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7/24/2019 LinerHangersnewCatalog.pdf
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TESTEST SECTION TITLE
7/24/2019 LinerHangersnewCatalog.pdf
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TEST SECTION TITLE
1
Smith Services Completion Systems
Products & Services CatalogQuality StatementSmith Internationals Quality Policy isto - establish a relentless focus onsatisfying customer needs and ex-pectations.
Our quality objectives are to:Provide customers with qualityproducts and services.Make these products and ser-vices available when and where
customers want them.Develop a cost structure that en-ables competitive pricing.Build and maintain a reputationfor absolute trustworthiness.
Health and Safety MissionStatementThe mission of the Smith Inter-national, Inc. Health & Safety De-partment is to educate and in-uence employees to adoptsafety and health policies, practicesand procedures that prevent andrelieve human and economic lossesarising from accidental causes andadverse occupational environmental
health exposures.
Smith Services Completion Systems Products & Services Catalog 1
Planning, Implementing, Evaluation 1
LINER HANGERS
Pocket Slip Liner Hanger System 2
Pocket Slip Setting Tool 3
Benets of the Pocket Slip Design 4
Frontier Series Packer & Accessories 5
Pocket Slip Liner Hanger & Tieback Receptacle Specicatio ns 6-7
Rotating Pocket Slip Liner Hanger 8
EZ Series Mechanical Set Non-Rotating Linger Hanger (EZRD) 9
EZ Series Mechanical Set Non-Rotating Linger Hanger Specications 10
HS Series Hydraulic Set Non-Rotating Liner Hanger (HSDB) 11
HS Series Hydraulic Set Non-Rotating Liner Hanger Specicatio ns 12
LINER TOP PACKERS 13
Long Reach Liner Top Packer 14
Hydraulic-S et Isolatio n Packer 15
Compression- Set Isolation Packer 15
TIEBACK & POLISHED BORE RECEPTACLE SYSTEM
Tieback Seal Nipple 16
Orice Float Collar 16
Tieback Receptacle Specicatio ns 17-18
Polished Bore Receptacle 19
Retrievable Landing Assembly (RLA) 20
Insert Seal Assembly (ISA) 21
Tubing Seal Assembly & Accessori es 22
Dual Flow Assembly (DFA) 23
INTEGRATED LINER HANGER PACKER 24
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
Drillabl e Cement Bushing 30
Cement Pack Off Coupling 31
Swab Cup Assembly 31
CASING HARDWARE
Landing Collars (LC) 32
Ball Catch Landing Collar (BC) 32
Float Landing Collar 33
Float Shoe and Guide Shoe 33
CEMENTING EQUIPMENT
Pressure Activated Stage Cementing Valve 34
Pump Down Plug and Liner Wiper Plug 35
Dual Liner Wiper Plug System 36
CEMENT MANIFOLD
Solid Body Cementing Manifold (CSMB) 37
Top Drive Cementing Manifold (CMIB) 38
INNER STRING CIRCULATION TOOLS 39
Ported Swab Cup Assembly 39
Tubing Swivel 39
Ball Catch Sub 39
DRESS MILL ASSEMBLY 40
LINER HANGER SYSTEMS
Premium Hydraulic/Mechanical Rotating Liner Hanger
(Pocket Slip with FSP Packer) 41
Heavy Duty Hydraulic Pocket Slip Rotating Liner Hanger
with JMPO Liner Top Packer 42
EZRD Mechanical Set Non Rotating Liner Hanger
with WMPO Liner Top Packer 43
HZDC Hydraulic Non Rotating Liner Hanger
with WMPO Liner Top Packer 44
Compression Set Isolatio n Packer (Second Trip) 45
TYPICAL LINER APPLICATIONS 46-48
TECHNICAL INFORMATION
Elastomer Guide 49-50
Engineering Test Cell Facility 51
Liner Hanger Data Sheet 52
Well Summary Sheet 53
TABLE OF CONTENTS
Planning, Implementing, Evaluation
One of Smith's main goals is to provide Customer Satisfaction. This is achieved by three basic but very e
PlanningSelection of Linger HangerSystemSurge & Swab simulationTorque & Drag simulation
EvaluationPlayback simulation using
actual job data for post jobevaluationPost job analysis predictand explain potential jobevaluation
ImplemeReal-time rec
parameters decution
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32
LINER HANGERS
Pocket Slip Liner Hanger System
The Pocket Slip Liner Hanger Systemcombines a premium liner hanger withaccessory items specically designed tomaximize system integrity.
The Pocket Slip Liner Hanger eliminatesmany of the problem features commonto conventional liner hangers: externalslips, slip arms, bow springs, cages, hy-draulic setting cylinders, and more. Thishanger utilizes a special tongue-and-
groove slip design completely recessedwithin the hanger body when run. Ashort body and recessed slips make it"clean running". These features lessenthe possibility of interference with tightspots, liner tops, doglegs, windows ormudline suspension systems - all poten-tial places for conventional liner hangersto encounter problems. Additionally, thePSH system has an enhanced uid owarrangement providing both external andinternal uid bypass. Integral liner run-ning threads eliminate the liner settingadapter, adding to improved uid ow atthe hanger.
ApplicationsRunning liners in damaged or ob-structed wellboresHanging extremely heavy liners inhigh-grade casing, where maximumbite is requiredHanging liners in low-strength, unce-mented, or multi-string casing wherethorough load distribution is critical
Features & Benets
Drive slots in the liner top permit ro- tation while running to orient aroundobstructions (PSHR), also availablewithout the Drive slots for non rota-tion applications (PSH)Heavy-wall tubular alloy steel con-struction designed specically tohang heavy liners; no pressure re-tention included for maximum hang-ing performanceTongue-and-groove slip design com-pletely recesses slips into the toolbody, reducing running interferenceHigh cone angle of slip design reduc-es horizontal slip forces in support-ing casingSlips manufactured to 55-60 Rock-well C hardness for high-gradecasing compatibilityEnhanced uid ow arrangement
permits internal and external uidbypassHanging capacity normally greaterthan the conventional dual cone de-signs of the same sizeExternal and internal uid ow by-pass is optimized by eliminatingclose tieback seal bore clearance
PSHR
The Pocket Slip Setting Tool provides a dualsetting method in most sizes - hydraulic ormechanical setting of the liner hanger. Ei-ther method can be selected when the lineris at setting depth - not an option with con-ventional liner setting tools! The Pocket SlipSetting Tool is designed to positively actuatethe hanger's slips resulting in uniform load-ing. This forceful wedging action eliminatesmany of the problems inherent with prefer-ential or unbalanced slip engagement com-
mon to conventional hangers.
Features and BenetsDual setting method - hydraulic or me-chanical - capability in most sizes.Positive, uniform, controlled slip activa-tionCentralizing system eliminates any po-tential for setting tool binding createdby doglegs - assures easy release of therunning nutSlip activating dogs "locked" into releas-ing position after setting - prevents anyaccidental re-engagementBearing system eliminates the need tond "neutral" to disengage the liner run-ning nutDesigned to augment system bypass byproviding internal ow pathDebris barrier to reduce potential fouling
problems associated with particle falloutabove the liner top
Pocket Slip Setting Tool
STPR
PSH
STP
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LINER HANGERS
54
Reduced Slip Loads Minimize Casing Damage:Most casing damage occurs with a conventional liner hangerbecause of slip setting problems: a shallow cone angle; un-even contact between the slips and the intermediate casing;and asymmetrical, erratically timed slip setting. Smith's PSHprotects casing with a design and a slip-setting method thatdelivers smooth setting and even slip loads every time.
Cone angle:The tongue-and-groove slip design on the PSH has an ef-fective cone angle about twice that of conventional hangers.
This reduces the horizontal slip force (burst pressure) onthe intermediate casing and lowers the collapse load on thehanger body. This design gives increased safety marginsunavailable with any other hanger on the market today.
Slip contact:The tool's slip design and positive setting method ensurecomplete contact with the intermediate casing, from the topto the bottom of the slip. The result is efcient, predictableand uniform transfer of weight to the intermediate casing.Conventional liner hangers tend to preferentially load theslip, reducing the effective slip area and increasing the slipload above the predicted value.
Slip timing:The Smith design overcomes the problem of poor slip tim-ing with carefully synchronized contact between the slipsand casing. Conventional hangers have a tendency for oneslip or set of slips to take weight before the others, causinguneven loading of the intermediate casing and increasing
the potential for liner/casing failure.
Finite Element Analysis:An FEA model was developed to depict the forces for a typi-cal 7" 108,000 lb. liner suspended from a Conventional Lin-er Hanger ( Fig. 1) and the Pocket Slip Liner Hanger ( Fig.2) inside 9-5/8" casing.
Figure 1:For the Conventional hanger, the 9-5/8" casing is stressedto a level of 152,381 psi at the center where the slip is lo-cated. In most cases this stress would exceed the strengthof the casing and there would be permanent deformation atthis point. In reality, the cement behind the casing wouldminimize this deformation but it demonstrates the start ofpossible pipe burst if the cement were not in place.
Figure 2:Shows the pipe stress levels when loaded by the PocketSlip 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 deforma-tion. The advantage of being able to hang long, heavy linersis clearly illustrated.
Benets of the Pocket Slip Design
PSIStress
PSIStress
Figure 1Typical stress distribution in supporting
casing using conventional cone and slip
liner hanger (9 58" casing with 108,000
lbs. liner loading illustrated).
Figure 2Typical stress distribution in supportingcasing using Smith PSH liner hanger(9 58" casing with 108,000 lbs. liner l oading
illustrated).
Frontier Series Packer & Accessories
PSTBR FSP
FSet
T
PSRT PSDT
The PSH Pocket Slip Liner Hanger isavailable with a range of accessoriesdesigned to maximize running perfor-mance, operational exibility and sys-tem integrity.
