD system.

SolutionPetroleum Technology Company’s MSAS-E, provides an additional independent barrier at the exit block. The MSAS-E is a hydraulically operated, normally closed valve connected to the ESD.

Should a situation arise where gas enters to the surface control system, the triggering of the ESD will close the MSAS-E, shutting off the conduit at the wellhead and thereby maintaining the well integrity

Features• Based on API 6A • Fire tested to API 6FD & 6FA• Metal to metal seal• Proximity switch (valve position indicator)• Fail safe close barrier valve

Benefits• Enhances well integrity

www.ptc.as

MSAS-E

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Surface Safety Valve for Control and Chemical Injection Lines

Proximity Switch Specifications

Body Shape Cylindrical

Body Material (Proximity Switch). 316 SS

Mody Material (Magnet Hose) Alloy 718

Switch Type SPCO/SPDT

Max Switching Currents 24V DC-2.5A

Connection Polyrad Cable (3 Wires)

Category Cat 1/ Zone 0

Temperature Range -60°C to +125°C

IP Rating IP68 + IP66

IECEx/ ATEX Marking ATEX Ex ia IIC T4/ T6 Ga

Actuation Magnetically Actuated

Suitable for use in the design of safety functions up to SIL2 or SIL3.

www.ptc.as

MSAS-E

Specifications

Size Range, in. 1-13/16 to 4-1/16

Valve/ Actuator Material Alloy 625

Seals Material FKM/PEEK/PEEK CARBON

Pressure Rating, psi [Mpa] 10 000 [69]

Temperature Class, L-U °F [°C] -51 to 250 [-46 to 121]

Flow Area, in² [cm²] 0.12 [0.77]

Applicable Standard API 6A

MSAS-E Surface Safety Valve

Safe and efficient Wellhead intervention operations.

Safest, shortest, lightest and most versatile lubricator tool on the market. The kit includes accessory tools for cleaning and refreshing the profile and removing stuck plugs.

ChallengeIntervention operations in narrow well bays or cellars can be difficult, time consuming and risky. Traditional tools are heavy, long and utilize stuffing boxes, often requiring hoisting equipment and additional personnel to perform operations. Adequate clean-up and/or refreshing of dirty, damaged and/or corroded VR profiles is often required. Old VR plugs and valves can be hard to unscrew due to high friction.

SolutionPetroleum Technology Company’s (PTC) VR Lubricator tool is fully sealed off, telescopic and manufactured in Titanium to minimize the weight and length. This greatly simplifies operations in narrow spaces and reduces the HSE risks.

For large bore plugs and valves (≥ 2 9/16") with higher friction, PTC has developed a high torque big bore VR Lubricator tool capable of transferring torque up to 3750 Nm / 2765 lb/ft.

Features• Lightweight• Short• Pressure bearing housing sealed off (no stuffing box)• Telescopic piston• Full range of accessory tools

Benefits• Simplifies operations in narrow spaces• Reduces HSE risks• Saves time• Less POB

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Lightweight and versatileVR profile intervention tool

www.ptc.as

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Specifications

Torque Capacity Range lbf/ft [Nm] 1 106 [1 500] to 2 765 [3 750]

Interface Range in. Standard API6A 2-1/6 to 4-1/16 *other sizes can be accommodated

Max Working Pressure psi [Mpa] 10 000 [69 Mpa]

Build lengt Stroke Length Weight

359 mm/ 14,3" 355mm/ 13,97" 13,2 kg

417 mm/ 16,42" 490mm/ 19,29" 17,3 kg

518 mm/ 20,39" 690mm/ 27,17" 20,05 kg

661 mm/ 26,02" 980mm/ 38,58" 23,6 kg

756 mm/ 29,76" 1180mm/ 46,46" 26,5 kg

856mm/ 33,7" 1380mm/ 54,33" 28,2 kg

Build length Stroke length

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Gas Lift Solutions

Solutions for todays Gas Lift challenges Little has changed over the past decades to prepare the industry for the gas lift challenges being faced today. These include:• Deeper, longer, and more highly deviated wells.• Higher pressures / temperatures and more corrosive / scaly environments• Increased focus on well integrity• Increased recognition of production inefficiencies due to multipointing• The need to retrofit new or upgrade existing gas lift systems without recompletion• The need to reduce the number of well interventions To address these challenges, PTC has developed the next generation of gas lift technologies, which are now widely used by most OPCO’s worldwide. The increased reliability, flexibility and longevity these technologies offer, has also led to the de-velopment of a unique life of field approach to gas lift system design. Today's Gas Lift Valve Technology

The Gas Lift Valve (GLV) has historically been the component most prone to malfunction and fail-ure in a gas lift system. Scale, erosion, chattering, and unloading valve bellows fatigue or dome charge valve leakage, are widely reported causes. PTC has designed, qualified and incorporated many revolutionary features in our Lift-family GLV’s that has greatly improved reliability and operational efficiency. These include:• Proprietary barrier certified orifice and back-check valve system, which is less prone to chat-

tering, and erosive wear of the metal to metal sealing surfaces• Unique low load rate / long stem travel dual operating bellows type Injection Pressure Operat-

ed (IPO) valves. These valves can be reliably used as operating valves, eliminating the need for interventions to change lift gas injection depth. The bellows are rated to 12 500 psi and have been tested to 50 000 full open/close cycles.

