Post on 13-Apr-2016
description
TEST SECTION TITLETEST SECTION TITLE
TEST SECTION TITLE
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
Benefits of the Pocket Slip Design 4
Frontier Series Packer & Accessories 5
Pocket Slip Liner Hanger & Tieback Receptacle Specifications 6-7
Rotating Pocket Slip Liner Hanger 8
EZ Series Mechanical-Set Non-Rotating Liner Hanger (EZRD) 9
EZ Series Mechanical-Set Non-Rotating Liner Hanger Specifications 10
HS Series Hydraulic-Set Non-Rotating Liner Hanger (HSDB) 11
HS Series Hydraulic-Set Non-Rotating Liner Hanger Specifications 12
LINER Top pAckERS 13
Long Reach Liner Top Packer 14
Hydraulic-Set Isolation Packer 15
Compression-Set Isolation Packer 15
TIEbAck & poLISHEd boRE REcEpTAcLE SySTEm
Tieback Seal Nipple 16
Orifice Float Collar 16
Tieback Receptacle Specifications 17
Polished Bore Receptacle 18
Tubing Seal Assembly & Accessories 19
INTEGRATEd LINER HANGER pAckER 20
SETTING TooLS, SETTING AdApTERS & AccESSoRIES
Mechanical Release Setting System (D-Tool, SATM) 21
Hydraulic Release Setting System (STHR, SHTS) 22
Double Spline Setting System (STS, SSTM) 23
"Jay" Release Setting System (Model J, SJTM) 24
Setting Tool Extension Assembly 25
Tamping Dog Assembly 25
cEmENT buSHING
Cementing Pack Offs 26
Retrievable Cement Bushing 26
Drillable Cement Bushing 26
Cement Pack Off Coupling 27
Swab Cup Assembly 27
cASING HARdwARE
Landing Collars (LC) 28
Ball Catch Landing Collar (BC) 28
Float Landing Collar 29
Float Shoe and Guide Shoe 29
cEmENTING EquIpmENT
Pressure Activated Stage Cementing Tool 30
Pump Down Plug and Liner Wiper Plug 31
Dual Liner Wiper Plug System 32
cEmENT mANIfoLd
Solid Body Cementing Manifold (CSMB) 33
Top Drive Cementing Manifold (CMIB) 34
INNER STRING cIRcuLATIoN TooLS 35
Ported Swab Cup Assembly 35
Tubing Swivel 35
Ball Catch Sub 35
dRESS mILL ASSEmbLy 36
LINER HANGER SySTEmS
Premium Hydraulic/Mechanical Rotating Liner Hanger
(Pocket Slip with FSP Packer) 37
Heavy Duty Hydraulic Pocket Slip Rotating Liner Hanger
with JMPO Liner Top Packer 38
EZRD Mechanical-Set Non-Rotating Liner Hanger
with WMPO Liner Top Packer 39
HSDB Hydraulic Non-Rotating Liner Hanger
with WMPO Liner Top Packer 40
Compression-Set Isolation Packer (Second Trip) 41
TypIcAL LINER AppLIcATIoNS 42-44
TEcHNIcAL INfoRmATIoN
Elastomer Guide 45-46
Engineering Test Cell Facility 47
Liner Hanger Data Sheet 48
Well Summary Sheet 49
TABLE OF CONTENTS
1
Smith Services Completion SystemsProducts & Services Catalog
quality StatementSmith International’s Quality Policy is to - “establish a relentless focus on satisfying customer needs and ex-pectations.”
Our quality objectives are to: Provide customers with quality • products 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 reputation • for absolute trustworthiness.
Health and Safety missionStatementThe mission of the Smith Inter-national, Inc. Health & Safety De-partment is to educate and in-fluence 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.
Planning, Implementing, EvaluationOne of Smith's main goals is to provide Customer Satisfaction. This is achieved by three basic but very efficient steps:
planningSelection of Liner Hanger • SystemSurge & Swab simulation• Torque & Drag simulation•
EvaluationPlayback simulation using • actual job data for post job evaluationPost job analysis explains • results of the job
ImplementingReal-time recording of key • parameters during job ex-ecution
2
LINER HANGERS
Pocket Slip Liner Hanger SystemThe 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, hy-draulic setting cylinders, and more. This hanger utilizes a special tongue-and-groove 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 poten-tial 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 run-ning threads eliminate the liner setting adapter, adding to improved fluid flow at the hanger.
ApplicationsRunning liners in damaged or ob-• structed wellboresHanging extremely heavy liners in • high-grade casing where maximum bite is requiredHanging liners in low-strength, unce-• mented, or multi-string casing where thorough load distribution is critical
Features & BenefitsDrive slots in the liner top permit ro-• tation while running to orient around obstructions (PSHR), also available without the Drive slots for non-rota-tion applications (PSH)Heavy-wall tubular alloy steel con-• struction designed specifically to hang heavy liners; no pressure re-tention included for maximum hang-ing performance Tongue-and-groove slip design com-• pletely recesses slips into the tool body, 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-grade casing compatibilityEnhanced fluid flow arrangement • permits internal and external fluid bypassHanging capacity normally greater • than the conventional dual cone de-signs of the same sizeExternal and internal fluid flow by-• pass is optimized by eliminating close tieback seal bore clearance
pSHRpSH
LINER HANGERS
3
The Pocket Slip Setting Tool provides a dual setting method in most sizes - hydraulic or mechanical setting of the liner hanger. Ei-ther method can be selected when the liner is at setting depth - not an option with con-ventional liner setting tools! The Pocket Slip Setting Tool is designed to positively actuate the hanger's slips resulting in uniform load-ing. This forceful wedging action eliminates many of the problems inherent with prefer-ential or unbalanced slip engagement com-mon to conventional hangers.
Features and BenefitsDual setting method - hydraulic or me-• chanical - capability in most sizesPositive, uniform, controlled slip activa-• tionCentralizing system eliminates any po-• tential for setting tool binding created by doglegs - assures easy release of the running nutSlip activating dogs "locked" into releas-• ing position after setting - prevents any accidental re-engagementBearing system eliminates the need to • find "neutral" to disengage the liner run-ning nutDesigned to augment system bypass by • providing internal flow pathDebris barrier to reduce potential fouling • problems associated with particle fallout above the liner top
Pocket Slip Setting Tool
STpRSTp
LINER HANGERS
4
Reduced Slip Loads minimize casing damage:Most casing damage occurs with a conventional liner hanger because 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 PSH protects casing with a design and a slip-setting method that delivers 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) 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.