The Pocket Slip Integral Packer (FSP)adds same-trip isolation capabilities tothe PSHR, with a high-pressure anti-swab element rated up to 10,000 psi at350 F. The packer sets mechanically
with the FSP. The FSP also includes anintegral tieback receptacle, and is avail-able with an integral cementing bushingprole for increased pressure perfor-mance.
The Pocket Slip Tieback Receptacle(PSTBR) honed seal bores to maximizeseal integrity, while bypass ports abovethe seal bore provide bypass area.
The PSTBR is also available with an in-tegral cementing bushing prole for in-creased pressure performance.
Features and BenetsHigh-pressure element rated 10,000psi at 350 degrees FAnti-swab element designSelf-energizing, non-extruding ele-
mentLarge bypass areaTieback ability below the hanger orpackerManufactured from mechanical tub-ing of equivalent liner grade
AccessoriesThe Pocket Slip Retrievable CementingBushing (PSRT) features an RCB pro-le and a honed seal bore to maximizepressure performance. The Pocket SlipDrillable Cementing Bushing (PSDT) in-cludes inserts to provide a seal betweenthe setting tool slick joint and housing,and leave minimal core when drilled outwith full gauge bits or mills.
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LINER HANGERS
76
Pocket Slip Liner Hanger & Tieback Receptacle Specications
Size Hanger Tieback
Liner x
CasingCasing OD ID OD ID
(in.)(mm)
(lb/ft)(kg/M)
(in.)(mm)
(in.)(mm)
(in.)(mm)
(in.)(mm)
3 x 5
88.9 x
127.0
11.50
17.30
4.30
109.22
3.60
91.44
4.12
104.65
3.50
88.90
13.00
19.30
4.25
107.95 3.47
88.14
4.00
101.60
3.375
85.7315.00
22.30
4.17
105.92
18.00
26.80
4.03
102.36
3.33
84.58
3 x 5
88.9 x
139.7
14.00
20.80
4.76
120.90
3.93
99.82 4.25
107.95
3.75
95.25
15.50
23.10
4.70
119.38
17.00
25.30
4.63
117.60
20.00
29.30
4.53
115.06
3.83
97.28
23.00
34.20
4.43
112.52
3.60
91.44
4.00
101.60
3.50
88.90
23.80
35.40
4.37
111.00
26.00
38.70
4.30
109.22
4 x 5
101.6 x
127.0
11.50
17.10
4.30
109.22
3.47
88.14
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
4 x 5
101.6 x
139.7
14.00
20.80
4.76
120.90
4.06
103.12 4.50
114.30
3.97
100.84
15.50
23.10
4.70
119.38
4.00
101.60
3.91
99.31
17.00
25.30
4.63
117.60
3.83
97.28
20.00
29.30
4.53
115.06
3.83
97.28
23.00
34.20
4.43
112.52
3.60
91.44
23.80
35.40
4.37
111.00
26.00
38.70
4.30
109.22
Size Hanger Tieback
Liner x
CasingCasing OD ID OD ID
(in.)(mm)
(lb/ft)(kg/M)
(in.)(mm)
(in.)(mm)
(in.)(mm)
(in.)(mm)
4 x 5
114.3 x
139.7
14
20.8
4.76
120.90
4.06
103.12
15.5
23.1
4.70
119.38
4.00
101.60
17
25.3
4.63
117.60
3.83
99.82
20
29.3
4.53
115.06
3.83
97.28
4 x 7
114.3 x
177.8
17.0 - 20.0
25.3 - 29.8
6.21
157.73
5.12
130.05
5.75
146.05
5.00
127.00
or
4.75
120.65
23.0 - 26.0
34.2 - 36.7
6.03
153.16
29
43.2
5.95
151.13
32.0 - 35.0
47.6 - 52.1
5.78
146.81 4.87
123.7
5.50
139.7
4.75
120.6538
56.5
5.70
144.78
5 x 7
127.0 x
177.8
17.0 - 20.0
25.3 - 29.8
6.21
157.73
5.12
130.05
5.75
146.05
5.00
127.00
23.0 - 26.0
34.2 - 36.7
6.03
153.16
29
43.2
5.95
151.13
32.0 - 35.0
47.6 - 52.1
5.78
146.81 4.87
123.7
5.50
139.7
4.75
120.6538
56.5
5.70
144.78
5 x 7
127.0 x
193.8
24.0 - 29.7
35.7 - 44.2
6.62
168.15 5.62
142.75
6.25
158.75
5.50
139.7033.7 - 39.0
50.1 - 58.0
6.43
163.32
42.8 - 45.3
63.7 - 67.4
6.18
156.97
5.25
133.35
5.87
149.10
5.125
130.18
5 x 7
139.7 x
177.8
17.0 - 20.0
25.3 - 29.8
6.21
157.73
5.12
130.05
23.0 - 26.0
34.2 - 36.7
6.03
153.16
29
43.2
5.95
151.13
32.0 - 35.0
47.6 - 52.1
5.78
146.81 4.87
123.738
56.5
5.70
144.78
Size Hanger Tieback
Liner xCasing
Casing OD ID OD ID
(in.)(mm)
(lb/ft)(kg/M)
(in.)(mm)
(in.)(mm)
(in.)(mm)
(in.)(mm)
5 x 7 139.7 x193.7
24.0 - 29.735.7 - 44.2
6.62168.15 5.62
142.746.25
158.755.50
139.733.7 - 39.050.1 - 58.0
6.43163.32
42.8 - 45.3
63.7 - 67.4
6.18
156.97
5.25
133.35
7 x 9 177.8 x244.5
32.3 - 40.048.1 - 59.5
8.50215.9
7.31185.67
8.00203.2
7.125180.9
or7.25
184.15
40.0 - 47.059.5 - 69.9
8.37212.6
47.0 - 53.569.9 - 79.6
8.25209.55
58.486.9
8.12206.25
7.12180.84
7.87199.9
7.00177.8
7 x 10 177.8 x273.0
40.5 - 45.560.3 - 67.7
9.62244.35
8.00203.2
8.50215.9
7.375187.3
51.5 - 55.576.6 - 82.6
9.43239.52
60.7 - 65.790.3 - 97.8
9.25234.95
7 x 9 193.7 x244.5and
7 x 9 196.85 x
244.5
32.3 - 40.048.1 - 59.5
8.50215.9
7.31185.67
8.00203.2
7.250184.15
40.0 - 47.059.5 - 69.9
8.37212.6
47.0 - 53.569.9 - 79.6
8.25209.55
58.486.9
8.12206.25
7.12180.84
7 x 10 193.7 x273.0
40.5 - 45.560.3 - 67.7
9.62244.35
8.00203.2
8.75222.25
7.75196.85
51.5 - 55.576.6 - 82.6
9.43239.52
60.7 - 65.790.3 - 97.8
9.25234.95
9 x11
244.5 x298.5
60.0 - 65.089.3 - 96.7
10.38263.65
9.38238.25
10.00254.00
9.25234.95
Pocket Slip Liner Hanger & Tieback Receptacle Specic
Size Hanger
Liner x Cas-
ingCasing OD ID
(in.)(mm)
(lb/ft)(kg/M)
(in.)(mm)
(in.)(mm)
((m
9 x 13
244.5 x 339.7
48.071.4
12.30312.42
10.70
271.78
1
29
54.581.1
12.20309.88
61.090.8
12.10307.34
68.0 - 72.0101.2 - 107.1
12.04305.82
10 x 13 244.5 x 339.7
48.071.4
12.30312.42
10.70271.78
129
54.581.1
12.20309.88
61.090.8
12.10307.34
68.0 - 72.0101.2 - 107.1
12.04305.82
11 x 13
298.5 x 339.7
48.071.4
12.30312.42
10.70
271.78
54.581.1
12.20309.88
61.090.8
12.10307.34
68.0 - 72.0101.2 - 107.1
12.04305.82
13 x 16339.7 x 406.4
55.0 - 70.081.8 - 104.2
14.75374.65
12.75323.85
134
75.0 - 84.0111.6 - 125.0
14.53369.06
109.0 - 118.0162.2 - 175.6
14.16359.66
146.0217.2
13.62345.95
12.00304.8
16 x 20
406.4 x 508.0
94.0 - 106.5139.9 - 158.5
18.37466.6
16.12
409.45
1
4
117.0 - 133.0174.1 - 197.9
18.12460.25
147.0218.7
18.06458.72
169251.5
17.93455.42
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LINER HANGERS
98
The Rotating Pocket Slip Liner Hanger delivers unmatched ro-tating performance by combining the slip design of the PocketSlip Hanger with an inner mandrel supported by a cylindricalroller bearing. The Rotating Pocket Slip Liner Hanger can becongured with a spacer sleeve in place of the bearing assemblyto deliver the same exceptional hanging capacities and minimalcasing loading characteristics for non-rotating applications.
The unique tongue-and-groove slip design minimizes runninginterference 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 hang-ers, reducing burst pressure exerted on casing and allowinglonger, heavier liners to be run on multi-string or uncementedcasing.
The Rotating Pocket Slip Liner Hanger is set either mechanically(RPSM) or Hydraulically (HPS).
Other components required for liner rotation are the setting tooland the setting adapter. Hydraulic release (SHTR) and DoubleSpline (STS) setting tool provide the most exibility.
MECHANICAL SET ROTATING POCKET SLIP LINERHANGER FEATURES:
Bodies are manufactured from mechanical tubing to equiv-alent grade of the liner. 80,000 psi and 110,000 psi yieldstrengths are standard. Other yield strengths and materi-als available on request.Pocket Slip design eliminates cone collapse common toconventional rotating liner hangers.
Reduced slip loads minimize stresses in supporting casing. Inner surface of cone coated with low friction materials foroptimal performanceDependable right hand setting is standard.Slips are manufactured to Rockwell "C" scale hardness of55 to 60 for use in the highest grade casing strings.
