Description
API 6A Tubing Hanger for Production, Injection, ESP and Replacement Wellheads
SGPE manufactures and supplies API 6A Tubing Hangers for onshore and offshore wellhead systems used in oil production, natural gas production, ESP artificial lift, water and gas injection, workover and mature-field replacement projects.
Installed inside the tubing head or tubing spool, the hanger supports the production or injection tubing string and transfers its suspended load into the wellhead. Its external sealing arrangement also helps isolate the tubing flow path from the surrounding annulus.
Selecting the correct API 6A Wellhead Tubing Hanger requires more than matching tubing OD and pressure class. The tubing connection, tubing head bowl, landing profile, seal geometry, tubing head adapter, suspended load, service conditions and completion interfaces all influence the final configuration.
Available designs include Mandrel Tubing Hangers, Slip-Type Tubing Hangers, Wrap-Around Tubing Hangers, Extended Neck Tubing Hangers, ESP Tubing Hangers, Control-Line Tubing Hangers, Single-String Tubing Hangers, Dual-String Tubing Hangers and custom Replacement Tubing Hangers.
Typical RFQs cover 2-3/8″, 2-7/8″, 3-1/2″ and 4-1/2″ production tubing with 2K, 3K, 5K, 10K and 15K wellhead pressure classes.
Depending on the completion program, the hanger may also incorporate EUE, NUE or specified premium tubing connections, BPV preparation, extended-neck seals, SCSSV hydraulic control lines, chemical-injection passages, downhole gauge interfaces and ESP electrical penetrators.
For new projects, provide the tubing program, pressure class and wellhead drawings. For a custom or Replacement API 6A Tubing Hanger, existing drawings, field photographs, nameplates, part numbers and measured dimensions provide a stronger basis for technical review and quotation.
Product Short Description
The SGPE API 6A Tubing Hanger supports production or injection tubing inside an oilfield tubing head and provides the mechanical and sealing interface between the tubing string and surface wellhead.
Configurations include mandrel, slip-type, wrap-around, extended-neck, ESP, control-line, single-string, dual-string and made-to-drawing replacement designs.
Common requirements cover 2-3/8″ to 4-1/2″ production tubing and 2,000 to 15,000 psi wellhead systems for oil and gas production, high-pressure wells, ESP artificial lift, SCSSV completions, injection service, sour-service wells, HPHT applications and mature-field retrofit.
Optional interfaces include BPV profiles, tubing hanger neck seals, hydraulic control lines, chemical-injection ports, downhole monitoring feed-throughs and ESP cable penetrators.
Product Overview
An API 6A Tubing Hanger connects the downhole completion with the surface wellhead by supporting the tubing string and providing the required sealing and completion interfaces.
In technical specifications, tenders and RFQs, the same equipment may also appear as a Wellhead Tubing Hanger, Production Tubing Hanger, Oil Well Tubing Hanger, Gas Well Tubing Hanger, API Tubing Hanger or Tubing Hanger Assembly.
The hanger lands in the tubing head bowl and transfers the tubing load into the wellhead. Its external seal system works with the mating wellhead surfaces to separate the production flow path from the tubing-casing annulus.
Modern completions can add electrical, hydraulic or chemical functions. ESP wells require a pressure-tight electrical path, SCSSV installations need hydraulic communication with the surface, and chemical injection or downhole monitoring may require additional passages.
Because these functions share the same wellhead interfaces, the tubing program, tubing head, adapter, pressure class, tubing load, operating temperature, well fluid, material requirement and completion layout should be considered together.
API 6A Tubing Hanger Technical Parameters
The following specifications provide practical references for preliminary selection, supplier comparison and RFQ preparation.
They represent common project configurations rather than one fixed SGPE model. Final dimensions, seals, materials and interfaces depend on the approved wellhead and completion drawings.