Slip Timing:The Smith design overcomes the problem of poor slip tim-ing 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.
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 ⅝" casing.
figure 1:For the Conventional hanger, the 9 ⅝" casing is stressed to a level of 152,381 psi at the center where the slip is lo-cated. 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 deforma-tion. The advantage of being able to hang long, heavy liners is clearly illustrated.
Benefits of the Pocket Slip Design
pSIStress
pSIStress
figure 1Typical stress distribution in supporting casing using conventional cone and slip liner hanger (9 5⁄8" casing with 108,000 lbs. liner loading illustrated).
figure 2Typical stress distribution in supporting casing using Smith PSH liner hanger(9 5⁄8" casing with 108,000 lbs. liner loading illustrated).
LINER HANGERS
5
Frontier Series Packer & Accessories
pSTbR fSp
fSp Setting
Tool
pSRT pSdT
The PSH Pocket Slip Liner Hanger is available with a range of accessories designed to maximize running perfor-mance, operational flexibility and sys-tem integrity.
The Pocket Slip Integral Packer (FSP) adds same-trip isolation capabilities to the PSHR, with a high-pressure anti-swab 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 avail-able with an integral cementing bushing profile for increased pressure perfor-mance.
The Pocket Slip Tieback Receptacle (PSTBR) honed seal bores to maximize seal integrity, while bypass ports above the seal bore provide bypass area.
The PSTBR is also available with an in-tegral cementing bushing profile for in-creased pressure performance.
Features and BenefitsHigh-pressure element rated 10,000 • psi at 350 degrees FAnti-swab element design• Self-energizing, non-extruding ele-• mentLarge bypass area• Tieback ability below the hanger or • packerManufactured from mechanical tub-• ing of equivalent liner grade
AccessoriesThe Pocket Slip Retrievable Cementing Bushing (PSRT) features an RCB pro-file and a honed seal bore to maximize pressure performance. The Pocket Slip Drillable Cementing Bushing (PSDT) in-cludes 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.
LINER HANGERS
6
Pocket Slip Liner Hanger & Tieback Receptacle SpecificationsSize Hanger Tieback
Liner xCasing Casing OD ID OD ID
(in.) (mm)
(lb/ft)(kg/M)
(in.) (mm)
(in.) (mm)
(in.) (mm)
(in.) (mm)
3 ½ 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
88.144.00
101.603.375 85.7315.00
22.304.17
105.92
18.00 26.80
4.03 102.36
3.33 84.58
3 ½ x 5 ½ 88.9 x 139.7
14.00 20.80
4.76 120.90
3.93 99.82 4.25
107.953.75
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 ½ 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 Casing Casing OD ID OD ID
(in.) (mm)
(lb/ft) (kg/M)
(in.) (mm)
(in.) (mm)
(in.) (mm)
(in.) (mm)
4 ½ x 5 ½114.3 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 ½ 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
123.75.50
139.74.75
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
123.75.50
139.74.75
120.6538 56.5
5.70 144.78
5 x 7 ⅝127.0 x 193.8
24.0 - 29.7 35.7 - 44.2
6.62 168.15 5.62
142.756.25
158.755.50
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 ½ 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
LINER HANGERS
7
Size Hanger Tieback
Liner x Casing Casing OD ID OD ID
(in.) (mm)
(lb/ft) (kg/M)
(in.) (mm)
(in.) (mm)
(in.) (mm)
(in.) (mm)
5 ½ x 7 ⅝ 139.7 x 193.7
24.0 - 29.7 35.7 - 44.2
6.62 168.15 5.62
142.746.25
158.755.50
139.733.7 - 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
7 x 9 ⅝177.8 x 244.5
32.3 - 40.0 48.1 - 59.5
8.50 215.9
7.31 185.67
8.00 203.2
7.125 180.9
or 7.25
184.15
40.0 - 47.0 59.5 - 69.9
8.37 212.6
47.0 - 53.5 69.9 - 79.6
8.25 209.55
58.4 86.9
8.12 206.25
7.12 180.84
7.87 199.9
7.00 177.8
7 x 10 ¾177.8 x 273.0
40.5 - 45.5 60.3 - 67.7
9.62 244.35
8.00 203.2
8.50 215.9
7.375 187.3
51.5 - 55.5 76.6 - 82.6
9.43 239.52
60.7 - 65.7 90.3 - 97.8
9.25 234.95
7 ⅝ x 9 ⅝193.7 x 244.5 and
7 ¾ x 9 ⅝196.85 x
244.5
32.3 - 40.0 48.1 - 59.5
8.50 215.9
7.31 185.67
8.00 203.2
7.250 184.15
40.0 - 47.0 59.5 - 69.9
8.37 212.6
47.0 - 53.5 69.9 - 79.6
8.25 209.55
58.4 86.9
8.12 206.25
7.12 180.84
7 ⅝ x 10 ¾ 193.7 x 273.0
40.5 - 45.5 60.3 - 67.7
9.62 244.35
8.00 203.2
8.75 222.25
7.75 196.85
51.5 - 55.5 76.6 - 82.6
9.43 239.52
60.7 - 65.7 90.3 - 97.8
9.25 234.95
9 ⅝ x11 ¾
244.5 x 298.5
60.0 - 65.0 89.3 - 96.7
10.38 263.65
9.38 238.25
10.00 254.00
9.25 234.95
Pocket Slip Liner Hanger & Tieback Receptacle SpecificationsSize Hanger Tieback
Liner x Cas-ing Casing OD ID OD ID
(in.) (mm)
(lb/ft) (kg/M)
(in.) (mm)
(in.) (mm)
(in.) (mm)
(in.) (mm)
9 ⅝ x 13 ⅜ 244.5 x 339.7
48.0 71.4
12.30 312.42
10.70 271.78
11.75 292.10
10.375 263.5
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
10 ¾ x 13 ⅜244.5 x 339.7
48.0 71.4
12.30 312.42
10.70 271.78
11.75 292.10
10.625 269.9
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
11 ¾ x 13 ⅜298.5 x 339.7
48.0 71.4
12.30 312.42
10.70 271.78
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
13 ⅜ x 16 339.7 x 406.4
55.0 - 70.0 81.8 - 104.2
14.75 374.65
12.75 323.85
13.62 345.95
12.625 320.7
75.0 - 84.0 111.6 - 125.0
14.53 369.06
109.0 - 118.0 162.2 - 175.6
14.16 359.66
146.0217.2
13.62 345.95
12.00 304.8
16 x 20 406.4 x 508.0
94.0 - 106.5 139.9 - 158.5
18.37 466.6
16.12 409.45
17.50 444.5
16.00 406.4
117.0 - 133.0 174.1 - 197.9
18.12 460.25
147.0 218.7
18.06 458.72
169 251.5
17.93 455.42
LINER HANGERS
8
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 ex-ceptional hanging capacities and minimal casing loading characteristics for non-rotating applica-tions.
