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PPS Permanent Seal Bore Packers

Top select PPS Wireline-Set Permanent Packer is designed to set in the well casing to divert casing-to-tubing flow. It is either hydraulically set with the hydraulic setting tool with tubing string pressure or the E-line setting tool. The PPS packer is mechanically moved and locked in the set position by the internal slip. An external set of opposing slips holds the packer against downward and upward forces. The removal of packer is by drill or milled out. The packer is designed with a left hand seal bore compatible with Sur Latch seal assemblies and the bottom sub thread is compatible with a mill-out extension or with a seal bore extension. The Packer is designed to be milled if removal from the wellbore required. Firstly remove the Sur-latch seal nipple from packer by tubing string, right-hand rotation with tension on the tubing to disengage the Sur-Latch from the packer head.

Features and Benefit
 
  •   Field proved reliable
  •   Simple to operation
  •   Economical
  •   Designed for most severe completion environments
  •   For high pressure and high temperature completions
  •   Provides an upper connector for attachment to seal unit locators
  •   Full seal bore ID through the packer
  •   Designed for high tensile loads
  •   Wireline and Hydraulic setting tools set
  •   Protected from pre-setting when run in hole
  •   Tubing rotation available when run in hole
  •   Milled if removal
  •  Standard 10ksi rate
Applications
 
  •   Sand control
  •   Horizontal completion assemblies
  •   Hanger packer in frac and stimulation jobs
  •   Production and injection sealbore packer
Technical Data
Casing Size Casing Weight Packer OD Packer ID
in. mm lb/ft kg/m in. mm in. mm

5 1/2

139.70
13-20 19.34-29.76 4.55 115.57 2.75 69.85
23-26 34.22-38.69 4.36 110.74 2.75 69.85

7

177.80
23-32 34.22-47.62 5.87 149.19 3.88 98.55
32-38 47.62-56.55 5.69 144.45 3.88 98.55

7 5/8

193.7
26.4-39 39.29-58.04 6.37 161.92 3.88 98.55
45.3-47.1 67.41-70.09 6.18 156.97 3.88 98.55
9 5/8 244.48 36-53.5 53.57-79.62 8.25 209.58 5.00 127.00

PRS Retrievable Seal Bore Packers

Top select PRS Packer is a retrievable, single-bore packer that has the completion features of a large-bore permanent packer. The packer delivers high performance with simplicity of design and desirable economics. It is a 10,000 PSI plus rated packer and can be equipped to withstand severe corrosion and high temperatures. The packers are designed to be used in Frac or gravel pack service, or suspend tools, or provide a pressure isolation point in the casing, which can be set by using hydraulic setting tool, and be pulled by running and latching the retrieving tool then applying a straight upward pull if needed.

Features and Benefit
 
  •  Field proved reliable
  •  Simple to operation
  •  Economical
  •  Designed for most severe completion environments
  •  For high pressure and high temperature completions
  •  Provides an upper connector for attachment to seal unit locators
  •  Full seal bore ID through the packer
  •  Designed for high tensile loads
  •  Wireline and Hydraulic setting tools set
  •  Protected from pre-setting when run in hole
  •  Tubing rotation available when run in hole
  •  Retrievable
  •  Able to be milled if retrieval attempts fail
  •  Standard 10ksi rate
Applications
 
  •  Sand control
  •  Horizontal completion assemblies
  •  Hanger packer in frac and stimulation jobs
  •  Production and Injection sealbore packer
  •  Retrieve required
Technical Data
Casing Size Casing Weight Packer OD Packer ID
in. mm lb/ft kg/m in. mm in. mm

5 1/2

139.70
17-20 25.30-29.76 4.61 117.09 2.75 69.85
23-26 34.22-38.69 4.36 110.74 2.75 69.85


7


177.80
26-29 38.09-43.16 6.02 152.78 3.88 98.55
32-35 47.62-52.09 5.82 147.83 3.88 98.55
38-42.7 56.55-63.54 5.57 141.35 3.25 82.55

7 5/8

193.7
29.7-33.7 44.20-50.15 6.55 166.37 3.88 98.55
45.3-47.1 67.41-70.09 6.15 155.96 3.88 98.55
9 5/8 244.48 47-53.5 69.94-79.62 8.29 210.57 5.00 127.00