• Shear activated GLV’s that allow operators to run multiple valves (unloading and orifice) in the same completion string and shear them open in one operation.

• Anti-scale valve design providing longevity in scaley environments. Side Pocket Mandrel Technology

Today, side pocket mandrel ‘s (SPM’s) are the only welded upper completion component. This introduces a range of QA QC repeatability risks and a number of failures have been reported. In March 2015, PTC launched the NexLift family of unwelded SPM’s which are machined from a single piece of steel. These are especially suited to high Cr and Ni alloy applications, where welding becomes increasingly challenging.

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GoLift retrofit Gas Lift Straddles

PTC’s GoLift through tubing gas lift straddle system offers a cost effective alternative to work-overs where there is a need to retrofit new or upgrade existing gas lift systems, without compro-mising well integrity. Life of Field Gas Lift Design

Traditionally decisions regarding the optimum number and setting depths of valves in gas lifted wells have been made considering only a small number of operating scenarios. As a result, wells often do not perform as expected. PTC’s unique life of field design process considers a wider range of life-cycle operating con-ditions and data uncertainties. It therefore provides a more robust design to ensure maximum production, and reliability over the life of the well.

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Barrier series gas lift orifice valves

Unsurpassed reliability and enhanced well integrity

The reverse back-check valve is fully qualified as a barrier, providing a positive seal between the tubing and casing annulus. The unique check valve design results in a valve that does not chatter under normal operation.

ChallengeChange out of gas lift valves (GLV) due to valve failures or non-optimum gas lift design can be costly, especially in offshore and subsea environments.

Interruption of, or non-optimum gas lifted production has a negative impact on field economics. Furthermore, leaking GLV’s often lead to downgrading of the wells integrity level.

SolutionPetroleum Technology Company´s (PTC) SafeLift and IsoLift orifice valves have a proprietary orifice and back-check system, which eliminates chatter and wear. This design has proven to have unsurpassed longevity and reliability, which reduces intervention costs. In addition to the valve geometry, PTC offers a unique life of field (LOF) gas lift design process, which ensures optimum design for all phases of the well.

QualificationSafeLift’s & IsoLift’s true metal-to-metal seal has been qualified as a well barrier for operators worldwide. It was designed, built and tested in accordance to API 19G part 2 and leak tested in accordance to ISO 14310-V1/V0. SafeLift valves are designed to be installed in all side-pocket mandrels with 1" & 1.5" pockets, designed according to API 19G part 1. 1.75" SafeLift valves are also available.

Features• True metal-to-metal back check seal• Patented orifice and back check design• The design eliminates vibration and chattering• Barrier qualified• Premium metallurgy• No internal elastomeric seals• CFD simulations and erosion tested• Suitable for harsh environments (H2S and CO2)• Square-Edge, Stealth and Venturi orifices available

Benefits• Field proven design and operation• Best in class reliability and longevity ensures

enhanced productivity and well integrity• Minimizes the need for interventions

www.ptc.as

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Barrier series gas lift orifice valves

Specifications

Size in. 1.0, 1.5 and 1.75

Orifice Size Range, 1.0" valve in. 1/8 - 5/16



Orifice Type Square-Edge/Stealth/Venturi

Body Material Alloy 718 (other material on request)

Seal Stack Material FKM/PTFE/PEEK

Max Operating Pressure for 1.0" psi [Mpa] 7 500 [51]

Max Operating Pressure for 1.5" & 1.75" psi [Mpa] 10 000 [69]

Max Operating Temperature for 1.0" °F [°C] 365 [185]

Max Operating Temperature for 1.5" & 1.75" °F [°C] 329 [165]

Min Operating Temperature °F [°C] 64.4 [18]

Applicable Standards, SafeLift Series API 19G2 - V1 TR2385 - 20cc/15min [0cc/15min - V0]

Applicable Standards, IsoLift Series API 19G2 - V1 PTC Leak Criteria - 3,5 scf/d (10% of API)

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Injection Pressure Operated (IPO) valve

Unsurpassed reliability and enhanced well integrity.

SafeLift & IsoLift IPO valves employ unique bellows technology, which ensures reliable operation throughout the life of the field.

ChallengeUnloading valve reliability issues often arise as traditional bellows systems have major limitations when it comes to pressure, open & close cycles and temperature. These effects are more pronounced in deeper, hotter wells.

SolutionPTC has developed a revolutionary dual operating bellows system that once installed in a gas lift valve can be charged to more than 12 500 psi. The system is built such that the stem tip is lifted a full ¼" off the seat during unloading operation, not a fraction of an inch, which is typical in the industry. This enables SafeLift & IsoLift IPO valves to be used as operating valves.

QualificationIPO valve section has been tested to more than 50 000 full open/close cycles.

SafeLift’s & IsoLift’s true metal-to-metal seal has been used as a well barrier for operators worldwide. It was designed, built and tested in accordance to API 19G part 2 and leak tested in accordance to ISO 14310-V1/V0. SafeLift valves are designed to be installed inside all side-pocket mandrels with 1.0" & 1.5" seal bores in accordance with API 19G part 1.

