Description

API 16C Choke and Kill Manifold for Drilling Rig Well Control

SGPE supplies API 16C Choke and Kill Manifold systems for onshore and offshore oil and gas drilling, BOP well control, deep wells, high-pressure wells, selected HPHT projects, sour-service wells, workover operations and drilling-rig upgrades.

Project configurations cover working pressures from 2,000 psi to 15,000 psi and nominal bore sizes from 2-1/16 inch to 4-1/16 inch. Selected configurations can also support oilfield temperature requirements from approximately -46°C to +121°C, subject to confirmation of the selected pressure-containing components, seals and materials.

Depending on the approved well-control design, the package can include manual adjustable chokes, hydraulic adjustable chokes, fixed or positive chokes, high-pressure gate valves, kill-line check valves, single or dual choke branches, bypass lines, local pressure gauges, pressure transmitters and remote hydraulic choke-control equipment.

The Drilling Choke Manifold handles returning well fluids and provides the restriction used to manage surface backpressure during kick circulation. The Kill Manifold provides a separate high-pressure path for pumping drilling mud or kill-weight fluid toward the BOP and wellbore.

Because both flow paths operate as part of the same surface well-control system, the manifold must match the actual BOP stack, pressure class, nominal bore, choke and kill interfaces, drilling-fluid properties, P&ID and operating philosophy.

SGPE supports new drilling-rig packages as well as Replacement Choke and Kill Manifold projects, BOP retrofits, obsolete manifold replacement, hydraulic choke upgrades and existing well-control system modernization.

Oil companies, drilling contractors, EPC companies, rig manufacturers and oilfield service companies can submit drawings, datasheets, equipment nameplates, P&IDs or existing rig information for project-specific technical review and quotation.

Product Overview

An API 16C Choke and Kill Manifold is part of the surface well-control system used with a drilling-rig BOP stack.

During normal drilling, drilling-fluid hydrostatic pressure helps control formation pressure. If formation fluid enters the wellbore and creates a kick, the crew may close the appropriate BOP according to the approved well-control procedure. Controlled circulation paths are then required.

Returning drilling mud and formation fluids travel through the choke line toward the BOP Choke Manifold. By selecting the required branch and changing the choke opening, the operator can regulate flow restriction and manage surface backpressure.

On the kill side, high-pressure pumps can deliver drilling mud or kill-weight fluid through the Kill Manifold, kill line and BOP interface toward the well.

Together, these systems support controlled kick circulation, well killing, fluid routing and surface pressure management.

No single pressure rating or bore size defines the correct manifold. BOP connections, choke capacity, circulation requirements, drilling-fluid properties, temperature, well conditions and the approved flow scheme all influence final selection.

API 16C Choke and Kill Manifold Technical Specifications

Core Technical Specifications

Final pressure, bore, temperature and material requirements depend on the approved project datasheet, BOP configuration and actual service conditions.

Choke Configuration, Controls and Project Support

Final configuration, testing scope and documentation follow the approved purchase order and project requirements.

Working Pressure, Bore and Operating Range

The following ranges provide a practical starting point for technical and procurement review.

These parameters should be considered together. A 15K offshore package, for example, can require different connections, materials, seals, controls, inspection requirements and documentation from a conventional 5K land-rig installation.

5K, 10K and 15K High Pressure Choke Manifold Selection

Project specifications can require 2K, 3K, 5K, 10K or 15K equipment. Among these, 5K, 10K and 15K Choke Manifold systems are common purchasing references for conventional, deep-well and high-pressure drilling projects.

A 5K Choke Manifold can suit selected conventional land drilling.

Deep wells and higher-pressure drilling programs may require a 10K Choke and Kill Manifold, while selected offshore, high-pressure and HPHT projects can require a 15K High Pressure Choke Manifold.

Pressure class changes more than valve rating. Choke configuration, flange and piping interfaces, materials, pressure instrumentation, erosion exposure, testing and inspection requirements also need to be considered.

For 10K or 15K requirements, a BOP stack drawing and well-control P&ID provide a much stronger basis for quotation than pressure class alone.

How a Choke and Kill Manifold Works

When the well is shut in during a kick, returning fluids can be routed from the BOP through the choke line to the Drilling Choke Manifold.

