SERVICE SERVICE UNDER UNDER PRESSURE. PRESSURE
Seaboard Wellhead Equipment and Gate Valves API 6A and ISO 9001:2000
Contents Casing Heads and Spools S-22 Casing Heads and Spools Spools.............. ............................ ............................ ............................ ............................. ............................. .......................1-2 .........1-2 Fas-Loc Wellhead System ............. .......................... .......................... ........................... ........................... ........................... ........................... ....................... .......... 3 SMB-22 Multibowl System ............. .......................... ........................... ........................... .......................... ........................... ........................... ....................... .......... 4 SS-L Buttweld Sub and CMH Hanger System ............ ......................... .......................... .......................... ........................... ...................... ........ 4
Tubing Heads, Casing Hangers, Secondary Seals S Tubin Tubing g Heads .............. ............................ ............................ ............................ ............................ ........................... ........................... ............................ ..................... ......... 5 SD Tubin Tubing g Heads .............. ............................ ............................ ............................ ........................... ........................... ............................ ............................ .................... ...... 5 SP,, SP-H, and IP Secondary Seals ............ SP .......................... ........................... ........................... ........................... ........................... ....................... ......... 5 S-22 Casing Hangers......................... Hangers...................................... ........................... ........................... .......................... ........................... ........................... ................... ...... 6 S-22-NL Casing Hangers ............ .......................... ........................... .......................... ........................... ........................... .......................... .......................... ............. 6 S-22-HL Casing Hangers ............ ......................... ........................... ........................... .......................... ........................... ........................... .......................... ............. 6
Tubing Completion Systems SM-E Tubing Hangers........................ Hangers..................................... ........................... ............................ ........................... ........................... ........................... .................. ..... 7 SM-T Tubing Hangers ............ .......................... ........................... ........................... ............................ ........................... ........................... ........................... ................ ... 7 SM-E-CL Tubing Hangers ............. .......................... ........................... ............................ ........................... ........................... ............................ ....................... ......... 8 SM-T-CL Tubing Tubing Hangers ............. .......................... ........................... ............................ ........................... ........................... ............................ ....................... ......... 8 ESP Feed Through Systems Systems ............. ............................ ............................. ............................ ............................ ............................ ............................ ................ 9 SD and SD-CL Dual Completion Hangers ............. .......................... ........................... ........................... ........................... .......................... ............ 9 Tension Tubing Hangers ............. .......................... ........................... ........................... ........................... ........................... .......................... ......................... ............ 10 Slim Line Tubing Hangers ............. ........................... ........................... .......................... ........................... ........................... .......................... ....................... .......... 10
Specialty Equipment Communication Slick Joint ............. ........................... ............................ ........................... ........................... ........................... ........................... ..................... ....... 11 NW-A Casing Heads Heads .............. ............................ ............................ ............................ ........................... ........................... ............................ .......................... .............. 12 NW-B Diverter Heads ............. .......................... ........................... ........................... ........................... ............................ ........................... ........................... ................ 12
Gate Valves Model 500 Wedge Gate (3M/5M) (3M/5M).............. ............................ ............................ ............................ ............................ ............................ .................... ......13-14 13-14 Model 1520 Wedge Gate (10M)......................... (10M)....................................... ............................ ........................... ........................... ..........................13-14 ............13-14 Model 1540 Wedge Wedge Gate (10M/15M) (10M/15M) .............. ........................... ........................... ............................ ............................ ............................ ................ .. 15 Model 1540S Slab Gate (20M) .............. ............................ ............................ ............................ ............................ ............................ ......................... ........... 16 Model 640 Slab Gate (3M/5M) ............. ........................... ............................ ............................ ............................ ............................ ........................... ............. 17 Model 1640 Slab Gate (10M/15M) (10M/15M)............. ........................... ........................... ........................... ............................ ............................ ...................... ........ 17 Gate Valve Trim Chart ............. .......................... ........................... ............................ ............................ ............................ ............................ ........................ ............. ... 18
Cover photograph courtesy of Jack Richburg Photography. Photography. Catalog and contents © contents © Seaboard. Seaboard.