Core API 6A Tubing Hanger Specifications
| Technical Parameter | Typical Range / Configuration | Main Selection Basis |
|---|---|---|
| Product | API 6A Tubing Hanger / Wellhead Tubing Hanger | Surface wellhead completion |
| Main function | Support production or injection tubing and provide sealing interface | Completion program |
| Main designs | Mandrel, slip-type, wrap-around, extended-neck, ESP, control-line and replacement | Wellhead configuration |
| Main service | Production, injection, artificial lift, workover and retrofit | Operating program |
| Common tubing sizes | 2-3/8″, 2-7/8″, 3-1/2″, 4-1/2″; others subject to engineering | Tubing program |
| Working-pressure class | 2K, 3K, 5K, 10K, 15K | Wellhead system |
| Tubing connection | EUE, NUE or specified premium connection | Tubing specification |
| Completion arrangement | Single-string, selected dual-string and engineered special completion | Completion design |
| Internal bore | Matched to tubing and completion requirements | Flow / intervention access |
| Drift requirement | According to approved completion program | Through-bore access |
| Landing profile | Matched to tubing head bowl | Load transfer |
| External sealing | Elastomeric, non-elastomeric or engineered sealing system | Pressure, temperature and fluid |
| Extended neck | Optional | Tubing head adapter interface |
| BPV preparation | Optional | Completion / workover |
| SCSSV control-line port | Optional | Downhole safety valve |
| ESP penetrator port | Optional | Electric submersible pump |
| Chemical-injection port | Optional | Production treatment |
| Downhole gauge feed-through | Optional | Monitoring |
| Running-tool interface | According to hanger design | Installation / retrieval |
| Lockdown / retention | Where required by wellhead design | Hanger retention |
| Material class | According to applicable API 6A and project requirements | Service environment |
| PSL | According to pressure, material class and project specification | Product requirement |
| Sweet service | Available | Conventional production |
| Sour service | Available when specified | H2S-containing service |
| HPHT service | Project-specific engineering | Pressure / temperature |
| Replacement design | Custom dimensional matching | Existing wellhead |
| Documentation | Drawings, material records, inspection, NDE and agreed test records | PO / project scope |
Working Pressure and High-Pressure Tubing Hanger Selection
Wellhead RFQs commonly describe tubing hangers using 2K, 3K, 5K, 10K and 15K pressure classes.
| Pressure Class | Rated Working Pressure | Metric Reference | Typical RFQ Description |
|---|---|---|---|
| 2K | 2,000 psi | 13.8 MPa | 2K Tubing Hanger |
| 3K | 3,000 psi | 20.7 MPa | 3K Wellhead Tubing Hanger |
| 5K | 5,000 psi | 34.5 MPa | 5K API 6A Tubing Hanger |
| 10K | 10,000 psi | 69.0 MPa | 10K High Pressure Tubing Hanger |
| 15K | 15,000 psi | 103.5 MPa | 15K API 6A Tubing Hanger |
Pressure class alone does not establish interchangeability.
Two 10K Tubing Hangers can have different body diameters, landing profiles, sealing geometry, extended-neck dimensions or BPV interfaces. The same principle applies to 5K and 15K configurations.
For example, a 2-7/8″ 10K Tubing Hanger should also identify the tubing connection, tubing head bowl, seal arrangement, BPV profile and upper adapter interface.
API 6A PSL Reference
The applicable PSL depends on rated working pressure, material class, product configuration and project requirements.
| API 6A Material Class | 2K | 3K | 5K | 10K | 15K |
|---|---|---|---|---|---|
| AA / BB / CC | PSL 1-4 | PSL 1-4 | PSL 1-4 | PSL 2-4 | PSL 2-4 |
| DD / EE / FF | PSL 1-4 | PSL 1-4 | PSL 1-4 | PSL 2-4 | PSL 3-4 |
| HH / ZZ | PSL 3-4 | PSL 3-4 | PSL 3-4 | PSL 3-4 | PSL 3-4 |
This table serves as a preliminary selection reference rather than a statement that every SGPE configuration covers every listed combination.
The approved technical proposal should identify the required pressure class, material class, PSL and service conditions.
Common Tubing Sizes and Connections
Production tubing OD is normally the starting point for a tubing hanger inquiry.
| Nominal Tubing OD | Approx. OD | Typical RFQ Description | Additional Information Required |
|---|---|---|---|
| 2-3/8″ | 60.3 mm | 2-3/8 Tubing Hanger | Connection, bowl, seal and pressure class |
| 2-7/8″ | 73.0 mm | 2-7/8 Tubing Hanger | Connection and wellhead drawing |
| 3-1/2″ | 88.9 mm | 3-1/2 Tubing Hanger | Tubing load, bore and seal profile |
| 4-1/2″ | 114.3 mm | 4-1/2 Tubing Hanger | Suspended load and tubing head compatibility |
These dimensions refer to the production tubing, not the tubing hanger body.
Tubing connections can include EUE, NUE or project-specified premium connections. The hanger OD, internal bore, landing geometry and external sealing dimensions remain dependent on the mating wellhead.