The operator selects the appropriate branch and changes the adjustable choke opening. Reducing the opening increases flow restriction; opening the choke reduces restriction. The pressure drop across the choke helps the crew manage surface backpressure while circulating the well.

The kill side provides a separate high-pressure route for pumping drilling or kill fluid toward the well through the kill line and BOP interface.

The actual flow path depends on the BOP configuration, manifold P&ID and approved well-control method.

Choke Manifold vs. Kill Manifold

The two sides perform different functions but must maintain compatible pressure ratings, connections and BOP interfaces.

For this reason, drilling contractors and EPC companies often evaluate them as one complete BOP Choke and Kill Manifold system.

Main Choke and Kill Manifold Components

A complete oilfield Choke Manifold depends on compatibility between these components, not simply the pressure rating of one valve or choke.

Manual Choke Manifold

A Manual Choke Manifold uses a locally operated adjustable choke.

This configuration can suit conventional onshore drilling and selected workover operations where local access is acceptable under the approved operating procedure.

Manual systems are generally less complex than hydraulic configurations, but working pressure, bore, choke sizing and BOP interfaces still need to match the actual drilling-rig well-control package.

Hydraulic Choke Manifold with Remote Control Panel

A Hydraulic Choke Manifold allows the adjustable choke to be operated from a remote control position.

Remote hydraulic choke control can be useful for offshore drilling, deep wells, high-pressure gas wells and other projects where remote operation forms part of the well-control philosophy.

The hydraulic choke, actuator and control panel need to operate as one matched package.

Providing these details during quotation helps reduce actuator, control-panel and instrumentation mismatches during installation.

Manual vs. Hydraulic Choke Manifold

Neither arrangement is automatically better. Selection depends on rig layout, operating philosophy and the required level of remote control.

Single, Dual and Bypass Choke Manifold Configurations

The manifold flow scheme should follow the approved well-control philosophy rather than a generic layout.

The approved P&ID and General Arrangement Drawing define the final valve locations, choke branches and flow directions.

Nominal Bore and Choke Manifold Flow Capacity

Available project configurations cover nominal bores from approximately 2-1/16 inch to 4-1/16 inch, or about 52 to 103 mm.

Bore size affects fluid velocity, pressure loss and circulation capacity, but simply selecting the largest available bore does not guarantee better performance.

Circulation rate, drilling-fluid density and rheology, gas content, solids loading, choke capacity and downstream piping should also be considered.

Abrasive solids can accelerate erosion where high velocity occurs around choke trim and downstream piping, so bore and choke capacity should be evaluated as part of the complete hydraulic flow path.

BOP Choke Manifold Integration

The BOP stack and Choke and Kill Manifold operate as one surface well-control system.

The BOP provides the mechanical barrier required to close, seal or shear according to its configuration. The choke and kill equipment then provides controlled circulation routes after the well has been shut in.

Common interfaces include BOP side outlets, drilling spools, choke lines, kill lines and high-pressure piping.

For new drilling-rig packages, these interfaces can normally be confirmed from approved drawings.

Replacement projects demand closer dimensional control because the new manifold may need to retain existing flange sizes, piping directions, centerline elevations and skid locations.

API 16C Choke and Kill Manifold Applications

Onshore Drilling Rig Choke Manifold

An Onshore Choke and Kill Manifold can form part of the surface BOP package on conventional land drilling rigs.

Applications include oil wells, natural gas wells, directional wells, horizontal wells, shale drilling and deep land wells.

The final configuration should match the BOP stack, pressure class, drilling-fluid system and rig piping arrangement.

Offshore Choke Manifold

An Offshore Choke Manifold can require closer attention to compact layout, remote operation, lifting arrangements, corrosion protection and documentation.

Applicable installations can include jack-up and platform drilling applications.

Available deck space, BOP interfaces, skid dimensions, control distance and environmental requirements can all influence the final package.

Deep-Well and High-Pressure Drilling

Deep wells and high-pressure formations can require a 10K or 15K Choke and Kill Manifold with hydraulic adjustable chokes and appropriate pressure monitoring.

Expected surface pressure, choke capacity, drilling-fluid properties, piping arrangement and erosion exposure become particularly important in these projects.

High-Pressure Gas Well Choke Manifold

Gas wells can create demanding flow conditions during well-control circulation.

A High Pressure Gas Well Choke Manifold may require higher pressure ratings, hydraulic choke operation and careful review of downstream fluid velocity and erosion.