S-22 Casing Heads and Spools The Seaboard conventional wellhead system incorporates the S-22 straight bowl design with a 45 degree load shoulder.
Significant advantages of the S-22 bowl:
1
• •
One bowl design that universally accepts slip-type or mandrel casing hangers
•
Design concept is carried forward into the Fas-Loc and SMB-22 multibowl systems for component interchangeability and retention of superior design characteristics
•
Damage during drilling activities is minimized, thereby decreasing the frequency of maintenance and/ or potential replacement
• •
Wear bushings can enhance the protection of important sealing surfaces
Low-weight hangers for tieback applications and high capacity hangers are also accommodated due to the straight bowl and 45 degree load shoulder which diminishes hoop stress on the casing heads and spools
Test plugs and wear bushings often wedge in tapered bowls under pressure, a possibility virtually eliminated with the S-22 bowl design
System Features
•
Scope 2,000 through 20,000 PSI
o
•
•
•
• •
o
API 6A PSL-1 through PSL-4
o
Appendix F Qualified
Top Connections o
API Flanges
o
API Hubs
S-22-R S-22-R
S-22-AP S-22-AP
Bottom Connections o
Threaded
o
Slip-on Weld
o
NW-A Sliplock
o
Baseplates (Welded or threaded)
Secondary Seals - Casing Spools o
Elastomer Seal Bushings (SP)
o
High pressure Seal Bushings (SP-H)
o
Integral Seal Bottoms (IPS)
Lockscrew Detail
Lockscrews (optional) Outlets o
Threaded
o
Studded
o
Flanged
S-22 Casing Spool Sizing Data Rated Working Bottom Flange Pressure 3,000 psi
S-22 Casing Head Sizing Data
PSI
Top Flange Size (in.)
PSI
Minimum
Weight
Bore (in.)
(lbs.)
11
3,000
11
3,000
10.00
745
13-5/8
3,000
11
3,000
10.00
1050
16-3/4
3,000
11
3,000
10.00
1145
16-3/4
3,000
13-5/8
3,000
12.50
1170
21-1/4
2,000
13-5/8
3,000
12.50
1450
20-3/4
3,000
16-3/4
3,000
15.38
2710
11
3,000
11
5,000
10.00
760
11
5,000
11
5,000
10.00
1250
Rated Working
Casing
Minimum
Weight
Pressure
Size (in.)
Size (in.)
PSI
Bore (in.)
(lbs.)
2,000 psi
20
21-1/4
2,000
19.00
1,550
3,000 psi
8-5/8
11
3,000
8.00
470
13-5/8
3,000
11
5,000
10.00
1260
9-5/8
11
3,000
9.00
450
13-5/8
5,000
11
5,000
10.00
1395
10-3/4
11
3,000
10.00
430
16-3/4
3,000
11
5,000
10.00
1220
3,000
13-5/8
5,000
12.50
1325
5,000 psi
13-3/8
13-5/8
3,000
12.50
645
16-3/4
16
16-3/4
3,000
15.38
825
20-3/4
3,000
13-5/8
5,000
12.50
2530
1,640
20-3/4
3,000
16-3/4
5,000
15.38
3005
720
21-1/4
5,000
13-5/8
5,000
12.50
2840
21-1/4
5,000
16-3/4
5,000
15.38
3305
13-5/8
5,000
11
10,000
10.00
2190
20
5,000 psi
Top Flange
Size (in.)