The unique tongue-and-groove slip design mini-mizes 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.
The Rotating Pocket Slip Liner Hanger is set either mechanically (RPSM) or Hydraulically (HPS).
Other components required for liner rotation are the setting tool and the setting adapter. Hydrau-lic release (SHTR) and Double Spline (STS) set-ting tool provide the most flexibility.
Hydraulic-Set Rotating pocket Slip Liner Hanger features:
Pocket slip design eliminates cone collapse • while providing an effective cone angle twice than the conventional hangersSlips are manufactured to 55-60 Rockwell • “C” hardness for high-grade casing compat-ibilityCylindrical roller bearing can be replaced • with a spacer sleeve when rotation is not requiredManufactured 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 orderReduces slip loads; minimizes stresses in • supporting casingRight hand rotation of liner after hanging • and during cementing
Rotating Pocket Slip Liner Hanger
HpS
LINER HANGERS
9
EZ Series Liner Hangers is one of the most reli-able and efficient Mechanical Set Liner Hangers, as it is comprised of the hanger body or man-drel, 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 gauge ring protects the slips when running the hanger into the wellbore.
Non-Rotating Mechanical Set (EZ) Liner Hang-ers are set through manipulation of the work string: quarter right hand turn aligns the cones and the slips, after which slack offsets the slips into the casing wall.
Features and BenefitsCasing body hanger is manufactured from • L-80 and P-110 casing grades, with other grades available by special orderSingle or multiple cone designs available to • match hanging capacity with liner strength, minimizing stress in supporting casingSlips manufactured to 55-60 Rockwell “C” • scale for high grade casing compatibilityEZ hangers are available with API threads • only, whereas SB hangers are available in API or premium threadsCone pads, “J” lug, and gauge rings are • welded to the tool body. “Solid body” hang-ers include these parts as integral features machined from the heavy-wall tool body, eliminating body welding and maximizing performanceSolid body hangers are machined from AISI • 4100 Series alloy steel with controlled yield strengths and hardness for liner compat-ibilityA full OD permits the matching of some • premium threads on the hanger body
EZ Series Mechanical-Set Non-Rotating Liner Hanger
EZ
LINER HANGERS
10
SizeMax. OD
Liner x Casing Casing
(in.) (mm)
(lb/ft) (kg/M)
(in.) (mm)
2 ⅞ x 5 75.03 x 127.0
13.0 - 18.0 19.63 - 26.8
4.08 103.63
20.3 - 24.2 30.2 - 36.0
3.81 96.77
3 ½ x 5 88.9 x 127.0
11.5 - 13.0 17.3 - 19.3
4.25 107.95
15.0 - 18.0 22.3 - 26.8
4.08 103.63
3 ½ x 5 ½ 88.9 x 139.7
14.0 - 17.0 20.8 - 25.3
4.68 118.87
20.0 - 23.0 29.8 - 34.2
4.45 113.03
4 x 5 ½101.6 x 139.7
14.0 - 17.0 20.8 - 25.3
4.68 118.87
4 ½ x 7 114.3 x 117.8
17.0 - 26.0 25.3 - 38.7
6.05 153.67
29.0 - 38.0 43.2 - 56.5
5.68 144.27
5 x 7 127.0 x 177.8
17.0 - 20.0 25.3 - 29.8
6.18 156.97
23.0 - 26.0 34.2 - 38.7
6.05 153.67
29.0 - 32.0 43.2 - 47.6
5.87 149.10
35.0 - 38.0 52.1 - 56.5
5.68 144.27
5 x 7 ⅝ 127.0 x 193.8
24.0 - 29.7 35.7 - 44.19
6.50 165.10
33.7 - 39.0 50.1 - 58.0
6.25 158.75
5 ½ x 7 139.7 x 177.8
17.0 - 20.0 25.3 - 29.8
6.21 157.73
23.0 - 26.0 34.2 - 38.7
6.05 153.67
SizeMax. OD
Liner x Casing Casing
(in.) (mm)
(lb/ft) (kg/M)
(in.) (mm)
5 ½ x 7 ⅝ 139.7 x 193.8
24.0 - 29.7 35.7 - 44.19
6.62 168.15
33.7 - 39.0 50.1 - 58.0
6.37 161.80
7 x 9 ⅝177.8 x 244.5
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
7 ⅝ x 9 ⅝193.67 x 244.5
and 7 ¾ x 9 ⅝
196.85 x 244.5
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
9 ⅝ x 11 ¾244.5 x 298.45
42.0 62.50
10.81 274.57
47.0 - 54.0 69.93 - 80.35
10.62 269.75
60.0 - 65.0 89.28 - 96.72
10.43 264.92
9 ⅝ x 13 ⅜ 244.5 x 339.73
48.0 71.42
12.25 311.15
54.5 - 68.0 81.09 - 101.18
12.00 304.80
72.0 - 85.0 107.14 - 126.48
11.75 298.45
10 ¾ x 13 ⅜273.05 x 339.73
48.0 71.42
12.37 314.20
54.5 - 68.0 81.09 - 101.18
12.12 307.85
72.0 - 85.0 107.14 - 126.48
11.87 301.50
EZ Series Mechanical-Set Non-RotatingLiner Hanger Specifications
LINER HANGERS
11
HS Series Liner Hangers is one of the most robust Hydraulic-Set Liner Hangers series, as it is comprised of the hanger body or mandrel, one or more sets of cone pads, slips and a hydraulic piston/cylinder as-sembly to actuate the slips. The hydraulic piston/cylinder is shear pinned to actuate at a predetermined value. The hydraulic cylinder also incorporates the gauge ring to protect the slip assembly when running the hanger assembly into the wellbore.