Features• Dual edge welded bellow filled with silicone oil• Field proven design and operation• True metal-to-metal back check seal• Patented orifice and back check design• The design eliminates vibration and chattering• Barrier qualified• Premium metallurgy• Can be used as an operation valve • CFD simulations and erosion tested• Suitable for harsh environments (H2S and CO2)

Benefits• Reduced ´multi-pointing´ • Best in class reliability and longevity ensures

enhanced productivity• Minimizes the need for interventions

www.ptc.as

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Injection Pressure Operated (IPO) valve

Specifications

Size in. 1.0 & 1.5



Orifice Type Square-Edge





Max Dome Pressure for 1.0" 7 500 [51]

Max Dome Pressure for 1.5" 10 000 [69]





Applicable Standards, IsoLift Series API 19G2 - V1 PTC Leak Criteria - 3,5 scf/d (10% of API)

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Tubing pressure activatedgas lift valve

ShearLift-T valves facilitate standard completion operations (annulus/ tubing pressure tests) without the need for a wireline intervention.

Multiple ShearLift-T valves can be opened in a single operation by pressuring up the tubing.

ChallengeWhen completing new gas lift wells the standard practice is often to install dummy valves in all side pocket mandrels. These dummy valves provide a barrier between the annulus and the tubing during the well completion phase. Before the wells can start producing, the dummy valves need to be replaced with gas lift valves. These intervention operations are often time consuming and costly.

SolutionPetroleum Technology Company’s ShearLift-T valve has a unique design, which utilizes the barrier technology from the standard SafeLift. The ShearLift-T valve provides a barrier between the tubing and annulus when installed in a side pocket mandrel.

The check valve is held in the closed position by a shear device located in the nose section of the valve. Increasing the tubing to annulus differential pressure, to a predeter-mined level, shears open all ShearLift-T (IPO & Orifice) valves in the tubing string. This allows communication from annulus to tubing.

Costly change out of dummy valves in new completions can be avoided by using ShearLift-T.

Features• A shear system that can be utilized in wells with

multiple GLV´s (IPO & Orifice valves) in the tubing string

• Act as a dummy valve until shear open• All ShearLift-T valves open during one operation• True metal-to-metal back check seal• Patented shear design• The check valve design eliminates vibration and

chattering• Barrier qualified• Premium metallurgy• CFD simulations and erosion tested• Suitable for harsh environments (H2S and CO2)• Square-Edge, Stealth and Venturi orifices available

Benefits• Field proven design and operation• Considerable time saving, as no wireline intervention

required prior to production start up• Best in class reliability and longevity ensures

enhanced productivity and well integrity

www.ptc.as

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Tubing pressure activated shear open Orifice and IPO Gas Lift Valve

QualificationsShearLift valves use SafeLift’s true metal-to-metal seal, which has been qualified as a well barrier for operators worldwide. It was designed, built and tested in accordance to API 19G part 2 and leak tested in accordance to ISO 14310-V1/V0. SafeLift valves are designed to be installed to all side-pocket mandrels with 1.0" & 1.5" seal bore, designed according to API 19G part 1.

Specifications

Size in. 1.5


Orifice Type Square-EdgeStealth/Venturi (Orifice valves only)




Max Dome Pressure for 1.5" psi [Mpa] 10 000 [69]


Max Shear Pressure (absolute tubing pressure) psi [Mpa] Up to 9 000 [62]



www.ptc.as

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Annulus pressure activated Gas Lift Valve

ShearLift-A valves facilitate standard completion operations (annulus/ tubing pressure tests) without the need for a wireline intervention.

The ShearLift-A valve is opened by pressuring up the annulus.

ChallengeWhen completing new gas lift wells the standard practice is often to install dummy valves in all side pocket mandrels. These dummy valves provide a barrier between the annulus and the tubing during the well completion phase. Before the wells can start producing, the dummy valves need to be replaced with gas lift valves. These intervention operations are often time consuming and costly.

SolutionPetroleum Technology Company’s ShearLift-A valve has a unique design, which utilizes the barrier technology from the standard SafeLift. The ShearLift-A valve provides a barrier between the tubing and annulus when installed in a side pocket mandrel.

The check valve is held in the closed position by a shear device located in the nose section of the valve. Increasing the annulus to tubing differential pressure, to a predetermined level shears the valve open. This allows communication from annulus to tubing.

Costly change out of dummy valves in new completions can be avoided using ShearLift-A.

Features• Act as a dummy valve until shear open• True metal-to-metal back check seal• Patented shear design• The check valve design eliminates vibration and

chattering• Barrier qualified• Premium metallurgy• CFD simulations and erosion tested• Suitable for harsh environments (H2S and CO2)• Square-Edge, Stealth and Venturi orifices available

Benefits• Field proven design and operation• Considerable time saving, as no wireline intervention

required prior to production start up• Best in class reliability and longevity ensures

enhanced productivity and well integrity• Offers protection against tubing collapse

(ShearLift-A).

www.ptc.as

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Annulus pressure activated shear open orifice gas lift valve

QualificationsShearLift valves use SafeLift’s true metal-to-metal seal, which has been qualified as a well barrier for operators worldwide. It was designed, built and tested in accordance to API 19G part 2 and leak tested in accordance to ISO 14310-V1/V0. SafeLift valves are designed to be installed to all side-pocket mandrels with 1.0" & 1.5" seal bore, designed according to API 19G part 1.