HPHT Choke and Kill Manifold

HPHT drilling combines high pressure with elevated temperature requirements.

Maximum anticipated pressure, operating temperature, drilling-fluid properties, seals and material requirements should be defined during technical review.

Final suitability remains project-specific.

Sour Service Choke Manifold for H2S Wells

A Sour Service Choke and Kill Manifold requires material selection based on the actual H2S-containing environment.

The project should provide available H2S and CO2 information, operating temperature and working-fluid data.

Where specified, applicable materials can follow NACE MR0175 / ISO 15156 requirements.

Directional, Horizontal and Shale Drilling

Directional, horizontal and shale wells can require flexible surface well-control arrangements.

The manifold should match the drilling program, BOP stack, pressure class, drilling-fluid system and available rig layout instead of relying on one standard configuration.

Workover Choke Manifold

A Workover Choke Manifold should match the workover BOP, expected well pressure and available installation space.

Compact skid layouts can be useful where space is limited or where new equipment needs to connect to an existing workover package.

Choke Manifold Selection by Application

API 16C Purchasing and Project Requirements

An RFQ stating only API 16C Choke and Kill Manifold does not completely define the required equipment.

A useful purchase specification should identify working pressure, nominal bore, choke arrangement, BOP interfaces, operating temperature, working fluid, manual or hydraulic control, inspection requirements and documentation scope.

The project should also identify the required standard edition, addenda and errata.

A clear technical basis reduces repeated clarification and allows procurement and engineering teams to compare proposals more effectively.

API 6A Components Used in the Manifold

An API 16C manifold package can include gate valves, chokes and other pressure-control components that have additional API 6A requirements.

Where applicable, material class, PSL and other requirements should be applied to the relevant API 6A components rather than automatically assigned to the complete API 16C manifold.

Final component requirements follow the approved project datasheet and purchase order.

Materials, Sour Service and Erosion

Material selection depends on working pressure, temperature and the fluids contacting the equipment.

Typical service can expose pressure-containing and wetted components to drilling mud, crude oil, natural gas, formation water, H2S, CO2, sand and drilling solids.

For conventional service, the project specification defines material and trim requirements.

For sour or corrosive service, pressure-containing parts, choke trim, valve trim, piping, seals, bolting and applicable welding requirements need to match the actual environment.

Erosion is also important in choke service. A substantial pressure drop across a restricted flow area can produce high local velocity, while sand and drilling solids can accelerate wear around choke trim and downstream piping.

Components exposed to severe throttling or abrasive fluids may require closer inspection.

Skid-Mounted Choke and Kill Manifold

A Skid-Mounted Choke and Kill Manifold combines chokes, high-pressure valves, piping and instrumentation into one installation package.

Land-rig skids may need to support transportation and repeated rig moves.

Offshore systems can place greater emphasis on equipment footprint, lifting arrangements and corrosion protection.

Replacement projects often require skid dimensions and piping centerlines to match existing equipment.

Manufacturing, FAT and Quality Control

A high-pressure well-control manifold requires controlled manufacturing from material identification through final assembly.

The approved project quality plan can cover machining, welding, assembly, inspection, pressure testing and functional checks.

The purchase order and approved ITP define the final test program.

Projects requiring FAT, TPI or third-party inspection should identify hold and witness points during quotation so that they can be incorporated into the agreed inspection scope.

Project Documentation

Depending on project requirements, documentation can include General Arrangement Drawings, P&IDs, technical datasheets, Material Test Certificates, applicable NDT records, welding documentation, dimensional inspection records, hydrostatic test reports, functional-test records, FAT documentation and recommended spare-parts information.

The final document index follows the approved purchase order.

Replacement API 16C Choke and Kill Manifold

A Replacement API 16C Choke and Kill Manifold often requires more interface checking than a new-rig package.

The replacement may need to connect directly to an existing BOP side outlet, drilling spool, choke line, kill line, control package and downstream piping.

Changing these interfaces at the rig site can increase installation cost and commissioning risk, so existing equipment information is particularly valuable.

Even when the original manufacturer no longer supports the equipment, drawings, nameplates and clear field photographs can provide a practical basis for a compatible Choke Manifold replacement quotation.

Choke Manifold Retrofit and Hydraulic Upgrade

A complete manifold replacement is not always necessary.