HYDRAULIC SET ROTATING POCKET SLIP LINER HANGERFEATURES:
Pocket slip design eliminates cone collapse while providingan effective cone angle twice than the conventional hang-ersSlips are manufactured to 55-60 Rockwell C hardness forhigh-grade casing compatibilityCylindrical roller bearing can be replaced with a spacersleeve when rotation is not requiredManufactured from mechanical tubing of equivalent linergrade; 80,000 psi through 125,000 psi yields are standard,with other yield strengths and materials available by spe-cial order
Reduces slip loads minimizes stresses in supporting casing Right hand rotation of liner after hanging and during ce-menting
Rotating Pocket Slip Liner Hanger
EZ Series Liner Hangers is one of the most reli-able and efcient Mechanical Set Liner Hangers,as it is comprised of the hanger body or mandrelone or more sets of cone pads, slips and a cageassembly to carry the slips. The cage containsa J slot and drag springs to control the move-ment of the slips into contact with the cones.A lug on the hanger body controls the cage Jslot. A gage ring protects the slips when run-ning the hanger into the wellbore.
Non-Rotating Mechanical Set (EZ) Liner Hang-ers are set through manipulation of the workstring: quarter right hand turn aligns the conesand the slips, after which slack off sets the slipsinto the casing wall
Features and BenetsCasing body hanger is manufactured fromL-80 and P-110 casing grades with othergrades available by special order.Single or multiple cone designs available tomatch hanging capacity with liner strength,minimizing stress in supporting casing.Slips manufactured to 55-60 Rockwell Cscale for high grade casing compatibility.The EZ Hanger is available with either cas-ing or heavy-wall tubing construction;
casing body hangerCone pads, J lug, and gauge rings arewelded to the tool body. Solid body hang-
ers include these parts as integral featuresmachined from the heavy-wall tool body,eliminating body welding and maximizingperformance.Solid Body hangers are machined from AISI4100 Series alloy steel with controlled yieldstrengths and hardness for liner compat-ibility.A full OD permits the matching of somepremium threads on the hanger body.
EZ Series Mechanical Set Non-Rotating Liner Hange
EZ
HPSRPSM
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LINER HANGERS
1110
SizeMax.OD
Liner x Casing Casing
(in.)(mm)
(lb/ft)(kg/M)
(in.)(mm)
2 x 575.03 x 127.0
13.0 - 18.019.63 - 26.8
4.08103.63
20.3 - 24.230.2 - 36.0
3.8196.77
3 x 588.9 x 127.0
11.5 - 13.017.3 - 19.3
4.25107.95
15.0 - 18.022.3 - 26.8
4.08103.63
3 x 5 88.9 x 139.7
14.0 - 17.020.8 - 25.3
4.68118.87
20.0 - 23.029.8 - 34.2
4.45113.03
4 x 5 101.6 x 139.7
14.0 - 17.020.8 - 25.3
4.68118.87
4 x 7114.3 x 117.8
17.0 - 26.025.3 - 38.7
6.05153.67
29.0 - 38.043.2 - 56.5
5.68144.27
5 x 7127.0 x 177.8
17.0 - 20.025.3 - 29.8
6.18156.97
23.0 - 26.034.2 - 38.7
6.05153.67
29.0 - 32.043.2 - 47.6 5.87149.10
35.0 - 38.052.1 - 56.5
5.68144.27
5 x 7 127.0 x 193.8
24.0 - 29.735.7 - 44.19
6.50165.10
33.7 - 39.050.1 - 58.0
6.25158.75
5 x 7139.7 x 177.8
17.0 - 20.025.3 - 29.8
6.21157.73
23.0 - 26.034.2 - 38.7
6.05153.67
SizeMax.OD
Liner x Casing Casing
(in.)(mm)
(lb/ft)(kg/M)
(in.)(mm)
5 x 7 139.7 x 193.8
24.0 - 29.735.7 - 44.19
6.62168.15
33.7 - 39.050.1 - 58.0
6.37161.80
7 x 9 177.8 x 244.5
32.3048.06
8.68220.47
36.0 - 43.553.57 - 64.73
8.43214.12
47.0 - 53.569.93 - 79.61
8.25209.55
7 x 9 193.67 x 244.5
and7 x 9
196.85 x 244.5
32.3048.06
8.68220.47
36.0 - 43.553.57 - 64.73
8.50215.90
47.0 - 53.569.93 - 79.61
8.31211.07
9 x 11 244.5 x 298.45
42.062.50
10.81274.57
47.0 - 54.069.93 - 80.35
10.62269.75
60.0 - 65.089.28 - 96.72
10.43264.92
9 x 13 244.5 x 339.73
48.071.42 12.25311.15
54.5 - 68.081.09 - 101.18
12.00304.80
72.0 - 85.0107.14 - 126.48
11.75298.45
10 x 13 273.05 x 339.73
48.071.42
12.37314.20
54.5 - 68.081.09 - 101.18
12.12307.85
72.0 - 85.0107.14 - 126.48
11.87301.50
HS Series Liner Hangers is one of the mostrobust Hydraulic Set Liner Hangers, as itis comprised of the hanger body or man-drel one or more sets of cone pads, slipsand a hydraulic piston/cylinder assemblyto actuate the slips. The hydraulic piston/hydraulic is shear pinned to actuate at apredetermined value. The hydraulic cyl-inder also incorporates the gage ring toprotect the slip assembly when runningthe hanger assembly into the wellbore.
Features and BenetsCasing body hanger is manufacturedfrom L-80 and P-110 casing gradeswith other grades available by specialorder.Hydraulic Cylinder manufactured frommaterial matching yield strength ofthe liner hanger.Hydraulic piston incorporates debriswiper seal and anti rotation system tomaintain slip/cone alignment.Slips manufactured to 55-60 Rockwell
C scale for high grade casing com-patibility.The HSDB hanger is available with ei-ther casing or heavy-wall tubing con-struction; casing body hanger Conepads, are welded to the tool body,while Solid body hangers include
these parts as integral features ma-chined from the heavy-wall tool body,eliminating body welding and maxi-mizing performance.Solid Body hangers are machinedfrom AISI 4100 Series alloy steel withcontrolled yield strengths and hard-ness for liner compatibility.A full OD permits the matching ofsome premium threads on the hangerbody.
HS Series Hydraulic Set Non-Rotating Liner HangeEZ Series Mechanical Set Non-Rotating
Liner Hanger Specications
HSDB
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LINLINER HANGERS
1312
SizeMax.OD
Liner x Casing Casing
(in.)(mm)
(lb/ft)(kg/M)
(in.)(mm)
2 x 575.03 x 127.0
13.0 - 18.019.63 - 26.8
4.08103.63
20.3 - 24.230.2 - 36.0
3.8196.77
3 x 588.9 x 127.0
11.5 - 13.017.3 - 19.3
4.25107.95
15.0 - 18.022.3 - 26.8
4.08103.63
3 x 5 88.9 x 139.7
14.0 - 17.020.8 - 25.3
4.68118.87
20.0 - 23.029.8 - 34.2
4.45113.03
4 x 5 101.6 x 139.7
14.0 - 17.020.8 - 25.3
4.68118.87
4 x 7114.3 x 117.8
17.0 - 26.025.3 - 38.7
6.05153.67
29.0 - 38.043.2 - 56.5
5.68144.27
5 x 7127.0 x 177.8
17.0 - 20.025.3 - 29.8
6.18156.97
23.0 - 26.034.2 - 38.7
6.05153.67
29.0 - 32.0
43.2 - 47.6
5.87
149.10
35.0 - 38.052.1 - 56.5
5.68144.27
5 x 7 127.0 x 193.8
24.0 - 29.735.7 - 44.19
6.50165.10
33.7 - 39.050.1 - 58.0
6.25158.75
5 x 7139.7 x 177.8
17.0 - 20.025.3 - 29.8
6.21157.73
23.0 - 26.034.2 - 38.7
6.05153.67
SizeMax.OD
Liner x Casing Casing
(in.)(mm)
(lb/ft)(kg/M)
(in.)(mm)
5 x 7 139.7 x 193.8
24.0 - 29.735.7 - 44.19
6.62168.15
33.7 - 39.050.1 - 58.0
6.37161.80
7 x 9 177.8 x 244.5
32.3048.06
8.68220.47
36.0 - 43.553.57 - 64.73
8.43214.12
47.0 - 53.569.93 - 79.61
8.25209.55
7 x 9 193.67 x 244.5
and7 x 9
196.85 x 244.5
32.3048.06
8.68220.47
36.0 - 43.553.57 - 64.73
8.50215.90
47.0 - 53.569.93 - 79.61
8.31211.07
9 x 11 244.5 x 298.45
42.062.50
10.81274.57
47.0 - 54.069.93 - 80.35
10.62269.75
60.0 - 65.089.28 - 96.72
10.43264.92
9 x 13 244.5 x 339.73
48.0
71.42
12.25
311.15
54.5 - 68.081.09 - 101.18
12.00304.80
72.0 - 85.0107.14 - 126.48
11.75298.45
10 x 13 273.05 x 339.73
48.071.42
12.37314.20
54.5 - 68.081.09 - 101.18
12.12307.85
72.0 - 85.0107.14 - 126.48
11.87301.50
HS Series Hydraulic Set Non-Rotating
Liner Hanger Specications Liner Top Packers are run as an integral partof the original liner string, replacing the linersetting adapter. Liner top packers consist of aTieback Receptacle, a setting adapter appro-priate to the setting tool used and a packerelement used to seal the annulus. Designedto be set after the liner is cemented, thepacker is set by picking up the running string,placing the tamping dogs in the setting toolassembly above the liner top and slacking offweight. Excess cement above the liner topcan be circulated out after the packer is set.
Liner top packers are available in thefollowing congurations:
WMP- for use with Model D setting toolJMP- for use with Model STHR settingtoolVMP- for use with Model STS setting tool
Holds down slips are available as special or-der for all packer types.