20-3/4
8-5/8
11
3,000 5,000
19.00 8.00
9-5/8
11
5,000
9.00
617
10-3/4
11
5,000
10.00
600
13-3/8
13-5/8
5,000
12.50
675
16-3/4
5,000
11
10,000
10.00
2380
16
16-3/4
5,000
15.38
1,655
16-3/4
5,000
13-5/8
10,000
12.50
2905
20
21-1/4
5,000
19.00
1,825
21-1/4
5,000
13-5/8
10,000
12.50
3365
10,000 psi
2
Fas
Loc
The Fas-Loc wellhead system was developed to meet all of the needs of conventional equipment while reducing much of the associated time, costs and risks. The Fas-Loc wellhead system significantly reduces rig time and associated rig costs over those utilizing conventional wellhead equipment. For multiple well programs, the diverter adapter and BOP service adapters may be transferred from well to well, eliminating the time required to nipple up and down between locations. Safety is enhanced with the Fas-Loc casing head by eliminating the requirements for torch cutting and welding operations normally associated with casing head installation. Another time saving feature is the ability to land the casing head through the BOP, eliminating the need to wait on cement. The Fas-Loc casing head bowl is designed to accept standard slip hanger arrangements. Further reducing time, the Fas-Loc tubing head makes up quickly without special tools. The Fas-Loc wellhead system easily adapts to accommodate intermediate casing strings according to the requirements of the drilling program.
•
Overall system designed to save time/rig costs
•
Dedicated diverter adapter
•
o
Transfers from well to well
o
Makes up quickly with no special tools
Dedicated BOP service adapter o
Transfers from well to well
o
Makes up quickly with no special tools
•
Increases safety by eliminating torch cutting/ welding operations for casing head installation
•
Fas-Loc casing head is landed through BOP o
3
Eliminates waiting on cement
•
Fas-Loc casing head accepts standard slip hanger arrangements
•
Fas-Loc tubing head makes up quickly without special tools
•
Fas-Loc tubing head accepts any Seaboard tubing hanger arrangement
•
Fas-Loc system easily adapts to accept intermediate casing string/spool if needed
SMB-22 Multibowl Systems SS-L Buttweld Sub and CMH Hanger System Installing and removing the BOP stack is a time consuming procedure performed each time a conventional head or spool is added during drilling operations. During BOP removal, there is a potential for disaster either through a blowout or injury to the drilling crew. The compact SMB-22 multibowl wellhead system eliminates the need for one nipple up by landing multiple casing strings in one head. The SMB-22 multibowl wellhead assembly is a fullbore design. The lower casing hanger is fluted to allow ample by-pass for circulating mud and cement. The seal assembly, which lands on the flutes, also acts as a support for the upper hanger. A wide choice of tubing hanger designs are available for various service conditions. Emergency suspension systems are available for the lower hanger. The SS-L buttweld sub and CMH hanger is a versatile wellhead system offering a flanged and non-flanged means of nippling up a diverter system. Conductor and surface casing can be run through the diverter, thus saving time (one less nipple down), money, and safety. Rig time is saved by utilizing the SM-E mandrel hanger for the surface casing, which allows for faster installation of a conventional wellhead, or multibowl system, because no welding is required. The SS-L buttweld sub system is flexible to most casing programs and offers emergency equipment options.
Additional Features:
•
Conductor hanger may be tested externally once landed
•
Conductor hanger seals may be re-energized, if necessary
•
Surface casing hanger may be landed prior to cementing, eliminating the need to reciprocate
• Annular seal for surface casing hanger may be run through the diverter, locked in place (flanged diverter head) and tested externally
• Annular seal for surface casing hanger may be re-energized, if necessary
• All running/retrieving tools run on casing
4
S Tubing Heads The S tubing head is designed to be full opening even over 7-5/8” casing. The straight bowl and 45 load shoulder allows the use of one bowl design for virtually all applications. A variety of single and dual tubing hangers are available for a wide array of service conditions and operating preferences. °
Multiple Completion Options SD dual tubing heads are equipped with two MC (multi-completion) guide pins located 180 apart just above the 45 load shoulder. When landing the dual tubing hanger, the MC guide pins are run in to orient the tubing hanger segments. °
°
Tubing Head Bottom Connections Standard bottom preparations for tubing heads include single or double IP seals, SP or SP-H packoff bushings. For IP secondary seal configurations, the tubing head provides injection ports through which plastic can be injected to enhance the IP seal.
