LinerHangersnewCatalog.pdf
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TEST SECTION TITLE
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Smith Services Completion Systems Products & Services Catalog
TABLE OF CONTENTS
Smith Services Completion Systems Products & Services Catalog
1
Cementing Equipment
Planning, Implementing, Evaluation
1
Pressure Activated Stage Cementing Valve
LINER HANGERS
34
Pump Down Plug and Liner Wiper Plug
35 36
Pocket Slip Liner Hanger System
2
Dual Liner Wiper Plug System
Pocket Slip Setting Tool
3
Cement Manifold
Benefits of the Pocket Slip Design
4
Solid Body Cementing Manifold (CSMB)
37
Frontier Series Packer & Accessories
5
Top Drive Cementing Manifold (CMIB)
38
Pocket Slip Liner Hanger & Tieback Receptacle Specifications
6-7
Inner String Circulation Tools
39
Rotating Pocket Slip Liner Hanger
8
Ported Swab Cup Assembly
39
EZ Series Mechanical Set Non-Rotating Linger Hanger (EZRD)
9
Tubing Swivel
39
EZ Series Mechanical Set Non-Rotating Linger Hanger Specifications
10
Ball Catch Sub
39
HS Series Hydraulic Set Non-Rotating Liner Hanger (HSDB)
11
Dress Mill Assembly
40
HS Series Hydraulic Set Non-Rotating Liner Hanger Specifications
12
liner hanger Systems
Liner Top Packers
13
Premium Hydraulic/Mechanical Rotating Liner Hanger
14
(Pocket Slip with FSP Packer)
Hydraulic-Set Isolation Packer
15
Heavy Duty Hydraulic Pocket Slip Rotating Liner Hanger
Compression-Set Isolation Packer
15
with JMPO Liner Top Packer
Long Reach Liner Top Packer
41
42
Planning, Implementing, Evaluation
43
One of Smith's main goals is to provide Customer Satisfaction. This is achieved by three basic but very efficient steps:
44
16
with WMPO Liner Top Packer
Orifice Float Collar
16
HZDC Hydraulic Non Rotating Liner Hanger
17-18
with WMPO Liner Top Packer
Polished Bore Receptacle
19
Compression Set Isolation Packer (Second Trip)
45
Retrievable Landing Assembly (RLA)
20
Typical Liner Applications
46-48
Insert Seal Assembly (ISA)
21
TECHNICAL INFORMATION
Tubing Seal Assembly & Accessories
22
Elastomer Guide
49-50
Dual Flow Assembly (DFA)
23
Engineering Test Cell Facility
51
Integrated Liner Hanger Packer
24
Liner Hanger Data Sheet
52
Well Summary Sheet
53
Setting Tools, Setting Adaptors & Accessories Mechanical Release Setting System (D-Tool, SATM)
25
Hydraulic Release Setting System (STHR, SHTS)
26
Double Spline Setting System (STS, SSTM)
27
"Jay" Release Setting System (Model J, SJTM)
28
Setting Tool Extension Assembly
29
Tamping Dog Assembly
29
•
Cement Bushing Cementing Pack Offs
30
Retrievable Cement Bushing
30
Drillable Cement Bushing
30
Cement Pack Off Coupling
31
Swab Cup Assembly
31
Health and Safety Mission Statement The mission of the Smith International, Inc. Health & Safety Department is to educate and influence employees to adopt safety and health policies, practices and procedures that prevent and relieve human and economic losses arising from accidental causes and adverse occupational environmental health exposures.
Tieback Seal Nipple
Our quality objectives are to: • Provide customers with quality products and services. • Make these products and services available when and where customers want them. • Develop a cost structure that enables competitive pricing. • Build and maintain a reputation for absolute trustworthiness.
EZRD Mechanical Set Non Rotating Liner Hanger
Tieback & Polished Bore Receptacle System
Tieback Receptacle Specifications
Quality Statement Smith International’s Quality Policy is to - “establish a relentless focus on satisfying customer needs and expectations.”
• •
Planning Selection of Linger Hanger System Surge & Swab simulation Torque & Drag simulation
Casing Hardware Landing Collars (LC)
32
Ball Catch Landing Collar (BC)
32
Float Landing Collar
33
Float Shoe and Guide Shoe
33
• •
Evaluation Playback simulation using actual job data for post job evaluation Post job analysis predict and explain potential job evaluation
1
•
Implementing Real-time recording of key parameters during job execution
LINER HANGERS
LINER HANGERS
Pocket Slip Liner Hanger System The Pocket Slip Liner Hanger System combines a premium liner hanger with accessory items specifically designed to maximize system integrity. The Pocket Slip Liner Hanger eliminates many of the problem features common to conventional liner hangers: external slips, slip arms, bow springs, cages, hydraulic setting cylinders, and more. This hanger utilizes a special tongue-andgroove slip design completely recessed within the hanger body when run. A short body and recessed slips make it "clean running". These features lessen the possibility of interference with tight spots, liner tops, doglegs, windows or mudline suspension systems - all potential places for conventional liner hangers to encounter problems. Additionally, the PSH system has an enhanced fluid flow arrangement providing both external and internal fluid bypass. Integral liner running threads eliminate the liner setting adapter, adding to improved fluid flow at the hanger.
Pocket Slip Setting Tool
Applications • Running liners in damaged or obstructed wellbores • Hanging extremely heavy liners in high-grade casing, where maximum bite is required • Hanging liners in low-strength, uncemented, or multi-string casing where thorough load distribution is critical Features & Benefits • Drive slots in the liner top permit rotation while running to orient around obstructions (PSHR), also available without the Drive slots for non rotation applications (PSH) • Heavy-wall tubular alloy steel construction designed specifically to hang heavy liners; no pressure retention included for maximum hanging performance • Tongue-and-groove slip design completely recesses slips into the tool body, reducing running interference • High cone angle of slip design reduces horizontal slip forces in supporting casing • Slips manufactured to 55-60 Rockwell “C” hardness for high-grade casing compatibility • Enhanced fluid flow arrangement permits internal and external fluid bypass • Hanging capacity normally greater than the conventional dual cone designs of the same size • External and internal fluid flow bypass is optimized by eliminating close tieback seal bore clearance
The Pocket Slip Setting Tool provides a dual setting method in most sizes - hydraulic or mechanical setting of the liner hanger. Either method can be selected when the liner is at setting depth - not an option with conventional liner setting tools! The Pocket Slip Setting Tool is designed to positively actuate the hanger's slips resulting in uniform loading. This forceful wedging action eliminates many of the problems inherent with preferential or unbalanced slip engagement common to conventional hangers.
PSH
Features and Benefits • Dual setting method - hydraulic or mechanical - capability in most sizes. • Positive, uniform, controlled slip activation • Centralizing system eliminates any potential for setting tool binding created by doglegs - assures easy release of the running nut • Slip activating dogs "locked" into releasing position after setting - prevents any accidental re-engagement • Bearing system eliminates the need to find "neutral" to disengage the liner running nut • Designed to augment system bypass by providing internal flow path • Debris barrier to reduce potential fouling problems associated with particle fallout above the liner top
PSHR
STP
2
3
STPR
LINER HANGERS
LINER HANGERS
Benefits of the Pocket Slip Design
Frontier Series Packer & Accessories
Reduced Slip Loads Minimize Casing Damage: Most casing damage occurs with a conventional liner hanger because of slip setting problems: a shallow cone angle; uneven contact between the slips and the intermediate casing; and asymmetrical, erratically timed slip setting. Smith's PSH protects casing with a design and a slip-setting method that delivers smooth setting and even slip loads every time.
The PSH Pocket Slip Liner Hanger is available with a range of accessories designed to maximize running performance, operational flexibility and system integrity. The Pocket Slip Integral Packer (FSP) adds same-trip isolation capabilities to the PSHR, with a high-pressure antiswab element rated up to 10,000 psi at 350° F. The packer sets mechanically with the FSP. The FSP also includes an integral tieback receptacle, and is available with an integral cementing bushing profile for increased pressure performance.
Cone angle: The tongue-and-groove slip design on the PSH has an effective cone angle about twice that of conventional hangers. This reduces the horizontal slip force (burst pressure) on the intermediate casing and lowers the collapse load on the hanger body. This design gives increased safety margins unavailable with any other hanger on the market today. Slip contact: The tool's slip design and positive setting method ensure complete contact with the intermediate casing, from the top to the bottom of the slip. The result is efficient, predictable and uniform transfer of weight to the intermediate casing. Conventional liner hangers tend to preferentially load the slip, reducing the effective slip area and increasing the slip load above the predicted value.
Figure 1 Typical stress distribution in supporting casing using conventional cone and slip liner hanger (9 5⁄8" casing with 108,000 lbs. liner loading illustrated).
The Pocket Slip Tieback Receptacle (PSTBR) honed seal bores to maximize seal integrity, while bypass ports above the seal bore provide bypass area.
PSI Stress
The PSTBR is also available with an integral cementing bushing profile for increased pressure performance.
Slip timing: The Smith design overcomes the problem of poor slip timing with carefully synchronized contact between the slips and casing. Conventional hangers have a tendency for one slip or set of slips to take weight before the others, causing uneven loading of the intermediate casing and increasing the potential for liner/casing failure.
Features and Benefits • High-pressure element rated 10,000 psi at 350 degrees F • Anti-swab element design • Self-energizing, non-extruding element • Large bypass area • Tieback ability below the hanger or packer • Manufactured from mechanical tubing of equivalent liner grade
Finite Element Analysis: An FEA model was developed to depict the forces for a typical 7" 108,000 lb. liner suspended from a Conventional Liner Hanger ( Fig. 1) and the Pocket Slip Liner Hanger ( Fig. 2) inside 9-5/8" casing.
FSP
PSRT
PSDT
Accessories The Pocket Slip Retrievable Cementing Bushing (PSRT) features an RCB profile and a honed seal bore to maximize pressure performance. The Pocket Slip Drillable Cementing Bushing (PSDT) includes inserts to provide a seal between the setting tool slick joint and housing, and leave minimal core when drilled out with full gauge bits or mills.
Figure 1: For the Conventional hanger, the 9-5/8" casing is stressed to a level of 152,381 psi at the center where the slip is located. In most cases this stress would exceed the strength of the casing and there would be permanent deformation at this point. In reality, the cement behind the casing would minimize this deformation but it demonstrates the start of possible pipe burst if the cement were not in place. Figure 2: Shows the pipe stress levels when loaded by the Pocket Slip Hanger. Here the stress of 29,239 psi is well within the strength of even J-55 pipe. Even in the absence of cement, the casing would not experience any permanent deformation. The advantage of being able to hang long, heavy liners is clearly illustrated.
