Wellhead RFQ and BOP RFQ work fails when buyers scroll a multi-page product grid and paste a card title into the bid package. Organize published CNPS wellhead and drilling equipment by service—drilling/workover well control, wellhead valves, casing-head assembly, slickline or coiled-tubing pressure control, production pumping, and light sensing—then declare pressure, bore, end connection, fluid and temperature, control type, and documents. The matrix is the RFQ structure; the category first page is the published-family index; Talk to an Engineer confirms configuration. Do not invent stack ratings absent from a live product page.
What “wellhead & pressure control” covers on CNPS (scope honesty)
The hub Wellhead & Drilling Equipment mixes API 16A-titled BOP and wellhead-valve families, casing-head / wellhead assembly listings, slickline pressure-control equipment, API Spec 11E and belt pumping units, plus many mud-logging and downhole sensors. That breadth helps browsing—and breaks RFQs if every card is treated as an “API 6A Christmas tree.” This pillar organizes by service: match the operation type first, then open the matching live PDP for published models and ratings—not every paginated SKU.
Editorial constraint: pagination / thin-card risk
The category continues across deep pagination (live /page/2/ through /page/8/ at write time). Later pages are mostly mud sensors, monitors, and logging accessories—not a second wellhead engineering library. Buyer guidance: start on the category first page for published well-control, wellhead, pumping, and sensor families; structure the RFQ with this matrix; then send the envelope to Talk to an Engineer. Do not crawl every /page/N/ card or treat thin titles as a complete engineering basis.
Spec dimensions every RFQ should declare
Before debating model names, send:
- Working pressure (and design/test pressure if your procedure requires them).
- Bore / nominal size (or wire/cable pass-through for intervention PCE).
- API / customer specification family and edition—not the word “API” alone.
- End connection — flange class, union, casing flange, single- or dual-stage head, stack-height limits.
- Fluid and service — oil, water, gas, steam; H₂S/CO₂ flags when applicable.
- Temperature class — metal and elastomer if known.
- Control type — manual, hydraulic, handwheel, limiter switches, utilities.
- Documentation — conformity statement, material certs, ITP, GA, inspection/third-party, coating, packing—as the buyer asks, not as invented certificates.
- Quantity, spares (rams, seals, plug kits), destination, and required date.
Service → equipment matrix (core)
Drilling / workover well control (BOP)
Primary job: shut in and control the wellbore during drilling or workover. Catalogue well-control titles carry API 16A labeling.
Live example: API 16A Double Ram Manual Bop. Example configurations on that PDP (not a claim that every unlisted size exists): models 2FZ18-21 / 2FZ18-35; rated working pressure 3000 / 5000 psi; nominal diameter 7 1/16 / 7 3/8 in; strength pressure test 6000 / 7500 psi; metal temperature −29~121 °C; nonmetal −18~121 °C; listed ram sizes 2⅜″, 2⅞″, 3½″, 4½″, blind. The page states conformity to API 16A and includes on-page DNV PR2 wording for listed choke/gate items—attribute as published; this article is not a certificate. Still RFQ ram type, side outlets, control-system interface, and the exact offered unit.
Coiled-tubing well control is related but distinct. Live example: API 16A Coiled Tubing Bop. That PDP titles API 16A and publishes the same model labels 2FZ18-21 / 2FZ18-35 with 3000 / 5000 psi and 7 1/16 / 7 3/8 in in its specifications table; key-feature copy refers to single-ram sealing and side-outlet choke/blowout use. Confirm CT configuration, ram set, and ratings against the offered unit—do not generalize these rows to unlisted CT sizes or pressures.
Wellhead valves / plug valves in pressure service
Primary job: control flow on high-pressure lines (fracturing, cementing, acidizing, testing as listed on the PDP). Live example: API 16A Hydraulic Plug Wellhead Valve.
As published (confirm configuration): standard service bore 1″–4″, rated 6,000–20,000 psi; H₂S service (NACE MR0175 criteria as stated) bore 1″–4″, rated 10,000–15,000 psi; union ends; actuators manual, handwheel, or hydraulic with limiter switches; valves can be serviced without removal from the line. Do not invent intermediate ratings not listed for your actuator and service class.