Features and BenefitsCasing body hanger is manufactured • from L-80 and P-110 casing grades, with other grades available by special orderHydraulic cylinder manufactured from • material matching yield strength of the liner hangerHydraulic piston incorporates debris • wiper seal and anti rotation system to maintain slip/cone alignmentSlips manufactured to 55-60 Rockwell • “C” scale for high grade casing com-patibilityThe HSDB hanger is available with ei-• ther casing or heavy-wall tubing con-struction; “casing body” hanger cone pads 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 performanceSolid body hangers are machined • from AISI 4100 Series alloy steel with controlled yield strengths and hard-ness for liner compatibilityA full OD permits the matching of • some premium threads on the hanger bodySolid body hangers are available with • either API or Premium threads
HS Series Hydraulic-Set Non-Rotating Liner Hanger
HSdb
LINER HANGERS
12
SizeMax. OD
Liner x Casing Casing
(in.) (mm)
(lb/ft) (kg/M)
(in.) (mm)
2 ⅞ x 5 75.03 x 127.0
13.0 - 18.0 19.63 - 26.8
4.08 103.63
20.3 - 24.2 30.2 - 36.0
3.81 96.77
3 ½ x 5 88.9 x 127.0
11.5 - 13.0 17.3 - 19.3
4.25 107.95
15.0 - 18.0 22.3 - 26.8
4.08 103.63
3 ½ x 5 ½ 88.9 x 139.7
14.0 - 17.0 20.8 - 25.3
4.68 118.87
20.0 - 23.0 29.8 - 34.2
4.45 113.03
4 x 5 ½101.6 x 139.7
14.0 - 17.0 20.8 - 25.3
4.68 118.87
4 ½ x 7 114.3 x 117.8
17.0 - 26.0 25.3 - 38.7
6.05 153.67
29.0 - 38.0 43.2 - 56.5
5.68 144.27
5 x 7 127.0 x 177.8
17.0 - 20.0 25.3 - 29.8
6.18 156.97
23.0 - 26.0 34.2 - 38.7
6.05 153.67
29.0 - 32.0 43.2 - 47.6
5.87 149.10
35.0 - 38.0 52.1 - 56.5
5.68 144.27
5 x 7 ⅝ 127.0 x 193.8
24.0 - 29.7 35.7 - 44.19
6.50 165.10
33.7 - 39.0 50.1 - 58.0
6.25 158.75
5 ½ x 7 139.7 x 177.8
17.0 - 20.0 25.3 - 29.8
6.21 157.73
23.0 - 26.0 34.2 - 38.7
6.05 153.67
SizeMax. OD
Liner x Casing Casing
(in.) (mm)
(lb/ft) (kg/M)
(in.) (mm)
5 ½ x 7 ⅝ 139.7 x 193.8
24.0 - 29.7 35.7 - 44.19
6.62 168.15
33.7 - 39.0 50.1 - 58.0
6.37 161.80
7 x 9 ⅝177.8 x 244.5
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
7 ⅝ x 9 ⅝193.67 x 244.5
and 7 ¾ x 9 ⅝
196.85 x 244.5
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
9 ⅝ x 11 ¾244.5 x 298.45
42.0 62.50
10.81 274.57
47.0 - 54.0 69.93 - 80.35
10.62 269.75
60.0 - 65.0 89.28 - 96.72
10.43 264.92
9 ⅝ x 13 ⅜ 244.5 x 339.73
48.0 71.42
12.25 311.15
54.5 - 68.0 81.09 - 101.18
12.00 304.80
72.0 - 85.0 107.14 - 126.48
11.75 298.45
10 ¾ x 13 ⅜273.05 x 339.73
48.0 71.42
12.37 314.20
54.5 - 68.0 81.09 - 101.18
12.12 307.85
72.0 - 85.0 107.14 - 126.48
11.87 301.50
HS Series Hydraulic-Set Non-RotatingLiner Hanger Specifications
LINER TOP PACKERS
13
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 appro-priate 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.
Liner top packers are available in the following configurations:
WMP - for use with Model D setting tool• JMP - for use with Model STHR setting • toolVMP - for use with Model STS setting • tool
Holddown slips are available as special order for all packer types.
Features and BenefitsOptimizes chemical resistance to comple-• tion and production fluids with a variety of elastomer options for packer elements and seal assembliesMaintains element setting with mandrel • lock ringFacilitates high circulating rates with en-• hanced packer element designEliminates extra components and connec-• tions with integral retrievable cementing bushing profileAvailable with optional hold down slips • for 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 Slips
LINER TOP PACKERS
14
The Long Reach Liner Top Packer (LRTP) facili-tates successful liner deployment in vertical and long reach horizontal wellbores. Hydraulic-set-ting, combined with push, pull and rotation capa-bilities allow controlled liner deployment without excessive work string manipulation. Ease of de-ployment is further enhanced by an internal by-pass included in the packer and the Long Reach Setting Tool (LRST) reducing “piston effect” dur-ing running. The packer features an internal cir-culating string for wellbore fluid displacement if required. Packer elements are available with standard or thermal elastomeric construction for use in steam injection applications.
Features and BenefitsPush, pull and rotation capabilities facilitate • liner deploymentHydraulic primary release reduces work • string manipulation and eliminates string weight requirementsSecondary mechanical release. One quarter • left hand turn shears pins; straight pick-up releases packerDesigned to accept inner string circulating • accessoriesInternal bypass feature reduces “piston ef-• fect”Available with or without slips for hanging • and hold down applicationsPacker can be manufactured to match casing • thread, eliminating liner crossover
ApplicationsRunning liners in long reach horizontal wells• Setting sand screens in open hole below a • linerApplications requiring extended drill down of • the linerRunning conditions where the liner may need • to be pushed or jarred to bottomHanging light weight liners when a conven-• tional inner hanger is not necessaryApplications in which the liner is either • dropped off or needs to be hung and held downArchitectures in which additional bypass area • is required for minimizing lost circulation, or facilitating faster running speeds
Long Reach Liner Top Packer
LRTp w/ Standard Element
LRST
LRTp w/ Thermal Element
LINER TOP PACKERS
15
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 ap-plied. 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 hydraulic-setting tool, sealing the annular area between the liner and casing. It also provides a new tieback receptacle for future operations.
Features and BenefitsSets with hydraulic pressure applied to setting tool for uniform • setting forceEliminates transfer of setting weight to the liner• Optimizes chemical resistance to completion and production flu-• ids with a variety of elastomer options for packer elements and seal assembliesMaintains element setting with mandrel lock ring • Dual slips prevent movement of packer• High-grade casing compatible slips manufactured to 55-60 Rock-• well “C” hardnessL80 and Q125 material grades are standard, with other material • grades available by special order
Compression-Set Isolation PackerThe 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.
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.