PSTBR
PSI Stress Figure 2 Typical stress distribution in supporting casing using Smith PSH liner hanger (9 5⁄8" casing with 108,000 lbs. liner loading illustrated).
FSP Setting Tool
4
5
LINER HANGERS
LINER HANGERS
Pocket Slip Liner Hanger & Tieback Receptacle Specifications Size
Hanger
Tieback
Size
Hanger
Pocket Slip Liner Hanger & Tieback Receptacle Specifications
Tieback
Size
Hanger
Tieback
Size
Hanger
Tieback
Liner x Casing
Casing
OD
ID
OD
ID
Liner x Casing
Casing
OD
ID
OD
ID
Liner x Casing
Casing
OD
ID
OD
ID
Liner x Casing
Casing
OD
ID
OD
ID
(in.) (mm)
(lb/ft) (kg/M)
(in.) (mm)
(in.) (mm)
(in.) (mm)
(in.) (mm)
(in.) (mm)
(lb/ft) (kg/M)
(in.) (mm)
(in.) (mm)
(in.) (mm)
(in.) (mm)
(in.) (mm)
(lb/ft) (kg/M)
(in.) (mm)
(in.) (mm)
(in.) (mm)
(in.) (mm)
(in.) (mm)
(lb/ft) (kg/M)
(in.) (mm)
(in.) (mm)
(in.) (mm)
(in.) (mm)
11.50 17.30
4.30 109.22
3.60 91.44
4.12 104.65
3.50 88.90
14 20.8
4.76 120.90
4.06 103.12
24.0 - 29.7 35.7 - 44.2
6.62 168.15
15.5 23.1
4.70 119.38
4.00 101.60
33.7 - 39.0 50.1 - 58.0
6.43 163.32
5.50 139.7
12.30 312.42
4.25 107.95
6.25 158.75
48.0 71.4
13.00 19.30
5.62 142.74
6.18 156.97
54.5 81.1
12.20 309.88
61.0 90.8
12.10 307.34
10.70 271.78
11.75 292.10
10.375 263.5
68.0 - 72.0 101.2 - 107.1
12.04 305.82
48.0 71.4
12.30 312.42
54.5 81.1
12.20 309.88
61.0 90.8
12.10 307.34
10.70 271.78
11.75 292.10
10.625 269.9
68.0 - 72.0 101.2 - 107.1
12.04 305.82
48.0 71.4
12.30 312.42
54.5 81.1
12.20 309.88
61.0 90.8
12.10 307.34
68.0 - 72.0 101.2 - 107.1
12.04 305.82
55.0 - 70.0 81.8 - 104.2
14.75 374.65
75.0 - 84.0 111.6 - 125.0
14.53 369.06
13.62 345.95
12.625 320.7
109.0 - 118.0 162.2 - 175.6
14.16 359.66
146.0 217.2
13.62 345.95
94.0 - 106.5 139.9 - 158.5
18.37 466.6
117.0 - 133.0 174.1 - 197.9
18.12 460.25
147.0 218.7
18.06 458.72
17.50 444.5
16.00 406.4
169 251.5
17.93 455.42
3½x5 88.9 x 127.0
3½x5½ 88.9 x 139.7
4x5 101.6 x 127.0
4x5½ 101.6 x 139.7
3.47 88.14
4.00 101.60
3.375 85.73
4½x5½ 114.3 x 139.7
5½x7⅝ 139.7 x 193.7
17 25.3
4.63 117.60
3.83 99.82
42.8 - 45.3 63.7 - 67.4
20 29.3
4.53 115.06
3.83 97.28
32.3 - 40.0 48.1 - 59.5
8.50 215.9
17.0 - 20.0 25.3 - 29.8
6.21 157.73
40.0 - 47.0 59.5 - 69.9
8.37 212.6
23.0 - 26.0 34.2 - 36.7
6.03 153.16
47.0 - 53.5 69.9 - 79.6
8.25 209.55
29 43.2
5.95 151.13
58.4 86.9
8.12 206.25
32.0 - 35.0 47.6 - 52.1
5.78 146.81
40.5 - 45.5 60.3 - 67.7
9.62 244.35
38 56.5
5.70 144.78
51.5 - 55.5 76.6 - 82.6
9.43 239.52
17.0 - 20.0 25.3 - 29.8
6.21 157.73
60.7 - 65.7 90.3 - 97.8
9.25 234.95
23.0 - 26.0 34.2 - 36.7
6.03 153.16
32.3 - 40.0 48.1 - 59.5
8.50 215.9
29 43.2
5.95 151.13
40.0 - 47.0 59.5 - 69.9
8.37 212.6
32.0 - 35.0 47.6 - 52.1
5.78 146.81
47.0 - 53.5 69.9 - 79.6
8.25 209.55
38 56.5
5.70 144.78
58.4 86.9
8.12 206.25
24.0 - 29.7 35.7 - 44.2
6.62 168.15
40.5 - 45.5 60.3 - 67.7
9.62 244.35
33.7 - 39.0 50.1 - 58.0
6.43 163.32
51.5 - 55.5 76.6 - 82.6
9.43 239.52
42.8 - 45.3 63.7 - 67.4
6.18 156.97
60.7 - 65.7 90.3 - 97.8
9.25 234.95
3.83 97.28
17.0 - 20.0 25.3 - 29.8
6.21 157.73
3.83 97.28
23.0 - 26.0 34.2 - 36.7
6.03 153.16
60.0 - 65.0 89.3 - 96.7
10.38 263.65
29 43.2
5.95 151.13
32.0 - 35.0 47.6 - 52.1
5.78 146.81
38 56.5
5.70 144.78
15.00 22.30
4.17 105.92
18.00 26.80
4.03 102.36
14.00 20.80
4.76 120.90
15.50 23.10
4.70 119.38
17.00 25.30
4.63 117.60
20.00 29.30
4.53 115.06
23.00 34.20
4.43 112.52
23.80 35.40
4.37 111.00
26.00 38.70
4.30 109.22
11.50 17.10
4.30 109.22
13.00 19.30
4.25 107.95
15.00 22.30
4.17 105.92
18.00 26.80
4.03 102.36
3.33 84.58
14.00 20.80
4.76 120.90
4.06 103.12
15.50 23.10
4.70 119.38
4.00 101.60
17.00 25.30
4.63 117.60
20.00 29.30
4.53 115.06
23.00 34.20
4.43 112.52
23.80 35.40
4.37 111.00
26.00 38.70
4.30 109.22
3.33 84.58
3.93 99.82
4.25 107.95
3.75 95.25
3.83 97.28
3.60 91.44
4.00 101.60
3.50 88.90
5x7 127.0 x 177.8
3.47 88.14
3.60 91.44
4½x7 114.3 x 177.8
4.50 114.30
3.97 100.84 3.91 99.31
5x7⅝ 127.0 x 193.8
5½x7 139.7 x 177.8
5.12 130.05
4.87 123.7
5.12 130.05
4.87 123.7
5.75 146.05
5.50 139.7
5.75 146.05
5.50 139.7
5.00 127.00 or 4.75 120.65
4.75 120.65
5.00 127.00
4.75 120.65
5.62 142.75
6.25 158.75
5.50 139.70
5.25 133.35
5.87 149.10
5.125 130.18
7x9⅝ 177.8 x 244.5
7 x 10 ¾ 177.8 x 273.0
7⅝x9⅝ 193.7 x 244.5 and 7¾x9⅝ 196.85 x 244.5
7 ⅝ x 10 ¾ 193.7 x 273.0
9⅝x 11 ¾ 244.5 x 298.5
5.12 130.05
4.87 123.7
9 ⅝ x 13 ⅜ 244.5 x 339.7
5.25 133.35
7.31 185.67
8.00 203.2
7.125 180.9 or 7.25 184.15
7.12 180.84
7.87 199.9
7.00 177.8
8.00 203.2
8.50 215.9
7.375 187.3
7.31 185.67
8.00 203.2
7.250 184.15
10 ¾ x 13 ⅜ 244.5 x 339.7
11 ¾ x 13 ⅜ 298.5 x 339.7
7.12 180.84
8.00 203.2
8.75 222.25
7.75 196.85 13 ⅜ x 16 339.7 x 406.4
9.38 238.25
10.00 254.00
9.25 234.95
16 x 20 406.4 x 508.0
6
7
10.70 271.78
12.75 323.85
12.00 304.8
16.12 409.45
LINER HANGERS
LINER HANGERS
Rotating Pocket Slip Liner Hanger
EZ Series Mechanical Set Non-Rotating Liner Hanger
The Rotating Pocket Slip Liner Hanger delivers unmatched rotating performance by combining the slip design of the Pocket Slip Hanger with an inner mandrel supported by a cylindrical roller bearing. The Rotating Pocket Slip Liner Hanger can be configured with a spacer sleeve in place of the bearing assembly to deliver the same exceptional hanging capacities and minimal casing loading characteristics for non-rotating applications.
EZ Series Liner Hangers is one of the most reliable and efficient Mechanical Set Liner Hangers, as it is comprised of the hanger body or mandrel one or more sets of cone pads, slips and a cage assembly to carry the slips. The cage contains a “J” slot and drag springs to control the movement of the slips into contact with the cones. A lug on the hanger body controls the cage “J” slot. A gage ring protects the slips when running the hanger into the wellbore.
The unique tongue-and-groove slip design minimizes running interference and reduces casing deformation potential once set. The Rotating Pocket Slip Liner Hanger body and slips feature an effective cone angle two times greater than conventional hangers, reducing burst pressure exerted on casing and allowing longer, heavier liners to be run on multi-string or uncemented casing.
Non-Rotating Mechanical Set (EZ) Liner Hangers are set through manipulation of the work string: quarter right hand turn aligns the cones and the slips, after which slack off sets the slips into the casing wall
The Rotating Pocket Slip Liner Hanger is set either mechanically (RPSM) or Hydraulically (HPS).
Features and Benefits • Casing body hanger is manufactured from L-80 and P-110 casing grades with other grades available by special order. • Single or multiple cone designs available to match hanging capacity with liner strength, minimizing stress in supporting casing. • Slips manufactured to 55-60 Rockwell “C” scale for high grade casing compatibility. • The EZ Hanger is available with either casing or heavy-wall tubing construction; “casing body” hanger • Cone pads, “J” lug, and gauge rings are welded to the tool body. “Solid body” hangers include these parts as integral features machined from the heavy-wall tool body, eliminating body welding and maximizing performance. • Solid Body hangers are machined from AISI 4100 Series alloy steel with controlled yield strengths and hardness for liner compatibility. • A full OD permits the matching of some premium threads on the hanger body.