STH-1 Hydraulic Setting Tool

Top select STH-1 hydraulic setting tool is used to set PRS or PPS packer. The STH-1 tool is attached to the top sub of the packer by pins or by the left hand thread by rotational. The set of lugs latches into the setting sleeve of the packer. When without a lower plugging device in the tailpipe the large internal by-pass allows fluid to enter the work string eliminating the need to fill the work string while running in the hole. If there is tailpipe assembly such as the Multi-Stage Frac system with some type of float shoe or other type of plugging device is in place then it may be necessary to fill while running in the hole. Once the packer has reached the desired depth, the tripping ball is dropped to land in ball seat circulation valve. Field adjustable differential pressure is applied activating a hydraulic chamber stroking the setting Tool against the packer which engages the slips and energizes the elements. There is a secondary ball seat within the setting tool if required. Once the packer is set, annual pressure test can be performed. The STH-1 setting tool is released with a combination of right hand rotation while holding tension, or continue pressure the running string to hydraulic to release

Features and Benefit
 
  •  Left hand thread connection allows heavy tail pipe weight
  •  Right hand rotate release and hydraulic release are available
  •  Anti-preset design
  •  Two stage ball seat permits reset the packer
Casing Size Packer Bore Max  O.D. Min  I.D. STD Connection
in mm in mm in mm in mm in mm
7 177.8 3.88 98.55 5.70 144.78 2.25 57.15 3 1/2 IF 88.9
7 177.8 4.00 101.6 5.70 144.78 3.00 76.20 3 1/2 IF 88.9
9 5/8 244.5 6.00 152.40 8.02 203.71 2.25 57.15 4 1/2 IF 114.3

PRS Packer Retrieving Tool

The Top select retrieving tools are is a latch type retrieving tool used to retrieve PRS packers. To retrieve the packer, the retrieving tool is run on a work string, stung into the packer bore, and latched into the packer. Once latched, downward set down engage the packer’s release sleeve and upward moves to release. Additional upward movement of the work string sheared releases the sleeve and moves the packer mandrel upward, which permits the packer slips to retract and pick up the packer to be retrieved. For emergency release, continue straight pull will shear the shear screws in the spring housing and allow shear ring to move by spring to push the spring housing downward and collapse the dogs inward, this allow the retrieving tool free to rotate out and pull back from the hole.

Features and Benefit
 
  •   No rotation is required for pulling operation
  •   Straight-through ID allows washing down to the packer
  •   Easy to release: 1/4 turn on lug-type tools, and six to eight turns on an acme tool
  •   Rugged lug-type design engages the release sleeve

Locator Seal Assembly

The Locator Seal Assembly is used when it is not desirable to anchor the seals into the packer. The Locator Seal Assembly allows movement of the seals in response to pressure and temperature changes on the tubing string. Force changes tending to elongate the tubing string are transferred through the locator into the packer and casing. Seals are dynamic and must be designed to accommodate sliding or reciprocation, in addition to temperature and wellbore fluids. The Locator Seal Assembly is retrieved by straight pick-up.

Anchor Seal Assembly

Anchor Seal Assemblies lock, or anchor, into the packer top and seal in the bore of the packer or seal bore extension below the packer. The anchor seal assembly transfers tubing forces through the anchor into the packer; the seals are static and are only subjected to pressure differentials. The anchor seal assembly consists of the seal mandrel, seal units as required, a re-entry guide bottom and a latch mechanism and locator. In some cases, a spacer tube is used to properly position the seals within the seal bore. The anchor seal assembly is released by right-hand rotation.

Sur-Latch Shear Release Seal Unit Assembly

The Sur-Latch Shear Release Seal Unit Assembly is used with Star Petrotech Seal Bore Packers. The seal unit provides a tubing-to-packer seal, a positive locking condition, for tubing left hand rotational release or straight pull shear release. The seal unit assembly is made up to the lower most part of the tubing string at the surface if a wireline-set packer is used. If a hydraulic packer is used, the seal unit assembly may be installed into the packer at the surface and RIH. The seal unit packing contacts the mating hone bore in the packer to form a seal. The floating latch moves up enough to allow its collet-type ends to flex inward. This allows the mating left-hand threads engaged in the packer. To release, a straight pull above the predetermined force will shear the shear pins, allow the latch to move downward and collapsed inward, disengaged from the packer head. Alternatively, by right hand rotational method with a tensile force 1,000 to 1,500 lb force.