S Tubing Head
SP, SP- H, and Double IP Seals
SP Secondary Seal
SP-H Secondary Seal
Double IP Secondary Seal
The SP seal is a simple press energized design comprised of an elastomer element sandwiched between two compression plates. The assembly is retained in the pocket with a snap ring. The SP-H seal is similar in design to the SP, but is better suited for use in higher pressure applications. The assembly is retained in the pocket by a threaded ring. The Double IP seal is ideal for use as crossover where moderately severe service is expected. Each seal is plastic energized, which can also be tested via a port located between the seals to verify seal integrity.
5
S-22 Casing Hangers The S-22 casing hanger is a slip style hanger which automatically seals the casing annulus. During installation, the hanger is wrapped around the casing and the slip retaining screws are removed, allowing the slips to ride down the internal taper. As the casing slides through the hanger, the segmented slips grab and wedge between the tapered bowl and the casing. The annulus seal below the bowl is automatically energized by the weight of the casing as it is transferred through the slips to the 45 load shoulder in the head or spool.
S-22 Casing Hanger
°
Casing weight must meet or exceed those listed in the chart to the right. If the minimum weight is not met, the elastomer seal may not extrude sufficiently to seal against the casing’s surface. If the casing weight is in excess of 50% of the casing joint strength, the seal may over-extrude and become ineffective. Alternate hangers are available for these conditions.
Minimum Casing Loads for S-22 Casing Hangers Bowl Sizes Casing Size 11” 13-5/8” 16” 4-1/2” - 5-1/2”
55,000
7” - 7-5/8”
40,000
8-5/8” - 9-5/8” 10-3/4”
20”
58,000 77,000
13-3/8”
150,000
The S-22-NL casing hanger is appropriate for no load or mudline applications. The slips are set by pulling slight tension on the casing. When the tension is released, the slight casing movement sets the slips. The annulus seal above the slips is energized manually after the BOP stack is removed.
S-22-NL Casing Hanger The S-22-HL casing hanger accommodates loads in excess of 50% of the casing joint strength. The double wedge back slip design permits the same length of slip to support a higher load without impinging the casing. The design also features a positive stop which limits extrusion of the seal.
S-22-HL Casing Hanger
6
Single Completion Tubing Hangers and Adapters for Land Installations
SM-E Tubing Hangers The SM-E tubing hanger is a versatile design using elastomer seals. The hanger can be equipped with a suspension style control line preparation and isolation seals on the neck to accommodate traditional control line porting through the adapter. The control line porting can be used or ignored without affecting the functioning of the tubing hanger. The tubing hanger consists of a main body, an elastomer seal and a compression/support ring. The annulus seal is automatically energized by the weight of the tubing string. Extrusion of the seal is controlled by a positive stop between the compression/support ring and the hanger body. If the tubing weight is not sufficient to extrude the seals, it will be energized by the lockscrews used to retain the hanger in the bowl. An internal profile is provided for setting a back pressure valve.
SM-E Tubing Hanger
SM-T Tubing Hangers The SM-T tubing hanger uses a metal taper design on the hanger’s neck to isolate the production flow. Metal seals are far superior to elastomers making this hanger suitable for more critical service applications. During installation, the hanger is landed and the lockscrews run in to retain the hanger and energize the annulus seal. The metal seal on the hanger neck is energized by making up the adapter. The taper on the ID of the adapter slightly opposes the OD of the tubing hanger neck, causing the neck to deform slightly. This deformation is safely within the elastic limits of the yield strength of the hanger material, permitting the connection to be broken and remade repeatedly without damaging the sealing surfaces. An internal profile is provided for setting a back pressure valve.
SM-T Tubing Hanger
7
Single Completion Tubing Hangers and Adapters for Offshore Installations
SM-E-CL Tubing Hangers The SM-E-CL tubing hanger provides a continuous control line setting using elastomer seals in the both hanger bowl and hanger neck. The tubing hanger consists of a main body, an elastomer seal and a compression ring. During installation, the hanger is landed and the lockscrews run in to retain the hanger and energize the annulus seal. The neck of the tubing hanger uses S seals to seal against the straight bore of the adapter. The continuous control line is supported and sealed above and below the hanger with common ferrule-type fittings. The control line exits through the adapter and is sealed off in a specially designed exit block (shown) or nipple/tapped bull plug arrangement. An internal profile is provided for setting a back pressure valve.