Features and BenefitsAn anti-trip safety lock ring prevents premature setting• Optimizes chemical resistance to completion and production flu-• ids with a variety of elastomer options for packer elements and seal assembliesMaintains element setting with mandrel lock ring • Hold down slips prevent upward movement of packer• High-grade casing compatible slips manufactured to 55-60 Rock-• well “C” hardnessCLT packers are manufactured from AISI 4100 series alloys, • with other material grades available by special orderAvailable for Pocket Slip Liner Systems (CLTP)•
Hydraulic-Set Isolation Packer
cLT
HLT
TIEBACK & POLISHED BORE RECEPTACLE SYSTEM
16
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.
Features and BenefitsLocator threaded to match tieback liner/• casing connectionVariety of seal materials available for com-• patibility with anticipated well conditions; Viton®/Aramid seal units standardMule shoe configuration aids in stabbing • and facilitates re-entry with wireline equip-mentOptional cementing ports available• L80 and Q125 material grades are stan-• dard, with other material grades available by special order
Orifice Float CollarThe 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 tie-back 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.
Features and BenefitsSingle poppet valve standard• All internal parts are PDC drillable• Orifice port allows tieback liner to fill during • run-inOrifice prevents pressure lock by providing • a fluid pathL80 and Q125 material grades are stan-• dard, with other material grades available by special order
Tieback Seal Nipple
ofc
TbR
TSN
TIEBACK & POLISHED BORE RECEPTACLE SYSTEM
17
Tieback Receptacle SpecificationsSize Tieback
Liner x Casing Casing OD ID
(in.) (mm)
(lb/ft) (kg/M)
(in.) (mm)
(in.) (mm)
3 ½ 88.9
x 5 ½
139.7
14 20.8
4.375 111.25
3.75 95.25
15 22.3
17 25.3
20 29.8
23 34.2
26 38.7
4 101.6
x 5 ½
139.7
14 20.8
4.625 117.60
4.125 104.78
15 22.3
17 25.3
4 ½114.3
x 7
177.8
20 29.8
5.625 143.00
5.00 127.00
23 34.2
26 38.7
29 43.2
32 47.6
35 52.1
38 56.5
Size Tieback
Liner x Casing Casing OD ID
(in.) (mm)
(lb/ft) (kg/M)
(in.) (mm)
(in.) (mm)
5 127.0
x 7
177.8
20 29.8
5.82 147.82
5.25 133.35
23 34.2
26 38.7
29 43.2
32 47.6
35 52.1 5.625
143.005.125
130.1838 56.5
5 127.0
x 7 ⅝
193.7
24 35.7
5.82 147.82
5.25 133.35
26.4 39.3
29.7 44.2
33.7 50.1
39 58.0
55.3 82.3
5 127.0
x 7 ⅝
193.7
24 35.7
6.25 158.75
5.25 133.35
26.4 39.3
29.7 44.2
33.7 50.1
39 58.0
Size Tieback
Liner x Casing Casing OD ID
(in.) (mm)
(lb/ft) (kg/M)
(in.) (mm)
(in.) (mm)
5 ½ 139.7
x 7
177.8
20 29.8
6.06 153.92
5.562 141.27
23 34.2
26 38.7
5 ½ 139.7
x 7 ⅝
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 ⅝
244.5
32 47.6
8.25 209.55
7.375
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 ⅝ 193.7
x 9 ⅝
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 79.6 8.25
209.557.75
196.8553.5 SD 79.6
9 ⅝ 244.5
x 11 ¾ 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 ⅝ 244.5
x 13 ⅜ 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
TIEBACK & POLISHED BORE RECEPTACLE SYSTEM
18
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.
Features and BenefitsHoned ID reduces potential seal damage during tub-• ing expansion or contractionThick wall construction permits machining most pre-• mium threads on the body, eliminating crossovers One-piece construction eliminates potential leak • pathsAvailable in lengths of up to 30 feet without splice • connections or concentric couplings for optimal pres-sure integrity and seal performanceAdaptable with a Retrievable Landing Assembly pro-• file sub for adding profile nipples or other accessory equipment to the completionAISI 4100 series material grades are standard, with • other grades available by request
Polished Bore Receptacle
PBR Sizes
ID OD Max. ID ThruSeal 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
Specifications
pbR
TIEBACK & POLISHED BORE RECEPTACLE SYSTEM
19
The Tubing Seal Assembly (TSA) is the working seal between formation pressure and the production tubing. The TSA con-sists 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 se-lection and the PBR are critical to the useful life of the seals and elimination of many of the problems associated with well com-pletions. Integrity of the entire system requires careful planning and consideration of all components used in the completion.
Features and BenefitsLocator threaded to match tubing connection• Variety of seal materials available for compatibility with • anticipated well conditions; Viton®/Aramid seal units stan-dardMule shoe configuration aids in stabbing and facilitates re-• entry with wireline equipmentSeal mandrel ID machined to match the production tubing • specifications for ID and driftL80 and Q125 material grades are standard, with other • material grades available by special order Tubing Seal As-sembly
Tubing Seal AccessoriesThe 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 man-drel with a connection down for a seal assembly.
Features and BenefitsTop connection to match tubing connection, eliminating • cross-over subRight-hand release latch threads• Designed to uniformly distribute compressive loads into • liner top or PBRID machined to match the production tubing specifications • for ID and driftL80 and Q125 material grades are standard, with other ma-• terial grades available by special order
Tubing Seal Assembly
pLA
TSA
INTEGRATED LINER HANGER PACKER
20
Integrated Liner Hanger Packers (LHP) com-bines 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) configu-rations, with or without hold down slips. Me-chanical packers feature reliable right-hand setting, while hydraulic packers incorporate debris wiper seals in the piston for depend-able performance. Due to their specialized nature, liner hanger packers are recommend-ed for less severe applications.
Features and BenefitsPacker bodies manufactured from casing • of equivalent grade as the liner; L80 and Q125 material grades are standard, with other material grades available by special orderHigh-grade casing compatible slips manu-• factured to 55-60 Rockwell “C” hardnessCan be used as a tension-set packer when • run inverted
ApplicationsThe LHP is commonly deployed with sand • screens or slotted linersThe packer is also particularly effective • when used with scab linersThe 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
Integrated Liner Hanger Packer
HHp
LHp
SETTING TOOLS, SETTING ADAPTERS & ACCESSORIES
21
Mechanical Release Setting SystemThe Mechanical Release Setting Assembly consists of "D" setting tool, slick joint, cementing pack-off bushing, liner wiper plug adapter and extension to make up with the running string. This system is used for conveying non-rotating 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 re-lease liner running thread and a spline arrangement be-low the running threads. These splines permit right-hand setting of mechanical liner hangers. With the splines dis-engaged, the setting tool is then released without the need to find “neutral”.