Specifications

Size in. 1.0, 1.5, 1.75

Orifice Size Range, 1.0” valve in. 1/8 - 5/16



Orifice Type Square-Edge/Stealth/Venturi




Max Operating Pressure for 1.5” & 1.75” psi [Mpa] 10 000 [69]


Max Shear Pressure (absolute tubing pressure) psi [Mpa] Up to 9 000 [62]



www.ptc.as

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Scale resistant barrier qualified Orifice and IPO gas lift valve

Improved longevity and well integrity in wells with scaling issue.

The DuraLift gas lift valve was designed to operate in wells with scaling issues, while providing reliable barrier function. The geometry of the valve has a unique feature that prevents produced fluid that may create scale, from entering the check-valve area.

ChallengeFailure of gas lift valves as a result of scale deposition has been an issue that has plagued the industry for decades. In certain fields GLV´s have to be changed several times per year.

Interruption of, or non-optimum gas lift assisted produc-tion will have a negative impact on field economics.

SolutionPetroleum Technology Company’s (PTC) DuraLift has a unique geometry to ensure that fluid, which could cause scale deposition does not enter the check-valve area, both during gas-lift operation or when well is shut in. Additionally, a special coating has been applied to the flow wetted parts, both on the GLV and latch, to further reduce the potential for scale to build.

QualificationsThe DuraLift builds on the same geometry as our SafeLift series which is used as a well barrier by most major operating companies. It was designed, built and tested in accordance to API 19G part 2 and leak tested in accordance to ISO 14310-V1/V0.

Features• Both Orifice and Injection Pressure Operated (IPO)

valves• Unique geometry to prevent produced fluids entering

the valve• True metal-to-metal back check seal• Patented orifice and back check design• The design eliminates vibration and chattering• Barrier qualified• Premium metallurgy• No internal elastomer seals• Suitable for harsh environments (H2S and CO2)• Square-Edge, Stealth and Venturi orifices available

Benefits• Best in class reliability and longevity ensures

enhanced productivity and well integrity• Minimizes the need for interventions

www.ptc.as

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Scale resistant barrier qualified gas lift valve

Specifications

Size in. 1.5


Orifice Type Square-Edge

Body Material Alloy 718 (other materials on request)


Max Operating Pressure psi [Mpa] 10 000 [69]

Max Operating Temperature °F [°C] 329 [165]


Applicable Standards, SafeLift Series API 19G2 - V1 TR2385 20cc/15min [0cc/15min]

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Quick production enhancementwithout workover

GoLift Retrievable Gas Lift Straddle with Petroleum Technology Company’s barrier qualified gas lift valves provide a fast, cost effective and reliable means to boost production.

ChallengeDwindling production and/or sub-optimal completion de-sign may require introduction of artificial lift or different gas unloading/injection depths at some point in well’s life cycle. Although a full workover could potentially solve the issue, the relatively high costs of such an operation may render the project to be unviable.

SolutionPetroleum Technology Company’s (PTC) GoLift Gas Lift Straddle facilitates the introduction of controlled gas lift into a well without the need for an expensive workover. GoLift is located across pre-punched tubing or even across an existing damaged gas lift mandrel. The GoLift straddles are conveyed by wireline, locked and sealed in place using standard bridge plug technology.

The workflow, starting from the gas lift design and tailoring it with the available geometry and operating parameters ensures a robust solution and optimum production. PTC's long experience, proprietary gas lift design software, GoLift straddles and large portfolio of barrier-accredited gas lift valves provides the most versatile technology tool-box in the market today.

A variety of applications such as, single station or com-plete gas lift string (installation of several GoLift straddles with IPO and orifice gas lift valves), tubing, annulus shear or anti-scale gas lift valves are now possible with PTC’s technology.

Features & Benefits• Cost effective gas lift solution• Proprietary gas lift software ensuring optimum gas lift

and hardware design• Barrier qualified gas lift valves ensuring unrivalled

longevity• Special gas lift valves for tubing/annulus shear and

anti-scale applications• Available sizes: 4.5" - 7" tubing and 1" - 1.5" GLV's

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Unique processes and proprietary software tools, providing optimized design decisions and equipment specifications

Life of Field Gas Lift Design Tool

ChallengeTraditionally decisions regarding the optimum number and setting depths of valves in gas lifted wells have been made considering only a small number of operating scenarios. As a result, wells often do not perform as expected.

A lack of rigor also often exists when checking the suitability of proposed valve set up specifications over the expected life of well operating conditions. This often means that injection of all available lift gas at the deepest possible location cannot be achieved.

SolutionA more rigorous well life-cycle design process is available, incorporating both Petroleum Experts ‘Prosper’ and proprietary Petroleum Technology Company software. It facilitates the consideration of a wider range of life-cycle operating conditions and data uncertainties and checks for life-cycle design resilience.

BenefitsWell reliability is enhanced and life-cycle productivity is op-timized, this is as a result of:• The impact of design compromises and uncertainties

are addressed to better facilitate informed decisions regarding valve numbers and depths.

• The requirement for anti-scale valves is also assessed

Life-cycle Gas Lift Valve Specifications:• Selected and checked for all expected life-cycle

operating conditions to ensure: kick off is always pos-sible and multi-pointing, unstable flow and check valve chatter is always avoided.