Main API 6A Tubing Hanger Types
| Tubing Hanger Type | Main Configuration | Typical Application | Critical Selection Point |
|---|---|---|---|
| Mandrel Tubing Hanger | Solid body with defined tubing connection | Oil/gas production, injection and high-pressure wells | Tubing connection and landing profile |
| Slip-Type Tubing Hanger | Slip / gripping arrangement | Selected completion and workover operations | Tubing OD, slip design and bowl |
| Wrap-Around Tubing Hanger | Split / segmented arrangement | Retrofit and selected workover projects | Body OD, bowl and seals |
| Extended Neck Tubing Hanger | Upper sealing neck | Production and high-pressure wellheads | Neck OD, length and adapter bore |
| ESP Tubing Hanger | Electrical feed-through incorporated | ESP artificial lift | Cable penetrator and orientation |
| Control-Line Tubing Hanger | Hydraulic passage incorporated | SCSSV completion | Line pressure and orientation |
| Single-String Tubing Hanger | One tubing bore | Conventional completion | Tubing / wellhead compatibility |
| Dual-String Tubing Hanger | Two tubing bores | Dual completion | Bore spacing and tree interface |
| Replacement Tubing Hanger | Matched to existing equipment | Mature-field / obsolete wellhead replacement | Dimensional compatibility |
Mandrel and Slip-Type Tubing Hangers
A Mandrel Tubing Hanger uses a solid body with a defined tubing connection. This provides controlled geometry for the landing area, seals, BPV preparation and optional completion feed-throughs.
A Slip-Type Tubing Hanger supports the tubing through a gripping arrangement. It can suit selected completion or workover procedures, although tubing OD, suspended load, slip design and tubing head bowl still need to be evaluated together.
Extended Neck Tubing Hanger
An Extended Neck Tubing Hanger projects into the tubing head adapter and provides an additional controlled sealing interface.
Its neck OD, length and seal profile must match the adapter bore. These dimensions become particularly important during replacement work.
ESP Tubing Hanger with Cable Penetrator
An ESP Tubing Hanger supports the tubing while providing an electrical path for an Electric Submersible Pump.
Project documents may also call it an ESP Wellhead Tubing Hanger, ESP Tubing Hanger Assembly, Tubing Hanger with Cable Penetrator or ESP Tubing Hanger with Electrical Penetrator.
Selected ESP completions can also incorporate SCSSV hydraulic lines, chemical-injection passages or downhole monitoring interfaces.
Control-Line and Dual Completion Designs
A Control-Line Tubing Hanger incorporates pressure-tight hydraulic passages, commonly for an SCSSV.
A Dual-String Tubing Hanger, also called a Dual Completion Tubing Hanger, supports two flow paths and requires close control of bore spacing, sealing and orientation.
API 6A Tubing Hanger Dimensions and Wellhead Interfaces
Searches for API 6A Tubing Hanger dimensions, Tubing Hanger drawing, Tubing Hanger OD, Tubing Hanger specification, Tubing Hanger seal dimensions and Tubing Hanger landing profile usually relate to custom or replacement requirements.
There is no universal dimensional table that fits every wellhead system.
| Mechanical Interface | Information Required | Why It Matters |
|---|---|---|
| Maximum hanger OD | Tubing head bowl dimensions | Physical fit |
| Overall height | Wellhead stack-up | Vertical position |
| Landing shoulder OD / profile | Tubing head drawing | Load transfer |
| Lower body OD | Internal wellhead geometry | Clearance |
| Internal bore / drift | Tubing / completion program | Flow and tool access |
| Tubing connection | EUE, NUE or premium | Tubing compatibility |
| External seal diameter | Tubing head bore | Pressure sealing |
| Seal groove geometry | Seal design | Seal compatibility |
| Extended-neck OD / length | Adapter seal bore | Upper sealing |
| Neck seal profile | Tubing head adapter | Upper pressure barrier |
| BPV profile | Existing / specified system | Workover interface |
| Running-tool profile | Hanger design | Installation / retrieval |
| Lockdown interface | Tubing head design | Retention |
| Anti-rotation feature | Where required | Port orientation |
| Control-line port | Completion drawing | Hydraulic interface |
| ESP penetrator location | ESP completion | Electrical interface |
| Chemical-injection port | Treatment program | Chemical interface |
For a Custom Tubing Hanger or Replacement Tubing Hanger RFQ, dimensions from both the existing hanger and the mating tubing head provide the strongest basis for compatibility review.