PPH Hydraulic Set Permanent Packer

Top select PPH Packer is designed for use in applications where one trip to completion and frac is required. The packer is a hydraulic set single trip permanent millable packer with smaller OD feature is used for restrict ID casing or smaller size frac string. The packer can with Top Tubing Thread or Latch Thread. Bottom sub threaded for mill-out extension or the customer's liner. The packer design around a proven base of sealing integrity, slip anchoring system and utilizes an integral one-piece mandrel with only three pressure sealing threads within the assembly. The packer is designed with premium seal for severe down hole environments such as sour and HPHT. The Packer is designed to be milled if removal from the wellbore required. Firstly remove the Sur-latch seal nipple from packer by tubing string, right-hand rotation with tension on the tubing to disengage the Sur-Latch from the packer head.

Features and Benefit
 
  •  Field proved reliable
  •  Simple to operation
  •  Designed for most severe completion environments
  •  For high pressure and high temperature completions
  •  Large ID
  •  Designed for high tensile loads
  •  Metal to metal premium thread connection, or seal anchor assembly
  •  Single piece mandrel and seal bore
  •  Minimized potential leak paths
  •  Up to 15ksi rate
Applications
 
  •  Single trip production and injection wells
  •  High deviated and horizontal completion wells
  •  High pressure and high temperature wells
  •  Extreme completion environments such as sour gas
  •  Frac and stimulation
  •  Act as a tubing hanger
Casing Size Casing Weight Packer OD Packer ID Sealbore ID
in. mm lb/ft kg/m in. mm in. mm in. mm

5 1/2

139.70
14-20 20.83-29.76 4.54 115.32 2.36 59.94 3.50 88.90
23-26 34.22-38.69 4.36 110.74 2.36 59.94 3.50 88.90


7


177.80
20-32 29.76-47.62 5.88 149.25 3.88 98.55 5.00 127.00
32-38 47.62-52.09 5.55 140.97 3.02 76.71 4.25 107.95
32-44 47.62-65.48 5.47 138.89 3.02 76.71 4.25 107.95

7 5/8

193.68
26.4-39 39.29-59.04 6.38 161.95 3.88 98.55 5.00 127.00
33.7-45.3 50.15-67.41 6.17 156.72 3.88 98.55 5.00 127.00
9 5/8 244.48 36-59.4 53.57-88.40 8.13 206.40 4.85 123.19 6.50 165.10

PRH1 Hydraulic-Set Retrievable Packer

PRH1 Hydraulic-Set Retrievable Packer is a single-string, hydraulic-set retrievable packer designed for Single or multi-packer production completions. The packer is made up to the tubing string and run into the well. At the desired setting depth, pressure is applied down the tub¬ing string against a plugging device below the packer. When the full setting pressure is applied, the packer slips and elements should be fully engaged and held in the set position by internal spring loaded slips. The Packer design allows for no mandrel movement during the setting sequence. The Packers can be run either in single packer or multiple packer completions. When used in multiple packer completions, the setting pressure can be adjusted to allow the packers to be set and tested individually. To release the Packer, straight pull on the tubing is all that is required. Straight pull on the tubing shears a set of release pins which allows the packer mandrel to move upward moving the supports from beneath the slips. Further upward movement relaxes the elements and enables the packer to be retrieved.

Features and Benefit
 
  •  Field proved reliable
  •  High performance at low cost
  •  Small OD
  •  Hydraulically-set for safe, dependable operation in multiple packer applications
  •  Triple-seal multidurometer elements
  •  Shear screws allow operator to vary the setting pressure and release force
  •  No mandrel movement when setting
  •  Requires only a straight pull to release
  •  Multiple packers can be run and set in one trip
  •  Standard 7.5ksi rate
Applications
 
  •  Single or multi-packer production completions
  •  Production and injection wells.
  •  The lower packer in dual completions
  •  Act as a bridge plug with an on off tool.
  •  Multi-zone completions
Technical Data
Casing Size Casing Weight Max OD Min ID
in mm lb/ft Kg/m in mm in mm

 

5 1/2

 

139.70

13-17 19.35-25.30 4.690 119.13 2.36 58.41
17-23 25.30-34.22 4.52 114.68 2.36 58.41

 

7

 

177.80

23-29 34.22-43.16 5.99 152.15 2.89 73.41
29-35 43.16-52.09 5.83 148.08 2.89 73.41
7 5/8 193.68 29.7-39 44.20-58.04 6.46 164.08 2.89 73.41

 

9 5/8

 

244.48

40-47 59.53-69.94 8.45 212.85 3.89 98.81
47-53.5 69.94-79.62 8.23 209.12 3.89 98.81

PRH2 Hydraulic-Set Retrievable Packer

The PRH2 Hydraulic-Set Retrievable packer is a retrievable single-string packer which is designed to be set by plugging the tubing below the packer and applying internal pressure. The packer is retrieved by simply raising the tubing string to shear the release shear pins. The packer does not require mandrel movement to establish a full set which makes it suitable for multi-packer installations. The packer is capable of hanging heavy tailpipe loads in the casing and is available with selective-set mechanisms. The packer is suitable for production and injection installations. In addition, service applications such as stimulation and tubing-conveyed perforating operations may also be carried out using this packer taking special precautions to prevent premature shear of the release pins.