Unloading Schedule Details:• To avoid the potential for gas lift valve damage during

this most critical period in the valves life.

Engineering working with gas lift designLife of Field (LOF) Gas-Lift Design

NS Well A1 - Unloading Schedule

0

200

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0 2000 4000 6000 8000 10000 12000 14000 16000 18000 20000

Time(sec)

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_int

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0

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Pann

_sur

face

,DP

MD_interface(m)

QL_valve(m3/d)

QL_valve_max(m3/d)

P_ann_surface(bara)

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Next Generation unwelded gas lift mandrel

Unwelded, machined from a single piece of steel providing unrivalled struc-tural integrity.

ChallengeConventional side pocket mandrels (SPM) have inherent challenges related to welding and heat-treatment. These issues are exacerbated when welding nickel-chromium alloys, such as S13%Cr, 25%Cr and Alloy 718, common materials for high cost completions.

Challenges caused by manufacturing processes such as welding and post weld heat treatment require strin-gent and elaborate QA/QC processes. Despite all efforts, satisfactory repeatability of the manufacturing process is difficult to achive.

SolutionToday, SPMs are the only welded loadbearing component in a modern completion string. The elimination of welding brings the SPM to the same structural integrity level as the rest of the machined components in the string.

Petroleum Technology Company’s (PTC) NexLift™ SPM enhances the robustness of the completion string and is the best choice for challenging well applications in which superior longevity, strength and enhanced pressure capa-bilities are required. The API 19G1 qualification assures full compatibility with the gas lift equipment designed and manufactured to API standards.

Features• Machined from a single piece of steel • Smooth inner bore• By-pass slots for cables and control lines• Hinged keeper plates for by-pass lines• Gas Lift and Chemical injection applications

Benefits• Superior structural integrity• Best choice for sour environments• Simpler QA/QC, less prone to scrappage and

delivery delays• Elimination of weak links in the completion string• Less chamfers and grooves where wireline tools may

hang up• No loose parts that can be dropped in hole (hinged

keeper plates)

Unwelded, machined from a single piece of steel.

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Specifications

Size in. 5 1/2

Pocket Size, in 1 1/2

Mandrel Body Round

Major OD, in 8.250

Min. ID, in 4.660

Bypass Dimensions 2 off 1.732" x 0.512" [13mm x 44mm]

Latch profile RM

Qualification Criteria API 19G1, Q1, V1, F1*

Next Generation unwelded gas lift mandrel

Unwelded, machined from a single piece of steel.

* Except external pressure test

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NexLift Ratings*

Material 80 Ksi 95 Ksi 110 Ksi

Burst, psi 13 770 16 339 18 909

Collapse, psi 12 137 14 401 16 666

Tension, klb 567 672 778

Compression, klb 567 672 778

* Based on yield strength at ambient temperature. Excluding end connections.

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Chemical Injection Solutions

Solutions for Todays Chemical Injection Challenges Wells with scale or corrosion issues often require the continuous injection of treatment chemicals. The most common method employs the use of control lines to place the chemicals at the desired injection point in the well. Issues associated with the stable flow of chemicals through the control lines (no u tubing), testing of control lines and well integrity have plagued the industry for decades. To address these challenges, PTC has developed their SureFlo range of barrier certified chemical injection systems. PTC has also developed their own proprietary software to simulate the entire chemical injection systems performance over the life of the well.

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Today's Chemical Injection Technology

Chemical injection systems have historically had issues when reservoir pressures fall (are) below the threshold required to maintain a stable column of chemical injection fluid in the control line. This U tubing effect is often the root cause of chemical injection system failure. Failure to properly size the control line based on fluid, hardware and well environment constraints has also been an issue. PTC's SureFlo range of chemical injection systems provide:• Anti U-Tubing protection• Barrier qualified back check systems• Shear disc to facilitate testing of control lines• Shearable filter system Life of Field Chemical Injection Design

PTC’s Life of Field chemical injection design software can simulate the entire chemical injection system and determine the optimum control line size, anti-u tubing setting and control line test pressure.

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Continuous, stable chemical injection with enhanced well integrity

The reverse back-check valve is fully qualified as a barrier, providing a positive seal between the tubing and casing annulus

Barrier Series Chemical Injection Sub

www.ptc.as

ChallengeWells with scale or corrosion issues often require the con-tinuous injection of treatment chemicals. The most com-mon method employs the use of control lines to place the chemicals at the desired injection point in the well. Issues associated with the stable flow of chemicals through the control lines (no U-tubing), testing of control lines and well integrity have plagued the industry for decades.

SolutionPetroleum Technology Company’s ClearFlo chemical injection sub has a unique design, which utilizes the barrier technology from the PTC’s SafeLift valve. The ClearFlo sub facilitates testing of control lines, stable flow of chemicals (no u tubing) and maintains well integrity. PTC’s Life of Field chemical injection design software can simulate the entire chemical injection system and deter-mine the optimum control line size, anti-u tubing setting and control line test pressure.

QualificationsClearFlo's true metal-to-metal seal has been qualified as a well barrier for operators worldwide. It was designed, built and tested in accordance to ISO 14310-V1/V0.