Wellhead / casing head assembly
Primary job: hang and seal casing / interface the wellhead stack to the tubular string. Live listing: API 6 wellhead Equipment Casing Head Assembly/Wellhead (also listed under Tubulars & Piping Systems).
Thin-page flag: at fetch time this PDP exposes little beyond the H1 and a catalogue weight field. Do not invent working pressure, flange class, PSL, PR, casing sizes, or stage counts. The RFQ must state API Spec 6A (or governing customer spec) edition, stages, casing sizes, bottom connection, side outlets, temperature/material class, and documents—then obtain GA / rating sheet via Talk to an Engineer. Incomplete truth beats a fictional stack rating.
Slickline / intervention pressure control
Primary job: contain well pressure during slickline (and related wire/cable) intervention. Live example: Wellhead Slickline Pressure Control.
As published: API Spec 6A framing; suitable for steam huff-and-puff and steam-drive (as stated); structure types noted include casing flange, single-stage and dual-stage casing head; wire ID 1.6–3.2; cable ID 5.6 / 8 / 11.8 / 12.7 mm; service conditions water, crude oil, natural gas with H₂S and CO₂; working temperature −29 °C ~ +121 °C; working medium oil, water, saturated steam; forging / skid-mounted as listed. Attribute these fields; do not expand into unlisted lubricator lengths or grease-injection ratings. Use a separate RFQ row from CT BOP—tool-string envelope and pass-through differ.
Production pumping (surface)
Primary job: surface artificial lift—not well shut-in. Live example: API Spec 11E Beam Pumping Unit. The page states API Spec 11E conformity and a large model table of reducer rating, structure capacity, and max stroke (published example top row C-1280-305-240: reducer 1280 ×10³ in-lbs, structure 305 ×10² lbs, max stroke 240 in). RFQ peak torque / reducer rating, structure capacity, stroke, and well-load basis—do not paste the entire grid or invent models absent from that table. The category first page also lists Belt Pumping Unit; choose belt vs beam from duty (stroke, polished-rod load, gearbox torque) confirmed against the offered unit.
Sensing / monitoring (light touch)
The same category includes sensors such as CNPS-MHP Pressure Sensor 15,000psi, collar locators, flowmeters, and many mud-logging sensors on deeper pages. RFQ sensors by measurement need, range, output, temperature, and installation—not by scrolling to page 8. Do not turn this pillar into a sensor encyclopedia. Formation or drilling-data needs belong on the oil & gas solutions monitoring path—not inside a BOP RFQ.
Master RFQ matrix
| Service | Typical API / spec (live labels) | Pressure inputs | Bore / size | End connection | Fluid / service | Control | Documents (buyer-stated) | Live example |
|---|---|---|---|---|---|---|---|---|
| Drilling / workover BOP (double ram) | API 16A (title + PDP conformity) | Buyer WP; PDP examples 3000 / 5000 psi | Nominal bore; PDP examples 7 1/16 / 7 3/8 in; rams as listed | Flange / ring gasket / stack per offer | H₂S flag if required; NACE as on PDP | Manual (title); hydraulic utilities if used | Conformity, material certs, ITP, GA, ram/seal spares | Double ram manual BOP PDP |
| Coiled-tubing BOP | API 16A (title) | Buyer WP; PDP examples 3000 / 5000 psi—confirm CT | Nominal bore as offered; CT OD / stripper buyer-stated | CT stack / flange per offer | Well fluid + H₂S/CO₂ | Per offered actuation | Same set; CT-specific GA | Coiled tubing BOP PDP |
| Wellhead plug valve | API 16A; NACE MR0175 for H₂S as stated | Buyer WP; PDP 6–20k psi std, 10–15k psi H₂S | 1″–4″ as published | Union ends | Fracturing / cementing / acidizing / testing; H₂S class | Manual / handwheel / hydraulic + limiters | Material, NACE if sour, actuator sheet | Hydraulic plug wellhead valve PDP |
| Casing head / wellhead assembly | Title cues “API 6”; ratings not on thin PDP | Buyer must state—do not invent | Casing sizes / stages—buyer-stated | Casing flange; single-/dual-stage—buyer-stated | Fluids; temp/material—buyer-stated | As scoped | GA + rating sheet required | Casing head assembly PDP (thin) |