If the existing pressure-containing equipment remains technically suitable after evaluation, selected upgrades may provide a more practical solution.

Typical retrofit requirements can include replacing an obsolete adjustable choke, converting manual operation to hydraulic choke control, renewing pressure instruments, replacing worn gate valves or modifying connection interfaces.

Retrofit feasibility depends on the existing design and actual equipment condition.

Choke Manifold Spare Parts and Maintenance

SGPE can review spare-part requirements for new and existing Choke Manifold packages.

Depending on the installed configuration, requirements can include adjustable choke trim, fixed choke components, gate-valve parts, seals, pressure gauges, transmitters and selected hydraulic-control components.

For replacement parts, equipment models, nameplates, drawings and photographs provide useful identification references.

Routine maintenance should pay attention to gate-valve sealing, stems, choke trim, hydraulic leakage, pressure instruments, flange connections, piping condition, bolting and skid integrity.

How to Select an API 16C Choke and Kill Manifold

Selecting the correct API 16C Choke and Kill Manifold begins with the complete BOP and drilling system rather than one catalog model.

Start with working pressure and confirm compatibility with the BOP stack and relevant pressure-control interfaces.

Then evaluate nominal bore against circulation rate, drilling-fluid properties, gas content, solids loading and choke capacity.

Mechanical interfaces are equally important. BOP side outlets, drilling spools, choke lines, kill lines and downstream piping determine how the manifold fits into the rig.

Next, define the operating arrangement. The project may require fixed chokes, manual adjustable chokes, hydraulic adjustable chokes, dual choke branches, bypass routes or another project-specific configuration.

For remote hydraulic control, actuator pressure, displacement, choke travel and control distance need to match the control package.

Finally, confirm temperature, fluid properties, abrasive solids, H2S/CO2 conditions, FAT/TPI requirements and documentation scope before order confirmation.

RFQ Information for an Accurate Choke Manifold Quote

A complete RFQ helps SGPE prepare a more accurate API 16C Choke and Kill Manifold price, technical proposal and delivery scope.

If complete technical information is unavailable, send the drawings, P&IDs, nameplates or field photographs already available. These references can provide the starting point for technical review without delaying the initial inquiry.

Why Choose SGPE for Choke and Kill Manifold Projects?

SGPE focuses on oilfield drilling, pressure-control and well-control equipment.

Customers can discuss the API 16C Choke and Kill Manifold together with BOP equipment, drilling chokes, high-pressure gate valves, wellhead equipment and remote choke-control systems.

This is particularly useful when several mechanical, hydraulic and pressure-control interfaces need to work together within one drilling-rig package.

SGPE supports land and offshore rigs, 10K and 15K high-pressure projects, hydraulic choke-control packages, sour-service requirements, existing-equipment replacement, retrofit work and spare-parts inquiries.

Technical and commercial support is available for oil companies, drilling contractors, EPC contractors, rig manufacturers, equipment distributors and oilfield service companies.

Choke and Kill Manifold for EPC and New Rig Projects

EPC contractors and rig manufacturers generally need more than a standalone manifold.

The BOP stack, drilling spool, choke and kill lines, high-pressure piping, mud system and hydraulic controls all need compatible interfaces during installation.

Early review of pressure classes, piping connections, skid layout and control philosophy can reduce field modifications and commissioning problems.

Choke and Kill Manifold for Drilling Contractors

Drilling contractors often evaluate maintainability and spare-parts availability alongside the original technical specification.

Useful considerations include choke accessibility, high-pressure gate-valve operation, remote controls, pressure instrumentation, maintenance space and recommended spares.

For multi-rig fleets, common choke, valve or spare-parts configurations can also be reviewed where compatible with each rig’s approved requirements.

Frequently Asked Questions About API 16C Choke and Kill Manifolds

1. What is an API 16C Choke and Kill Manifold used for in oil and gas drilling?

An API 16C Choke and Kill Manifold forms part of the surface well-control system used with a drilling-rig BOP stack. During kick circulation and well-killing operations, the choke side provides a controlled path for returning drilling mud and formation fluids while helping the crew manage surface backpressure. The kill side provides a separate high-pressure route for pumping drilling mud or kill-weight fluid toward the BOP and wellbore.

