Table of Contents Petroleum Technology Company...4 Wellhead Solutions...5 Gas Lift Solutions...16 Chemical Injection Solutions...

Transcription

1 1 PRODUCT CATALOGUE

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3 Table of Contents Petroleum Technology Company...4 Wellhead Solutions...5 MSAS Master Surface Annulus Safety Valve...6 VR Sensor - Wired & Wireless...8 A-Pro Annulus Pressure Management System...10 MSAS-E Surface Safety Valve for Control and Chemical injection Lines...12 VR Lubricator Tool...14 Gas Lift Solutions...16 SafeLift & IsoLift Orifice Gas Lift Valves...18 SafeLift & IsoLift Injection Pressure Operated Gas Lift Valves...20 ShearLift-T Tubing pressure activated Gas Lift Valve...22 ShearLift-A Annulus pressure activated Gas Lift Valve...24 DuraLift Scale Resistant Gas Lift Valve...26 GoLift Retrievable Gas Lift Straddle...28 Life of Field Gas Lift Design Tool...29 NexLift Unwelded Gas Lift Mandrel...30 Chemical Injection Solutions...32 SureFlo Chemical Injection Sub...34 SureFlo Chemical Injection Valve...36 Completion Solutions...38 SaveFlo Bleed Off Valve...40 Annulus Safety Valve Packer...42 Water Injection Valve...44 JetLift Retrievable Jet Pump...46 Contacts...47

4 Innovation Petroleum Technology Company (PTC) was founded in 2002 by a group of experienced 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 offices in Norway (Head Office), UK, UAE, US and Brazil. PTC is committed to providing 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 management Unrivalled solutions for Gas Lift design and equipment, including harsh environment applications Reliable Chemical Injection design and equipment Annulus bleed off subs and valves 4

5 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 operations. 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 instrument 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 intervention modes. The system can be self-sustained or connected to an external power source. 5

6 MSAS Master Surface Annulus Safety Valve 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. Challenge Gas 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. Solution Petroleum Technology Company s MSAS, provides an additional independent barrier in the wellhead VR profile. The MSAS is hydraulically operated and connected to ESD. Should an impact or collision take place, the API 6FD/FB fire tested check 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) 6 PTC s Dual Barrier MSAS and VR Sensors installed in a wellhead. Wellhead gate valve knocked off, no MSAS installed. Entire Annulus volume can be vented to atmosphere.

7 MSAS Master Surface Annulus Safety Valve 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] [69] Temperature Class, L-U F [ C] -51 to 250 [-46 to 121] Flow Area Range, in² [cm²] [0.97 to 6.45] Min. Hydr. Pressure, psi [Mpa] 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 inside 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 installations are provided by simply replacing the excising gate valve with PTC's gate valve and MSAS-G system. Assures well integrity even upon impact or collision. 7

8 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. Challenge Wells 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. Solution Petroleum 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. 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 The VR sensor removes potential issues related to viscous valve lubricant and can substantially lower installation and maintenance costs. Wireless VR Sensor 8

9 Double Barrier Wellhead P&T Sensor 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 PSL3G PR2 VR Sensor ExitBlock is designed to monitor the cavity above the tubing hanger. PTC VR Sensor System vs conventional monitoring rig up. 9

10 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 technologies provide a system for autonomous and controlled annulus pressure monitoring and bleed off. Challenge Sustained annulus pressure (SAP) pose a considerable risk to personell, well infrastructure and facilities, especially for remote and unmanned locations. Monitoring and bleed off operations typically require human intervention. Solution The integration of PTC s VR Sensor, Master Surface Annulus 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 closes the MSAS system (Alarm signals for process monitoring can be implemented). 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) As the system is modular several options can be included with varying levels of redundancy and ATEX classifications. 10 Features

11 A-Pro 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 MSAS-G and VR Sensor ccontrolled by HCPU 11

12 MSAS-E 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 Challenge Wells 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, posing considerable risk to personnel and facilities. Most of the current exit block valves are manually operated and not part of the ESD system. Solution Petroleum 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. 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 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 12

13 MSAS-E Surface Safety Valve for Control and Chemical Injection Lines 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] [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 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 IP Rating IECEx/ ATEX Marking Actuation -60 C to +125 C IP68 + IP66 ATEX Ex ia IIC T4/ T6 Ga Magnetically Actuated Suitable for use in the design of safety functions up to SIL2 or SIL3. 13