Features • Anti U-tubing system• Barrier qualified back check valve• Shear disc to facilitate testing of control lines

Benefits• Field proven design and operation • Best in class reliability and longevity ensure enhanced

productivity and well integrity

SureFlo

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Barrier Series Chemical Injection Sub

Life of Field Chemical InjectionPTC has developed a unique Chemical Injection well design work-flow, which employs a combination of proprietary and industry recognized software tools. These tools cater for uncertainties and changes in key parameters over the life of the well. PTC’s design tools provide operators with all the information they require, to make the best Chemical Injection design selection decisions.

www.ptc.as

SureFlo

Specifications

Material AISI 410S, 420M, 25%Cr, S13%Cr, Alloy 718

Maximum O.D. 7,5" 8.0" 9,2"

Minimal I.D. 3,867" 4,778" 6,102"

Tubing Thread 4½" or 5½" Box Pin**threads and tubing weight based on customer request

Body Operating Pressure psi [Mpa] 5 000-10 000 [34,5-69] Based on the base material

Operating Temperature oF [oC] 64,4-329 [18-165]

Elastomer on Shear-out Device FKM

Bypass for Control Lines 1 X 11mm X 11mm1 X 11mm X 22mm1 X 11mm X 36mm(other dimensions up to 6 on request)

Control Line Connection 1/4" or 3/8" Jam Nut Conection

Valve Type Dual Check

Valve Primary Seal Metal to Metal

Valve Material Alloy 718

Back Check Valve Maximum Operating Pressure Psi [Mpa] 10 000 [69]

U-tube Valve Crack Open Preassure psi [Mpa] 50- 5 000 [0,34-34,5]

Maximum Injection Rate gal/hr* [liter/hr] 13,2 [50]

Applicable Standards API 19G2-V1, TR2385 - 20cc/15min (0cc/15min)

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Barrier Series Chemical Injection Valve

Continuous, stable chemical injection with enhanced well integrity

The reverse back-check valve is fully qualified as a barrier, providing a positive seal between the tubing and casing annulus

ChallengeWells with scale or corrosion issues often require con-tinuous injection of treatment chemicals. The most com-mon method employs the use of control lines to place the chemicals at the desired injection point in the well. Issues associated with the stable flow of chemicals through the control lines (no U-tubing), testing of control lines and well integrity have plagued the industry for decades.

SolutionPetroleum Technology Company’s ClearFlo chemical injection valve has a unique design, which utilizes the barrier technology from the PTC’s SafeLift Gas Lift valve. The ClearFlo valve facilitates stable flow of chemicals, prevents u-tubing and maintains well integrity. PTC’s Life of Field chemical injection design software can simulate the entire chemical injection system and determine the optimum control line size, and the Chemical Injection Valve setup.

QualificationsClearFlo's true metal-to-metal seal has been qualified as a well barrier for operators worldwide. It was designed and manufactured in accordance to API 19G1 & 2/ ISO 17078-1 & 2.

ClearFlo valves are designed to be installed in all side-pocket mandrels with 1.5" pockets, designed accor-dig to API 19G part1.

Features • Barrier qualified back check valve• Anti U-tubing function• True metal to metal back check seal• Premium metallurgy• In-line filter, and chemical injection line testing

cartridges

Benefits• Field proven design and operation• Best in class reliability and longevity ensures

enhanced productivity and well integrity

SureFlo

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Barrier Series Chemical Injection Valve

Life of Field Chemical InjectionPTC has developed a unique Chemical Injection well design work-flow, which employs a combination of proprietary and industry recognized software tools. These tools cater for uncertainties and changes in key parameters over the life of the well. PTC’s design tools provide operators with all the information they require, to make the best Chemical Injection design selection decisions.

* US

SureFlo

Specifications

Size in. 1.5

Valve Material Alloy 718


Valve Crack Open Pressure psi [Mpa] 50-5 000 psi [0.34-34.5]

Valve Primary Seal Metal to metal

Valve Type Dual Check

Back Check valve Operating Pressure psi [Mpa] 10 000 [69]

U-tube Valve Crack Open Preassure psi [Mpa] 50-5 000 [0.34-34.5]

Operating Temperature °F [°C] 64.4-329 [18-165]

Max Injection Rate gal/hr* [liter/hr] 13,2 [50]

Applicable Standards ISO 17078-2, API 19G2 TR2385 - 20cc/15min [0cc/15min - V0]

*US

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Completion Solutions

Solutions for todays Completion challenges Today as operators move into more challenging enriornments there is increased pressure to re-duce costs while improving well integrity and reliability. PTC, founded with the vision to improve the existing technologies in response to specific client requests has over the years developed many innovative completion solutions which save money and improve well integrity. SaveFlo Autonomous Annulus Bleed off System

Annulus pressure build up during well start up or due to leaks or gas venting is common. Annu-lus pressure, if not managed carefully, can collapse or burst tubular strings, exacerbate integrity issues or damage ESP cable (ED). Effective bleed off rate control using subsea or dry tree valves is almost impossible and requires human intervention. PTC’s SaveFlo bleed off valve provides automatic pressure relief with bleed off rate control. SaveFlo is installed and run as an integral part of the tubing sting. It will be set up to open and close at predetermined annulus to tubing pressure differentials, allowing annulus pressure vent-ing into the tubing. Annular Safety Valve (ASV) Packer

Gas lifted wells typically have a large volume of explosive lift gas contained in the A annulus of the well. Major damage to the wellhead can result in the uncontrolled escape and ignition of the lift gas with catastrophic consequences for both personnel and equipment. Designing a re-trievable ASV packer capable of containing the lift gas over the life of the well has been a major challenge for the industry. PTC’s ASV packer features a solid mandrel design with cut to release functionality, providing a gas tight barrier in an easily retrievable packer.