ESP, SCSSV and Completion Feed-Through Options
Modern completion wellheads may route electrical, hydraulic and chemical services through the tubing hanger.
| Completion Interface | Typical Requirement | Main RFQ Information |
|---|---|---|
| SCSSV hydraulic control line | Pressure-tight hydraulic passage | Line OD, pressure, connection and orientation |
| ESP cable penetrator | Electrical feed-through | Penetrator model / interface |
| Chemical-injection line | Pressure-tight passage | Line size, pressure and medium |
| Downhole gauge line | Monitoring interface | Instrument connection |
| Additional hydraulic line | Project-specific | Quantity and pressure |
| ESP + SCSSV | Electrical + hydraulic interfaces | Port layout and orientation |
| ESP + chemical injection | Electrical + chemical interfaces | Available hanger space |
| Multi-feed-through completion | Multiple completion services | Complete completion drawing |
Where several functions share one hanger, available body space, sealing areas and port orientation need to be evaluated together.
Materials, Sealing and Service Conditions
| Service Parameter | Selection Basis | RFQ Information |
|---|---|---|
| Body material | Applicable API 6A / project requirement | Material class |
| Production medium | Oil, gas or multiphase | Fluid composition |
| Injection medium | Water, gas or specified fluid | Fluid chemistry |
| Working pressure | Wellhead rating | Maximum pressure |
| Operating temperature | Project-specific | Minimum / maximum temperature |
| Suspended tubing load | Tubing + downhole equipment | Expected load |
| External sealing system | Fluid, pressure and temperature | Service conditions |
| Extended-neck seal | Adapter interface | Adapter seal bore |
| H2S exposure | Sour-service review | H2S data |
| CO2 exposure | Corrosion review | CO2 data |
| Chloride environment | Material review | Fluid chemistry |
| NACE MR0175 / ISO 15156 | When specified | Project requirement |
| HPHT service | Project-specific engineering | Pressure / temperature |
| Offshore service | Material, QA and documentation review | Offshore specification |
For a Sour Service Tubing Hanger, H2S concentration alone does not define the complete material requirement. CO2, operating pressure, temperature, chlorides and production-fluid chemistry can also influence material and sealing selection.
How an API 6A Tubing Hanger Works
Tubing Support and Sealing
The hanger transfers the suspended production or injection tubing load into the tubing head through its landing shoulder.
At the same time, the external Tubing Hanger Seal Assembly works against the tubing head bore to help isolate the tubing flow path from the surrounding annulus.
Both functions depend on correct mating dimensions.
Completion-System Integration
ESP electrical penetrators, SCSSV hydraulic control lines, chemical-injection passages and downhole monitoring interfaces can be incorporated into selected hanger configurations.
The tubing hanger therefore becomes an important connection between the downhole completion and surface wellhead equipment.
Tubing Head Adapter and Christmas Tree Interface
An extended-neck hanger can project into the tubing head adapter.
Its neck and sealing dimensions must match the adapter, while the internal bore and BPV profile need to coordinate with the upper wellhead and Christmas tree arrangement.
API 6A Tubing Hanger Applications
| Application | Typical Configuration | Main Requirement |
|---|---|---|
| Onshore oil production | Mandrel / single-string | Tubing support and sealing |
| Offshore production | Engineered production hanger | Interfaces, QA and documentation |
| Natural gas production | Mandrel / high-pressure | Seal and material compatibility |
| 10K / 15K gas well | High-pressure hanger | Complete wellhead matching |
| ESP artificial lift | ESP Tubing Hanger | Electrical penetrator |
| SCSSV completion | Control-Line Tubing Hanger | Hydraulic feed-through |
| Water injection | Injection Tubing Hanger | Injection-fluid compatibility |
| Gas injection / EOR | High-pressure hanger | Gas-service materials and seals |
| Sour-service well | Sour Service Tubing Hanger | H2S material review |
| HPHT application | Engineered hanger | Pressure, temperature and tubing load |
| Dual completion | Dual-String Tubing Hanger | Bore spacing and orientation |
| Workover | Existing / replacement hanger | BPV, seal and running-tool compatibility |
| Mature-field replacement | Custom Replacement Tubing Hanger | Dimensional matching |
| ESP retrofit | Customized ESP hanger | Existing wellhead + new penetrator |
Production, Gas and Injection Wells
Conventional production wells commonly use mandrel or single-string designs.
High-pressure gas wells place greater demands on sealing, materials and interface control. A 10K Tubing Hanger or 15K Tubing Hanger should therefore be evaluated together with the tubing head, tubing connection, sealing system and upper wellhead arrangement.
Water and gas injection applications also require compatibility with the actual pressure, temperature and injection medium.
ESP, SCSSV and Artificial-Lift Completions
ESP wells require a pressure-tight electrical path through the wellhead, while SCSSV completions require hydraulic control.
When both functions are present, available hanger space and port orientation become important design considerations.