Features and BenefitsDependable right-hand setting and release of the set-• ting tool from the liner is standard - no left-hand ro-tation required at any time Tensile ratings exceed liner hanger hanging capacity • with large overpull marginsSetting 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 set-ting tool from the linerEasily adapted with tamping dog assembly for setting • integrally run liner top packers without performance lossAccommodates a variety of cementing pack offs•
The Setting Adapter with Tieback Receptacle (SATM) As-sembly incorporates the right-hand release liner running thread 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 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 BenefitsManufactured from heavy-wall tubular alloys with • yield strengths matching the linerSpline system provides positive torque transmission • to the linerPolished bore-type tieback receptacle is standard• Metal-to-metal seal eliminates elastomers• Integral RCB profile•
model d/STL
SATm
SETTING TOOLS, SETTING ADAPTERS & ACCESSORIES
22
Hydraulic Release Setting SystemThe 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 hang-ers. A tamping dog assembly can be included if running an integral liner packer.
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, de-liberate 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 BenefitsHydraulic release from the liner with mechanical sec-• ondary releaseTorque transmitted through a right-hand drive clutch for • the 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 rotating • liner 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 release liner running thread with an auto-clutch arrangement that permits right-hand hanger setting as well as right-hand ro-tation. 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 be-tween the work string and the liner top. The SHTS features a back up mechanical release.
Features and BenefitsIntegral high torque, right-hand autoclutch• Manufactured from heavy-wall tubular alloys with yield • strengths matching the linerPolished bore-type tieback receptacle is standard• Metal-to-metal seal eliminates elastomers• Integral RCB profile•
SHTS
STHR
SETTING TOOLS, SETTING ADAPTERS & ACCESSORIES
23
The Double Spline Setting (STS) assembly consists of a Model STS Liner Setting Tool, slick joint, cementing pack-off bushing, liner wiper plug adapter and extension to make up with the running string. 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 arrange-ment 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 BenefitsDependable 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 torque Right-hand rotation of liners after hanging the rotating • liner 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 for conveying 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-set hangers as well as facilitating liner rotation after the hanger is set.
Features and BenefitsDependable 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 rotating • liner 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
SSTm
SETTING TOOLS, SETTING ADAPTERS & ACCESSORIES
25
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 un-necessary loss of rig time. The extension assembly is provided with a box connection to match the drill pipe.
Features & BenefitsHeavy wall tubular body manufactured from • AISI 4100 series alloy steelAssembled with Junk Strainer Assembly to re-• duce solids fallout into the liner tieback recep-tacleAvailable in various lengths to complement liner • tieback 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 the liner setting tool and the extension assembly. When the 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 ensure complete extension when the assembly is removed from the tieback receptacle. Work string slack off weight is transferred through the dogs into the tie-back receptacle and into the packing element, set-ting the packer.
Features & BenefitsHeavy-duty body manufactured from AISI 4100 • series alloy steelTensile rating equal to or greater than the liner • setting toolLarge dogs with machined shoulders for opti-• mum weight transfer to the packerSmooth ID matched to liner setting tool and • extension assembly for trouble free passage of drill pipe wiper plugs
Tamping dog Assembly
ExtensionAssembly
Setting Tool Extension Assembly
SETTING TOOLS, SETTING ADAPTERS & ACCESSORIES
24
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 set-ting adapter incorporates a “Jay” configura-tion instead of the running thread normally used in setting adapters. The “Jay” profile can be configured for either left- or right-hand re-lease. The system can also be supplied with double “Jay” arrangement if additional tensile and torque capacities are desired. If a Tie-back Receptacle (TBR) is required, the “Jay” Setting Adapter uses the same dependable metal-to-metal seal design between the set-ting adapter and the TBR as with other Smith Services setting systems.
J–Setting Tool Features and Benefits“Jay” lugs are an integral part of the set-• ting tool mandrel - no welds to break Same setting tool used for either right- or • left-hand release “Jay” setting adaptersRight-hand rotation of liners after hang-• ing the rotating liner hangerOne quarter-turn for easy removal of the • setting tool when liner cementing is com-pleted Usable with all Smith cementing pack off • assembliesSuitable for use with packer tamping dogs • when running integral liner top packers
J–Setting Adapter features andBenefits
Quarter-turn machined “Jay” slot con-• figuration for easy release from the liner hanger after settingL80 and Q125 material grades are stan-• dard, with other material grades avail-able by special orderMetal-to-metal seal system for maximum • TBR pressure integrityEasily adapted for use with Retrievable • Cementing Bushing assemblies“Jay” configuration setting adapter can • be incorporated into integrally run liner top packers
"Jay" Release Setting System
SJTm
model “J”
CEMENT BUSHING
27
The Cementing Pack Off Coupling (POC) is a Pol-ished 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.
Features and BenefitsPremium PBR sealing system for optimum • pressure integritySleeve design permits easy seal size changes • to accommodate different seal bore IDsElastomer selection available for compatibility • with various drilling/wellbore fluids
Swab Cup AssemblyThe Swab Cup Assembly (SWCA) is used in appli-cations 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 avail-able 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 be-low the setting tool, providing unrestricted access to the liner when retrieved.
Features and BenefitsUtilizes commercially available swab cups• Field re-dressable without special tools• API end connections allow easy “space out” • using standard pup joints
poc
SwcA
Cementing Pack Off Coupling
CEMENT BUSHING
26
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 con-ditions and preferences.
Retrievable Cementing BushingThe 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.
Features and BenefitsFull circle locking lugs for optimum pressure resistance• Small piston area reduces forces on work string while cir-• culating and cementingCompletely retrievable, leaving full opening to liner below • without drilling out
Slick Joint featuresPolished OD for maximum sealing integrity and pressure • resistanceReduced diameter to allow retraction of RCB locking lugs• Swivel adapter assembly for liner wiper plug attachment• Available in lengths up to 25 feet•
Drillable Cementing BushingThe 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 BenefitsSmall 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
Rcb w/ Slick Joint
dcb
CASING HARDWARE
29
The Float Landing Collar (FLC) combines the features of the landing collar with a float valve, and it is typi-cally used as an economical alternative to separate components or to reduce shoe track length.
Features and BenefitsThreaded 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
Float Shoe and Guide ShoeThe Float Shoe (FS) is made up as the first compo-nent in a liner assembly. The tool features an insert dart-type poppet valve with elastomer seals cement-ed into the housing, and includes a standard cement nose, 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 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.