Features and BenetsOptimizes chemical resistance to comple-tion and production uids with a varietyof elastomer options for packer elementsand seal assemblies.Maintains element setting with mandrellock ring.Facilitates high circulating rates with en-
hanced packer element design.Eliminates extra components and connec-tions with integral retrievable cementingbushing proleAvailable with optional hold down slipsfor use with light weight linersHigh-grade casing compatible slips manu-factured to 55-60 Rockwell C hardnessL80 and Q125 material grades are stan-dard, with other material grades avail-able by special order
Liner Top Packers
WMP w/oHold Down
Slips
WMP w/Hold Down Sli
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LINLINER TOP PACKERS
1514
The Long Reach Liner Top Packer (LRTP) fa-cilitates successful liner deployment in verticaland long reach horizontal wellbores. Hydraulic-setting, combined with push, pull and rotationcapabilities allow controlled liner deploymentwithout excessive work string manipulation.Ease of deployment is further enhanced by aninternal bypass included in the packer and theLong Reach Setting Tool (LRST) reducing pistoneffect during running. The packer features aninternal circulating string for wellbore uid dis-placement where required. Packer elements areavailable with standard or thermal elastomericconstruction for use in steam injection applica-tions.
Features and BenetsPush, pull and rotation capabilities facilitateliner deploymentHydraulic primary release reduces workstring manipulation and eliminates stringweight requirementsSecondary mechanical release. One quarterleft hand turn shears pins; straight pick-upreleases packerDesigned to accept inner string circulatingaccessoriesInternal bypass feature reduces piston ef-fectAvailable with or without slips for hangingand hold down applicationsPacker can be manufactured to match casingthread, eliminating liner crossover
ApplicationsRunning liners in long reach horizontal wellsSetting sand screens in open hole below alinerApplications requiring extended drill down ofthe linerRunning conditions where the liner may needto be pushed or jarred to bottomHanging light weight liners when a conven-tional inner hanger is not necessaryApplications in which the liner is eitherdropped off or needs to be hung and helddownArchitectures in which additional bypass areais required for minimizing lost circulation, orfacilitating faster running speeds
Long Reach Liner Top Packer
The Hydraulic-set Isolation Packer (HLT) is run on a second trip toisolate leaks at the liner top. Hydraulic-setting is benecial in highlydeviated wellbores where adequate slack-off force cannot be ap-plied. The HLT is used after the liner has been run, cemented andthe liner tieback receptacle seal bore cleaned out. The HLT sealsinto the existing liner tieback receptacle and is set with a hydraulic-setting tool, sealing the annular area between the liner and casing.It also provides a new tieback receptacle for future operations.
Features and BenetsSets with hydraulic pressure applied to setting tool for uniformsetting forceEliminates transfer of setting weight to the linerOptimizes chemical resistance to completion and production u-ids with a variety of elastomer options for packer elements andseal assembliesMaintains element setting with mandrel lock ringDual slips prevent movement of packerHigh-grade casing compatible slips manufactured to 55-60 Rock-well C hardnessL80 and Q125 material grades are standard, with other materialgrades available by special order
Compression-Set Isolation PackerThe Compression Set Isolation Packer (CLT / CLTP) is run on a sec-ond trip to isolate leaks at the liner top. The CLT is used after theliner has been run, cemented and the liner tieback receptacle sealbore cleaned out.
The CLT seals into the existing liner ti eback receptacle and is set withcompression, sealing the annular area between the liner and casing.It also provides a new tieback receptacle for future operations. TheCLTP includes the same features as the CLT, but is designed for usewith pocket slip liner systems.
Features and BenetsAn anti-trip safety lock ring prevents premature settingOptimizes chemical resistance to completion and production u-ids with a variety of elastomer options for packer elements andseal assembliesMaintains element setting with mandrel lock ringHold down slips prevent upward movement of packerHigh-grade casing compatible slips manufactured to 55-60 Rock-well C hardness
L80 and Q125 material grades are standard, with other material grades available by special orderAvailable for Pocket Slip Liner Systems (CLTP)
Hydraulic-Set Isolation Packer
HLT
LRTP w/StandardElement
LRST
LRTP w/ThermalElement
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TIEBACK & POLISHED BORE RECETIEBACK & POLISHED BORE RECEPTACLE SYSTEM
1716
Tieback liners provide a new casing string tocover intermediate casing worn by drilling orcorrosion, protect a weak casing string fromshut-in or excessive production pressure or toisolate a leaking liner top. A typical tieback linersystem includes a Tieback Seal Nipple (TSN),Orice Float Collar (OFC) and an existing LinerTieback Receptacle (TBR). The TSN consists ofa locator, seal mandrel, seals or seal units and ahalf mule shoe bottom. This assembly is madeup to the tieback string and is landed into theexisting TBR.
Features and BenetsLocator threaded to match tieback liner /casing connectionVariety of seal materials available for com-patibility with anticipated well conditions;Viton* / Aramid seal units standardMule shoe conguration aids in stabbingand facilitates re-entry with wireline equip-mentOptional cementing ports availableL80 and Q125 material grades are stan-dard, with other material grades availableby special order
* Trademark of DuPont Company
Orice Float CollarThe Orice Float Collar (OFC) reduces lost rigtime and drilling uids by allowing the tiebackliner / casing to ll as it is run. In addition, whenthe Tieback Seal Nipple (TSN) enters the tie-back receptacle, displaced uids ow throughthe orice, preventing a pressure lock duringstabbing. The OFC is normally run one to two
joints above the TSN and provides a stop forthe cementing plug.
Features and BenetsSingle poppet valve standardAll internal parts are PDC drillableOrice port allows tieback liner to ll duringrun-inOrice prevents pressure lock by providinga uid pathL80 and Q125 material grades are stan-dard, with other material grades available
by special order
Tieback Seal Nipple
OFC
TBR
TSN
Tieback Receptacle Specications
Size Tieback
Liner x Casing Casing OD ID
(in.)
(mm)
(lb/ft)
(kg/M)
(in.)
(mm)
(in.)
(mm)
3
88.9x
5
139.7
1420.8
4.375111.25
3.7595.25
1522.3
17
25.3
2029.8
2334.2
2638.7
4101.6
x5
139.7
1420.8
4.625117.60
4.125104.78
1522.3
1725.3
4
114.3x7
177.8
2029.8
5.625143.00
5.00127.00
23
34.2
2638.7
2943.2
32
47.6
3552.1
38
56.5
Size Tieback
Liner x Casing Casing OD ID
(in.)
(mm)
(lb/ft)
(kg/M)
(in.)
(mm)
(in.)
(mm)
5127.0
x7
177.8
2029.8
5.82
147.82
5.25
133.35
2334.2
26
38.7
2943.2
3247.6
3552.1
5.625
143.00
5.125
130.1838
56.5
5127.0
x7
193.7
2435.7
5.82147.82
5.25133.35
26.439.3
29.744.2
33.7
50.1
3958.0
55.382.3
5127.0
x7
193.7
24
35.7
6.25
158.75
5.25
133.35
26.439.3
29.7
44.2
33.750.1
39
58.0
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TIEBACK & POLISHED BORE RECETIEBACK & POLISHED BORE RECEPTACLE SYSTEM
1918
Tieback Receptacle Specications
Size Tieback
Liner x Casing Casing OD ID
(in.)
(mm)
(lb/ft)
(kg/M)
(in.)
(mm)
(in.)
(mm)
5
139.7
x
7
177.8
20
29.8
6.06
153.92
5.562
141.27
23
34.2
26
38.7
5
139.7
x
7
193.7
24
35.7
6.38
162.05
5.75
146.05
26.4
39.3
29.7
44.2
33.7
50.1
39
58.0
7
177.8
x
9
244.5
32
47.6
8.25
209.557.375
36
53.6
40
59.5
43
64.0
47
66.9
53.5
79.6
53.5 SD
79.6
58
86.30
8.12
206.25
7.375
187.33
Size Tieback
Liner x Casing Casing OD ID
(in.)
(mm)
(lb/ft)
(kg/M)
(in.)
(mm)
(in.)
(mm)
7
193.7
x
9
244.5
32
47.6
8.38
212.85
7.75
196.85
36
53.6
40
59.5
43
64.0
47
69.9
53.5
79.68.25
209.55
7.75
196.8553.5 SD
79.6
9
244.5
x
11
298.5
42
62.5
10.38
263.65
9.875
250.83
47
69.9
54
80.4
60
89.3
65
96.7
9
244.5
x
13
339.7
48
71.4
11.5
292.10
10.375
263.53
54
80.4
61
90.8
68
101.2
72
107.1
77
114.6
85
126.5
The Polished Bore Receptacle (PBR) provides a honed IDsealing surface for a production tubing seal assembly.The PBR may be used in lieu of a production packer andis typically run integrally with the production liner. PBRlength is determined by analysis of the production tubingmovement during various situations such as stimulation,production and well shut-in.
Features and BenetsHoned ID reduces potential seal damaging expansion or contractionThick wall construction permits machinmium threads on the body, eliminating One-piece construction eliminates ppathsAvailable in lengths of up to 30 feet connections or concentric couplings forsure integrity and seal performanceAdaptable with a Retrievable Landing Ale sub for adding prole nipples or otequipment to the completionL-80 and P-110 material grades are sother grades available by request
Polished Bore Receptacle
PBR Sizes
ID ODMax. 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
Specications
PBR
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TIEBACK & POLISHED BORE RECEPTACLE SYSTEM TIEBACK & POLISHED BORE REC
2120
The Retrievable Landing Assembly (RLA) is used tosuspend tailpipe and prole nipples when using a Pol-ished Bore Receptacle (PBR) completion, enhancingexibility by providing a method to temporarily iso-late the producing zone. The assembly locks into theprole of a previously run PBR and allows productiontubing to be pulled without killing the well or dumpingdamaging uids on the formation.