SM-E-CL Tubing Hanger
SM-T-CL Tubing Hangers The SM-T-CL tubing hanger provides a continuous control line setting while using metal seals in the hanger neck to isolate the production flow. Metal seals are far superior to elastomers making this hanger suitable for more critical service applications. The tubing hanger consists of a main body, an elastomer seal and a compression ring. During installation, the hanger is landed and the lockscrews run in to retain the hanger and energize the annulus seal. The metal seal on the hanger neck is energized by making up the adapter. The taper on the ID of the adapter slightly opposes the OD of the tubing hanger neck, causing the neck to deform slightly. This deformation is safely within the elastic limits of the yield strength of the hanger material, permitting the connection to be broken and remade repeatedly without damaging the sealing surfaces. The continuous control line is supported and sealed above and below the hanger with common ferrule-type fittings. The control line exits through the adapter and is sealed off in a specially designed exit block.
SM-T-CL Tubing Hanger
An internal profile is provided for setting a back pressure valve.
8
ESP Feed Through Systems When the oil is heavy or reservoir pressure is depleted, it is often necessary to resort to artificial lift methods for bringing the oil to the surface. A commonly used device is the electric submersible pump. The pump is made up into the bottom of the tubing string as it is run in the hole. An electric cable, which will eventually transmit power to the pump, is run side by side with the tubing string. The ESP tubing hanger is eccentrically aligned, offsetting the tubing string to allow passage of the electric cable through the hanger to the outside. A mandrel with a uniquely designed, pigtail style electric plug connector on each end creates a totally sealed conduit for passing the electricity from the outside power source through the wellhead hou sing and into the production annulus. ESP equipment is designed for hostile environments and can be adapted for temperatures up to 350 F, pressures up to 10,000 psi and for highly corrosive service. °
Adapter Assemblies ESP systems are often used in rework applications. Adapter assemblies are available in common sizes and pressure ratings to connect to existing wellheads without removing the tubing head. They are completely compatible with the ESP hangers and mandrels and provide the simplest method for converting a well to an ESP system.
SD and SD-CL Dual Completion Tubing Hangers Dual completion tubing hangers are segmented designs available for both offshore and onshore applications (with or without continuous control lines). Both designs can be used in the SD tubing head. The annulus seal is energized by running in the lockscrews after both hanger segments are landed. The SD-CL hangers provide a control line nipple which supports and seals the control line while protecting it from the extrusion seal. Both the SD and SD-CL designs use seal subs which are installed after the hanger is landed to seal on the dual adapter. An internal profile is provided in each hanger segment for setting a back pressure valve.
9
Tension Tubing Hangers The Tension tubing head and hanger system was designed to allow the tubing string to be lowered into the production casing in order to provide an overpull of the string weight prior to engaging the load pins in the landed position. This compensates for elongation due to temperature variations during the completion of the well to ensure that the tubing string is not exposed to buckling that can occur with conventional tubing hanger applications. Tension tubing hangers utilize an MRS metal seal between the hanger neck and adapter to isolate the production flow. A continuous control line feature is standard with the Tension tubing hanger system that allows the control line to exit through the adapter and be sealed in a specially designed exit block. The Tension tubing head and hanger system is available in applications up to 20,000 psi and all API trim levels. Additional Features:
•
Fluted thru-bore Tension hanger available for liquid or N2 type annular completions
•
BOP slick joint utilized to maintain N 2 in annulus during hanger completion
•
DHCV pressure controlled during completions
Slim Line Tubing Hangers The SL tubing hanger system is designed for use over TLC (Tubingless Completion) equipment. Once production through a larger tubing string begins to slow, the operator may choose to install a smaller tubing string in order to continue lifting fluids. In this application, the SL tubing head can be installed between the TLC adapter and lower master valve. The SL tubing head features a retractable tag pin that allows for full opening bore for passage of back pressure valves and ensures positive tubing hanger location. The SL tubing hanger is landed through the tree, secured in place and may begin taking production. If so desired, the operator may also choose to utilize a crossover adapter in order to install a smaller bore tree over the installed SL tubing hanger.