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JetLift Artificial Lift Technology

The commonly used well pumping methods (ESP, PCP, Rod Pumping) often suffer short run life requiring workover, especially in harsher environments ( High deviation, high temperature, solids production, scale deposition etc). They also tend to gas lock in high GOR wells. PTC’s JetLift Systems are reliable in all wells including harsh environment wells and can handle high gas fractions. Water Injection Valves

Water injection wells with damaged tubing or no requirement for SSSVs must still maintain a barrier against reservoir inflow. Cost effective systems that can be retrofitted to producing wells are almost nonexistent. PTC’s WIVs feature metal to metal seals tested in accordance with ISO 10432 leakage rates for SSSVs. The valves are designed to be cost effective and easy to retrofit when run on wireline locks or bridge plugs.

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Downhole Autonomous Annulus Pressure Management System

Safe and controlled bleed off of the annulus pressure.

SaveFlo was designed to operate in wells where annulus pressure build up needs to be vented in controlled manner. The field proven and barrier accredited design provides a simple and cost effective way to protect tubular strings and ESP cables.

ChallengeAnnulus pressure build up during well start up or due to leaks or gas venting is common. Annulus pressure, if not managed carefully, can collapse or burst tubular strings, exacerbate integrity issues or damage ESP cable (ED). Effective bleed off rate control using subsea or dry tree valves is almost impossible and requires human intervention.

SolutionPetroleum Technology Company’s (PTC) SaveFlo bleed off valve provides automatic pressure relief with bleed off rate control. SaveFlo is installed and run as an integral part of the tubing sting. It will be set up to open and close at predetermined annulus to tubing pressure differen-tials, allowing annulus pressure venting into the tubing. The open/close functionality is achieved using PTC’s high reliability dual bellows syetem. A Well barrier accredited check valve prohibits tubing to annulus flow and the shear module facilitates annulus pressure testing. PTC’s proprietary in-house simulation software models the set up parameters and subsequent testing of every system validates functionality.

Features • Autonomous open and close function• Tubing mounted• Adjustable bleed off rate• Barrier qualified back check valve (tubing to casing)• PTC Dual Bellows operated open and close function

Benefits• Protects casing and tubing from bust and collapse• Protects annular elastomers from explosive

decompression

Bleed Off Valve

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Downhole Autonomous Annulus Pressure Management System

Bleed Off Valve

Specifications

Pressure Rating psi 5 000

Temperature Rating °C 5 to 124

Max OD in. 9.3

Internal Drift Diameter in. 4.767

Sub Material Alloy 718

Spring, Restrictor & Filter Material MP35N

Elastomer Material Gazguard, FKM, PEEK & PTFE w/carbon

Tubing Threads 5.5" - 17# VAM TOP HC (Box X Pin)

By-Pass for Control Lines mm. 1 X 15 X 15 & 1 X 11 X 11

By-Pass for ESP Lines in. 2 X 1.401

Filter Hole Size 200 µm

Valve Opening Pressure Specified by Customer

Sub Shear Pressure Specified by Customer

Filter Shear Pressure Specified by Customer

Bleed off Rate Specified by Customer

Figure 1. Sample of SaveFlo simulation

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Annular Safety Valve Packer

V0 Rated (bubble tight) ASV Packer

Continuous gas injection with enhanced well integrity

The ASV packer provides the V0 rated barrier required to contain the lift gas present in the A annulus of a gas lifted well.

ChallengeGas lifted wells typically have a large volume of explosive lift gas contained in the A annulus of the well. Major dam-age to the wellhead can result in the uncontrolled escape and ignition of the lift gas with catastrophic consequences for both personnel and equipment. Designing a retrievable ASV packer capable of containing the lift gas over the life of the well has been a major challenge for the industry.

SolutionPetroleum Technology Company’s ASV packer features a solid mandrel design with cut to release functionality, providing a gas tight barrier in an easily retrievable packer.

QualificationsPTC’s ASV Packer has been qualified and tested in accor-dance with ISO14310 and Norsok D-010.

Features • Field proven design and operation • Simple operation to retrieve the packer• Provides a gas tight barrier• No mandrel movement when setting packer

Benefits• Cut to release design• Control line set• ISO 14310 V0 qualified

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Annular Safety Valve Packer

V0 Rated (bubble tight) ASV PackerSpecifications 10 ¾" ASV

Material 13CrL80

Casing Size 10 ¾" 55,5#, 60.7#

Max OD in. 9.56, 9.46

Min ID in. 4.669

Length in. 78.7


Minimum Setting Pressure psi 5 000


Elastomers Viton O-Rings, HNBR Packer Element

Primary Threads 5 ½" 23# Tenaris Box X Pin

Secondary Threads 2" - 8 TPI Stub Acme

Secondary Bore ID in. 1.38

Control Line Bypass 3 X ¼" NPT Box

Release Mechanism Cut to release (Sondex Cutter)