Other components required for liner rotation are the setting tool and the setting adapter. Hydraulic release (SHTR) and Double Spline (STS) setting tool provide the most flexibility. Mechanical Set Rotating Pocket Slip Liner Hanger Features: • Bodies are manufactured from mechanical tubing to equivalent grade of the liner. 80,000 psi and 110,000 psi yield strengths are standard. Other yield strengths and materials available on request. • Pocket Slip design eliminates cone collapse common to conventional rotating liner hangers. • Reduced slip loads minimize stresses in supporting casing. • Inner surface of cone coated with low friction materials for optimal performance • Dependable right hand setting is standard. • Slips are manufactured to Rockwell "C" scale hardness of 55 to 60 for use in the highest grade casing strings. Hydraulic Set Rotating Pocket Slip Liner Hanger Features: • Pocket slip design eliminates cone collapse while providing an effective cone angle twice than the conventional hangers • Slips are manufactured to 55-60 Rockwell “C” hardness for high-grade casing compatibility • Cylindrical roller bearing can be replaced with a spacer sleeve when rotation is not required • Manufactured from mechanical tubing of equivalent liner grade; 80,000 psi through 125,000 psi yields are standard, with other yield strengths and materials available by special order • Reduces slip loads minimizes stresses in supporting casing • Right hand rotation of liner after hanging and during cementing RPSM
EZ
HPS
8
9
LINER HANGERS
LINER HANGERS
EZ Series Mechanical Set Non-Rotating Liner Hanger Specifications Size
Max. OD
Casing
(in.) (mm)
(lb/ft) (kg/M)
(in.) (mm)
24.0 - 29.7 35.7 - 44.19
6.62 168.15
33.7 - 39.0 50.1 - 58.0
6.37 161.80
32.30 48.06
8.68 220.47
36.0 - 43.5 53.57 - 64.73
8.43 214.12
47.0 - 53.5 69.93 - 79.61
8.25 209.55
32.30 48.06
8.68 220.47
36.0 - 43.5 53.57 - 64.73
8.50 215.90
47.0 - 53.5 69.93 - 79.61
8.31 211.07
42.0 62.50
10.81 274.57
47.0 - 54.0 69.93 - 80.35
10.62 269.75
6.05 153.67
60.0 - 65.0 89.28 - 96.72
10.43 264.92
29.0 - 32.0 43.2 - 47.6
5.87 149.10
48.0 71.42
12.25 311.15
35.0 - 38.0 52.1 - 56.5
5.68 144.27
54.5 - 68.0 81.09 - 101.18
12.00 304.80
24.0 - 29.7 35.7 - 44.19
6.50 165.10
72.0 - 85.0 107.14 - 126.48
11.75 298.45
33.7 - 39.0 50.1 - 58.0
6.25 158.75
48.0 71.42
12.37 314.20
17.0 - 20.0 25.3 - 29.8
6.21 157.73
54.5 - 68.0 81.09 - 101.18
12.12 307.85
23.0 - 26.0 34.2 - 38.7
6.05 153.67
72.0 - 85.0 107.14 - 126.48
11.87 301.50
Casing
(in.) (mm)
(lb/ft) (kg/M)
(in.) (mm)
13.0 - 18.0 19.63 - 26.8
4.08 103.63
20.3 - 24.2 30.2 - 36.0
3.81 96.77
11.5 - 13.0 17.3 - 19.3
4.25 107.95
15.0 - 18.0 22.3 - 26.8
4.08 103.63
14.0 - 17.0 20.8 - 25.3
4.68 118.87
20.0 - 23.0 29.8 - 34.2
4.45 113.03
14.0 - 17.0 20.8 - 25.3
4.68 118.87
17.0 - 26.0 25.3 - 38.7
6.05 153.67
29.0 - 38.0 43.2 - 56.5
5.68 144.27
17.0 - 20.0 25.3 - 29.8
6.18 156.97
23.0 - 26.0 34.2 - 38.7
3½x5 88.9 x 127.0
3½x5½ 88.9 x 139.7 4x5½ 101.6 x 139.7 4½x7 114.3 x 117.8
5x7 127.0 x 177.8
5x7⅝ 127.0 x 193.8
5½x7 139.7 x 177.8
5½x7⅝ 139.7 x 193.8
7x9⅝ 177.8 x 244.5
7⅝x9⅝ 193.67 x 244.5 and 7¾x9⅝ 196.85 x 244.5
9 ⅝ x 11 ¾ 244.5 x 298.45
9 ⅝ x 13 ⅜ 244.5 x 339.73
10 ¾ x 13 ⅜ 273.05 x 339.73
HS Series Liner Hangers is one of the most robust Hydraulic Set Liner Hangers, as it is comprised of the hanger body or mandrel one or more sets of cone pads, slips and a hydraulic piston/cylinder assembly to actuate the slips. The hydraulic piston/ hydraulic is shear pinned to actuate at a predetermined value. The hydraulic cylinder also incorporates the gage ring to protect the slip assembly when running the hanger assembly into the wellbore.
Max. OD
Liner x Casing
Liner x Casing
2⅞x5 75.03 x 127.0
Size
HS Series Hydraulic Set Non-Rotating Liner Hanger
Features and Benefits • Casing body hanger is manufactured from L-80 and P-110 casing grades with other grades available by special order. • Hydraulic Cylinder manufactured from material matching yield strength of the liner hanger. • Hydraulic piston incorporates debris wiper seal and anti rotation system to maintain slip/cone alignment. • Slips manufactured to 55-60 Rockwell “C” scale for high grade casing compatibility. • The HSDB hanger is available with either casing or heavy-wall tubing construction; “casing body” hanger Cone pads, are welded to the tool body, while “Solid body” hangers include these parts as integral features machined from the heavy-wall tool body, eliminating body welding and maximizing performance. • Solid Body hangers are machined from AISI 4100 Series alloy steel with controlled yield strengths and hardness for liner compatibility. • A full OD permits the matching of some premium threads on the hanger body.
HSDB
10
11
LINER HANGERS
LINER TOP PACKERS
HS Series Hydraulic Set Non-Rotating Liner Hanger Specifications Size
Max. OD
Casing
(in.) (mm)
(lb/ft) (kg/M)
(in.) (mm)
24.0 - 29.7 35.7 - 44.19
6.62 168.15
33.7 - 39.0 50.1 - 58.0
6.37 161.80
32.30 48.06
8.68 220.47
36.0 - 43.5 53.57 - 64.73
8.43 214.12
47.0 - 53.5 69.93 - 79.61
8.25 209.55
32.30 48.06
8.68 220.47
36.0 - 43.5 53.57 - 64.73
8.50 215.90
47.0 - 53.5 69.93 - 79.61
8.31 211.07
42.0 62.50
10.81 274.57
47.0 - 54.0 69.93 - 80.35
10.62 269.75
6.05 153.67
60.0 - 65.0 89.28 - 96.72
10.43 264.92
29.0 - 32.0 43.2 - 47.6
5.87 149.10
48.0 71.42
12.25 311.15
35.0 - 38.0 52.1 - 56.5
5.68 144.27
54.5 - 68.0 81.09 - 101.18
12.00 304.80
24.0 - 29.7 35.7 - 44.19
6.50 165.10
72.0 - 85.0 107.14 - 126.48
11.75 298.45
33.7 - 39.0 50.1 - 58.0
6.25 158.75
48.0 71.42
12.37 314.20
17.0 - 20.0 25.3 - 29.8
6.21 157.73
54.5 - 68.0 81.09 - 101.18
12.12 307.85
23.0 - 26.0 34.2 - 38.7
6.05 153.67
72.0 - 85.0 107.14 - 126.48
11.87 301.50
Casing
(in.) (mm)
(lb/ft) (kg/M)
(in.) (mm)
13.0 - 18.0 19.63 - 26.8
4.08 103.63
20.3 - 24.2 30.2 - 36.0
3.81 96.77
11.5 - 13.0 17.3 - 19.3
4.25 107.95
15.0 - 18.0 22.3 - 26.8
4.08 103.63
14.0 - 17.0 20.8 - 25.3
4.68 118.87
20.0 - 23.0 29.8 - 34.2
4.45 113.03
14.0 - 17.0 20.8 - 25.3
4.68 118.87
17.0 - 26.0 25.3 - 38.7
6.05 153.67
29.0 - 38.0 43.2 - 56.5
5.68 144.27
17.0 - 20.0 25.3 - 29.8
6.18 156.97
23.0 - 26.0 34.2 - 38.7
3½x5 88.9 x 127.0
3½x5½ 88.9 x 139.7 4x5½ 101.6 x 139.7 4½x7 114.3 x 117.8
5x7 127.0 x 177.8
5x7⅝ 127.0 x 193.8
5½x7 139.7 x 177.8
5½x7⅝ 139.7 x 193.8
7x9⅝ 177.8 x 244.5
7⅝x9⅝ 193.67 x 244.5 and 7¾x9⅝ 196.85 x 244.5
9 ⅝ x 11 ¾ 244.5 x 298.45
9 ⅝ x 13 ⅜ 244.5 x 339.73
10 ¾ x 13 ⅜ 273.05 x 339.73
Liner Top Packers are run as an integral part of the original liner string, replacing the liner setting adapter. Liner top packers consist of a Tieback Receptacle, a setting adapter appropriate to the setting tool used and a packer element used to seal the annulus. Designed to be set after the liner is cemented, the packer is set by picking up the running string, placing the tamping dogs in the setting tool assembly above the liner top and slacking off weight. Excess cement above the liner top can be circulated out after the packer is set.