Sour-Service and HPHT Applications
Sour-service and HPHT wells require more complete service information because pressure, temperature and fluid composition can directly affect material and seal selection.
Workover and Mature-Field Replacement
Older wellheads may need replacement hangers after original components become unavailable, damaged or unsuitable for a revised completion program.
Existing drawings, field photographs, nameplates, part numbers and measured dimensions can support the development of a custom Replacement Wellhead Tubing Hanger.
API 6A Tubing Hanger Selection Guide
A complete RFQ helps reduce technical queries, drawing revisions and field compatibility problems.
| Selection Item | Information to Provide | Why It Matters |
|---|---|---|
| Tubing OD | 2-3/8″, 2-7/8″, 3-1/2″, 4-1/2″ or other | Bore / connection |
| Tubing weight / wall | Where relevant | Load / drift review |
| Tubing connection | EUE, NUE or premium | Thread compatibility |
| Tubing head | Model or drawing | Mating equipment |
| Tubing head bowl | Dimensions / profile | Hanger landing |
| Pressure class | 2K, 3K, 5K, 10K or 15K | Pressure requirement |
| Material class / PSL | Project specification | Product requirement |
| Temperature | Minimum / maximum | Material / seal selection |
| Well fluid | Production or injection medium | Service compatibility |
| H2S / CO2 | Available data | Sour / corrosion review |
| Tubing load | Expected suspended load | Mechanical review |
| Hanger configuration | Mandrel, slip, ESP, extended-neck or other | Completion design |
| Landing / seal dimensions | Drawing or measurements | Dimensional compatibility |
| BPV profile | Type / drawing / dimensions | Well-control interface |
| Running-tool interface | Existing / proposed | Installation |
| SCSSV control line | OD, pressure, connection | Hydraulic interface |
| ESP penetrator | Model / drawing | Electrical interface |
| Chemical-injection line | Size / pressure | Treatment interface |
| Tubing head adapter | Drawing / dimensions | Upper sealing |
| Christmas tree arrangement | Bore / interface data | Production flow path |
| Inspection requirements | Operator / EPC specification | ITP |
| Documentation requirements | MTC, NDE, reports, TPI | MDR |
Tubing Hanger vs Tubing Head and Casing Hanger
A Tubing Head forms part of the pressure-containing wellhead body and provides the bowl that receives the tubing hanger.
The Tubing Hanger lands inside that bowl and supports the production or injection tubing.
A Casing Hanger performs a similar suspension function for casing but sits lower in the wellhead during well construction.
| Comparison | Tubing Hanger | Casing Hanger |
|---|---|---|
| Supported tubular | Production / injection tubing | Casing |
| Installed in | Tubing head / tubing spool | Casing head / casing spool |
| Main stage | Completion / production | Drilling / casing |
| Typical special interfaces | BPV, ESP, SCSSV, chemical injection | Packoff / casing sealing |
| Wellhead position | Upper production interface | Lower wellhead section |
This difference becomes particularly important when specifying replacement wellhead equipment.
Tubing Hanger Seal, BPV and Running Tool Interfaces
Tubing Hanger Seal and Neck Seal
The external hanger seal must match the tubing head bore.
For an extended-neck configuration, the neck OD and sealing profile must also match the tubing head adapter.
Replacement RFQs should include seal-area and mating-bore dimensions wherever possible.
Back Pressure Valve Preparation
A Back Pressure Valve (BPV) can provide a temporary pressure barrier inside the tubing during selected completion and workover operations.
Because BPV profiles vary between wellhead systems, the existing BPV type, drawing or dimensional information should be included in replacement requests.
Tubing Hanger Running Tool
The Tubing Hanger Running Tool supports installation, landing and, where applicable, retrieval.
Running-tool profile, hanger orientation and completion feed-through positions should be confirmed before installation. ESP, SCSSV and chemical-injection interfaces may require a defined rotational position.
Replacement API 6A Tubing Hanger for Existing Wellheads
Replacement work often requires more dimensional review than supplying a hanger with a new wellhead package.
An existing hanger may have worn threads, corrosion, damaged sealing surfaces or a configuration that no longer suits a revised completion. In other cases, the original OEM may no longer support the wellhead.
SGPE can review Replacement API 6A Tubing Hangers, Replacement Wellhead Tubing Hangers, Custom Tubing Hangers, Made-to-Drawing Tubing Hangers and Obsolete Tubing Hanger Replacements.
The preferred starting point is the original hanger drawing together with the tubing head and tubing head adapter drawings. When documentation is incomplete, field photographs and dimensional measurements can support preliminary review.