Qualification Standard ISO 14310 V0, Norsok D-010

Specifications 13 ⅝" ASV

Material 13CrL80

Casing Size 13 ⅝" 88.2#

Max OD in. 12.205

Min ID in. 4.892

Length in. 75.6


Minimum Setting Pressure psi 5 000


Elastomers Viton O-Rings, HNBR Packer Element

Primary Threads 5 ½" 17# Tenaris Box X Pin

Secondary Threads 2 ⅜" - 6.3# Vam Ace

Secondary Bore ID in. 1.38

Control Line Bypass 4 X ¼" NPT Box

Release Mechanism Cut to release (Sondex Cutter)

Qualification Standard ISO 14310 V0, Norsok D-010

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Water Injection Valve

Continuous water injection with enhanced well integrity

Flow control valve tested in accordance with Sub Surface Safety Valve (SSSV) standards.

PTC’s water injection valves facilitate stable water injection operations while providing a barrier against reservoir inflow.

ChallengeWater injection wells with damaged tubing or no require-ment for SSSVs must still maintain a barrier against res-ervoir inflow. Cost effective systems that can be retrofitted to producing wells are almost nonexistent.

SolutionPetroleum Technology Company’s WIVs feature metal to metal seals tested in accordance with ISO 10432 leakage rates for SSSVs. The valves are designed to be cost ef-fective and easy to retrofit when run on wireline locks or bridge plugs.

QualificationsPTC’s WIVs feature metal to metal seals tested in accor-dance with ISO 10432 leakage rates for SSSVs.

Features • Metal to metal seal• Can be installed on wireline locks or bridge plugs • Leak tested in accordance with ISO 10432

Benefits• Field proven design and operation • Can be installed in producing wells via a wireline in-

tervention• Provides a barrier against the reservoir

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Specifications

Size in. 2.750 3.313 3.437 3.688

Lock Type 2.750" RN 3.313" RN 3.437" RN 3.688" RN

Material K-500 Monel/S 165M K-500 Monel/S 165M K-500 Monel/S 165M K-500 Monel/S 165M

Max OD in. 2.65 3.31 3.43 3.68

Flow Area in² 1.90 3.55 2.86 4.31

Pressure Rating psi 5 000 5 000 5 000 5 000

Temperature Rating °C 25-125 25-125 25-125 25-125

Upper Thread 2.109" - 11.5" National Threads

2 ¼" - 12 TPI StubAcme Box

2 ¾" - 12 SLB Box

3 1/16" - 12 TPI StubAcme Box

Specifications

Size in. 4.313 4.437 4.610 5.720

Lock Type 4.313" RN 4.437" RN 4.610" RN 5.720" RN

Material K-500 Monel/S 165M K-500 Monel/S 165M K-500 Monel/S 165M K-500 Monel/S 165M

Max OD in. 4.31 4.43 4.61 5.72

Flow Area in² 4.50 4.50 6.31 8.14

Pressure Rating psi 5 000 5 000 5 000 5 000

Temperature Rating °C 25-125 25-125 25-125 25-125

Upper Thread 3 1/16" - 12 TPI StubAcme Box

3 ⅝" - 12 SLB Box

2.109" - 11.5" National Threads

3 15/16" - 12 OTIS SBL-RPT Box

Water Injection Valve

Continuous water injection with enhanced well integrity

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Wireline Retrievable Jet Pumpswith Integral Flow Control Valve

Retrofit artificial lift system with Enhanced Well Integrity

Jet Pumps are widely recognised as one of the most flexible and reliable well pumping methods. An integral flow control valve, now addresses a previously recognised drawback.

ChallengesThe commonly used well pumping methods (ESP, PCP, Rod Pumping) often suffer short run life requiring work-over, especially in harsher environments ( High deviation, high temperature, solids production, scale deposition etc). They also tend to gas lock in high GOR wells.

Tubing to annulus communication can occur when the power fluid is not being pumped. This breaches the well management policy of many OPCO’s.

User friendly jet pumped well simulation software is also not readily available to OPCO engineers.

SolutionPTC’s Jet Pump Systems are reliable in all wells including harsh environment wells and can handle high gas fractions.

The system incorporates an integral power fluid operated flow control valve, located immediately below the pump. It closes when the power fluid pressure is bled off. Consequently the possibility of tubing to annulus flow when the well is not being jet pumped is eliminated.

User friendly well performance simulation software is freely accessible via our website.

Features • Jet Pump contains no moving parts• Installed / retrieved using wireline • Power fluid delivered to pump via the annulus • Treating chemicals can be added to the power fluid • Production delivered via the tubing • Integral power fluid controlled flow control valve • User friendly design software

Benefits• Reliable lift method • Ideally suited for harsh environments• No gas locking at high gas fractions• Low cost well interventions to install system• Ideal for temporary lift applications

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www.ptc.as

General Inquiries [email protected] +47 51 95 08 00

Norway [email protected] +47 51 95 08 08

UEA [email protected] +971 258 311 66

UK [email protected] +44 (0) 1224 57 93 50

USA [email protected] +1 832 604 7664

Brazil [email protected] +55 21 4105 0932

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PRODUCT CATALOGUE · • NORSOK D-010 compliant Benefits • Enhances well integrity • Can be...

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