10
Communication Slick Joint
The Communication Slick Joint was designed to allow operators to reciprocate tubing up to 24 feet for displacement during completion or de-completion of a well where hydraulic control lines are necessary for downhole control valves. An annular seal is maintained with the S wrap around tubing hanger, and an external shroud provides protection for the DHCV line during controlled reciprocation while under pressure.
Additional Features Include:
•
Separate suspension nut eliminates galling during installation and allows for easy makeup without requiring the rotation of the tree
•
PolyPak® seals separate DHCV ports, expediting installation and maximizing years of trouble-free service
•
Metal seal between coupling and adapter provides leak-proof integrity
•
External fitting allows testing of flow bore sea l
•
Modular two piece design allows for disassembly and seal access without disturbing tubing
•
Shroud has an integral stop to prevent over extending during reciprocation
• Avai la bl e fo r work in g pr es su re s th ro ug h 15,000 psi
11
NW-A and NW-B Connectors Shutting in a production platform during installation of welded casing and diverter heads is costly, yet necessary for the safety of personnel and the environment. The only safe way to continue platform activities uninterrupted is to use an alternative connection method which requires no open flame. The NW series of diverter and casing heads provides a simple, safe and reliable solution to this problem.
Casing Heads The NW-A casing head consists of a standard S-22 bowl with a manually locked slip mechanism. The seal between the conductor and the wellhead is achieved with injectable elastomers.
NW-A Casing Head
Diverter Heads The NW-B diverter head consists of a full-open bore and friction pin locking mechanism which makes the head easily removable. The low pressure seal is formed by injectable elastomers.
NW-B Diverter Head
12
Model 500 Gate Valves Seaboard International Model 500 gate valves are designed with an expanding split gate and non-rising stem. Metal-to-metal sealing technology is utilized throughout the valve to increase performance integrity. These valves are available for applications from 3,000 to 5,000 psi. Trim levels are available to suit all types of oil and gas service. Flanged or threaded configurations are available in standard bore sizes from 2-1/16 through 6-3/8.
Model 1520 Gate Valves Seaboard International Model 1520 gate valves are designed with an expanding split gate and a pressurebalancing stem. Metal-to-metal sealing technology is utilized throughout the valve to increase performance integrity. These valves are available for applications through 10,000 psi. Trim levels are available to suit all types of oil and gas service. Flanged end configurations are available in standard bore sizes from 1-13/16 through 41/16.
Model 500
Model 1520
13
Key Features: Full-Bore Through-Conduit Design All Mode l 500/152 0 gate valves utilize a full- bore through-conduit seat/gate design.
• Maximizes valve life by eliminating the collection of destructive particles
• Unrestricted flow reduces turbulence and pressure drops
Body Lubrication Although Model 500/1520 gate valves do not require lubrication to seal, only the highest quality lubricants are used to reduce operating torque and inhibit corrosion.
• Gate guides act as skirts, assisting in retention of lubricants
• Prevents potential corrosion and collection of solSealing Technology
ids
Dependable seals are critical to valve safety and performance. Model 500/1520 gate valves utilize In-line Repairability reliable metal-to-metal sealing technology. A routine maintenance program keeps repairs to a • Seals are stable, thermally insensitive, and environ- minimum. Should repairs be necessary, vital valve components may be replaced. mentally resistant • Gates, seats, stems and other critical parts are eas• Utilized in the gate/seat, body/ bonnet, and body/ ily replaced in the field seat interfaces
• Stem packing can be re-energized while the valve Parallel Expanding Gate Design
is under pressure
The expanding action of the gate provides a positive mechanical seal across the seats both upstream and Extended Stem Life downstream. As the primary operating component of the valve, Model • Wedging only occurs in the full open or full closed 1520 gate valve stems are designed with threads located outside of the valve cavity. positions
• Provides a positive mechanical seal regardless of line pressure
• Stem threads are not exposed to wellbore particles • Design of the stem/stem nut interface offers enhanced galling resistance
Low Operating Torque Ease of operation is inherent in the design of all Model 500/1520 gate valves.
