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  • Sliding Sleeve & Landing Nipple
  • Gas Lift Products & Soft Release Gauge Hanger
  • Back-Pressure & Travel Joints

Sliding Sleeve

Side Door Sleeve SDS is used together tubing which when open, allows flow between the well tubing and the annular area. Which can be opened or closed by standard slickline methods to gain communication between the tubing/casing annulus. It is designed with a landing nipple profile in the top sub, packing bores in both the top and bottom sub, and a non-elastomer seal package and with full tubing flow through the nipple and the sleeve. This circulation & production sleeve is installed as an integral part of the main tubing string and any number of pieces can be run in a single tubing string. It can be run in either the open or closed position. The closing sleeve may be placed in three positions: open, equalizing, or closed. This operation is done with a positioning tool attached to a standard slickline tool string.

Features and Benefit

  •  Nipple profile available
  •  Non-elastomer seals
  •  Polished pack off area
  •  Several pieces of equipment can be run in a single tubing string
  •  All the pieces can be shifted on a single trip of the slickline, and individual sleeves can also be opened or closed selectively as desired
  •  The sleeve can be kept in full open, equalizing or full closed position by three-position collet lock
  •  Inner sleeve can be shifted repeatedly, opens up or down
  •  Packing does not move when the sleeve is shifted
  •  Circulation/production area equals the tubing area
  •  Equalizing ports in the inner sleeve allow equalizing at high differential pressure

Applications

  •  Circulating completion or kill fluids
  •  Single selective production and injection completions
  •  Tubing pressure test by running a plug inside
  •  Washing above packer
Technical Data
Tubing Size Tubing Weight Tubing ID Seal Bore
In. mm lb/ft kg/m in. mm in. mm

 

2 3/8

 

60.3

4.6 6.85 1.995 50.67

 

1.875

 

47.63

4.7 6.99 1.995 50.67

 

2 7/8

 

73.0

6.4 9.52 2.441 62.00

 

2.312

 

58.72

6.5 9.67 2.441 62.00

 

3 1/2

 

88.9

9.2 13.69 2.992 76.00 2.812 71.42
10.3 15.33 2.992 76.00 2.750 69.85

 

4

 

101.6

10.9 16.22 3.476 88.29

 

3.312

 

84.12

11 16.37 3.476 88.29

 

 

4 1/2

 

 

114.3

12.6 18.75 3.958 100.53

 

3.812

 

96.82

12.75 18.97 3.958 100.53
15.2 22.62 3.826 97.18 3.688 93.68

Landing Nipple and Lock Mandrel, Equalizing Prong

Landing nipples are downhole components, fabricated as a short section of heavy wall tubular with a machined internal surface that provides a seal area and a locking profile. The Landing Nipples are included in most completions at a pre-determined intervals to enable the installation of flow-control devices, such as Plugs and Chokes. Three basic types of Landing Nipples are commonly used: No-Go Nipples, Selective-Landing Nipples and Ported Safety Valve Nipples. The Landing Nipples have the same Packing Bore ID for a particular tubing size and weight. ‘LNX’ and ‘LNXN’ Landing Nipples are designed for use with standard weight tubing. ‘LNR’ and ‘LNRN’ Landing Nipples are for heavy weight tubing. The ‘N’ designation is for No-Go Nipples. The completion can have as many LNX and LNR selective nipples with the same ID in any sequence as desired on the tubing string. This versatility result in an unlimited number of positions for setting and locking subsurface flow controls. The flow control, which is attached to the required lock mandrel, is run in the well via the selective running tool on the slickline.