14 Lightweight and versatile VR profile intervention tool 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. Challenge Intervention 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. Solution Petroleum 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. 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 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. 14

15 Specifications Torque Capacity Range lbf/ft [Nm] [1 500] to [3 750] Interface Range in. Max Working Pressure psi [Mpa] Standard API6A 2-1/6 to 4-1/16 *other sizes can be accommodated [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 15

16 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 development 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 failure 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 chattering, and erosive wear of the metal to metal sealing surfaces Unique low load rate / long stem travel dual operating bellows type Injection Pressure Operated (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 psi and have been tested to 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. 16

17 GoLift retrofit Gas Lift Straddles PTC s GoLift through tubing gas lift straddle system offers a cost effective alternative to workovers where there is a need to retrofit new or upgrade existing gas lift systems, without compromising 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 conditions and data uncertainties. It therefore provides a more robust design to ensure maximum production, and reliability over the life of the well. 17

18 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. Challenge Change 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. Solution Petroleum 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. Qualification SafeLift 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 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 " 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 18

19 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 Size Range, 1.5" valve in. 1/8-1/2 Orifice Size Range, 1.75" valve in. 1/8-11/16 Orifice Type Body Material Seal Stack Material Square-Edge/Stealth/Venturi Alloy 718 (other material on request) FKM/PTFE/PEEK Max Operating Pressure for 1.0" psi [Mpa] [51] Max Operating Pressure for 1.5" & 1.75" psi [Mpa] [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 TR cc/15min [0cc/15min - V0] Applicable Standards, IsoLift Series API 19G2 - V1 PTC Leak Criteria - 3,5 scf/d (10% of API) 19

20 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. Challenge Unloading 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. Solution PTC has developed a revolutionary dual operating bellows system that once installed in a gas lift valve can be charged to more than 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. Qualification IPO valve section has been tested to more than 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 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 20

21 Injection Pressure Operated (IPO) valve Specifications Size in. 1.0 & 1.5 Orifice Size Range, 1.0" valve in. 1/8-5/16 Orifice Size Range, 1.5" valve in. 1/8-1/2 Orifice Type Body Material Seal Stack Material Square-Edge Alloy 718 (other material on request) FKM/PTFE/PEEK Max Operating Pressure for 1.0" psi [Mpa] [51] Max Operating Pressure for 1.5" psi [Mpa] [69] Max Dome Pressure for 1.0" [51] Max Dome Pressure for 1.5" [69] Max Operating Temperature for 1.0" F [ C] 365 [185] Max Operating Temperature for 1.5" F [ C] 329 [165] Min Operating Temperature F [ C] 64.4 [18] Applicable Standards, SafeLift Series Applicable Standards, IsoLift Series API 19G2 - V1 TR cc/15min [0cc/15min - V0] API 19G2 - V1 PTC Leak Criteria - 3,5 scf/d (10% of API) 21

22 Tubing pressure activated gas 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. Challenge When 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. Solution Petroleum 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 predetermined 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 22

23 Tubing pressure activated shear open Orifice and IPO Gas Lift Valve Specifications Size in. 1.5 Orifice Size Range, 1.5" valve in. 1/8-1/2 Orifice Type Body Material Seal Stack Material Square-Edge Stealth/Venturi (Orifice valves only) Alloy 718 (other material on request) FKM/PTFE/PEEK Max Operating Pressure for 1.5" psi [Mpa] [69] Max Dome Pressure for 1.5" psi [Mpa] [69] Max Operating Temperature for 1.5" F [ C] 329 [165] Max Shear Pressure (absolute tubing pressure) psi [Mpa] Up to [62] Min Operating Temperature F [ C] 64.4 [18] Applicable Standards, SafeLift Series API 19G2 - V1 TR cc/15min [0cc/15min - V0] Qualifications ShearLift 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 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. 23

24 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. Challenge When 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. Solution Petroleum 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). 24