Max. OD
Liner x Casing
Liner x Casing
2⅞x5 75.03 x 127.0
Size
Liner Top Packers
Liner top packers are available in the following configurations: • WMP- for use with Model D setting tool • JMP- for use with Model STHR setting tool • VMP- for use with Model STS setting tool Holds down slips are available as special order for all packer types. Features and Benefits • Optimizes chemical resistance to completion and production fluids with a variety of elastomer options for packer elements and seal assemblies. • Maintains element setting with mandrel lock ring. • Facilitates high circulating rates with enhanced packer element design. • Eliminates extra components and connections with integral retrievable cementing bushing profile • Available with optional hold down slips for use with light weight liners • High-grade casing compatible slips manufactured to 55-60 Rockwell “C” hardness • L80 and Q125 material grades are standard, with other material grades available by special order
WMP w/o Hold Down Slips
WMP w/ Hold Down Slips
12
13
LINER TOP PACKERS
LINER TOP PACKERS
Long Reach Liner Top Packer
Hydraulic-Set Isolation Packer
The Long Reach Liner Top Packer (LRTP) facilitates successful liner deployment in vertical and long reach horizontal wellbores. Hydraulicsetting, combined with push, pull and rotation capabilities allow controlled liner deployment without excessive work string manipulation. Ease of deployment is further enhanced by an internal bypass included in the packer and the Long Reach Setting Tool (LRST) reducing “piston effect” during running. The packer features an internal circulating string for wellbore fluid displacement where required. Packer elements are available with standard or thermal elastomeric construction for use in steam injection applications.
The Hydraulic-set Isolation Packer (HLT) is run on a second trip to isolate leaks at the liner top. Hydraulic-setting is beneficial in highly deviated wellbores where adequate slack-off force cannot be applied. The HLT is used after the liner has been run, cemented and the liner tieback receptacle seal bore cleaned out. The HLT seals into the existing liner tieback receptacle and is set with a hydraulicsetting tool, sealing the annular area between the liner and casing. It also provides a new tieback receptacle for future operations. Features and Benefits • Sets with hydraulic pressure applied to setting tool for uniform setting force • Eliminates transfer of setting weight to the liner • Optimizes chemical resistance to completion and production fluids with a variety of elastomer options for packer elements and seal assemblies • Maintains element setting with mandrel lock ring • Dual slips prevent movement of packer • High-grade casing compatible slips manufactured to 55-60 Rockwell “C” hardness • L80 and Q125 material grades are standard, with other material grades available by special order •
Features and Benefits • Push, pull and rotation capabilities facilitate liner deployment • Hydraulic primary release reduces work string manipulation and eliminates string weight requirements • Secondary mechanical release. One quarter left hand turn shears pins; straight pick-up releases packer • Designed to accept inner string circulating accessories • Internal bypass feature reduces “piston effect” • Available with or without slips for hanging and hold down applications • Packer can be manufactured to match casing thread, eliminating liner crossover
LRTP w/ Thermal Element
LRTP w/ Standard Element
Compression-Set Isolation Packer The Compression Set Isolation Packer (CLT / CLTP) is run on a second trip to isolate leaks at the liner top. The CLT is used after the liner has been run, cemented and the liner tieback receptacle seal bore cleaned out.
Applications • Running liners in long reach horizontal wells • Setting sand screens in open hole below a liner • Applications requiring extended drill down of the liner • Running conditions where the liner may need to be pushed or jarred to bottom • Hanging light weight liners when a conventional inner hanger is not necessary • Applications in which the liner is either dropped off or needs to be hung and held down • Architectures in which additional bypass area is required for minimizing lost circulation, or facilitating faster running speeds
The CLT seals into the existing liner tieback receptacle and is set with compression, sealing the annular area between the liner and casing. It also provides a new tieback receptacle for future operations. The CLTP includes the same features as the CLT, but is designed for use with pocket slip liner systems.
LRST HLT
Features and Benefits • An anti-trip safety lock ring prevents premature setting • Optimizes chemical resistance to completion and production fluids with a variety of elastomer options for packer elements and seal assemblies • Maintains element setting with mandrel lock ring • Hold down slips prevent upward movement of packer • High-grade casing compatible slips manufactured to 55-60 Rockwell “C” hardness • L80 and Q125 material grades are standard, with other material grades available by special order • Available for Pocket Slip Liner Systems (CLTP) CLT
14
15
TIEBACK & POLISHED BORE RECEPTACLE SYSTEM
TIEBACK & POLISHED BORE RECEPTACLE SYSTEM
Tieback Seal Nipple
Tieback Receptacle Specifications
Tieback liners provide a new casing string to cover intermediate casing worn by drilling or corrosion, protect a weak casing string from shut-in or excessive production pressure or to isolate a leaking liner top. A typical tieback liner system includes a Tieback Seal Nipple (TSN), Orifice Float Collar (OFC) and an existing Liner Tieback Receptacle (TBR). The TSN consists of a locator, seal mandrel, seals or seal units and a half mule shoe bottom. This assembly is made up to the tieback string and is landed into the existing TBR.
Size
ID
Liner x Casing
Casing
OD
ID
(in.) (mm)
(lb/ft) (kg/M)
(in.) (mm)
(in.) (mm)
(in.) (mm)
(lb/ft) (kg/M)
(in.) (mm)
(in.) (mm)
5.82 147.82
5.25 133.35
5.625 143.00
5.125 130.18
5.82 147.82
5.25 133.35
6.25 158.75
5.25 133.35
4 101.6 x 5½ 139.7
20 29.8
15 22.3
23 34.2
17 25.3 20 29.8
4.375 111.25
3.75 95.25
29 43.2 32 47.6
14 20.8
38 56.5
15 22.3
4.625 117.60
4.125 104.78
24 35.7
17 25.3
26.4 39.3 5 127.0 x 7⅝ 193.7
29 43.2
5.625 143.00
33.7 50.1
55.3 82.3
5.00 127.00
24 35.7
32 47.6
38 56.5
29.7 44.2
39 58.0
26 38.7
35 52.1
Features and Benefits • Single poppet valve standard • All internal parts are PDC drillable • Orifice port allows tieback liner to fill during run-in • Orifice prevents pressure lock by providing a fluid path • L80 and Q125 material grades are standard, with other material grades available by special order
26 38.7
35 52.1
23 34.2
4½ 114.3 x 7 177.8
5 127.0 x 7 177.8
26 38.7
20 29.8
Orifice Float Collar
TSN
14 20.8
23 34.2
The Orifice Float Collar (OFC) reduces lost rig time and drilling fluids by allowing the tieback liner / casing to fill as it is run. In addition, when the Tieback Seal Nipple (TSN) enters the tieback receptacle, displaced fluids flow through the orifice, preventing a pressure lock during stabbing. The OFC is normally run one to two joints above the TSN and provides a stop for the cementing plug.
Tieback
OD
* Trademark of DuPont Company
TBR
Size
Casing
3½ 88.9 x 5½ 139.7
Features and Benefits • Locator threaded to match tieback liner / casing connection • Variety of seal materials available for compatibility with anticipated well conditions; Viton* / Aramid seal units standard • Mule shoe configuration aids in stabbing and facilitates re-entry with wireline equipment • Optional cementing ports available • L80 and Q125 material grades are standard, with other material grades available by special order
Tieback
Liner x Casing
5 127.0 x 7⅝ 193.7
26.4 39.3 29.7 44.2 33.7 50.1 39 58.0
OFC
16
17
TIEBACK & POLISHED BORE RECEPTACLE SYSTEM
TIEBACK & POLISHED BORE RECEPTACLE SYSTEM
Tieback Receptacle Specifications Size
Polished Bore Receptacle
Size
Tieback
Liner x Casing
Casing
OD
ID
Liner x Casing
Casing
OD
ID
(in.) (mm)
(lb/ft) (kg/M)
(in.) (mm)
(in.) (mm)
(in.) (mm)
(lb/ft) (kg/M)
(in.) (mm)
(in.) (mm)
8.38 212.85
7.75 196.85
5½ 139.7 x 7 177.8
20 29.8 23 34.2
32 47.6 6.06 153.92
5.562 141.27
26 38.7
26.4 39.3 29.7 44.2
6.38 162.05
5.75 146.05
40 59.5 43 64.0 47 69.9 53.5 79.6
33.7 50.1
53.5 SD 79.6
39 58.0
42 62.5
32 47.6
9⅝ 244.5 x 11 ¾ 298.5
36 53.6 40 59.5 7 177.8 x 9⅝ 244.5
36 53.6
7⅝ 193.7 x 9⅝ 244.5
24 35.7
5½ 139.7 x 7⅝ 193.7
43 64.0
8.25 209.55
54 80.4
53.5 79.6
54 80.4
8.12 206.25
7.375 187.33
7.75 196.85
10.38 263.65
9.875 250.83
60 89.3
48 71.4
53.5 SD 79.6
PBR Sizes 8.25 209.55
65 96.7
7.375
9⅝ 244.5 x 13 ⅜ 339.7
61 90.8 68 101.2
Features and Benefits • Honed ID reduces potential seal damage during tubing expansion or contraction • Thick wall construction permits machining most premium threads on the body, eliminating crossovers • One-piece construction eliminates potential leak paths • Available in lengths of up to 30 feet without splice connections or concentric couplings for optimal pressure integrity and seal performance • Adaptable with a Retrievable Landing Assembly profile sub for adding profile nipples or other accessory equipment to the completion • L-80 and P-110 material grades are standard with other grades available by request Specifications
47 69.9
47 66.9
58 86.30
The Polished Bore Receptacle (PBR) provides a honed ID sealing surface for a production tubing seal assembly. The PBR may be used in lieu of a production packer and is typically run integrally with the production liner. PBR length is determined by analysis of the production tubing movement during various situations such as stimulation, production and well shut-in.
Tieback
11.5 292.10
10.375 263.53
72 107.1 77 114.6
PBR
85 126.5
18
19
ID
OD
Max. ID Thru Seal Nipple
(in.) (mm)
(in.) (mm)
(in.) (mm)
2.60 62.28
3.50 88.9
1.929 49.00
3.00 76.20
4.00 101.6
2.372 60.25
3.25 82.55
4.25 180.0
2.372 60.25
3.50 88.90
4.50 114.3
2.372 60.25
3.75 95.25
5.00 127.0
2.372 60.25
4.00 101.60
5.25 133.4
2.917 74.09
4.25 107.95
5.50 139.7
2.917 74.09
4.40 111.76
5.75 149.1
2.917 74.09
4.75 120.65
6.00 157.4
2.917 74.09
5.00 127.00
6.25 158.8
3.398 86.31
6.00 152.40
7.50 190.5
4.276 108.61
6.25 158.75
7.75 196.9
4.276 108.61
6.625 168.28
8.25 209.6
4.276 108.61
TIEBACK & POLISHED BORE RECEPTACLE SYSTEM
TIEBACK & POLISHED BORE RECEPTACLE SYSTEM
Retrievable Landing Assembly
Insert Seal Assembly
The Retrievable Landing Assembly (RLA) is used to suspend tailpipe and profile nipples when using a Polished Bore Receptacle (PBR) completion, enhancing flexibility by providing a method to temporarily isolate the producing zone. The assembly locks into the profile of a previously run PBR and allows production tubing to be pulled without killing the well or dumping damaging fluids on the formation.