Typical applications include onshore and offshore drilling rigs, conventional oil and gas wells, deep wells, high-pressure gas wells, directional and horizontal drilling, selected HPHT wells, sour-service projects and workover operations. The final BOP Choke and Kill Manifold configuration should match the actual pressure class, nominal bore, BOP interfaces, drilling-fluid conditions and approved well-control P&ID.

2. What is the difference between a Choke Manifold and a Kill Manifold?

A Drilling Choke Manifold handles fluids returning from the well through the BOP choke line. Adjustable or fixed chokes create the required flow restriction, while high-pressure gate valves select the appropriate circulation path. This arrangement allows controlled backpressure management during well-control circulation.

A Kill Manifold works on the pumping side of the system and provides a high-pressure route for drilling mud or kill-weight fluid toward the BOP and wellbore. Although the choke and kill manifolds perform different functions, both need compatible working pressures, nominal bores, connections and BOP interfaces. For this reason, drilling contractors and EPC companies often evaluate them as one integrated Choke and Kill Manifold system.

3. What working pressure ratings are available for an API 16C Choke and Kill Manifold?

SGPE project configurations cover working pressures from approximately 2,000 psi to 15,000 psi, including 2K, 3K, 5K, 10K and 15K pressure classes.

A 5K Choke Manifold can suit selected conventional onshore drilling and workover projects. Deep wells and higher-pressure drilling programs may require a 10K Choke and Kill Manifold, while selected offshore, high-pressure gas and HPHT projects can require a 15K High Pressure Choke Manifold.

Pressure rating should not be selected independently. The BOP stack rating, nominal bore, choke capacity, flange and piping interfaces, operating temperature, materials, instrumentation and project testing requirements also need to match the complete well-control system.

4. What nominal bore sizes are available for an API 16C Choke Manifold?

Available project configurations cover nominal bore sizes from approximately 2-1/16 inch to 4-1/16 inch, or about 52 to 103 mm.

The correct bore size depends on more than the required connection diameter. Circulation rate, drilling-fluid density and rheology, gas content, abrasive solids, choke capacity, BOP connections and downstream piping all influence flow performance.

For deep wells, high-pressure gas wells or drilling fluids with significant solids content, SGPE reviews bore size together with the complete hydraulic flow path because excessive velocity can increase pressure loss and erosion around the choke and downstream piping.

5. What is the difference between a Manual Choke Manifold and a Hydraulic Choke Manifold?

A Manual Choke Manifold uses a locally operated adjustable choke and can suit conventional land drilling or selected workover applications where local operation is acceptable under the approved well-control procedure.

A Hydraulic Choke Manifold uses a hydraulic actuator and compatible remote control panel, allowing the operator to adjust the choke from another location. Remote hydraulic choke control is often considered for offshore drilling rigs, deep wells and high-pressure drilling projects where remote operation forms part of the well-control philosophy.

For a hydraulic configuration, actuator operating pressure, hydraulic displacement, choke travel, control distance, pressure indication and available rig utilities should be confirmed so that the choke and control package operate as a matched system.

6. Can SGPE supply 10K and 15K High Pressure Choke and Kill Manifolds?

SGPE can review 10K and 15K High Pressure Choke and Kill Manifold requirements for deep wells, offshore drilling, high-pressure oil and gas wells, drilling-rig upgrades and selected HPHT applications.

A higher pressure rating affects more than the pressure class of the gate valves. The technical review also considers choke configuration, nominal bore, flange and piping connections, materials, erosion exposure, pressure instrumentation, hydraulic control requirements and the agreed inspection and testing scope.

For a 10K or 15K project, providing the BOP stack drawing, P&ID and choke/kill connection information during the initial RFQ helps establish a more accurate technical basis for quotation.

7. How does an API 16C Choke and Kill Manifold connect to the BOP stack?

The manifold normally connects to the BOP system through choke and kill lines from BOP side outlets, a drilling spool or another approved pressure-control interface.

The required flange size, pressure rating, orientation, centerline elevation and piping direction can vary significantly between drilling rigs. New-rig projects can usually confirm these interfaces from the BOP stack drawing, drilling spool drawing and well-control P&ID.

For a Replacement Choke and Kill Manifold, existing drawings, dimensions and field photographs become particularly important because the new equipment may need to retain the original BOP connections, piping centerlines and skid location to reduce field modifications during installation.