The RLA also permits placing bottom-hole pressuregauges, chokes, plugs or other wireline tools belowthe tubing. Additional versatility is gained by installing
a smaller ID PBR on top of an RLA, providing a re-duced piston area for PBR completions with small ODproduction tubing in a larger casing ID. Reducing thepiston area allows higher differential pressures with-out tubing damage. The RLA is run after the liner andPBR are cemented in the well and cleaned out. TheRLA and tailpipe are run to setting depth on a workstring and hydraulically or mechanically set with thedual method setting tool. The work string and settingtool are retrieved and production tubing is run.
If it becomes necessary to re-enter the liner with fullgauge tools, the tubing is pulled and the RLA is re-trieved with a specially designed retrieving tool. Withthe RLA removed, the liner is unrestricted.
Features and BenetsL80 and Q125 material grades are standard, withother material grades available by special orderInternal, positive locking setting sleeve cannot beaccidentally released by wireline toolsLocking lug system suitable for differential pres-sures as high as 10,000 psiTop and bottom locating designs permit usage atthe bottom of a PBR or at the upper end of a PBRfor completion design exibilityViton* / Aramid seal units are standard. A vari-ety of seal materials are available for compatibilitywith anticipated well conditions; see the Elasto-mer Guide for these materialsRedundant seal system provides increased systemreliabilityEasily adapted with a reduced ID PBR above theRLA for reduced piston area when using smaller IDproduction tubing strings
* Trademark of DuPont Company
RLA Setting Tool Features and BenetsCombined hydraulic or mechanical setting for op-
timum exibilityRight-hand release running threadFluid bypass prevents necessity of pulling wetstring after setting the RLA
Retrievable Landing Assembly
RLA
The Insert Seal Assembly (ISA) is designed toset, seal and lock into an existing RetrievableCementing Bushing (RCB) or Retrievable Land-ing Assembly (RLA) prole in the production linerassembly. This provides an economical tool forcompletions that does not require prole nipplesfor isolation of the producing interval when tub-ing is pulled for maintenance.
The ISA consists of a body with internal and ex-ternal seals, a locking lug arrangement and aoating, polished OD slick joint that connects to
the production tubing. The assembly is lockedinto the receiving prole by the slick joint. A re-duced OD section of the slick joint permits the as-sembly to be stabbed into the prole and lockedby ve to six right-hand rotations, releasing theslick joint from the body and moving the lugsinto the locked position. Once seated, the slick
joint is free to move within the full OD length.Slick joint length is determined by tubing move-ment in reaction to well conditions.To re-enter the liner with full gauge tools, theISA is retrieved by straight pick up of the pro-duction tubing. This places the reduced sectionof the slick joint under the locking lugs, permit-ting retrieval. The liner is unrestricted followingremoval of the ISA.
Features and BenetsReduces completion costs by utilizing an ex-isting RCB prole in the production liner as-semblyReduced piston area minimizes tubingstressRight-hand set / straight pull releaseSlick joint retention system prevents acci-dental re-engagementL80 and Q125 material grades are standard,with other material grades available by spe-cial orderBroad range of seal materials available forcompatibility with anticipated well condi-tions; Viton* / Aramid seal units are stan-dard
* Trademark of DuPont Company
Insert Seal Assembly
ISA
RLASetting Tool
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TIEBACK & POLISHED BORE RECETIEBACK & POLISHED BORE RECEPTACLE SYSTEM
2322
The Tubing Seal Assembly (TSA) is the working seal betweenformation pressure and the production tubing. The TSA con-sists of a locator top threaded to match the production tubingconnection, seal mandrel, seals or seal units and a half muleshoe guide. The TSA is stung into the Polished Bore Receptacle(PBR), close to the liner top. Proper design of the TSA, seal se-lection and the PBR are critical to the useful life of the seals andelimination of many of the problems associated with well com-pletions. Integrity of the entire system requires careful planningand consideration of all components used in the completion.
Features and Benets
Locator threaded to match tubing connectionVariety of seal materials available for compatibility with an-ticipated well conditions; Viton* / Aramid seal units stan-dardMule shoe conguration aids in stabbing and facilitates re-entry with wireline equipmentSeal mandrel ID machined to match the production tubingspecications for ID and driftL80 and Q125 material grades are standard, with othermaterial grades available by special order Tubing Seal As-sembly
* Trademark of DuPont Company
Tubing Seal AccessoriesThe Positive Latch Assembly (PLA) is used to latch or anchortubing seal assemblies in a seal bore. This prevents movementof the seals due to changing well conditions, while withstandingboth tensile and compressive forces. Restricted seal movementextends seal life and reduces necessary seal bore lengths. ThePLA consists of a top coupling threaded to match the productiontubing connection, right-hand release latch and an inner man-drel with a connection down for a seal assembly.
Features and BenetsTop connection to match tubing connection, eliminatingcross-over subRight-hand release latch threadsDesigned to uniformly distribute compressive loads intoliner top or PBRID machined to match the production tubing specicationsfor ID and driftL80 and Q125 material grades are standard, with othermaterial grades available by special order
Tubing Seal Assembly
PLA
TSA
The Dual Flow Assembly (DFA) provides a practi-cal method of completing a well with two tubingstrings using Polished Bore Receptacles (PBR).The Dual Flows Seal Assembly seals at the topof a liner. The long string side seals inside a lowerPBR at a transition point in the liner. The Dual FlowAssembly can also be used in single zone comple-tions for continuous treatment or where intermit-tent or continual chemical injection is warranted.Alternately the second tubing string could be usedas a kill string.
Features and BenetsEliminates hydraulic hold-downs, ratchetrings, and setting pistons found in productionpackers.Pressure rating limited by tubing stress notequipment rating.Equipment is retrieved with straight pick-up;no shear sleeves or jays to manipulate.
Equipment Required:Dual ow head and seal assembly located inthe upper PBR of the production liner.Long side string PBR Seal Assembly stunginto the lower PBR of the production liner;the dual ow head assembly is run in on thelong side or lower zone tubing - Smith recom-mends and can supply blast joints and owcouplings.Short side PBR seal assembly stings into theshort side seal bore in the dual ow head.Upper zone PBR run in the production linerassembly.Production liner hanger.Lower zone PBR run in the production linerassembly; a tapered liner with PBR installedat the transition has been illustrated.Retrievable Landing Assembly (RLA) and tailpipe assembly with prole nipples - the RLAwould be run prior to running the Dual FlowHead and lower zone tubing. The RLA is not arequirement.
Dual Flow Assembly
DFA
SETTING TOOLS SETTING ADAPTORSINTEGRATED LINER HANGER PACKER
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SETTING TOOLS, SETTING ADAPTORSINTEGRATED LINER HANGER PACKER
2524
Mechanical Release Setting System
The Mechanical Release Setting Assembly consists ofa Model D Setting Tool, a cementing pack off and linerwiper plug holder. This system is used for conveying non-rotating mechanically or hydraulically-set liner hangers.A tamping dog assembly can be included if running anintegral liner packer.
The Model D Setting Tool incorporates a right-hand re-lease liner running thread and a spline arrangement be-low the running threads. These splines permit right-handsetting of mechanical liner hangers. With the splines dis-engaged, the setting tool is then released without the
need to nd neutral.
Features and BenetsDependable right-hand setting and release of the set-ting tool from the liner is standard - no left-hand ro-tation required at any timeTensile ratings exceed liner hanger hanging capacitywith large overpull marginsSetting tool Kelly with bearing below the running nuteliminates the need to nd neutral to release thesetting toolSpline dogs provide positive torque transmission tothe liner and prevent inadvertent release of the set-ting tool from the linerEasily adapted with tamping dog assembly for settingintegrally run liner top packers without performancelossAccommodates a variety of cementing pack offs
The Setting Adapter with Tieback Receptacle (SATM) As-
sembly incorporates the right-hand release liner runningthread with a spline arrangement that permits both right-hand hanger set and release. A metal-to-metal seal sur-face between the setting adapter and tieback receptacleprovides maximum pressure integrity, while the includedRetrievable Cementing Bushing (RCB) seals the annulararea between the work string and the liner top.
Features and BenetsManufactured from heavy-wall tubular alloys withyield strengths matching the linerSpline system provides positive torque transmissionto the linerPolished bore-type tieback receptacle is standardMetal-to-metal seal eliminates elastomersIntegral RCB prole
Model D/STL
SATM
Integrated Liner Hanger Packers (LHP) com-bines a liner top packer with a liner hanger,with the packing element set at the same timethe hanger is engaged. LHPs are available inmechanical- or hydraulic- set (HHP) congu-rations, with or without hold down slips. Me-chanical packers feature reliable right-handsetting, while hydraulic packers incorporatedebris wiper seals in the piston for depend-able performance. Due to their specializednature, liner hanger packers are recommend-ed for less severe applications.
Features and BenetsPacker bodies manufactured from casingof equivalent grade as the liner; L80 andQ125 material grades are standard, withother material grades available by specialorderHigh-grade casing compatible slips man-ufactured to 55-60 Rockwell CCan be used as a tension-set packer whenrun inverted
ApplicationsThe LHP is commonly deployed with sandscreens or slotted liners.The packer is also particularly effectivewhen used with scab liners.The LHP is used as the bottom packer witha weight-set packer above with casing inbetween to straddle a damaged section of
casing or perforations.
Integrated Liner Hanger Packer
HHP
LHP
SETTING TOOLS SETTING ADAPTORSSETTING TOOLS SETTING ADAPTORS & ACCESSORIES
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SETTING TOOLS, SETTING ADAPTORSSETTING TOOLS, SETTING ADAPTORS & ACCESSORIES
2726
Hydraulic Release Setting System
The Hydraulic Release Setting (STHR) Assembly Systemconsists of a Model STHR Liner Setting Tool, a cementingpack off and liner wiper plug holder for running rotatingand non-rotating liner hangers. This is used exclusively withhydraulic release setting adapters. This system is used forconveying rotating mechanical or hydraulic-set liner hang-ers. A tamping dog assembly can be included if running anintegral liner packer.