The Insert Seal Assembly (ISA) is designed to set, seal and lock into an existing Retrievable Cementing Bushing (RCB) or Retrievable Landing Assembly (RLA) profile in the production liner assembly. This provides an economical tool for completions that does not require profile nipples for isolation of the producing interval when tubing is pulled for maintenance.
The RLA also permits placing bottom-hole pressure gauges, chokes, plugs or other wireline tools below the tubing. Additional versatility is gained by installing a smaller ID PBR on top of an RLA, providing a reduced piston area for PBR completions with small OD production tubing in a larger casing ID. Reducing the piston area allows higher differential pressures without tubing damage. The RLA is run after the liner and PBR are cemented in the well and cleaned out. The RLA and tailpipe are run to setting depth on a work string and hydraulically or mechanically set with the dual method setting tool. The work string and setting tool are retrieved and production tubing is run.
The ISA consists of a body with internal and external seals, a locking lug arrangement and a floating, polished OD slick joint that connects to the production tubing. The assembly is locked into the receiving profile by the slick joint. A reduced OD section of the slick joint permits the assembly to be stabbed into the profile and locked by five to six right-hand rotations, releasing the slick joint from the body and moving the lugs into the locked position. Once seated, the slick joint is free to move within the full OD length. Slick joint length is determined by tubing movement in reaction to well conditions. To re-enter the liner with full gauge tools, the ISA is retrieved by straight pick up of the production tubing. This places the reduced section of the slick joint under the locking lugs, permitting retrieval. The liner is unrestricted following removal of the ISA.
If it becomes necessary to re-enter the liner with full gauge tools, the tubing is pulled and the RLA is retrieved with a specially designed retrieving tool. With the RLA removed, the liner is unrestricted.
RLA
Features and Benefits • L80 and Q125 material grades are standard, with other material grades available by special order • Internal, positive locking setting sleeve cannot be accidentally released by wireline tools • Locking lug system suitable for differential pressures as high as 10,000 psi • Top and bottom locating designs permit usage at the bottom of a PBR or at the upper end of a PBR for completion design flexibility • Viton* / Aramid seal units are standard. A variety of seal materials are available for compatibility with anticipated well conditions; see the Elastomer Guide for these materials • Redundant seal system provides increased system reliability • Easily adapted with a reduced ID PBR above the RLA for reduced piston area when using smaller ID production tubing strings
Features and Benefits • Reduces completion costs by utilizing an existing RCB profile in the production liner assembly • Reduced piston area minimizes tubing stress • Right-hand set / straight pull release • Slick joint retention system prevents accidental re-engagement • L80 and Q125 material grades are standard, with other material grades available by special order • Broad range of seal materials available for compatibility with anticipated well conditions; Viton* / Aramid seal units are standard
RLA Setting Tool
* Trademark of DuPont Company
* Trademark of DuPont Company
RLA Setting Tool Features and Benefits • Combined hydraulic or mechanical setting for optimum flexibility • Right-hand release running thread • Fluid bypass prevents necessity of pulling “wet string” after setting the RLA
20
21
ISA
TIEBACK & POLISHED BORE RECEPTACLE SYSTEM
TIEBACK & POLISHED BORE RECEPTACLE SYSTEM
Tubing Seal Assembly
Dual Flow Assembly
The Tubing Seal Assembly (TSA) is the working seal between formation pressure and the production tubing. The TSA consists of a locator top threaded to match the production tubing connection, seal mandrel, seals or seal units and a half mule shoe guide. The TSA is stung into the Polished Bore Receptacle (PBR), close to the liner top. Proper design of the TSA, seal selection and the PBR are critical to the useful life of the seals and elimination of many of the problems associated with well completions. Integrity of the entire system requires careful planning and consideration of all components used in the completion.
The Dual Flow Assembly (DFA) provides a practical method of completing a well with two tubing strings using Polished Bore Receptacles (PBR). The Dual Flow’s Seal Assembly seals at the top of a liner. The long string side seals inside a lower PBR at a transition point in the liner. The Dual Flow Assembly can also be used in single zone completions for continuous treatment or where intermittent or continual chemical injection is warranted. Alternately the second tubing string could be used as a kill string.
Features and Benefits • Locator threaded to match tubing connection • Variety of seal materials available for compatibility with anticipated well conditions; Viton* / Aramid seal units standard • Mule shoe configuration aids in stabbing and facilitates reentry with wireline equipment • Seal mandrel ID machined to match the production tubing specifications for ID and drift • L80 and Q125 material grades are standard, with other material grades available by special order Tubing Seal Assembly
Features and Benefits • Eliminates hydraulic hold-downs, ratchet rings, and setting pistons found in production packers. • Pressure rating limited by tubing stress not equipment rating. • Equipment is retrieved with straight pick-up; no shear sleeves or jays to manipulate. Equipment Required: • Dual flow head and seal assembly located in the upper PBR of the production liner. • Long side string PBR Seal Assembly stung into the lower PBR of the production liner; the dual flow head assembly is run in on the long side or lower zone tubing - Smith recommends and can supply blast joints and flow couplings. • Short side PBR seal assembly stings into the short side seal bore in the dual flow head. • Upper zone PBR run in the production liner assembly. • Production liner hanger. • Lower zone PBR run in the production liner assembly; a tapered liner with PBR installed at the transition has been illustrated. • Retrievable Landing Assembly (RLA) and tail pipe assembly with profile nipples - the RLA would be run prior to running the Dual Flow Head and lower zone tubing. The RLA is not a requirement.
* Trademark of DuPont Company
Tubing Seal Accessories The Positive Latch Assembly (PLA) is used to latch or anchor tubing seal assemblies in a seal bore. This prevents movement of the seals due to changing well conditions, while withstanding both tensile and compressive forces. Restricted seal movement extends seal life and reduces necessary seal bore lengths. The PLA consists of a top coupling threaded to match the production tubing connection, right-hand release latch and an inner mandrel with a connection down for a seal assembly.
TSA
Features and Benefits • Top connection to match tubing connection, eliminating cross-over sub • Right-hand release latch threads • Designed to uniformly distribute compressive loads into liner top or PBR • ID machined to match the production tubing specifications for ID and drift • L80 and Q125 material grades are standard, with other material grades available by special order
PLA
DFA
22
23
INTEGRATED LINER HANGER PACKER
SETTING TOOLS, SETTING ADAPTORS & ACCESSORIES
Integrated Liner Hanger Packer
Mechanical Release Setting System
Integrated Liner Hanger Packers (LHP) combines a liner top packer with a liner hanger, with the packing element set at the same time the hanger is engaged. LHPs are available in mechanical- or hydraulic- set (HHP) configurations, with or without hold down slips. Mechanical packers feature reliable right-hand setting, while hydraulic packers incorporate debris wiper seals in the piston for dependable performance. Due to their specialized nature, liner hanger packers are recommended for less severe applications.
The Mechanical Release Setting Assembly consists of a Model D Setting Tool, a cementing pack off and liner wiper plug holder. This system is used for conveying nonrotating mechanically or hydraulically-set liner hangers. A tamping dog assembly can be included if running an integral liner packer. The Model D Setting Tool incorporates a right-hand release liner running thread and a spline arrangement below the running threads. These splines permit right-hand setting of mechanical liner hangers. With the splines disengaged, the setting tool is then released without the need to find “neutral”.
Features and Benefits • Packer bodies manufactured from casing of equivalent grade as the liner; L80 and Q125 material grades are standard, with other material grades available by special order • High-grade casing compatible slips manufactured to 55-60 Rockwell “C” • Can be used as a tension-set packer when run inverted
Features and Benefits • Dependable right-hand setting and release of the setting tool from the liner is standard - no left-hand rotation required at any time • Tensile ratings exceed liner hanger hanging capacity with large overpull margins • Setting tool Kelly with bearing below the running nut eliminates the need to find “neutral” to release the setting tool • Spline dogs provide positive torque transmission to the liner and prevent inadvertent release of the setting tool from the liner • Easily adapted with tamping dog assembly for setting integrally run liner top packers without performance loss • Accommodates a variety of cementing pack offs
Applications • The LHP is commonly deployed with sand screens or slotted liners. • The packer is also particularly effective when used with scab liners. • The LHP is used as the bottom packer with a weight-set packer above with casing in between to straddle a damaged section of casing or perforations. Model D/ STL
The Setting Adapter with Tieback Receptacle (SATM) Assembly incorporates the right-hand release liner running thread with a spline arrangement that permits both righthand hanger set and release. A metal-to-metal seal surface between the setting adapter and tieback receptacle provides maximum pressure integrity, while the included Retrievable Cementing Bushing (RCB) seals the annular area between the work string and the liner top. Features and Benefits • Manufactured from heavy-wall tubular alloys with yield strengths matching the liner • Spline system provides positive torque transmission to the liner • Polished bore-type tieback receptacle is standard • Metal-to-metal seal eliminates elastomers • Integral RCB profile
HHP LHP
SATM
24
25
SETTING TOOLS, SETTING ADAPTORS & ACCESSORIES
SETTING TOOLS, SETTING ADAPTORS & ACCESSORIES
Hydraulic Release Setting System
Double Spline Setting System
The Hydraulic Release Setting (STHR) Assembly System consists of a Model STHR Liner Setting Tool, a cementing pack off and liner wiper plug holder for running rotating and non-rotating liner hangers. This is used exclusively with hydraulic release setting adapters. This system is used for conveying rotating mechanical or hydraulic-set liner hangers. A tamping dog assembly can be included if running an integral liner packer.
The Double Spline Setting (STS) assembly consists of a Model STS Liner Setting Tool, a cementing pack off and liner wiper plug holder. This is used exclusively with double spline setting adapters. This system is used for conveying rotating mechanically or hydraulically set liner hangers. A packer dog assembly can be included if running an integral liner packer. The Model STS Liner Setting Tool incorporates the right-hand release liner running thread with a double spline arrangement having approximately 48 inches between the upper and lower splines. These splines permit right hand setting of mechanical-set hangers as well as facilitating liner rotation after the hanger is set.
The Model STHR Setting Tool features a right-hand drive clutch at the top, which provides torque transmission to the liner for rotating and /or drilling down. The setting tool is released by applied hydraulic pressure. This positive, deliberate release method permits drilling down of the liner with the system in compression or tension. After releasing the setting tool the liner is rotated through the right-hand drive clutch.