Features and BenefitsSingle or dual poppet valves• All internal parts PDC drillable• 80,000 psi through 125,000 psi yield strengths • are standardAPI RP 10F Category III C compliant• Cement nose standard; bladed bottom available • by special order
Float Landing Collar
fLc
GS
fS
CASING HARDWARE
28
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.
Features and BenefitsProvides the landing seat for cementing plugs • Acts as a backup to the float collar/shoe with the • plugs latched and sealedThreaded 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
Ball Catch Landing CollarThe Ball Catch Landing Collar (BC) is run when any hy-draulically-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, in-creasing pressure shears the ball seat and re-establishes circulation.
Features and BenefitsThreaded 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 sealedAnti-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 systemHousing suitable for all premium connections• L80 and Q125 material grades are standard, with • other material grades available by special order
Landing Collars
bc
Lc
CEMENTING EQUIPMENT
31
pump down plug
Liner wiperplug
Pump Down Plug and Liner Wiper PlugThe Pump Down Plug and Liner Wiper Plug provide separation between drilling/dis-placing 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 Liner Wiper Plug is normally shear pinned to the setting tool and provides the seal bore for the pump down plug. A hol-low 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 land-ing collar, the plugs prevent back flow of cement. If desired, the liner wiper plug can be placed in a plug holder bushing below the liner hanger.
Features and BenefitsLocking system provides back pressure • capability when locked and sealed in the landing collarElastomer selection for compatibility • with today's complex drilling fluidsPDC drillable• Anti-rotation feature reduces drill-out • times
CEMENTING EQUIPMENT
30
The Pressure Activated Stage Cementing Tool functions by applied pressure to per-mit upper stage cementing. Opening is con-trolled by a piston at the end of first stage cementing. Opening pressure moves an in-ner sleeve upward aligning the cementing ports. The Stage Cementing Tool 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 Stage Cementing Tool is particularly advantageous when cementing long liners. Waiting time for a conventional opening ball is eliminated and the probability of success-ful second stage cementing is greatly en-hanced.
This tool is also useful in cementing liner tieback strings. By placing the Stage Tool above the tieback seal assembly the seals can be left in the tieback receptacle. This eliminates pumping cement past the tie-back seals. The Stage Tool is closed by the plug following the cement. Pressure integ-rity is regained when the inner sleeve is closed and locked.
Features and BenefitsManufactured from alloy steel matching • liner grade for optimum performanceOpening pressure easily adjustable in • the fieldHydraulic opening, mechanical closing • for positive, reliable operationInner sleeve locked closed at end of ce-• ment placement; cannot be reopened later by full gauge tools
pressure Activated Stage cementing Tool
Pressure Activated Stage Cementing Tool
CEMENT MANIFOLD
33
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 cement-ing has been completed. The CMSB also connects the cementing lines to the run-ning 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 BenefitsMaximum strength and toughness • from quenched and tempered alloy steel construction Displacement fluid and cement are • diverted below or above the plug through an external manifoldManifold rated to 5,000 PSI working • pressureAvailable in single or dual plug con-• figurationCementing flag sub available for vi-• sual indication of drill pipe wiper plug releaseHeavy duty swivel permits easy ma-• nipulation of the string without hav-ing to break down the cementing lines
Solid Body Cementing Manifold
cmSb
ball drop Assembly
plug drop Assembly
CEMENTING EQUIPMENT
32
The Dual Liner Wiper Plug System (DPS) provides en-hanced 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.
Features and BenefitsPrevents cement contamination in drill pipe and liners • Locking system provides back pressure capability when • locked and sealed in the landing collarElastomer selection for compatibility with most drilling • fluidsPDC drillable• Anti-rotation feature reduces drill-out times•
Dual Liner Wiper Plug System
dpS
CEMENT MANIFOLD
34cmIb
The Top Drive Cementing Manifold (CMIB) elimi-nates cement contamination of top drive compo-nents. It creates a flow path for cement and dis-placing 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 capac-ity CMIB consists of a swivel and an internal bypass manifold with integral ball drop and plug drop as-semblies. 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 main-tenance and feature an independent indicator for each plug or ball dropped. The CMIB can be config-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 BenefitsHigh 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 boreFlush 13-inch OD profile maximizes rig safety • during handling and rotationUnobstructed bore after plug or ball is • droppedLarge flow area accommodates high displace-• ment ratesAnti-rotation tie-off integral to swivel housing• Canister design prevents plugs or balls from • floating into drop mechanismsTorque-keyed connections do not require heavy • make-up torquesReduces cement adhesion with coated and • treated internal partsPneumatic remote control available as an op-• tionKelly valve available in upper or lower end of • swivel, if desired
Top Drive Cementing Manifold
INNER STRING CIRCULATION TOOLS
35
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 AssemblyThe Ported Swab Cup Assembly (SWCA) utilizes op-posed packer cups between a ported mandrel. This configuration, when combined with a pressure con-taining device such as the Ball Catch Sub, allows pressure to be directed between the opposed cups. This pressure is then directed to specific hydrau-lically-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.
Tubing SwivelThe Tubing Swivel (TS) permits easier make-up or manipulation of the inner string. The swivel bearing assembly functions in both compression and ten-sion. 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 pres-sure integrity
Ball Catch SubThe Ball Catch Sub (BCS) is normally used with in-ner 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.
TS
bcS
ported SwcA
Inner String Circulation Tools
DRESS MILL ASSEMBLY
36
The Dress Mill Assembly (DMA) is config-ured 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 pi-lot mill sized to the liner, a bladed polishing mill and a Stop Sub with a drill pipe box connection. Depending on the liner config-uration, the DMA may include one or more spacer tubes for proper mill placement.