Critical Dimensions for Replacement Tubing Hangers
| Measurement | Why It Matters |
|---|---|
| Overall height | Vertical positioning |
| Maximum hanger OD | Tubing head clearance |
| Landing shoulder OD / profile | Load-bearing fit |
| Lower body OD | Internal clearance |
| Central bore / drift | Flow and intervention access |
| Tubing connection | Tubing compatibility |
| Seal diameter / groove | Pressure sealing |
| Extended-neck OD / length | Adapter fit |
| Neck seal profile | Upper sealing |
| BPV profile | Well-control compatibility |
| Running-tool profile | Installation / retrieval |
| Lockdown interface | Retention |
| Control-line ports | Hydraulic completion |
| ESP penetrator port | Artificial lift |
| Chemical-injection port | Treatment interface |
| Orientation features | Feed-through alignment |
The final replacement interface drawing should be approved before manufacturing.
API 6A Tubing Hanger Price, Quote and Procurement Factors
An API 6A Tubing Hanger price cannot be compared accurately using tubing size alone.
Buyers evaluating a tubing hanger manufacturer, supplier quotation or replacement offer should compare the complete technical scope.
| Price / Procurement Factor | Why It Matters |
|---|---|
| Hanger type | Mandrel, slip, ESP and dual-string designs differ |
| Tubing size / connection | Changes bore and interface |
| Pressure class | Changes technical requirements |
| Material class / PSL | Affects materials and inspection |
| Sour-service requirement | Can change material / QA scope |
| Seal system | Changes sealing components and machining |
| Extended neck | Adds upper sealing interface |
| BPV preparation | Adds well-control interface |
| ESP penetrator | Adds electrical completion interface |
| SCSSV line | Adds hydraulic feed-through |
| Chemical injection | Adds another pressure-tight passage |
| Dual completion | Adds bore / sealing complexity |
| Replacement engineering | Requires dimensional review |
| NDE / TPI | Changes inspection scope |
| Documentation package | Affects project documentation |
| Quantity | Affects production planning |
A request for “2-7/8 10K Tubing Hanger price” is therefore only the starting point.
For an accurate API 6A Tubing Hanger quote, provide the tubing head drawing, tubing connection, material requirement, service environment and completion interfaces.
Manufacturing, Inspection and Documentation
A tubing hanger is a critical wellhead interface, so dimensional control and sealing-surface condition matter throughout manufacturing and inspection.
| Manufacturing / QC Item | Typical Control |
|---|---|
| Material identification | Heat / material traceability |
| Hanger OD and bore | Dimensional verification |
| Drift | Through-bore verification |
| Landing shoulder | Profile / dimensional inspection |
| External sealing surfaces | Diameter / surface-condition inspection |
| Extended neck | OD, length and sealing-surface inspection |
| Tubing connection | Applicable thread inspection |
| BPV profile | Dimensional verification |
| Control-line ports | Position / interface verification |
| ESP interface | Dimensional / assembly review |
| Applicable NDE | According to approved ITP / project scope |
| Final dimensional report | Comparison with approved drawing |
| Third-party inspection | Available when specified |
Depending on the agreed purchase scope, documentation can include manufacturing drawings, material certificates, traceability records, dimensional reports, applicable NDE reports, tubing-thread inspection records, agreed test documentation, certificates of conformity and third-party inspection records.
Operators, EPC contractors and distributors should define documentation requirements during the RFQ or PO stage.
Installation, Maintenance and Workover Inspection
Before installation, inspect the tubing connection, tubing head bowl, landing shoulder, external sealing surfaces, extended neck, BPV profile and completion feed-throughs.
Critical machined surfaces should remain protected from corrosion, contamination and impact during transportation and storage.
During workover, inspect a retrieved hanger for thread wear, erosion, corrosion, sealing-surface damage, landing-shoulder deformation and damage around hydraulic or electrical interfaces.
High-pressure gas wells and corrosive or sour-service applications may require closer inspection.
A hanger should not return to service simply because it still fits the tubing head. Its tubing connection, sealing surfaces and other critical interfaces should remain suitable for the intended operating conditions.
Why Choose SGPE for API 6A Tubing Hangers?
SGPE supplies wellhead, drilling, completion and pressure-control equipment for new projects, equipment replacement and wellhead retrofit.
Because the tubing hanger works directly with surrounding wellhead equipment, it can be reviewed together with Tubing Heads, Tubing Head Adapters, Casing Heads, Casing Spools, Casing Hangers, Christmas Trees and Wellhead Valves.
For new projects, technical review can cover the tubing program, pressure class, wellhead configuration and completion interfaces before quotation.