Features and Benefits • Dependable mechanical right-hand release from the liner • High torque transmission capability through long, heavyduty spline Dogs • 48-inch stroke kelly for determining drill pipe torque independent from liner torque • Right-hand rotation of liners after hanging the rotating liner hanger • Easily adapted with packer tamping dogs for setting integrally run liner top packers without performance loss • Accommodates a variety of cementing pack offs
Features and Benefits • Hydraulic release from the liner with mechanical secondary release • Torque transmitted through a right-hand drive clutch for the most demanding torque requirements • Positive retention system keeps the releasing components locked after actuation - no inadvertent re-engagement. • Right-hand rotation of liners after hanging a rotating liner hanger • Easily adapted with packer tamping dogs for setting integrally run liner top packers without performance loss • Built-in secondary mechanical release
STHR
Model STS
The Hydraulic Release Setting Adapter with Tieback Receptacle (SHTS) Assembly incorporates a hydraulic release liner running thread with an auto-clutch arrangement that permits right-hand hanger setting as well as right-hand rotation. A metal-to-metal seal surface between the setting adapter and tieback receptacle provides maximum pressure integrity, while the included RCB seals the annular area between the work string and the liner top. The SHTS features a back up mechanical release.
The Double Spline Setting Adapter (SSTM) is used exclusively with double spline setting tools. This system is used for conveying rotating mechanical or hydraulic-set liner hangers. The DS incorporates the right-hand release liner running thread with a double spline arrangement having approximately 48 inches between the upper and lower splines. These splines permit right-hand setting of mechanical set hangers as well as facilitating liner rotation after the hanger is set. Features and Benefits • Dependable mechanical right-hand release from the liner. • High torque transmission capability through long, heavyduty spline dogs • 48 inch stroke kelly for determining drill pipe torque independent from liner torque • Right-hand rotation of liners after hanging the rotating liner hanger • Easily adapted with packer tamping dogs for setting integrally run liner top packers without performance loss • Accommodates a variety of cementing pack offs
Features and Benefits • Integral high torque, right-hand autoclutch • Manufactured from heavy-wall tubular alloys with yield strengths matching the liner • Polished bore-type tieback receptacle is standard • Metal-to-metal seal eliminates elastomers • Integral RCB profile
SSTM
SHTS
26
27
SETTING TOOLS, SETTING ADAPTORS & ACCESSORIES
SETTING TOOLS, SETTING ADAPTORS & ACCESSORIES
"Jay" Release Setting System
Setting Tool Extension Assembly
The “Jay” Release Setting assembly consists of a specially configured liner setting adapter and liner setting tool for running relatively short length rotating liner hangers where torque requirements are not strenuous. The system illustrated is Smith’s standard “Jay” system and is used for both mechanically and hydraulically set liner hangers. The liner setting adapter incorporates a “Jay” configuration instead of the running thread normally used in setting adapters. The “Jay” profile can be configured for either left- or right-hand release. The system can also be supplied with double “Jay” arrangement if additional tensile and torque capacities are desired. If a Tieback Receptacle (TBR) is required, the “Jay” Setting Adapter uses the same dependable metal-to metal seal design between the setting adapter and the TBR as with other Smith Services setting systems.
The Setting Tool Extension provides the connection between the liner setting tool and the operator's work string. In most cases the outside diameter of the extension assembly will be the same as the drill pipe used for running the liner, preventing unnecessary loss of rig time. The extension assembly is provided with a box connection to match the drill pipe. Features & Benefits • Heavy wall tubular body manufactured from AISI 4100 series alloy steel. • Assembled with Junk Strainer Assembly to reduce solids fallout into the liner tieback receptacle. • Available in various lengths to complement liner tieback receptacle lengths without "splice" connections to improve performance characteristics and leak resistance.
J–Setting Tool Features and Benefits • “Jay” lugs are an integral part of the setting tool mandrel - no welds to break • Same setting tool used for either right- or left-hand release “Jay” setting adapters • Right-hand rotation of liners after hanging the rotating liner hanger • One quarter-turn for easy removal of the setting tool when liner cementing is completed • Usable with all Smith cementing pack off assemblies • Suitable for use with packer tamping dogs when running integral liner top packers
Model “J”
Tamping Dog Assembly Extension Assembly
J–Setting Adapter Features and Benefits • Quarter-turn machined “Jay” slot configuration for easy release from the liner hanger after setting • L80 and Q125 material grades are standard, with other material grades available by special order • Metal-to-metal seal system for maximum TBR pressure integrity • Easily adapted for use with Retrievable Cementing Bushing assemblies • “Jay” configuration setting adapter can be incorporated into integrally run liner top packers
The Tamping Dog Assembly is used with a liner setting tool to enable "setting" of liner top packers. The tamping dog assembly is installed between the liner setting tool and the extension assembly. When the complete setting tool is assembled with the setting adapter of the packer, the tamping dog assembly is contained within the tieback receptacle (setting sleeve). The dogs are spring loaded to ensure complete extension when the assembly is removed from the tieback receptacle. Work string slack off weight is transferred through the dogs into the tieback receptacle and into the packing element, setting the packer. Features & Benefits • Heavy-duty body manufactured from AISI 4100 series alloy steel. • Tensile rating equal to or greater than the liner setting tool. • Large dogs with machined shoulders for optimum weight transfer to the packer. • Smooth ID matched to liner setting tool and extension assembly for trouble free passage of drill pipe wiper plugs.
SJTM
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Tamping Dog Assembly
CEMENT BUSHING
CEMENT BUSHING
Cementing Pack Offs
Cementing Pack Off Coupling
The Cementing pack off seals the annular area between the work string and the top of the liner. Several different types are used to achieve this seal; their usage is dependent on well conditions and preferences.
The Cementing Pack Off Coupling (POC) is a Polished Bore Receptacle (PBR)-type seal attached to the liner setting tool. It seals into a PBR run in the liner assembly or the tieback receptacle. This seal assembly utilizes one PBR seal unit for premium pressure integrity. Following retrieval, access to the liner is unrestricted.
Retrievable Cementing Bushing
Features and Benefits • Premium PBR sealing system for optimum pressure integrity • Sleeve design permits easy seal size changes to accommodate different seal bore IDs • Elastomer selection available for compatibility with various drilling/wellbore fluids
The Retrievable Cementing Bushing (RCB) is comprised of a body with locking lugs, interior and exterior seals. The bushing seats and locks into a profile machined into the liner setting adapter or a profile sub. A polished OD slick joint completes the assembly. The RCB provides a fully retrievable seal between the liner and the work string.
POC
Features and Benefits • Full circle locking lugs for optimum pressure resistance • Small piston area reduces forces on work string while circulating and cementing • Completely retrievable, leaving full opening to liner below without drilling out
Swab Cup Assembly
Slick Joint Features • Polished OD for maximum sealing integrity and pressure resistance • Reduced diameter to allow retraction of RCB locking lugs • Swivel adapter assembly for liner wiper plug attachment • Available in lengths up to 25 feet
RCB w/ Slick Joint
The Swab Cup Assembly (SWCA) is used in applications that do not require the higher performance capability of a Retrievable Cementing Bushing, Drillable Cementing Bushing or Pack Off coupling. The packer cup assembly uses commercially available swab cups. When assembled to the mandrel, these swab cups are designed to hold pressure in one direction only. The SWCA is run on tail pipe below the setting tool, providing unrestricted access to the liner when retrieved.
Drillable Cementing Bushing The Drillable Cementing Bushing (DCB) performs the same function as the Retrievable Cementing Bushing but must be drilled out to achieve unrestricted access to the liner below. Normally this seal assembly is installed in a separate housing. A polished OD slick joint completes the assembly.
Features and Benefits • Utilizes commercially available swab cups • Field re-dressable without special tools • API end connections allow easy “space out” using standard pup joints
Features and Benefits • Small piston area reduces forces acting on work string during circulating and cementing • Aluminum alloy insert for easy drill out, leaves minimal material in housing when drilled out with full gauge bit or mill • Cemented insert style available in most sizes
SWCA
DCB
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CASING HARDWARE
CASING HARDWARE
Landing Collars
Float Landing Collar
The Landing Collar (LC) acts as a seat and latch for the liner wiper plug, and is normally run one joint above the float collar or float shoe if a float collar is not installed. The LC provides a positive stop for the cementing plugs. This system holds pressure from above and below when the pump down or liner wiper plugs land and latch at the end of cement displacement.
The Float Landing Collar (FLC) combines the features of the landing collar with a float valve, and it is typically used as an economical alternative to separate components, or to reduce shoe track length. Features and Benefits • Threaded or cement-style inserts available • Single or dual poppet valves • All internal parts are PDC drillable • Eliminates float collar and connection • Anti-rotation feature aids drill-out • L80 and Q125 material grades are Standard, with other material grades available by special order
Features and Benefits • Provides the landing seat for cementing plugs • Acts as a backup to the float collar/shoe with the plugs latched and sealed • Threaded or cement style inserts available • All internal parts are PDC drillable • Anti-rotation feature for fast drillout • Housing suitable for all premium connections • L80 and Q125 material grades are standard, with other material grades available by special order LC
Float Shoe and Guide Shoe FLC
The Guide Shoe (GS) aids in running liners by providing a purpose-built guide in place of an open ended liner joint, and are run on screened or slotted liners in place of a float shoe. A cement nose is standard, with bladed bottoms available by special order.
Ball Catch Landing Collar The Ball Catch Landing Collar (BC) is run when any hydraulically-set device is used. The landing collar contains a seat and latch for plugs and a ball seat, pinned to shear at approximately 1,000 psi above the pressure required to set the hanger. After setting the hydraulic hanger, increasing pressure shears the ball seat and re-establishes circulation. Features and Benefits • Threaded or cement style insert • All internal parts are PDC drillable • Acts as a backup to the float collar/shoe with the plug set latched and sealed • Anti-rotation feature for fast drill out • Standard BC incorporates ball seat catch • Shear-out ball seat falls to the bottom of the liner when using dual plug system • Housing suitable for all premium connections • L80 and Q125 material grades are standard, with other material grades available by special order
The Float Shoe (FS) is made up as the first component in a liner assembly. The tool features an insert dart-type poppet valve with elastomer seals cemented into the housing, and includes a standard cement nose, with a bladed bottom available by special order. All internal parts are PDC drillable.