Features and Benefit

  •  Large bore for minimum restriction
  •  Universal nipple with one internal profile
  •  Lock mandrel locks design to holds pressure from above and below
  •  Extra large ID for high flow rate
  •  Simple operation
  •  Versatility helps reduce completion and production maintenance costs
  •  Multiple options when running, setting, or retrieving subsurface flow controls
  •  Field proven
  •  Versatility helps reduce completion and production maintenance costs

Applications

  •  Gauge hangers for bottom hole pressure/temperature surveys
  •  Almost unlimited locations for setting and locking subsurface flow controls
  •  Lock Mandrel with plugs holds pressure from above and below
  •  Setting packers
  •  Killing the well
  •  Removing the wellhead
Tubing For Standard Tubing Weights
LNX profile LNXN profile
Size Weight ID Drift Packing bore Packing bore NO-Go ID
in. mm Lb/ft Kg/m in. mm in. mm in. mm in. mm in. mm
2 3/8

 

60.3

4.6 6.85

 

1.995

 

50.67

 

1.901

 

48.29

 

1.875

 

47.63

 

1.875

 

47.63

 

1.791

 

45.49

4.7 6.99
2 7/8 73.0 6.4 9.52

 

2.441

 

62.00

 

2.347

 

59.61

 

2.312

 

58.72

 

2.312

 

58.72

 

2.205

 

56.01

6.5 9.67
3 1/2

 

88.9

9.3 13.84 2.992 76.00 2.867 72.82 2.812 71.42 2.812 71.42 2.666 67.72
10.2 15.18 2.992 74.22 2.797 71.04 2.750 69.85 2.750 69.85 2.635 66.93
4 1/2

114.3

12.75 18.97 3.958 100.53 3.833 97.36 3.812 96.82 3.812 96.82 3.725 94.62
5 1/2

139.7

17 25.30 4.892 124.26 4.767 121.08 4.562 115.87 4.562 115.87 4.455 113.16

Chemical Injection System

The Chemical Injection System is designed to inject and control the amount of chemicals or fluids into the tubing to control corrosion in wells, treat paraffin, salt and/or hydrate formation. Which can optimize flow assurance, reduce expensive intervention costs, and ultimately optimize production. The system includes Chemical Injection Mandrel (CIM) and Chemical Injection Valve (CIV). The chemicals or fluids are injected through a control line from surface. The check valve in CIV provides absolute protection for the check valves during installation in the well and provides a barrier between the production tubing and the annulus.

Features and Benefit

  •  Optimize flow assurance and production performance
  •  Reduce costly intervention
  •  CIM are eccentric non-welded mandrels, can absorb shock without damage
  •  CIV with check valve and rupture disc feature
  •  Land Nipple profile is available

Flow Coupling/Blast Joint

Flow couplings are thick-walled tubular components normally utilized in completions and located adjacent to changes in the tubing ID. They are an important part of life-of-the-well completion planning and used where erosional turbulence caused by changes in the tubing ID. STAR PETROTECH recommends flow couplings to be installed above and below landing nipples, safety valve landing nipples or any other restrictions that may cause turbulent flow. Flow couplings are generally connection OD and are available in 3, 4, 6 and 8 ft lengths.

Features and Benefit

  •  Wall thickness greater than tubing and normal connection OD
  •  Available in various lengths
  •  Available in various materials
  •  Helps extend the life of the well completion
  •  Installed above and below landing nipples, safety valve landing nipples or any other restriction that may cause turbulent flow

Gas Lift Products

Dummy Valve (DV) is slickline retrievable, and designed to be installed in series side pocket mandrel. The Dummy Valve is available for standard or high-temperature service to suit individual well conditions. Multi-purpose tool used to blank off the mandrel pocket to allow production by natural flow before installing gas lift valves, blank off the side pocket mandrel to allow pressure to be applied to the tubing to set a hydraulic-set packer and isolate tubing flow from annular flow for test purposes during multi-point waterflood or gas injection.

Gas lift valve (GLV)  is slickline retrievable, designed to be installed in series side pocket mandrel, production pressure operated and be used in continuous flow gas lift installations. The valve is used to enhance production by injecting high-pressure gas from the casing/tubing annulus into the production fluid.