• The 500 features non-rising stems using durable Acme threads
• Roller thrust bearings are isolated from cavity pressure
• Lubrication ports in body Pressure Venting Capabilities A safe method for bleeding pressure from the valve cavity is essential.
• Wedge gates in the full closed position provide a positive mechanical seal isolating valve cavity from wellbore pressure
• Block and bleed design isolates line pressure
14
Model 1540 Gate Valves Seaboard International Model 1540 gate valves are designed with a forged body, expanding split gate, and a pressure-balancing stem. Metal-to-metal sealing technology is utilized throughout the valve to increase performance integrity. These valves are available for applications from 10,000 to 15,000 psi. Trim levels are available to suit all types of oil and gas service. Flanged end configurations are available in standard bore sizes.
Key Features: Full-Bore Through-Conduit Design • Maximizes valve life by eliminating the collection of destructive particles
• Unrestricted flow reduces turbulence and pressure drops
Sealing Technology • Seals are stable, thermally insensitive, and environmentally resistant
• Utilized in the gate/seat, body/ bonnet, and body/ seat interfaces
Parallel Expanding Gate Design • Wedging only occurs in the full open or full closed positions
• Provides a positive mechanical seal regardless of line pressure
Low Operating Torque • Roller thrust bearings are isolated from cavity pressure
• Lubrication ports in body In-line Repairability • Gates, seats, stems and other critical parts are easily replaced in the field
• Stem packing can be re-energized while the valve is under pressure
Reduction of Lost Body Lubrication • Gate guides act as skirts, assisting in retention of lubricants
• Prevents potential corrosion and collection of solids Pressure Venting Capabilities • Wedge gates in the full closed position provide a positive mechanical seal isolating valve cavity from wellbore pressure
• Block and bleed design isolates line pressure Extended Stem Life • Stem threads are not exposed to wellbore particles • Design of the stem/stem nut interface offers enhanced galling resistance
15
Model 1540
Model 1540S Gate Valves Seaboard International Model 1540S gate valves are designed with a forged body, bi-directional slab gate, pressure balancing stem, metal-to-metal sealing technology, and stem backseating capability. The one-piece slab gate utilizes floating seats that co-opt line pressure to supply the sealing force. S tem packing is chemically inert, using spring energizing rings which require no adjustment or plastic injection. These valves are specifically designed for 20,000 psi service. Trim levels are available to suit all types of oil and gas service. Flanged end configurations are available in standard bore sizes.
Key Features: Metal-to-Metal Seals • Seals are stable, thermally insensitive, and environmentally resistant
• Utilized in the gate/seat, body/ bonnet, and stem/ bonnet backseat
Selective Backseat • Provides unparalleled safety during venting, lubrication, and stem packing replacement
• Premature backseating is prevented by a positive stop in the bearing cap that controls stem travel
• Allows stem packing replacement without removing valve from service
• Backseat can be employed without shifting position of the gate
Slab Gate • Excessive force is not required to close and seal the valve
• Potential for valve cavity pressure lock is eliminated • Assures smooth operation during extreme thermal cycles
Floating Seats • Allows bi-directional use • Spring-energized seals pre-load the seats to maintain constant contact with gate, ensuring low pressure sealing
• Requires no lubrication to seal Threaded Packing Gland • Transfers stem packing loads to the bonnet, protecting the bearing assemblies
Model 1540S
• Accommodates replacement of bearings and shear pin at full pressure differential
No Body Penetrations • A single lubrication injection port is located outboard
In-line Repairability • Gates, seats, stems and other critical parts are eas-
of the backseat in the each bonnet allowing cavity lubrication or venting of trapped pressure after backseat operation
• Stem packing can be replaced while the valve is
ily replaced without the use of special tools under pressure
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Model 640 /1640 Gate Valves Seaboard International Model 640 and Model 1640 gate valves are designed with a bi-directional slab gate, metal-to-metal sealing technology, and stem backseating capability. The one-piece parallel sided slab gate utilizes floating seats that co-opt line pressure to supply the sealing force. Stem packing is chemically inert, using spring energizing rings which require no adjustment or plastic injection. These valves are available for applications from 3,000 to 15,000 psi. Trim levels are available to suit all types of oil and gas service. Flanged end configurations are available in standard bore sizes from 1-13/16 through 5-1/8.