The Model STHR Setting Tool features a right-hand driveclutch at the top, which provides torque transmission to theliner for rotating and /or drilling down. The setting tool is
released by applied hydraulic pressure. This positive, de-liberate release method permits drilling down of the linerwith the system in compression or tension. After releasingthe setting tool the liner is rotated through the right-handdrive clutch.
Features and BenetsHydraulic release from the liner with mechanical sec-ondary releaseTorque transmitted through a right-hand drive clutch forthe most demanding torque requirementsPositive retention system keeps the releasing compo-nents locked after actuation - no inadvertent re-en-gagement.Right-hand rotation of liners after hanging a rotatingliner hangerEasily adapted with packer tamping dogs for setting in-tegrally run liner top packers without performance lossBuilt-in secondary mechanical release
The Hydraulic Release Setting Adapter with Tieback Re-ceptacle (SHTS) Assembly incorporates a hydraulic releaseliner running thread with an auto-clutch arrangement thatpermits right-hand hanger setting as well as right-hand ro-tation. A metal-to-metal seal surface between the settingadapter and tieback receptacle provides maximum pressureintegrity, while the included RCB seals the annular area be-tween the work string and the liner top. The SHTS featuresa back up mechanical release.
Features and BenetsIntegral high torque, right-hand autoclutchManufactured from heavy-wall tubular alloys with yieldstrengths matching the linerPolished bore-type tieback receptacle is standardMetal-to-metal seal eliminates elastomersIntegral RCB prole
The Double Spline Setting (STS) assembly consists of a Mod-el STS Liner Setting Tool, a cementing pack off and linerwiper plug holder. This is used exclusively with double splinesetting adapters. This system is used for conveying rotatingmechanically or hydraulically set liner hangers. A packer dogassembly can be included if running an integral liner packer.
The Model STS Liner Setting Tool incorporates the right-handrelease liner running thread with a double spline arrange-ment having approximately 48 inches between the upperand lower splines. These splines permit right hand setting ofmechanical-set hangers as well as facilitating liner rotation
after the hanger is set.
Features and BenetsDependable mechanical right-hand release from the lin-erHigh torque transmission capability through long, heavy-duty spline Dogs48-inch stroke kelly for determining drill pipe torque in-dependent from liner torqueRight-hand rotation of liners after hanging the rotatingliner hangerEasily adapted with packer tamping dogs for setting in-tegrally run liner top packers without performance lossAccommodates a variety of cementing pack offs
The Double Spline Setting Adapter (SSTM) is used exclusive-ly with double spline setting tools. This system is used forconveying rotating mechanical or hydraulic-set liner hang-ers. The DS incorporates the right-hand release liner run-ning thread with a double spline arrangement having ap-
proximately 48 inches between the upper and lower splines.These splines permit right-hand setting of mechanical sethangers as well as facilitating liner rotation after the hangeris set.
Features and BenetsDependable mechanical right-hand release from the lin-er.High torque transmission capability through long, heavy-duty spline dogs48 inch stroke kelly for determining drill pipe torque in-dependent from liner torqueRight-hand rotation of liners after hanging the rotatingliner hangerEasily adapted with packer tamping dogs for setting in-tegrally run liner top packers without performance lossAccommodates a variety of cementing pack offs
Double Spline Setting System
Model STS
SSTSHTS
STHR
SETTING TOOLS SETTING ADAPTORS & ACCESSORIES SETTING TOOLS SETTING ADAPTORS
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SETTING TOOLS, SETTING ADAPTORS & ACCESSORIES SETTING TOOLS, SETTING ADAPTORS
2928
The Jay Release Setting assembly consistsof a specially congured liner setting adapterand liner setting tool for running relativelyshort length rotating liner hangers wheretorque requirements are not strenuous. Thesystem illustrated is Smiths standard Jaysystem and is used for both mechanically andhydraulically set liner hangers. The liner set-ting adapter incorporates a Jay congura-tion instead of the running thread normallyused in setting adapters. The Jay prole canbe congured for either left- or right-hand re-
lease. The system can also be supplied withdouble Jay arrangement if additional tensileand torque capacities are desired. If a Tie-back Receptacle (TBR) is required, the JaySetting Adapter uses the same dependablemetal-to metal seal design between the set-ting adapter and the TBR as with other SmithServices setting systems.
JSetting Tool Features and BenetsJay lugs are an integral part of the set-ting tool mandrel - no welds to breakSame setting tool used for either right- orleft-hand release Jay setting adaptersRight-hand rotation of liners after hang-ing the rotating liner hangerOne quarter-turn for easy removal of thesetting tool when liner cementing is com-pletedUsable with all Smith cementing pack off
assembliesSuitable for use with packer tamping dogswhen running integral liner top packers
JSetting Adapter Features andBenets
Quarter-turn machined Jay slot con-guration for easy release from the linerhanger after settingL80 and Q125 material grades are stan-dard, with other material grades avail-able by special orderMetal-to-metal seal system for maximumTBR pressure integrityEasily adapted for use with RetrievableCementing Bushing assemblies
Jay conguration setting adapter canbe incorporated into integrally run linertop packers
"Jay" Release Setting System
The Setting Tool Extension provides the connectionbetween the liner setting tool and the operator'swork string. In most cases the outside diameter ofthe extension assembly will be the same as the drillpipe used for running the liner, preventing unnec-essary loss of rig time. The extension assembly isprovided with a box connection to match the drillpipe.
Features & BenetsHeavy wall tubular body manufactured fromAISI 4100 series alloy steel.
Assembled with Junk Strainer Assembly to re-duce solids fallout into the liner tieback recep-tacle.Available in various lengths to complement linertieback receptacle lengths without "splice" con-nections to improve performance characteris-tics and leak resistance.
Tamping Dog AssemblyThe Tamping Dog Assembly is used with a liner set-ting tool to enable "setting" of liner top packers.The tamping dog assembly is installed between theliner setting tool and the extension assembly. Whenthe complete setting tool is assembled with the set-ting adapter of the packer, the tamping dog assem-bly is contained within the tieback receptacle (set-ting sleeve). The dogs are spring loaded to ensurecomplete extension when the assembly is removedfrom the tieback receptacle. Work string slack offweight is transferred through the dogs into the tie-back receptacle and into the packing element, set-ting the packer.
Features & BenetsHeavy-duty body manufactured from AISI 4100series alloy steel.Tensile rating equal to or greater than the linersetting tool.Large dogs with machined shoulders for opti-
mum weight transfer to the packer.Smooth ID matched to liner setting tool andextension assembly for trouble free passage ofdrill pipe wiper plugs.
Tamping DAssemb
SJTM
ModelJ
ExtensionAssembly
Setting Tool Extension Assembly
CCEMENT BUSHING
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CCEMENT BUSHING
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The Cementing pack off seals the annular area between thework string and the top of the liner. Several different types areused to achieve this seal; their usage is dependent on well con-ditions and preferences.
Retrievable Cementing BushingThe Retrievable Cementing Bushing (RCB) is comprised of abody with locking lugs, interior and exterior seals. The bushingseats and locks into a prole machined into the liner settingadapter or a prole sub. A polished OD slick joint completes theassembly. The RCB provides a fully retrievable seal betweenthe liner and the work string.
Features and BenetsFull circle locking lugs for optimum pressure resistanceSmall piston area reduces forces on work string while cir-culating and cementingCompletely retrievable, leaving full opening to liner belowwithout drilling out
Slick Joint FeaturesPolished OD for maximum sealing integrity and pressureresistanceReduced diameter to allow retraction of RCB locking lugsSwivel adapter assembly for liner wiper plug attachmentAvailable in lengths up to 25 feet
Drillable Cementing BushingThe Drillable Cementing Bushing (DCB) performs the samefunction as the Retrievable Cementing Bushing but must bedrilled 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 BenetsSmall piston area reduces forces acting on work string dur-ing circulating and cementingAluminum alloy insert for easy drill out, leaves minimal ma-terial in housing when drilled out with full gauge bit or millCemented insert style available in most sizes
Cementing Pack Offs
The Cementing Pack Off Coupling (POC) is a Pol-ished Bore Receptacle (PBR)-type seal attached tothe liner setting tool. It seals into a PBR run in theliner assembly or the tieback receptacle. This sealassembly utilizes one PBR seal unit for premiumpressure integrity. Following retrieval, access tothe liner is unrestricted.
Features and BenetsPremium PBR sealing system for optimumpressure integritySleeve design permits easy seal size changes
to accommodate different seal bore IDsElastomer selection available for compatibilitywith various drilling/wellbore uids
Swab Cup AssemblyThe Swab Cup Assembly (SWCA) is used in appli-cations that do not require the higher performancecapability of a Retrievable Cementing Bushing,Drillable Cementing Bushing or Pack Off coupling.The packer cup assembly uses commercially avail-able swab cups. When assembled to the mandrel,these swab cups are designed to hold pressure inone direction only. The SWCA is run on tail pipe be-low the setting tool, providing unrestricted accessto the liner when retrieved.
Features and BenetsUtilizes commercially available swab cupsField re-dressable without special toolsAPI end connections allow easy space outusing standard pup joints
POC
SWCA
RCB w/Slick Joint
DCB
Cementing Pack Off Coupling
CASCASING HARDWARE
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The Landing Collar (LC) acts as a seat and latch for theliner wiper plug, and is normally run one joint above theoat collar or oat shoe if a oat collar is not installed.The LC provides a positive stop for the cementing plugs.This system holds pressure from above and below whenthe pump down or liner wiper plugs land and latch at theend of cement displacement.
Features and BenetsProvides the landing seat for cementing plugsActs as a backup to the oat collar/shoe with theplugs latched and sealed
Threaded or cement style inserts availableAll internal parts are PDC drillableAnti-rotation feature for fast drilloutHousing suitable for all premium connectionsL80 and Q125 material grades are standard, withother material grades available by special order
Ball Catch Landing CollarThe Ball Catch Landing Collar (BC) is run when any hy-draulically-set device is used. The landing collar containsa seat and latch for plugs and a ball seat, pinned to shearat approximately 1,000 psi above the pressure requiredto set the hanger. After setting the hydraulic hanger, in-creasing pressure shears the ball seat and re-establishescirculation.