8. Can an API 16C Choke and Kill Manifold be supplied for H2S sour-service wells?

SGPE can review Sour Service Choke and Kill Manifold requirements for oil and gas wells containing H2S.

Material selection should be based on the actual service environment rather than a general sour-service description. Available H2S and CO2 information, operating temperature, working-fluid composition and project material requirements should therefore be provided during technical review.

Where specified by the project, applicable materials can follow NACE MR0175 / ISO 15156 requirements. Sour-service conditions can influence pressure-containing components, choke and valve trim, piping, seals, bolting and other wetted parts.

9. Can the Choke and Kill Manifold be used for offshore, deep-well and HPHT drilling?

Yes, subject to project-specific technical confirmation. An Offshore Choke Manifold can require compact skid dimensions, hydraulic choke control, lifting arrangements, corrosion protection and additional documentation to suit the drilling unit and available deck space.

Deep-well and high-pressure projects may require 10K or 15K Choke and Kill Manifold configurations with hydraulic adjustable chokes and suitable pressure monitoring. HPHT drilling adds operating-temperature, seal and material considerations to the pressure requirements.

For these applications, the equipment should be selected from the complete drilling conditions and BOP configuration rather than pressure rating alone.

10. Can SGPE replace an old or obsolete API 16C Choke and Kill Manifold?

Yes. SGPE can review Replacement API 16C Choke and Kill Manifold, BOP retrofit and hydraulic choke upgrade projects where the original equipment is worn, corroded, obsolete or no longer supported.

Existing nameplates, GA drawings, P&IDs, working pressure, nominal bore, flange dimensions, centerline elevations, skid dimensions, hydraulic-control information and rig-site photographs can help establish the required replacement interfaces.

Where technically practical, the replacement design can be reviewed around the existing BOP and piping arrangement. Selected retrofit projects may also focus on replacing obsolete chokes, upgrading manual operation to hydraulic control, renewing pressure instruments or replacing worn valves instead of changing the complete manifold package.

11. What testing and documentation are available for an API 16C Choke and Kill Manifold?

Depending on the approved project scope, inspection and testing can include material verification, dimensional inspection, applicable NDT, valve and choke functional checks, hydrostatic pressure testing, hydraulic-control testing, flow-path verification and Factory Acceptance Testing.

Projects can also include customer witness points, TPI or third-party inspection where specified in the approved inspection and test plan.

The documentation package can include General Arrangement Drawings, P&IDs, technical datasheets, Material Test Certificates, applicable NDT records, pressure-test reports, functional-test records, FAT documentation and other agreed inspection records. Final testing and documentation requirements follow the approved purchase order and project ITP.

12. What information should I provide for an API 16C Choke and Kill Manifold quotation?

For a new API 16C Choke and Kill Manifold quotation, useful starting information includes the required working pressure, nominal bore, BOP stack drawing, drilling spool or choke/kill connection details, P&ID, choke configuration, operating temperature and working-fluid conditions.

Hydraulic Choke Manifold projects should also identify available actuator data and required control distance. Sour-service projects should provide available H2S and CO2 information, while FAT, TPI and documentation requirements should be identified when they form part of the purchasing specification.

For replacement equipment, customers can send existing nameplates, GA drawings, interface dimensions and rig-site photographs even when a complete original datasheet is unavailable. SGPE can review the available information first and use it as the basis for the required technical proposal and quotation.

Request an API 16C Choke and Kill Manifold Quotation

For new equipment, please provide the required working pressure, nominal bore, BOP stack drawing, P&ID, choke and kill connections, choke configuration and operating conditions.

For a Replacement API 16C Choke and Kill Manifold, existing nameplates, GA drawings, interface dimensions and rig-site photographs can help confirm compatibility with the current BOP and piping system.

SGPE can also support hydraulic choke-control packages, sour-service requirements, FAT/TPI inspection, offshore skid arrangements and compatible spare parts.

SGPE supplies API 16C Choke and Kill Manifolds for onshore and offshore drilling, deep wells, high-pressure gas wells, selected HPHT and sour-service applications. Available solutions include 5K, 10K and 15K Choke Manifolds, manual and hydraulic choke systems, skid-mounted packages, BOP well-control manifolds, replacement units and retrofit solutions.

Send us your RFQ, drawings or existing manifold information. SGPE will review your project requirements and provide a suitable technical proposal and corresponding quotation.

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