25 Annulus pressure activated shear open orifice gas lift valve Specifications Size in. 1.0, 1.5, 1.75 Orifice Size Range, 1.0 valve in. 1/8-5/16 Orifice Size Range, 1.5" valve in. 1/8-1/2 Orifice Size Range, 1.75" valve in. 1/8-11/16 Orifice Type Body Material Seal Stack Material Square-Edge/Stealth/Venturi Alloy 718 (other material on request) FKM/PTFE/PEEK Max Operating Pressure for 1.0" psi [Mpa] [51] Max Operating Pressure for 1.5 & 1.75 psi [Mpa] [69] Max Operating Temperature for 1.5" F [ C] 329 [165] Max Shear Pressure (absolute tubing pressure) psi [Mpa] Up to [62] Min Operating Temperature F [ C] 64.4 [18] Applicable Standards, SafeLift Series API 19G2 - V1 TR cc/15min [0cc/15min - V0] Qualifications ShearLift 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 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. 25

26 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. Challenge Failure 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 production will have a negative impact on field economics. Solution Petroleum 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. Qualifications The 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 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 26

27 Scale resistant barrier qualified gas lift valve Specifications Size in. 1.5 Orifice Size Range, 1.5" valve in. 1/8-3/8 Orifice Type Square-Edge Body Material Alloy 718 (other materials on request) Seal Stack Material FKM/PTFE/PEEK Max Operating Pressure psi [Mpa] [69] Max Operating Temperature F [ C] 329 [165] Min Operating Temperature F [ C] 64.4 [18] Applicable Standards, SafeLift Series API 19G2 - V1 TR cc/15min [0cc/15min] 27

28 Quick production enhancement without 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. Challenge Dwindling production and/or sub-optimal completion design 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. Solution Petroleum 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. 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 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 toolbox in the market today. A variety of applications such as, single station or complete 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. 28

29 Life of Field Gas Lift Design Tool Unique processes and proprietary software tools, providing optimized design decisions and equipment specifications Challenge 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. 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. Solution A 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. Benefits Well reliability is enhanced and life-cycle productivity is optimized, 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 possible 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. NS Well A1 - Unloading Schedule MD_interface,QL MD_interface(m) QL_valve(m3/d) QL_valve_max(m3/d) P_ann_surface(bara) Pann_surface,DP Time(sec) Life of Field (LOF) Gas-Lift Design Engineering working with gas lift design 29

30 Next Generation unwelded gas lift mandrel Unwelded, machined from a single piece of steel providing unrivalled structural integrity. Challenge Conventional 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 stringent and elaborate QA/QC processes. Despite all efforts, satisfactory repeatability of the manufacturing process is difficult to achive. Solution Today, 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. 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) 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 capabilities are required. The API 19G1 qualification assures full compatibility with the gas lift equipment designed and manufactured to API standards. Unwelded, machined from a single piece of steel. 30

31 Next Generation unwelded gas lift mandrel Specifications Size in. 5 1/2 Pocket Size, in 1 1/2 Mandrel Body Round Major OD, in Min. ID, in Bypass Dimensions 2 off 1.732" x 0.512" [13mm x 44mm] Latch profile RM Qualification Criteria API 19G1, Q1, V1, F1* * Except external pressure test NexLift Ratings* Material 80 Ksi 95 Ksi 110 Ksi Burst, psi Collapse, psi Tension, klb Compression, klb * Based on yield strength at ambient temperature. Excluding end connections. Unwelded, machined from a single piece of steel. 31

32 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. 32

33 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. 33

34 SureFlo Barrier Series Chemical Injection Sub 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 Challenge 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. Solution Petroleum 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 determine the optimum control line size, anti-u tubing setting and control line test pressure. 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 Qualifications ClearFlo'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 V1/V0. 34

35 SureFlo Barrier Series Chemical Injection Sub 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] [34,5-69] Based on the base material Operating Temperature o F [ o C] 64,4-329 [18-165] Elastomer on Shear-out Device Bypass for Control Lines Control Line Connection Valve Type Valve Primary Seal FKM 1 X 11mm X 11mm 1 X 11mm X 22mm 1 X 11mm X 36mm (other dimensions up to 6 on request) 1/4" or 3/8" Jam Nut Conection Dual Check Metal to Metal Valve Material Alloy 718 Back Check Valve Maximum Operating Pressure Psi [Mpa] [69] U-tube Valve Crack Open Preassure psi [Mpa] [0,34-34,5] Maximum Injection Rate gal/hr* [liter/hr] 13,2 [50] Applicable Standards API 19G2-V1, TR cc/15min (0cc/15min) Life of Field Chemical Injection PTC 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. 35