Features and Benefit
 
  •  Field proved reliable
  •  Designed for deep or deviated wells
  •  Production and Injection application
  •  Designed for high tensile loads
  •  Internal locking mechanism
  •  Protected from pre-setting when RIH
  •  hydraulic-actuated hold down slips above and
  •  Standard slips below the elements to bite into the casing
  •  Lower setting pressure
  •  Prevents both upward and downward movement
  •  Straight pull to release
  •  Field adjustable the setting pressure and shear release
  •  Standard 7.5ksi rate
Applications
 
  •  Single or multi-packer production completions
  •  Production and injection wells
  •  Frac and stimulation jobs
Technical Data
Casing Size Casing Weight Max OD Min ID
in mm lb/ft Kg/m in mm in mm

 

5 1/2

 

139.70

13-17 19.35-25.30 4.62 117.35 1.93 49.02
17-23 25.30-34.22 4.51 114.55 1.93 49.02

 

 

7

 

 

177.80

17-23 25.30-34.22 6.19 157.23 2.90 73.66
23-29 34.22-43.16 6.01 152.65 2.90 73.66
29-35 43.16-52.09 5.83 148.08 2.90 73.66

 

7 5/8

 

193.68

24-29.7 35.72-44.20 6.63 168.40 2.90 73.66
33.7-39 50.15-59.04 6.39 162.31 2.90 73.66

 

 

9 5/8

 

 

244.48

36-40 53.57-59.53 8.63 219.20 2.90 73.66
40-47 59.53-69.94 8.37 212.85 4.80 121.92
47-53.5 69.94-79.62 8.32 211.33 4.80 121.92

PRM Mechanical -Set Retrievable Packer

The PRM Mechanical-set Retrievable packer is design for testing ad zone stimulation application. The packer run, set, released and reset in one trip. Internal J-Latch holds the packer set, and only 1/4 turn of tubing at packer to set and release. Second straight pull shear release available when the tubing rotating limited. The feature of fluid bypass areas through the packer allows high run in hole speed. The PRM packer can be use as tubing anchor or temporary bridge plug. Pressure can be up to 10K.

Features and Benefit
 
  •  Field proved reliable
  •  Testing and stimulation application
  •  Tubing anchor or temporary bridge plug application
  •  Internal J-Latch holds the packer set
  •  1/4 turn of tubing at packer to set and release
  •  Reset and release packer in one trip
  •  Easy redress and reassemble
  •  High run speed when run in hole
  •  Shear release for option
  •  High pressure rating, Standard 10ksi
Applications
 
  •  Well testing
  •  Frac and stimulation
  •  Temporary bridge plug
  •  Tubing hanger
Technical Data
Casing Size Casing Weight Packer OD Packer ID
in. mm lb/ft Kg/m in. mm in. mm

 

5 1/2

 

139.70

13-17 19.35-25.30 4.69 119.12 2.40 60.96
20-23 29.76-34.23 4.51 114.55 2.40 60.96

 

 

 

7

 

 

 

177.80

20-26 29.76-38.69 6.03 153.16 2.98 75.69
26-32 38.69-47.62 5.91 150.11 2.98 75.69
32-38 47.62-56.55 5.70 144.78 2.98 75.69
41-44 61.01-65.48 5.50 139.70 2.98 75.69

 

7 5/8

 

193.68

26.4-29.7 39.29-44.20 6.65 168.91 2.98 75.69
29.7-39 44.20-58.04 6.45 163.83 2.98 75.69
9 5/8 244.48 36-43.5 53.57-64.74 8.55 217.17 3.88 98.55

PRH4 Packers

PRH4 ESP packer is designed to be run with Electric Submersible Pumps. The packer is a hydraulic-set, straight pull shear release, upper single-string, double-bore retrievable packer. The packer with several additional optional ports allows venting of annular pressure, fluid injection through the packer, and/or instrument wire port bypass. The vent valve is designed to be threaded to the top of the packer. The valve is hydraulically operated and allows for gas bypass around the packer. The packer comes with a plug for when the vent valve is not used.