Gas Lift Mandrel (GLM),  which made up as part of the tubing string when preparing a well for gas lift production, chemical injection, waterflood or other special applications. Facilitates the operation of running tools, pulling tools and kickover tools that are used to install and retrieve the flow control devices.

Features and Benefit

  •  Field proved reliable
  •  Heat treated for two different types of service, sweet, and H2S service
  •  Accept standard 1” top and bottom latch equipment
  •  Designed with a round cross section and are available in a variety of tubing sizes and thread types

Features and Benefit

  •  Soft mechanical release
  •  Can be set in one of many landing nipples
  •  Allows data surveys using conventional slickline methods
  •  Does not require jarring to set

Soft Release Gauge Hanger

The Gauge Hanger is designed to locate a bottom hole pressure and temperature gauge in NO-GO Landing Nipple with the appropriate profile to survey the well data. The gauge hanger is installed/retrieved using standard slickline methods.

Back-Pressure Valve System

The Top select Back-Pressure Valve System is designed primarily for use in Xmas Tree Wellhead Tubing Hangers. This PRS back-pressure valve can be used in conjunction with PRS Nipple Profile. This PRS Back-Pressure Valve has several special features. It has two external packing stacks, one internal packing stack, two internal MTM seals, three shear pin hold-down features, a knockout plug feature, and O-rings in the packing stacks. This PRS back-pressure valve is a high-pressure top no-go lock system. The top no-go provides a position locating means to simplify running procedures and eliminate mis-runs. The PRS back-pressure valve is designed such that pressure from above and below is held by key/nipple engagement. This assembly is designed for H2S service, has Teflon/PEEK packing, Chemraz O-rings, and meets the requirements of NACE MR-01-75.

Features and Benefit

  •  Application for tubing hangers and Xmas Tree
  •  Top No-Go locator feature
  •  Simply running and retrieving
  •  Reduce cost and time of service
  •  Using slickline to install
  •  Metal to Metal seal feature
  •  Can used in other landing nipples
  •  High pressure seal stack, standard for 10,000psi

Travel Joints

Travel Joints are made up in the tubing string and run into the well with packers and other down hole flow control equipments, and provide alternate methods of compensating for tubing contraction and elongation in producing, injection, and disposal wells. The travel joint are pinned in the closed, mid, or extended position before running. They also are keyed to prevent future rotation. The joints without keys are used when tubing torque below the joint is not required. These travel joints can be pinned at any point in the stroke. The release value can be varied by the number of shear screws and can be sheared by tension or compression.

Features and Benefit

  •  Compensating tubing moving in various conditions
  •  Adjusted shear value
  •  Can be locked in open, mid-stroke, or closed positions
  •  ID of the tool is compatible with tubing ID
  •  Rotation is available by keyed type
Technical Data
C OD ID Stroke
In. mm In. mm In. mm ft m

 

2 7/8

 

73.03

 

4.28

 

108.71

 

2.42

 

61.47

10 3.05
20 6.10

 

3 1/2

 

88.90

 

4.78

 

121.41

 

2.90

 

73.66

10 3.05
20 6.10

 

4 1/2

 

114.30

 

5.80

 

147.32

 

3.88

 

98.55

10 3.05
20 6.10
About Us

Iranian Refinement development premier is specialized in providing a complete line of drilling and well completion downhole tools, well hydraulic and acid fracturing downhole tools, oilfield equipment and facilities and most of well engineering services. To meet high expectation of clients in Middle East, Irdp has dedicated its upmost effort to deliver equipment, services and solutions that improve customers’ performance.

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Contact us
  •  phone: +98 21 228 15761
  •  Fax:+98 21 228 15346
  •  Adress: Unit 401, Laleh Alley, Qasemi (North Golestan) St., Movahed Danesh St., Aghdasiye. Tehran, Iran
  •  Email:  Info@tpselect.com