Features and Benefits • Single or dual poppet valves • All internal parts PDC drillable • 80,000 psi through 125,000 psi yield strengths are standard • API RP 10F Category III C compliant • Cement nose standard; bladed bottom available by special order
FS
BC
GS
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CEMENTING EQUIPMENT
CEMENTING EQUIPMENT
Pressure Activated Stage Cementing Valve
Pump Down Plug and Liner Wiper Plug
The Pressure Activated Stage Cementing Valve functions by applied pressure to permit upper stage cementing. Opening is controlled by a piston at the end of first stage cementing. Opening pressure moves an inner sleeve upward aligning the cementing ports. The Stage Cementing Valve is closed by the wiper plug following the second stage cement. The inner sleeve is held in this position by a ratchet type lock ring and pressure integrity is maintained.
The Pump Down Plug and Liner Wiper Plug provide separation between drilling/displacing fluids and the cement slurry when cementing liners. Two plugs are required because of the wide ID difference between the liner and the work string. The Pump Down Plug is released from the cementing manifold at the surface after the cement is pumped. Traveling between the cement and the displacement fluid, it wipes cement from the drill pipe. The pump down plug locks and seals into the liner wiper plug. Together the two plugs function as a single plug.
The Stage Cementing Valve is particularly advantageous when cementing long liners. Waiting time for a conventional opening ball is eliminated and the probability of successful second stage cementing is greatly enhanced.
The Liner Wiper Plug is normally shear pinned to the setting tool and provides the seal bore for the pump down plug. A hollow interior passes cement and fluids. With the pump down plug sealed and latched, the liner wiper plug will shear off, wipe the cement from inside of the liner and keep the cement separate from the displacing fluid. When seated and latched in the landing collar, the plugs prevent back flow of cement. If desired the liner wiper plug can be placed in a plug holder bushing, normally below the liner hanger.
This tool is also useful in cementing liner tieback strings. By placing the Stage Valve above the tieback seal assembly the seals can be left in the tieback receptacle. This eliminates pumping cement past the tieback seals. The Stage Valve is closed by the plug following the cement. Pressure integrity is regained when the inner sleeve is closed and locked. Pressure Activated Stage Cementing Tool
Pump Down Plug
Features and Benefits • Manufactured from alloy steel matching liner grade for optimum performance. • Opening pressure easily adjustable in the field. • Hydraulic opening, mechanical closing for positive, reliable operation. • Inner sleeve locked closed at end of cement placement; cannot be reopened later by full gage tools.
Features and Benefits • Locking system provides back pressure capability when locked and sealed in the landing collar • Elastomer selection for compatibility with today's complex drilling fluids • PDC drillable • Anti-rotation feature reduces drill-out times
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Liner Wiper Plug
CEMENTING EQUIPMENT
CEMENT MANIFOLD
Dual Liner Wiper Plug System The Dual Liner Wiper Plug System (DPS) provides enhanced cement contamination prevention. The DPS uses two PDPC plugs and two LWPC plugs, matched to wipe ahead of and behind the cement column. The system has the same advantages as the traditional lead and following plugs in conventional full string cementing.
Solid Body Cementing Manifold
Features and Benefits • Prevents cement contamination in drill pipe and liners • Locking system provides back pressure capability when locked and sealed in the landing collar • Elastomer selection for compatibility with most drilling fluids • PDC drillable • Anti-rotation feature reduces drill-out times
The Solid Body Cementing Manifold (CMSB) suspends drill pipe weight from the rig elevators while retaining the plug so that it can be released after cementing has been completed. The CMSB also connects the cementing lines to the running string during liner operations, and includes a heavy-duty swivel for easy string manipulation with the cementing lines in place. This swivel mechanism and drill pipe plug retainer are built in below the elevators for unobstructed operation. The CMSB is available with single or dual plug drop capabilities; an optional ball drop assembly is available for use with hydraulic-set liner systems. Features and Benefits • Maximum strength and toughness from quenched and tempered alloy steel construction • Displacement fluid and cement are diverted below or above the plug through an external manifold • Manifold rated to 5,000 PSI working pressure • Available in single or dual plug configuration • Cementing flag sub available for visual indication of drill pipe wiper plug release • Heavy duty swivel permits easy manipulation of the string without having to break down the cementing lines
Plug Drop Assembly
Ball Drop Assembly
CMSB
DPS
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CEMENT MANIFOLD
INNER STRING CIRCULATION TOOLS
Top Drive Cementing Manifold
Inner String Circulation Tools
The Top Drive Cementing Manifold (CMIB) eliminates cement contamination of top drive components by creating a flow path for cement and displacing fluids without passing through the rig’s top drive assembly, making it ideal for cementing liners with a top drive system on the rig. The high capacity CMIB consists of a swivel and an internal bypass manifold with integral ball drop and plug drop assemblies. The one-piece swivel housing eliminates threads, flanges or welds while increasing strength and reducing bending loads imposed on the inlets. Drop mechanisms are self-contained for low maintenance, and feature an independent indicator for each plug or ball dropped. The CMIB can be configured for single plug, single ball drop or dual plug, single ball drop, and is suitable for running and cementing all types of liner systems, including rotating liner systems.
Setting hydraulic tools and controlling circulation can be a problem when running slotted or screened liners, as these liners do not permit conventional circulation methods. For these cases, Smith offers a number of items specifically designed for circulating through an inner string. These components include Ported Swab Cup Assemblies, Tubing Swivels and Ball Catch Subs.
Ported Swab Cup Assembly The Ported Swab Cup Assembly (SWCA) utilizes opposed packer cups between a ported mandrel. This configuration, when combined with a pressure containing device such as the Ball Catch Sub, allows pressure to be directed between the opposed cups. This pressure is then directed to specific hydraulically-actuated devices such as hydraulic-set liner hangers and external casing packers. The Ported SWCA can be positioned to actuate several devices independently and is retrieved with the liner setting tool and work string.
Features and Benefits • High operational capacities: 1,594,000 lbs. hook load, 1,496,000 lbs. at full rated torque of 50,000 ft-lbs; 10,000 PSI working pressure with 4 inch through bore • Flush 13 inch OD profile maximizes rig safety during handling and rotation • Unobstructed bore after plug or ball is dropped • Large flow area accommodates high displacement rates • Anti-rotation tie-off integral to swivel housing • Canister design prevents plugs or balls from floating into drop mechanisms • Torque-keyed connections do not require heavy make-up torques • Reduces cement adhesion with coated and treated internal parts • Pneumatic remote control available as an option • Kelly valve available in upper or lower end of swivel, if desired
Tubing Swivel Ported SWCA
The Tubing Swivel (TS) permits easier make-up or manipulation of the inner string. The swivel bearing assembly functions in both compression and tension. Connection make-up does not “torque” any component below the swivel assembly. In addition to the bearing assemblies, the TS also incorporates mandrel and housing seals to provide needed pressure integrity
Ball Catch Sub The Ball Catch Sub (BCS) is normally used with inner string tools to provide the pressure “seat” to permit activation of one or more pressure actuated components. This tool incorporates a ball seat with shear pins to provide the required shear pressure. After all hydraulic components have been actuated, increased pressure against the ball seat shears the seat pins and circulation is regained. This prevents the necessity of “pulling a wet string”, thus saving drilling fluid and rig time. May be configured to shift with pump down plugs. CMIB
BCS
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TS
DRESS MILL ASSEMBLY
LINER HANGER SYSTEMS
Dress Mill Assembly The Dress Mill Assembly (DMA) is configured to clean out the various IDs at the liner top, such as tieback receptacles and Polished Bore Receptacles. As a minimum configuration the DMA will consist of a pilot mill sized to the liner, a bladed polishing mill and a Stop Sub with a drill pipe box connection. Depending on the liner configuration, the DMA may include one or more spacer tubes for proper mill placement. The various mill surfaces are dressed and ground to dimension to prevent damage to seal surfaces. Retrievable Landing Assembly (RLA) and Retrievable Cementing Bushing (RCB) profiles can be cleaned when a jet sub is incorporated into the assembly. Mills should be run when completions require using the Polished Bore Receptacle (PBR) and / or RLA and RCB profiles. Proper cleaning of a honed receptacle is necessary to ensure a quality seal surface.
Premium Hydraulic/Mechanical Rotating Liner Hanger ( Pocket Slip with FSP Packer)
Features and Benefits • Ground dressing surfaces clean honed bores without damaging seal surfaces. • Drill pipe connections on all components for maximum performance. • Stop sub is dressed to repair any bit damage to the liner top while providing positive indication the mill assembly has worked through the liner top. • Bodies and spacer tubes manufactured from AISI 41XX series alloy steel for durability and toughness.
Pocket Slip Rotating Liner Hanger (available with Non-Rotating Pocket Slip)
Frontier Series Packer
Pump Down Plug
STPR Pocket Slip Setting Tool
Tieback Receptacle
Cement Bushing Profile (PSRT)
Landing Collar FSP Setting Tool
Dual Valve Float Collar
Retrievable Cementing Bushing Slick Joint
DMA
Dual Valve Float Shoe
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Liner Wiper Plug
LINER HANGER SYSTEMS
LINER HANGER SYSTEMS
Heavy Duty Hydraulic Pocket Slip Rotating Liner Hanger with JMPO Liner Top Packer
EZRD Mechanical Set Non-Rotating Liner Hanger with WMPO Liner Top Packer Polished Bore Receptacle
JMPO Liner Top Packer with Integral Setting Adapter SHTS
Retrievable Cement Bushing Profile
Pump Down Plug PWPC
WMPO Liner Top Packer Integral with SATM Setting
Junk Strainer
Junk Strainer STX Drill Pipe Extension Hydraulic Rotating Pocket Slip Liner Hanger HPS
Drill Pipe Extension STX EZRD Non-Rotating Mechanical Set Liner Hanger
Tamping Dogs
DA Tamping Dog
Model D/STL Mechanical Release Tool
Hydraulic Release Tool SHTR
Ball Catch Landing Collar
Landing Collar Retrievable Cement Bushing Profile
Retrievable Cementing Bushing
Slick Joint Double Valve Float Collar
Dual Valve Float Collar
Liner Wiper Plug Liner Wiper Plug LWPC
Dual Valve Float Shoe
Double Valve Float Shoe
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LINER HANGER SYSTEMS
LINER HANGER SYSTEMS
HZDC Hydraulic Non-Rotating Liner Hanger with WMPO Liner Top Packer
Compression Set Isolation Packer (Second Trip)
Polished Bore Receptacle Retrievable Cement Bushing Profile
Tieback Junk Strainer
WMPO Liner Top Packer with Integral Setting Adapter SATM
SATM Setting Adapter
STX Drill Pipe Extension
Junk Strainer
HZDC NonRotating Hydraulic Set Liner Hanger
STX Drill Pipe Extension
DA Tamping Dog Model D/STL Mechanical Release Tool Compression Setting Tool (CLT)
Ball Catch Landing Collar
Model D/STL Mechanical Release Tool
Retrievable Cement Bushing Profile RSJC Slick Joint
LWPC Liner Wiper Plug Double Valve Float Collar
Seal Nipple
Retrievable Cement Bushing
RSJC Slick Joint
Double Valve Float Shoe
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TYPICAL LINER APPLICATIONS
TYPICAL LINER APPLICATIONS
Typical Liner Applications Figure A A standard Pocket Slip (PSH) Liner Hanger installation. Starting at the top, the PSH liner hanger, tieback receptacle and a retrievable cementing bushing (RCB) sub. Figure B The Integral Packer provides the PSH liner hanger with a true one trip liner top packer system. It can be run with or without a tieback receptacle. External and internal bypass allow quicker trip time and higher circulating rates.