ESP and SCSSV projects may require additional coordination of electrical or hydraulic interfaces with the hanger body and mating wellhead.
Mature-field replacement projects can be reviewed from existing drawings, field photographs, nameplates, part numbers and dimensional measurements, including situations where the original manufacturer no longer supplies the required component.
Project supply can also include agreed drawings, dimensional inspection, material documentation, NDE records and third-party inspection requirements for operators, EPC contractors and oilfield equipment distributors.
These capabilities support buyers evaluating an API 6A Tubing Hanger Manufacturer, API 6A Tubing Hanger Supplier, Wellhead Tubing Hanger Supplier, ESP Tubing Hanger Supplier, High Pressure Tubing Hanger Supplier, Custom Tubing Hanger Manufacturer or Replacement Tubing Hanger Supplier.
Information Required for an API 6A Tubing Hanger RFQ
For new equipment, provide the production tubing size and connection, tubing head information, working-pressure class, material requirement, operating temperature and well fluid.
The RFQ should also identify the required hanger configuration and any ESP, SCSSV, chemical-injection or monitoring interfaces.
Sour-service and HPHT projects should include the available pressure, temperature and fluid information together with the project material requirements.
For replacement work, provide the existing tubing hanger, tubing head and adapter drawings whenever available. Photographs, nameplates, part numbers and measured dimensions are useful when original documentation is incomplete.
A complete RFQ allows the tubing connection, landing profile, seal system, extended neck, BPV profile, running-tool interface and completion feed-throughs to be reviewed before the technical and commercial proposal is finalized.
Frequently Asked Questions About API 6A Tubing Hangers
1. What is an API 6A Tubing Hanger used for?
An API 6A Tubing Hanger supports the production or injection tubing string inside a tubing head or tubing spool and transfers the suspended tubing load into the surface wellhead. Its external sealing arrangement works with the mating tubing head surfaces to help separate the tubing flow path from the surrounding annulus.
Depending on the completion design, a Wellhead Tubing Hanger can also provide interfaces for a Back Pressure Valve (BPV), SCSSV hydraulic control line, ESP electrical penetrator, chemical-injection passage or downhole monitoring system.
Typical applications include onshore and offshore oil production, natural gas production, water and gas injection, ESP artificial lift, workover operations and mature-field wellhead replacement.
2. What is the difference between a Tubing Hanger and a Tubing Head?
A Tubing Head forms part of the pressure-containing surface wellhead and provides the bowl, landing area and sealing surfaces required for the tubing hanger.
The Tubing Hanger is installed inside the tubing head and carries the production or injection tubing string. Its landing profile must match the tubing head bowl, while its external seals must match the corresponding tubing head bore.
This distinction is especially important when purchasing a Replacement Wellhead Tubing Hanger. Matching only the tubing size or pressure rating is not enough; the tubing head dimensions and sealing interfaces must also be confirmed.
3. What is the difference between a Mandrel Tubing Hanger and a Slip-Type Tubing Hanger?
A Mandrel Tubing Hanger uses a solid-body design with a defined production tubing connection. The tubing connects directly to the mandrel, allowing the hanger body to provide controlled landing, sealing, BPV and completion-interface geometry.
A Slip-Type Tubing Hanger supports the tubing through a slip or gripping arrangement. This configuration can suit selected completion or workover procedures where the installation sequence requires additional flexibility.
Choosing between a Mandrel and Slip-Type Tubing Hanger depends on the tubing OD, tubing connection, suspended load, tubing head bowl, installation method and sealing requirements rather than pressure class alone.
4. What tubing sizes and connections are commonly used with API 6A Tubing Hangers?
Common project requirements include 2-3/8″, 2-7/8″, 3-1/2″ and 4-1/2″ production tubing. These dimensions refer to the tubing OD rather than the outside diameter of the tubing hanger body.
Tubing connections can include EUE, NUE or project-specified premium connections, depending on the production tubing and completion program.
For example, an inquiry for a 2-7/8″ Tubing Hanger should also identify the tubing connection, tubing head model or drawing, pressure class, landing profile and sealing arrangement before the final configuration is selected.
5. What pressure classes are available for API 6A Tubing Hangers?
Common oilfield requirements cover 2K, 3K, 5K, 10K and 15K wellhead pressure classes. High-pressure applications may therefore involve a 10K Tubing Hanger or 15K Tubing Hanger for gas production, injection or other demanding wellhead service.
Pressure class by itself does not establish interchangeability. Two 10K tubing hangers may have different body diameters, landing shoulders, seal profiles, extended-neck dimensions or BPV interfaces.