Features and BenetsThreaded or cement style insertAll internal parts are PDC drillableActs as a backup to the oat collar/shoe with theplug set latched and sealedAnti-rotation feature for fast drill outStandard BC incorporates ball seat catchShear-out ball seat falls to the bottom of the linerwhen using dual plug systemHousing suitable for all premium connections
L80 and Q125 material grades are standard, withother material grades available by special order
Landing Collars
The Float Landing Collar (FLC) combines the featuresof the landing collar with a oat valve, and it is typi-cally used as an economical alternative to separatecomponents, or to reduce shoe track l ength.
Features and BenetsThreaded or cement-style inserts availableSingle or dual poppet valvesAll internal parts are PDC drillableEliminates oat collar and connectionAnti-rotation feature aids drill-outL80 and Q125 material grades are Standard, with
other material grades available by special order
Float Shoe and Guide ShoeThe Float Shoe (FS) is made up as the rst compo-nent in a liner assembly. The tool features an insertdart-type poppet valve with elastomer seals cement-ed into the housing, and includes a standard cementnose, with a bladed bottom available by special or-der. All internal parts are PDC drillable.
The Guide Shoe (GS) aids in running liners by provid-ing a purpose-built guide in place of an open endedliner joint, and are run on screened or slotted liners
in place of a oat shoe. A cement nose is standard,with bladed bottoms available by special order.
Features and BenetsSingle or dual poppet valvesAll internal parts PDC drillable80,000 psi through 125,000 psi yield strengthsare standardAPI RP 10F Category III C compliantCement nose standard; bladed bottom availableby special order
Float Landing Collar
FLC
GS
FS
BC
LC
CEMENTCEMENTING EQUIPMENT
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The Pressure Activated Stage CementingValve functions by applied pressure to per-mit upper stage cementing. Opening is con-trolled by a piston at the end of rst stagecementing. Opening pressure moves an in-ner sleeve upward aligning the cementingports. The Stage Cementing Valve is closedby the wiper plug following the secondstage cement. The inner sleeve is held inthis position by a ratchet type lock ring andpressure integrity is maintained.
The Stage Cementing Valve is particularlyadvantageous when cementing long liners.Waiting time for a conventional opening ballis eliminated and the probability of success-ful second stage cementing is greatly en-hanced.
This tool is also useful in cementing linertieback strings. By placing the Stage Valveabove the tieback seal assembly the sealscan be left in the tieback receptacle. Thiseliminates pumping cement past the tie-back seals. The Stage Valve is closed bythe plug following the cement. Pressure in-tegrity is regained when the i nner sleeve isclosed and locked.
Features and BenetsManufactured from alloy steel matchingliner grade for optimum performance.
Opening pressure easily adjustable inthe eld.Hydraulic opening, mechanical closingfor positive, reliable operation.Inner sleeve locked closed at end of ce-ment placement; cannot be reopenedlater by full gage tools.
PressureActivated StageCementing Tool
Pump DownPlug
Liner WiperPlug
Pump Down Plug and Liner Wiper PlugPressure Activated Stage Cementing Valve
The Pump Down Plug and Liner Wiper Plugprovide separation between drilling/dis-placing uids and the cement slurry whencementing liners. Two plugs are requiredbecause of the wide ID difference betweenthe liner and the work string.
The Pump Down Plug is released from thecementing manifold at the surface after thecement is pumped. Traveling between thecement and the displacement uid, it wipescement from the drill pipe. The pump down
plug locks and seals into the liner wiperplug. Together the two plugs function as asingle plug.
The Liner Wiper Plug is normally shearpinned to the setting tool and provides theseal bore for the pump down plug. A hollowinterior passes cement and uids. With thepump down plug sealed and latched, theliner wiper plug will shear off, wipe the ce-ment from inside of the liner and keep thecement separate from the displacing uid.When seated and latched in the landing col-lar, the plugs prevent back ow of cement.If desired the liner wiper plug can be placedin a plug holder bushing, normally belowthe liner hanger.
Features and BenetsLocking system provides back pressure
capability when locked and sealed inthe landing collarElastomer selection for compatibilitywith today's complex drilling uidsPDC drillableAnti-rotation feature reduces drill-outtimes
CECEMENTING EQUIPMENT
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The Solid Body Cementing Manifold(CMSB) suspends drill pipe weight fromthe rig elevators while retaining the plugso that it can be released after cement-ing has been completed. The CMSB alsoconnects the cementing lines to the run-ning string during liner operations, andincludes a heavy-duty swivel for easystring manipulation with the cementinglines in place. This swivel mechanism anddrill pipe plug retainer are built in belowthe elevators for unobstructed operation.
The CMSB is available with single or dualplug drop capabilities; an optional balldrop assembly is available for use withhydraulic-set liner systems.
Features and BenetsMaximum strength and toughnessfrom quenched and tempered alloysteel constructionDisplacement uid and cement arediverted below or above the plugthrough an external manifoldManifold rated to 5,000 PSI workingpressureAvailable in single or dual plug con-gurationCementing ag sub available for vi-sual indication of drill pipe wiper plugreleaseHeavy duty swivel permits easy ma-
nipulation of the string without hav-ing to break down the cementinglines
Solid Body Cementing Manifold
CMSB
Ball DropAssembly
Plug DropAssembly
The Dual Liner Wiper Plug System (DPS) provides en-hanced cement contamination prevention. The DPS usestwo PDPC plugs and two LWPC plugs, matched to wipeahead of and behind the cement column. The system hasthe same advantages as the traditional lead and followingplugs in conventional full string cementing.
Features and BenetsPrevents cement contamination in drill pipe and linersLocking system provides back pressure capability whenlocked and sealed in the landing collarElastomer selection for compatibility with most drillinguidsPDC drillableAnti-rotation feature reduces drill-out times
Dual Liner Wiper Plug System
DPS
INNER STRING CIRCEMENT MANIFOLD
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Setting hydraulic tools and controlling circulationcan be a problem when running slotted or screenedliners, as these liners do not permit conventionalcirculation methods. For these cases, Smith offers anumber of items specically designed for circulatingthrough an inner string. These components includePorted Swab Cup Assemblies, Tubing Swivels andBall Catch Subs.
Ported Swab Cup AssemblyThe Ported Swab Cup Assembly (SWCA) utilizes op-posed packer cups between a ported mandrel. Thisconguration, when combined with a pressure con-taining device such as the Ball Catch Sub, allowspressure to be directed between the opposed cups.This pressure is then directed to specic hydrau-lically-actuated devices such as hydraulic-set linerhangers and external casing packers. The PortedSWCA can be positioned to actuate several devicesindependently and is retrieved with the liner settingtool and work string.
Tubing SwivelThe Tubing Swivel (TS) permits easier make-up ormanipulation of the inner string. The swivel bearing
assembly functions in both compression and ten-sion. Connection make-up does not torque anycomponent below the swivel assembly. In additionto the bearing assemblies, the TS also incorporatesmandrel and housing seals to provide needed pres-sure integrity
Ball Catch SubThe Ball Catch Sub (BCS) is normally used with in-ner string tools to provide the pressure seat topermit activation of one or more pressure actuatedcomponents. This tool incorporates a ball seat withshear pins to provide the required shear pressure.After all hydraulic components have been actuated,increased pressure against the ball seat shears theseat pins and circulation is regained. This preventsthe necessity of pulling a wet string, thus saving
drilling uid and rig time. May be congured to shiftwith pump down plugs.
TS
BCS
PortedSWCA
CMIB
The Top Drive Cementing Manifold (CMIB) elimi-nates cement contamination of top drive compo-nents by creating a ow path for cement and dis-placing uids without passing through the rigs topdrive assembly, making it ideal for cementing linerswith a top drive system on the rig. The high capac-ity CMIB consists of a swivel and an internal bypassmanifold with integral ball drop and plug drop as-semblies. The one-piece swivel housing eliminatesthreads, anges or welds while increasing strengthand reducing bending loads imposed on the inlets.Drop mechanisms are self-contained for low main-
tenance, and feature an independent indicator foreach plug or ball dropped. The CMIB can be cong-ured for single plug, single ball drop or dual plug,single ball drop, and is suitable for running and ce-menting all types of liner systems, including rotat-ing liner systems.
Features and BenetsHigh operational capacities: 1,594,000 lbs.hook load, 1,496,000 lbs. at full rated torqueof 50,000 ft-lbs; 10,000 PSI working pressurewith 4 inch through boreFlush 13 inch OD prole maximizes rig safetyduring handling and rotationUnobstructed bore after plug or ball isdroppedLarge ow area accommodates high displace-ment ratesAnti-rotation tie-off integral to swivel housingCanister design prevents plugs or balls from
oating into drop mechanismsTorque-keyed connections do not require heavymake-up torquesReduces cement adhesion with coated andtreated internal partsPneumatic remote control available as an op-tionKelly valve available in upper or lower end ofswivel, if desired
Top Drive Cementing Manifold Inner String Circulation Tools
LINER HDRESS MILL ASSEMBLY
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Premium Hydraulic/Mechanical Rotating Liner Hang
( Pocket Slip with FSP Packer)The Dress Mill Assembly (DMA) is con-gured to clean out the various IDs atthe liner top, such as tieback recep-tacles and Polished Bore Receptacles.As a minimum conguration the DMAwill consist of a pilot mill sized to theliner, a bladed polishing mill and aStop Sub with a drill pipe box con-nection. Depending on the liner con-guration, the DMA may include oneor more spacer tubes for proper millplacement. The various mill surfaces
are dressed and ground to dimensionto prevent damage to seal surfaces.Retrievable Landing Assembly (RLA)and Retrievable Cementing Bushing(RCB) proles can be cleaned whena jet sub is incorporated into the as-sembly. Mills should be run whencompletions require using the Pol-ished Bore Receptacle (PBR) and / orRLA and RCB proles. Proper cleaningof a honed receptacle is necessary toensure a quality seal surface.