Typical Liner Applications (cont.)
Figure H A typical liner is run with an integral packer above the liner hanger. The integral, weight set packer with hold down slips is set after cementing. The packer allows excess cement to be reversed out above the liner top, saving clean out time. Circulating pressures do not affect the formation below the packer. The packer's hold down slips also assist in keeping short, lightweight liners in position until cement is set.
Figure C A standard liner installation. Starting at the top, a setting system with a tieback receptacle, setting adapter with setting thread and RCB profile. The receptacle provides a tieback alternative whether planned or unplanned. A mechanical set liner hanger suspends the liner weight from the intermediate casing. Figure D This profile shows two Smith innovations - Compression Set Packer and the retrievable PBR on an Retrievable Landing Assembly (RLA). The packer is run in a second trip and set to isolate the liner-casing annulus and shut off a liner top leak. The RLA, PBR and tail pipe with tubing profiles are run to isolate the tubing from the liner below. The RLA is completely retrievable, allowing full bore access to the liner below during workover operations. Figure E The Insert Seal Assembly (ISA) uses the same profile used by the RCB offering an economical tubing completion. It provides most of the advantages of a PBR for low pressure applications. After the liner is set and cemented, the profile remains in the top of the liner to accept the ISA. Figure F This diagram shows a wellbore design using the conventional approach to tie back a liner. A tieback receptacle is mounted on top of a PBR having an RLA profile. The hanger below the PBR must be designed to have a burst pressure rating equal to the liner. Figure G At some time in the life of a well it may become necessary to isolate a damaged section of the casing. From the top, the casing patch consists of a weight set Liner Top Packer (with or without holddowns slips), number of joints of liner required, a stage cementing collar, and a Liner Hanger Packer with a guide shoe on bottom. The patch is run on tubing or drill pipe with a mechanical set setting tool with tamping dog assembly.
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TYPICAL LINER APPLICATIONS
TECHNICAL INFORMATION
Typical Liner Applications (cont.)
Elastomer Guide Good seal performance depends on matching materials, properties, and stack design to the demands of the well environment. Temperature, pressure differentials, acids, inhibitors, H S, CO , and other harsh elements dictate seal material selection. Disregarding these factors can shorten the life of the completion and increase costs. Completion Technology provides a wide range of elastomer selections to meet demanding requirements. Smith’s standard Seal Stack is not nitrile based, but is a compounded Viton* pressure ring design with glass-filled Teflon* pressure and adapter rings. Our standard seal designs are capable of withstanding HCl, low concentrations (5% maximum) of H S, C O , and temperatures to 400° F. Viton seals are not recommended where high concentrations of amine corrosion inhibitors are likely to be present. Our standard seal stack is an economical selection suitable for use in both high and low pressure applications where well conditions fall within the conditions outlined above. In order to maintain suitable performance levels, this seal should not leave the seal bore under differential pressure. Aflas** Seal Stacks incorporate Aflas primary pressure rings (replacing the Viton rings on the standard Smith seal arrangement) with secondary pressure rings of glass-filled Teflon and adapter rings offering H S and CO resistance. In addition to temperature ratings up to 450°F these seal assemblies offer good pressure performance, as well as proven chemical resistance to most well fluids, including amine based inhibitors.
“HPHT” High Performance Seal Stack The “HPHT” high performance seal stack utilizes a proprietary blend of Teflon and Carbon that are basically inert materials and maintain a high degree of lubricity. The seals contain an expander that is captured in a groove on the face of the seal body. When conditions, such as the following, require high performance seals Smith's high performance seal stack provides practical solutions. Service Conditions: • 400º F and 15,000 psi • Presence of H S (35% max.) and CO . • Completion and production environments involving amine based corrosion inhibitors. • Seal assembly "stabbing" and removal problems. A dual back-up system is incorporated that is comprised of PEEK*** and Stainless Steel Seal components are as follows: 1. Stainless Steel Back-up 2. PEEK-LLV (Polyetheretherketone) Back-up 3. TFM-FTMM Teflon (Proprietary blend) 4. PTFE-LRC AH Polytetrafluoroetheylene primary seal element
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Teflon Adapter Ring
Teflon Pressure Ring
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Standard Seal Stack
Viton Pressure Ring
"HPHT" High Performance Seal Stack
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TECHNICAL INFORMATION
TECHNICAL INFORMATION
Elastomer Guide (cont.) Special Application Material Smith’s Kalrez* Seal Stacks are similar to the standard seal unit. The primary pressure rings are Kalrez instead of the Viton* material, with other components of Ryton*** and Teflon* as illustrated. Kalrez seals provide proven temperature and chemical resistance, as well as pressure performance. Kalrez has restricted movement and should never be allowed to leave the seal bore.
Ryton*** Adapter Ring
Ryton*** Pressure Ring
Molded Seal Packing Molded seal units of either nitrile or Viton should be specified if you cannot prevent the complete seal assembly from moving out of the polished bore under pressure. These seals are not as easily damaged as chevron style seals. Molded seals are also very resistant to washoff while going in the hole or displacing the hole with packer fluid after spacing out the tubing string. The compounded nitrile seal units are suitable for wells where temperatures do not exceed 275° F, and where H S is totally absent. Low concentrations of HCl will not adversely affect molded nitrile seals. Molded Viton seals are suitable for most well conditions, including low concentrations of H S where temperatures do not exceed 350° F and amine based inhibitors are not used. Molded Seal Material Availability: • Viton* • Aflas** • HSN
Engineering Test Cell Facility Completion Systems’ test cell facility at the Hardy Road campus in Houston, Texas, improves product verification turnaround times by expanding in-house testing capabilities. A broad range of downhole temperatures, pressures and loads can be simulated to meet both industry and customer-specific testing requirements. Testing parameters are fully documented and compliant with the latest industry standards.
Kalrez* Pressure Ring
Summary of Testing Capabilities • Hydrostatic Pressure: 15,000 psi for 9-5/8 inches and smaller sizes. 10,000 psi for larger tools • Nitrogen Pressure: 15,000 psi for 9-5/8 inches and smaller sizes. 10,000 psi for larger tools • Temperature: 450 degrees F • Push: 785,000 lbs. • Pull: 589,000 lbs. • Continuous Rotation: 40 RPM @ 1,450 ft-lbs (variable) with a 200,000 lb. applied load • Static Torque: 50,000 ft-lbs
Teflon Pressure Ring
temperature channels. These results can be stored in the test lab’s database, ready to be burned to a CD for attachment to test reports. All phases of the testing process can also be visually monitored and recorded through two digital cameras mounted within the test cell. Panel to control air, water and nitrogen pressures
Any of the above parameters can be used in combination to provide an accurate simulation of downhole conditions. Safety Features Ensuring the safety of personnel and the environment is of primary concern during testing. Extensive safety checks are performed prior to every test, and entrances to the test chamber are locked during testing. Steel reinforced walls in the control room and the main structure further reduce risk to personnel and property. The test cell features 36-inch conductor casing cemented in place to a depth of 30 feet. Fully sealed 20-inch protective casing is suspended in the test well to prevent the release of test media into the environment. Each piece of equipment being tested is lowered inside the casing below a wellhead to confine test pressures below the surface. Following testing, a water recovery system scavenges any excess test media and processes out contaminants, preventing release into the environment.
Molded Seal Molded Seal
A view inside the cell with a packer in place for a test to be conducted
Molded Seal Packing
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Commitment to Excellence The new high bay test cell facility is another example of Smith Services — Completion Systems’ commitment to provide customers with products that represent the industry benchmark for quality of design, performance and value.
During testing, real time test data may be monitored from the control room, or can be accessed remotely using proprietary software. Test data is digitally recorded on four pressure channels and two
The heat controller with the camera monitor (at top)
TECHNICAL INFORMATION
TECHNICAL INFORMATION
Liner Hanger Data Sheet
Well Summary Sheet Well Summary Sheet Date:
Smith District / Rep.:
Prepared By:
Page ——
Field:
Customer: Casing
Casing
Liner
Size (in.) Weight, (lb / ft) Pipe Grade Nominal ID. (in.) Drift (in.) Thread Inside what hole ID (in.) Top Depth (ft.) (T.V. / Mea.) Depth Bottom (ft.) (T.V. / Mea.) Length (ft.) Deviation Top (deg.) Deviation Bottom (deg.) Burst Requirements (psi) Collapse Requirements (psi) Bottom Hole Temperature (deg. f ) Bottom Hole Pressure (psi) H2S or CO2 % Amounts Mud Weight (lb / gal) Mud Type, Condition (lcm %) Torque Requirement (ft / lbs) General Hole Condition
Seal Assembly Specifications
Planned Hanger Type (hyd. / mech.)
PBR or T.B. Rec. ID (in.)
Planned Liner Setting Pressure (psi)
PBR Receptacle Length (ft.)
Rotation and / or Reciprocation
No. of Seals, Spacing
Landing Collar Setting Pressure (psi)
Expected Tubing Movement (ft.)
Type of Rig
Elastomer Spec. / Required
Treating (yes / no)
Planned Slack-off (lbs.)
Drill Pipe Being Used
Type Requested Setting Type (hyd. / mech.) Pack Off Type Planned Setting Pressure (psi) Planning Setting Weight (lbs.) Planned Overpull Weight (lbs.) Planned Test Pressure (psi)
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Miscellaneous
PBR or T.B. Rec. OD (in.)
Packer Data
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of: ——
Lease:
Comments:
Tieback
Tubing Drill Pipe
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