A 2-7/8″ 10K API 6A Tubing Hanger, for example, should still be matched to the actual tubing head bowl, tubing connection, seal system and upper wellhead arrangement.
6. How do I select the correct API 6A Tubing Hanger for a wellhead?
Start with the production tubing OD and connection, then confirm the tubing head model or drawing, tubing head bowl, working-pressure class, material requirements, operating temperature, well fluid and expected tubing load.
The next step is to identify the completion configuration. A conventional production well may use a Mandrel Tubing Hanger, while an ESP completion may require an electrical penetrator and an SCSSV completion may require one or more hydraulic control-line passages.
For an accurate API 6A Tubing Hanger RFQ, drawings of the tubing head and tubing head adapter provide the strongest basis for confirming the landing profile, seals, extended neck, BPV profile and running-tool interface.
7. Can SGPE supply an ESP Tubing Hanger with a cable penetrator?
Yes. SGPE can review ESP Tubing Hangers, ESP Wellhead Tubing Hangers, ESP Tubing Hanger Assemblies and Tubing Hangers with Cable Penetrators for Electric Submersible Pump completions.
An ESP Tubing Hanger supports the production tubing while providing a pressure-tight electrical path through the wellhead for the ESP power system. The penetrator location and orientation need to match the tubing head, adapter and overall completion arrangement.
Selected ESP completions can also combine an SCSSV hydraulic control line, chemical-injection passage or downhole monitoring interface in the same tubing hanger.
8. Can an API 6A Tubing Hanger include SCSSV control lines and chemical-injection passages?
Yes. A Control-Line Tubing Hanger can incorporate pressure-tight hydraulic passages for an SCSSV or other downhole control equipment.
Selected completion designs can combine SCSSV hydraulic control, ESP electrical power, chemical injection and downhole monitoring through one tubing hanger. When several feed-throughs share the same hanger body, available space, seal locations and port orientation become important design considerations.
The RFQ should identify the number of control lines, line OD, operating pressure, connection type, chemical-injection requirement and required orientation wherever this information is available.
9. Can SGPE supply a Sour Service Tubing Hanger for H2S wells?
Yes, subject to the actual service conditions and project material requirements. A Sour Service API 6A Tubing Hanger should be reviewed using more than an H2S service description alone.
Available H2S, CO2, pressure, temperature, chloride and fluid-composition data can influence the body material and sealing system. If the project specifies NACE MR0175 / ISO 15156, that requirement should be included in the RFQ.
This type of review is particularly relevant for sour gas production, high-pressure wells and other corrosive wellhead environments where material and seal compatibility are critical.
10. Can SGPE manufacture a Replacement API 6A Tubing Hanger for an obsolete wellhead?
Yes. SGPE can review Replacement API 6A Tubing Hangers, Replacement Wellhead Tubing Hangers, Custom Tubing Hangers, Made-to-Drawing Tubing Hangers and obsolete wellhead replacement requirements.
Replacement projects are common in mature oilfields where the original OEM no longer supplies spare parts, where an existing hanger has corrosion or sealing-surface damage, or where the completion has been modified for ESP, SCSSV or another production system.
Original drawings provide the best starting point, but field photographs, nameplates, part numbers and measured dimensions can also support preliminary engineering when documentation is incomplete.
11. What dimensions are required for a Replacement Tubing Hanger quote?
Important Tubing Hanger dimensions include the overall height, maximum hanger OD, landing shoulder OD and profile, lower body OD, internal bore or drift, tubing connection, external seal diameter and seal-groove geometry.
An extended-neck design also requires the neck OD, neck length and sealing profile. Other important interfaces can include the BPV profile, running-tool profile, lockdown feature, SCSSV control-line ports, ESP penetrator location and chemical-injection passage.
Providing both the old hanger dimensions and the mating tubing head or tubing head adapter drawing gives SGPE a stronger basis for preparing a Replacement Tubing Hanger quote and reducing dimensional compatibility risks.
12. Are API 6A Tubing Hangers interchangeable between different wellhead systems?
Not necessarily. Tubing hangers with the same tubing size and working-pressure class can still use different body diameters, landing profiles, seal geometry, extended-neck dimensions, tubing connections, BPV profiles and running-tool interfaces.
For example, two 2-7/8″ 10K Tubing Hangers may both be intended for 10,000 psi service but fit completely different tubing heads.
For new equipment as well as mature-field replacement, the complete wellhead interface should therefore be confirmed before ordering. Providing the tubing head drawing, adapter drawing and existing hanger dimensions helps determine whether a standard, customized or Replacement API 6A Tubing Hanger is required.