Features and Benefits Ground dressing surfaces clean honed • bores without damaging seal surfacesDrill pipe connections on all compo-• nents for maximum performanceStop sub is dressed to repair any bit • damage to the liner top while provid-ing positive indication the mill assem-bly has worked through the liner topBodies and spacer tubes manufactured • from AISI 41XX series alloy steel for durability and toughness
Dress Mill Assembly
dmA
LINER HANGER SYSTEMS
37
Premium Hydraulic/Mechanical Rotating Liner Hanger ( Pocket Slip with FSP Packer)
Pocket Slip Rotating Liner Hanger (available with Non-Rotating Pocket Slip)
Frontier SeriesPacker
Tieback Receptacle
Dual Valve Float Shoe
Cement BushingProfile (PSRT)
Landing Collar
Dual ValveFloat Collar
Pump Down Plug
STPR Pocket SlipSetting Tool
FSP Setting Tool
Retrievable Cementing Bushing
Slick Joint
Liner Wiper Plug
LINER HANGER SYSTEMS
38
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 CatchLanding Collar
Dual ValveFloat Collar
Dual ValveFloat Shoe
Pump Down PlugPWPC
Junk Strainer
Tamping Dogs
Drill Pipe Extension STX
Hydraulic Release Tool SHTR
Retrievable Cementing Bushing
Liner WiperPlug LWPC
LINER HANGER SYSTEMS
39
EZRD Mechanical-Set Non-Rotating Liner Hangerwith WMPO Liner Top Packer
Polished BoreReceptacle
Retrievable Cement BushingProfile
WMPO Liner Top Packer Integral with SATM Setting
EZRD Non-Rotating Mechanical Set Liner Hanger
Double ValveFloat Shoe
Double ValveFloat Collar
Landing Collar
Liner Wiper Plug
Slick Joint
Retrievable Cement BushingProfile
Model D/STL Mechanical Release Tool
DA Tamping Dog
STX Drill PipeExtension
Junk Strainer
LINER HANGER SYSTEMS
40
HSDB Hydraulic Non-Rotating Liner Hangerwith WMPO Liner Top Packer
Polished BoreReceptacle
Retrievable Cement BushingProfile
WMPO Liner Top Packer with Integral Setting Adapter SATM
HSDB Non-Rotating Hydraulic Set Liner Hanger
Double ValveFloat Shoe
Double ValveFloat Collar
Ball CatchLanding Collar
Junk Strainer
STX Drill Pipe Extension
DA Tamping Dog
Model D/STL Mechanical Release Tool
Retrievable Cement BushingProfile
RSJC Slick Joint
LWPC Liner Wiper Plug
LINER HANGER SYSTEMS
41
Compression-Set Isolation Packer (Second Trip)
Tieback
SATM Setting Adapter
Compression Setting Tool (CLT)
Seal Nipple
Junk Strainer
STX Drill Pipe Extension
Model D/STL Mechanical Release Tool
Retrievable Cement Bushing
RSJC Slick Joint
TYPICAL LINER APPLICATIONS
42
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 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.
figure cA 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 me-chanical-set liner hanger suspends the liner weight from the intermediate casing.
figure dThis diagram shows a wellbore design using the conven-tional 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 EAt 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 holddown 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.
figure fA 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 ex-cess 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 holddown slips also assist in keeping short, lightweight liners in position until cement is set.
Typical Liner Applications
TYPICAL LINER APPLICATIONS
43
Typical Liner Applications (cont.)
figureA
figureb
figurec
TYPICAL LINER APPLICATIONS
Typical Liner Applications (cont.)
44
figured
figureE
figuref
TECHNICAL INFORMATION
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 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 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 ar-rangement) 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 StackThe “HPHT” high performance seal stack utilizes a pro-prietary blend of Teflon and Carbon that are basically in-ert 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 per-formance seals, Smith's high performance seal stack pro-vides 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:Stainless steel back-up1. PEEK-LLV (Polyetheretherketone) back-up2. TFM-FTMM Teflon (Proprietary blend)3. PTFE-LRC AH Polytetrafluoroetheylene primary seal 4. element
Elastomer Guide
"HpHT" High performance Seal Stack
Teflon Adapter
Ring
Teflon pressure
Ring
StandardSeal
Stack
Viton pressure
Ring
1 2 3 4 3 4 3
45
TECHNICAL INFORMATION
Elastomer Guide (cont.)Special Application materialSmith’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. Ka-lrez seals provide proven temperature and chemical resistance, as well as pres-sure performance. Kalrez has restricted movement and should never be allowed to leave the seal bore.
molded Seal packingMolded seal units of either nitrile or Viton should be specified if you cannot pre-vent 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 wash-off 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 condi-tions, 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•
Ryton Adapter
Ring
Ryton pressure
Ring
kalrezpressure
Ring
Teflon pressure
Ring
moldedSeal
moldedSeal
molded Seal packing
46
TECHNICAL INFORMATION
Completion Systems’ test cell facility at the Hardy Road campus in Hous-ton, Texas, improves product verifi-cation turnaround times by expand-ing in-house testing capabilities. A broad range of downhole tempera-tures, pressures and loads can be simulated to meet both industry and customer-specific testing require-ments. Testing parameters are fully documented and compliant with the latest industry standards.
Summary of Testingcapabilities
Hydrostatic Pressure: 15,000 psi • for 9 ⅝ inches and smaller sizes. 10,000 psi for larger tools Nitrogen Pressure: 15,000 psi • for 9 ⅝ 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•
Any of the mentioned parameters can be used in combination to provide an accurate simulation of downhole con-ditions.
Safety featuresEnsuring the safety of personnel and the environment is of primary con-cern during testing. Extensive safety checks are performed prior to ev-ery 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 environ-ment. 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 scav-enges any excess test media and processes out contami-nants, preventing release into the environment.
During testing, real time test data may be monitored from the control room, or can be accessed remotely using pro-prietary software. Test data is digitally recorded on four pressure channels and two
temperature channels. These results can be stored in the test lab’s data-base, ready to be burned to a CD for attachment to test reports.
All phases of the testing process can also be visually monitored and re-corded through two digital cameras mounted within the test cell.
commitment to ExcellenceThe 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.
A view inside the cell with a packer in place for a test to be conducted
panel to control air, water and nitro-gen pressures
The heat controller with the camera monitor (at top)
Engineering Test Cell Facility
47
TECHNICAL INFORMATION
49
Well Summary Sheetwell Summary Sheet
date: Smith district/Rep.: page ——
of: ——prepared by: field:
customer: Lease:
casing casing Liner Tieback Tubing drill pipe
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
PBR or T.B. Rec. OD (in.)
PBR or T.B. Rec. ID (in.)
PBR Receptacle Length (ft.)
No. of Seals, Spacing
Expected Tubing Movement (ft.)
Elastomer Spec./Required
Planned Slack-off (lbs.)
Seal Assembly Specifications
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)
packer data
Planned Hanger Type (hyd./mech.)
Planned Liner Setting Pressure (psi)
Rotation and / or Reciprocation
Landing Collar Setting Pressure (psi)
Type of Rig
Treating (yes/no)
Drill Pipe Being Used
Comments:
miscellaneous
48
Liner Hanger Data Sheet
TECHNICAL INFORMATION