Features
 
  •  Hydro-test capability of feed through connection.
  •  A pack-off power cable feed-through system is provided with thread connections
  •  Additional bores for venting of annular pressure, chemical-injection lines, control lines, and well-monitoring devices through the packer
  •  Slip design offers exceptional hang weight capability
  •  Case carburized bi-directional slips anchor the packer against well pressure from above or below
Benefits
 
  •  Field redress is quick, easy, and cost effective
  •  Efficiently reduce the overall costs of submersible pump completions
  •  Performance is long-term and dependable
  •  No relative movement between tubing and cable
  •  Low pressure set
  •  Requires only straight pull to release
  •  Field adjusted the setting pressure and shear value
  •  Allows adjustment of pull-to-release in the field
Technical Data
Casing Max.OD Pressure Rating Pressure Rating
Size Weight
in. mm lb in. mm in. mm psi MPa

 

 

7

 

 

177.8

23-26 6.10 154.94

 

 

2.360

 

 

59.94

 

 

3000-5000

 

 

20.7-35

26-29 5.99 152.15
29-32 5.94 150.88

 

 

9 5/8

 

 

244.5

36-40 8.59 218.19

 

 

2.918

 

 

74.12

 

 

3000-5000

 

 

20.7-35

40-47 8.50 215.90
47-53.5 8.26 209.80

Gas Vent Valve

The Gas Vent Valve is designed to be threaded onto PRH4 ESP packer and vent the gas to maintain optimum fluid levels for the ESP. It is a control line actuated valve from surface. The valve is opened by applying hydraulic control pressure, and closes when the pressure is released.

Features and Benefit
 
  •  Controlled by hydraulic control-line pressure
  •  Sealing reliable and long service life
  •  Large flow area
  •  Two sizes: 1” and 1 1/2”, c/w 1/4” NPT connection
  •  5000psi working pressure rating

Cable Pack-Off

The Cable Pack-Off provides an effective seal for an electrical submersible pump (ESP) cable when used with a multistring packer. To achieve a seal, the metal shield on the cable is removed from a short section, and the cable is installed through the secondary side of the ESP packer. The tool isolates pressure below from pressure above the packer by sealing on the rubber jacket of the cable.

Features and Benefit
 
  •  Compression energized elastomeric seals
  •  Without splicing or using expensive penetrators when running cable through the packer
  •  Seals on cable OD, designs available for round and flat cables
  •  Simple tighten of a nut to compress the elastomers
  •  Standard 3000psi working pressure rating

Trip sub

The Model Hydro Trip Pressure Sub is a pressure actuated device installed in tubing string below a hydrostatically actuated tool such as a Hydraulic set packer. It provides a method of applying pressure to activate and set the packer and then through continued pressure, activate the Hydro Trip Sub. Packer is set by circulating a ball through packer down to ball seat in the Hydro Trip Sub.

After packer is set, a continued increase in pressure is applied to shear the shear screws in the shear ring, allowing the ball seat collet to move down into the collet relief area and allowing the ball to pass down the Hydro Trip Sub through the tubing, leaving a “full open” Sub with no restrictions to production. The Collet Catcher Sub is used when any restrictions are installed below, ball and solid bar are available.

Y-Tool

The Y-Tool is designed to be run with ESP below ESP packer. As the produced fluid leaves the ESP it flows through a pump sub and then joins the main production string through the Y-Tool profile that has been carefully designed to minimize flow erosion. The Y-Tool offsets the ESP in the well to provide a straight line conduit for wireline or coiled tubing tools to bypass the ESP. The Y-Tool has an upper connection for the production tubing and two lower connections, one for the ESP and the other for the bypass. A blanking plug is located in the bypass side in a special nipple to prevent recirculation of the pumped fluid. The blanking plug is removed prior to and after intervention. For logging operations, the blanking plug is replaced by a logging plug which allows real time or memory logging to be conducted whilst the pump is operating.

Features and Benefit
 
  •  Large flow area
  •  Minimize flow erosion
  •  Simple design
  •  Standard 2 3/8”, 2 7/8” and 3 1/2” sizes

Control line and Cable Protectors

The Control Line and Cable Protectors fix the cable on tubing, and it protects the cable. The tubing supports the control line and cable and ensures they not be destroyed while running the string. Consequently, the control line and cable could be used again and the cost is reduced. Negative effects would occur if the cable were not protected while running the string. Such as attrition, changing pump and well repair work. Especially the big diameter cables are more easily damaged at the coupling.

Features and Benefit
 
  •  Different size for tubing
  •  Anticorrosion material capable
  •  Special tools for right installation
  •  Record the torque and position
  •  Guard against falling objects