Key Features: Metal-to-Metal Seals • Seals are stable, thermally insensitive, and environmentally resistant
• Utilized in the gate/seat, body/ bonnet, and stem/ bonnet backseat
Selective Backseat • Provides unparalleled safety during venting, lubrication, and stem packing replacement
• Premature backseating is prevented by a positive stop in the bearing cap that controls stem travel. This design feature also protects the metal-to-metal sealing surface
• Allows stem packing replacement without removing valve from service
• Backseat can be employed without shifting position of the gate
Slab Gate • Excessive force is not required to close and seal the valve
• Potential for valve cavity pressure lock is eliminated • Assures smooth operation during extreme thermal
Model 1640
cycles
Floating Seats • Allows bi-directional use • Spring-energized seals pre-load the seats to maintain constant contact with gate, ensuring low pressure sealing
• Requires no lubrication to seal Threaded Packing Gland • Transfers stem packing loads to the bonnet, pro-
Non-Rising Stem • Reduces tearing of stem packing • Acme thread enhances durability and lowers torque requirements
Stem Shear Pin • Protects valve stem from being damaged due to excessive torque
In-line Repairability • Accommodates replacement of bearings and shear • A routine maintenance program keeps repairs to a tecting the bearing assemblies pin at full pressure differential
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minimum. Should repairs be necessary, vital valve components may be replaced
No Body Penetration • A single lubrication injection port is located above
• Gates, seats, stems and other critical parts are eas-
the backseat in the bonnet allowing cavity lubrication or venting of trapped pressure after backseat operation
• Stem packing can be replaced while the valve is
ily replaced without the use of special tools under pressure
Seaboard Gate Valve Trim Chart Service Conditions
API Trim
Body
Bonnet
Gate
Seats
General Service Non-Corrosive
AA
4130
4130
Alloy (1)
Alloy
General Service Slightly Corrosive
BB
4130
4130
410SS (1)
410SS (1)
17-4PHSS
General Service Moderate to Highly Corrosive
CC
410SS
410SS
410SS (1)
410SS (1)
17-4PHSS
Sour Service Non-Corrosive
DD
4130
4130
Alloy (1)
Alloy
(1)
4140
Sour Service Non-Corrosive
DD-1
4130
4130
Alloy (2)
Alloy
(2)
17-4PHSS
Sour Service Slightly Corrosive
EE
4130
4130
410SS (1)
410SS (1)
17-4PHSS
Sour Service Slightly Corrosive
EE-1
4130
4130
410SS (2)
410SS (2)
17-4PHSS
Sour Service Slightly Corrosive
EE-7
4130 (4)
4130 (4)
17-4PHSS (1)
17-4PHSS (1)
17-4PHSS
Sour Service Moderate to Highly Corrosive
FF
410SS
410SS
410SS (1)
410SS (1)
17-4PHSS
Sour Service Moderate to Highly Corrosive
FF-1
410SS
410SS
410SS (2)
410SS (2)
17-4PHSS
HH
4130 (3)
4130 (3)
Inconel®
Stellite
Inconel®
Sour Service Highly Corrosive
(1)
Stem 4140
Notes: (1) Nitrided (2) Stellite Overlay or Equivalent (3) Inconel ® Clad (4) Xylan Coated
The chart above includes Seaboard standard trim designations and are subject to change. Additional trims are available to meet special customer requirements and well conditions. Please contact Seaboard for assistance with trim requirements.
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