Features and BenetsGround dressing surfaces cleanhoned bores without damagingseal surfaces.Drill pipe connections on all com-ponents for maximum perfor-mance.Stop sub is dressed to repair anybit damage to the liner top whileproviding positive indication themill assembly has worked throughthe liner top.
Bodies and spacer tubes manu- factured from AISI 41XX seriesalloy steel for durability andtoughness.
Dress Mill Assembly
DMA
Pocket Slip
Rotating Liner
Hanger (available
with Non-RotatingPocket Slip)
Frontier Series
Packer
Tieback
Receptacle
Dual ValveFloat Shoe
Cement Bushing
Prole (PSRT)
Landing Collar
Dual Valve
Float Collar
Pump Down Plug
STPR Pocket SlipSetting Tool
FSP Setting Tool
Retrievable
Cementing
Bushing
Slick Joint
Liner Wiper Plug
LINER HANGER SYSTEMS LINER H
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EZRD Mechanical Set Non-Rotating Liner Hanger
with WMPO Liner Top Packer
Heavy Duty Hydraulic Pocket Slip Rotating Liner Hanger with
JMPO Liner Top Packer
JMPO Liner Top Packer
with Integral Setting
Adapter SHTS
Hydraulic Rotating
Pocket Slip Liner
Hanger HPS
Ball Catch
Landing Collar
Dual Valve
Float Collar
Dual Valve
Float Shoe
Pump Down Plug
PWPC
Junk Strainer
Tamping Dogs
Drill Pipe
Extension STX
Hydraulic Release
Tool SHTR
Retrievable
Cementing
Bushing
Liner Wiper
Plug LWPC
Polished Bore
Receptacle
RetrievableCement Bushing
Prole
WMPO Liner Top
Packer Integral
with SATM Setting
EZRD Non-Rotating
Mechanical SetLiner Hanger
Double ValveFloat Shoe
Double Valve
Float Collar
Landing Collar
Liner Wiper Plug
Slick Joint
Retrievable
Cement BushingProle
Model D/STL
Mechanical
Release Tool
DA Tamping Dog
STX Drill Pipe
Extension
Junk Strainer
LINER HLINER HANGER SYSTEMS
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Compression Set Isolation Packer (Second Trip)HZDC Hydraulic Non-Rotating Liner Hanger
with WMPO Liner Top Packer
Polished Bore
Receptacle
Retrievable
Cement BushingProle
WMPO LinerTop Packer with
Integral SettingAdapter SATM
HZDC Non-
Rotating Hydraulic
Set Liner Hanger
Double Valve
Float Shoe
Double Valve
Float Collar
Ball Catch
Landing Collar
Junk Strainer
STX Drill PipeExtension
DA Tamping Dog
Model D/STL
Mechanical
Release Tool
Retrievable
Cement Bushing
Prole
RSJC Slick Joint
LWPC Liner WiperPlug
Tieback
SATM Setting
Adapter
Compression
Setting Tool (CLT)
Seal Nipple
Junk Strainer
STX Drill Pipe
Extension
Model D/STL
Mechanical
Release Tool
RetrievableCement Bushing
RSJC Slick Joint
TYPICAL LINETYPICAL LINER APPLICATIONS
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Typical Liner Applications (cont.)
Figure AA standard Pocket Slip (PSH) Liner Hanger installation.Starting at the top, the PSH liner hanger, tieback recep-tacle and a retrievable cementing bushing (RCB) sub.
Figure BThe Integral Packer provides the PSH liner hanger with atrue one trip liner top packer system. It can be run with orwithout a tieback receptacle. External and internal bypassallow quicker trip time and higher circulating rates.
Figure C
A standard liner installation. Starting at the top, a settingsystem with a tieback receptacle, setting adapter withsetting thread and RCB prole. The receptacle provides atieback alternative whether planned or unplanned. A me-chanical set liner hanger suspends the liner weight fromthe intermediate casing.
Figure DThis prole shows two Smith innovations - CompressionSet Packer and the retri evable PBR on an Retrievable Land-ing Assembly (RLA). The packer is run in a second trip andset to isolate the liner-casing annulus and shut off a linertop leak. The RLA, PBR and tail pipe with tubing prolesare run to isolate the tubing from the liner below. The RLAis completely retrievable, allowing full bore access to theliner below during workover operations.
Figure EThe Insert Seal Assembly (ISA) uses the same prole usedby the RCB offering an economical tubing completion. It
provides most of the advantages of a PBR for low pressureapplications. After the liner is set and cemented, the pro-le remains in the top of the liner to accept the ISA.
Figure FThis diagram shows a wellbore design using the conven-tional approach to tie back a liner. A tieback receptacleis mounted on top of a PBR having an RLA prole. Thehanger below the PBR must be designed to have a burstpressure rating equal to the liner.
Figure GAt some time in the life of a well it may become necessaryto 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 lin-er required, a stage cementing collar, and a Liner HangerPacker with a guide shoe on bottom. The patch is run ontubing or drill pipe with a mechanical set setting tool withtamping dog assembly.
Figure HA typical liner is run with an integral packer above theliner hanger. The integral, weight set packer with holddown slips is set after cementing. The packer allows ex-cess cement to be reversed out above the liner top, savingclean out time. Circulating pressures do not affect theformation below the packer. The packer's hold down slipsalso assist in keeping short, lightweight liners in positionuntil cement is set.
Typical Liner Applications
TECHNICTYPICAL LINER APPLICATIONS
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Good seal performance depends on matching materials,properties, and stack design to the demands of the wellenvironment. Temperature, pressure differentials, acids,inhibitors, H S, CO , and other harsh elements dictate sealmaterial selection. Disregarding these factors can shortenthe life of the completion and increase costs. CompletionTechnology provides a wide range of elastomer selectionsto meet demanding requirements.
Smiths standard Seal Stack is not nitrile based, but is acompounded Viton* pressure ring design with glass-lledTeon* pressure and adapter rings. Our standard seal de-
signs 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 concentra-tions of amine corrosion inhibitors are likely to be pres-ent. Our standard seal stack is an economical selectionsuitable for use in both high and low pressure applicationswhere well conditions fall within the conditions outlinedabove. In order to maintain suitable performance levels,this seal should not leave the seal bore under differentialpressure.
Aas** Seal Stacks incorporate Aas primary pressurerings (replacing the Viton rings on the standard Smith sealarrangement) with secondary pressure rings of glass-lledTeon and adapter rings offering H S and CO resistance.In addition to temperature ratings up to 450F these sealassemblies offer good pressure performance, as well asproven chemical resistance to most well uids, includingamine based inhibitors.
HPHT High Performance Seal StackThe HPHT high performance seal stack prietary blend of Teon and Carbon that arert materials and maintain a high degree oseals contain an expander that is captured the face of the seal body.
When conditions, such as the following, reqformance seals Smith's high performance svides practical solutions.
Service Conditions:
400 F and 15,000 psi Presence of H S (35% max.) and CO .Completion and production environmamine based corrosion inhibitors.Seal assembly "stabbing" and removal
A dual back-up system is incorporated that iPEEK*** and Stainless Steel
Seal components are as follows:Stainless Steel Back-up1.PEEK-LLV (Polyetheretherketone) Back-2.TFM-FTMM Teon (Proprietary blend)3.PTFE-LRC AH Polytetrauoroetheylene4.element
Elastomer Guide
"HPHT" High PerformanceSeal Stack
TeonAdapter
Ring
TeonPressure
Ring
StandardSeal
Stack
VitonPressure
Ring
1 2 3 4 3 4 3
Typical Liner Applications (cont.)
48 49
TECHNICAL INFORMATION TECHNIC
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Completion Systems test cell facilityat the Hardy Road campus in Hous-ton, Texas, improves product veri-cation turnaround times by expand-ing in-house testing capabilities. Abroad range of downhole tempera-tures, pressures and loads can besimulated to meet both industry andcustomer-specic testing require-ments. Testing parameters are fullydocumented and compliant with thelatest industry standards.
Summary of TestingCapabilities
Hydrostatic Pressure: 15,000 psifor 9-5/8 inches and smaller siz-es. 10,000 psi for larger toolsNitrogen Pressure: 15,000 psi for9-5/8 inches and smaller sizes.10,000 psi for larger toolsTemperature: 450 degrees FPush: 785,000 lbs.Pull: 589,000 lbs.Continuous Rotation: 40 RPM@ 1,450 ft-lbs (variable) with a200,000 lb. applied loadStatic Torque: 50,000 ft-lbs
Any of the above parameters can beused in combination to provide an ac-curate simulation of downhole condi-tions.
Safety FeaturesEnsuring the safety of personnel andthe environment is of primary con-cern during testing. Extensive safetychecks are performed prior to ev-ery test, and entrances to the testchamber are locked during testing.Steel reinforced walls in the controlroom and the main structure further
reduce risk to personnel andproperty.
The test cell features 36-inchconductor casing cemented
in place to a depth of 30 feet.Fully sealed 20-inch protectivecasing is suspended in the testwell to prevent the release oftest media into the environ-ment. Each piece of equipmentbeing tested is lowered insidethe casing below a wellhead toconne test pressures belowthe surface. Following testing,a water recovery system scav-enges any excess test mediaand processes out contami-nants, preventing release intothe environment.
During testing, real time testdata may be monitored fromthe control room, or can beaccessed remotely using pro-
prietary software. Test datais digitally recorded on fourpressure channels and two
temperature channels.can be stored in the tebase, ready to be burnattachment to test repo
All phases of the testinalso be visually monicorded through two dmounted within the tes
Commitment to ExceThe new high bay testanother example of SmCompletion Systems cprovide customers withrepresent the industry qualit