36 SureFlo 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 Challenge Wells with scale or corrosion issues often require 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. Solution Petroleum 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. 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 Qualifications ClearFlo'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 & 2. ClearFlo valves are designed to be installed in all side-pocket mandrels with 1.5" pockets, designed accordig to API 19G part1. 36

37 SureFlo Barrier Series Chemical Injection Valve Specifications Size in. 1.5 Valve Material Alloy 718 Seal Stack Material * US Applicable Standards FKM/PTFE/PEEK Valve Crack Open Pressure psi [Mpa] psi [ ] Valve Primary Seal Valve Type Metal to metal Dual Check Back Check valve Operating Pressure psi [Mpa] [69] U-tube Valve Crack Open Preassure psi [Mpa] [ ] Operating Temperature F [ C] [18-165] Max Injection Rate gal/hr* [liter/hr] 13,2 [50] ISO , API 19G2 TR cc/15min [0cc/15min - V0] *US Life of Field Chemical Injection PTC 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. 37

38 38 Completion Solutions Solutions for todays Completion challenges Today as operators move into more challenging enriornments there is increased pressure to reduce 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. 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. 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 venting 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 retrievable 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.

39 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 leakage rates for SSSVs. The valves are designed to be cost effective and easy to retrofit when run on wireline locks or bridge plugs. 39

40 Bleed Off Valve 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. Challenge Annulus 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. Solution Petroleum 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 differentials, 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. 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 PTC s proprietary in-house simulation software models the set up parameters and subsequent testing of every system validates functionality. 40

41 Bleed Off Valve Downhole Autonomous Annulus Pressure Management System Specifications Pressure Rating psi Temperature Rating C 5 to 124 Max OD in. 9.3 Internal Drift Diameter in 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 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 41

42 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. Challenge 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 retrievable ASV packer capable of containing the lift gas over the life of the well has been a major challenge for the industry. Solution Petroleum 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. 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 V0 qualified Qualifications PTC s ASV Packer has been qualified and tested in accordance with ISO14310 and Norsok D

43 Annular Safety Valve Packer V0 Rated (bubble tight) ASV Packer Specifications 10 ¾" ASV Material 13CrL80 Casing Size 10 ¾" 55,5#, 60.7# Max OD in. 9.56, 9.46 Min ID in Length in Pressure Rating psi Minimum Setting Pressure psi Temperature Rating C 4 to 110 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 Control Line Bypass 3 X ¼" NPT Box Release Mechanism Cut to release (Sondex Cutter) Qualification Standard ISO V0, Norsok D-010 Specifications 13 ⅝" ASV Material 13CrL80 Casing Size 13 ⅝" 88.2# Max OD in Min ID in Length in Pressure Rating psi Minimum Setting Pressure psi Temperature Rating C 4 to 110 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 Control Line Bypass 4 X ¼" NPT Box Release Mechanism Cut to release (Sondex Cutter) Qualification Standard ISO V0, Norsok D

44 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. Challenge 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. Features Metal to metal seal Can be installed on wireline locks or bridge plugs Leak tested in accordance with ISO Solution Petroleum Technology Company s WIVs feature metal to metal seals tested in accordance with ISO leakage rates for SSSVs. The valves are designed to be cost effective and easy to retrofit when run on wireline locks or bridge plugs. Benefits Field proven design and operation Can be installed in producing wells via a wireline intervention Provides a barrier against the reservoir Qualifications PTC s WIVs feature metal to metal seals tested in accordance with ISO leakage rates for SSSVs. 44

45 Water Injection Valve Continuous water injection with enhanced well integrity Specifications Size in 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 Flow Area in² Pressure Rating psi Temperature Rating C Upper Thread 2.109" " National Threads 2 ¼" - 12 TPI Stub Acme Box 2 ¾" - 12 SLB Box 3 1/16" - 12 TPI Stub Acme Box Specifications Size in 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 Flow Area in² Pressure Rating psi Temperature Rating C Upper Thread 3 1/16" - 12 TPI Stub Acme Box 3 ⅝" - 12 SLB Box 2.109" " National Threads 3 15/16" - 12 OTIS SBL- RPT Box 45

46 Wireline Retrievable Jet Pumps with 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. Challenges 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. 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. Solution PTC s Jet Pump Systems are reliable in all wells including harsh environment wells and can handle high gas fractions. 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 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. 46

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