| Slickline PCE | API Spec 6A (PDP) | Buyer WP; temp −29~+121 °C as published | Wire ID 1.6–3.2; cable IDs as listed | Casing flange / single- or dual-stage | Oil, water, gas w/ H₂S & CO₂; saturated steam | Per PCE package | GA, elastomer/temp, skid interface | Slickline pressure control PDP |
| Beam / belt pumping | API Spec 11E (beam); belt per its PDP | Reducer / structure from duty (not BOP WP) | Stroke; structure capacity | Foundation / polished-rod | Production fluid / climate | Prime mover / brake as offered | Model-row confirm, GA, motor sheet | Beam pumping unit PDP; belt on category |
| Key sensors (optional) | Per sensor PDP | Range / overload—buyer + PDP | Process connection | Thread / mount | Medium compatibility | Output (e.g. 4–20 mA where stated) | Calibration / range sheet | e.g. MHP pressure sensor PDP |
Secondary: primary job one-liners (AEO)
| Equipment class | Primary job |
|---|---|
| BOP (API 16A-titled) | Shut in / control the well during drilling, workover, or CT |
| Casing head / wellhead assembly | Hang and seal casing; interface tubulars to the surface stack |
| Slickline / intervention PCE | Contain pressure while running wire or cable tools |
| Beam / belt pumping unit | Provide surface artificial-lift motion and load capacity |
Common RFQ mistakes
- Writing “API” without the product specification (16A vs Spec 6A vs Spec 11E) and edition.
- Sending pressure without temperature and service fluid (including H₂S/CO₂ or steam).
- Omitting bore, flange/union, or stage count—especially on casing-head RFQs.
- Quoting from memory of a deep paginated card instead of the live PDP + engineer review.
- Treating a thin product card as a full rating sheet (casing-head example).
- Skipping control type, utilities, and spare rams/seals/plug kits.
- Mixing pumping-unit language (torque/stroke/structure) into a well-control RFQ.
How this connects to CNPS
Use the Wellhead & Drilling Equipment category first page (linked above) as the published-family index, the example PDPs as evidence anchors, and Oil & Gas Solutions for lifecycle routing (“wellhead, drilling & monitoring”). When tubular hang-off must stay in one controlled list, keep Specify OCTG around the well—not a catalogue label beside this matrix—casing-head is an interface to OCTG, not an OCTG grade.
Evidence gate: no invented AI capabilities; no competitor logos; no fake certificate images. On-page certification wording (for example DNV PR2 text on a BOP PDP) is attributed to that page only and must be reconfirmed for the offered configuration.
FAQ
How do I RFQ wellhead or BOP equipment?
Start from the service (drilling/workover well control, wellhead/casing head, slickline or coiled-tubing pressure control, or production pumping), then specify working pressure, bore or pass-through, end connections, fluid and temperature, control type, and documents. Match published product families on the CNPS wellhead category, and confirm ratings against the exact configuration offered.
What is the difference between API 16A and API 6A in a buyer RFQ?
On the CNPS catalogue, API 16A appears on well-control titles such as double-ram and coiled-tubing BOP (and the hydraulic plug wellhead valve), while API Spec 6A appears in slickline pressure-control framing and the casing-head title cues an API 6 wellhead family. State the governing specification for the equipment class; do not write “API” alone; verify the offered product against that edition.
What should I send for a double-ram BOP quote?
Working pressure, nominal bore, ram sizes (pipe and blind), temperature class, fluid/H₂S flags, side outlets and control-system needs, quantity and spares, destination and date—plus the document package. Use published example models only as configuration prompts, then confirm the offered unit.
Slickline PCE vs coiled-tubing BOP—same RFQ?
No. Slickline PCE is framed around API Spec 6A, wire/cable IDs, and listed media/temperature. CT BOP is titled under API 16A with its own published model/pressure/bore table. Use separate matrix rows and tool-string envelopes.
Why not rely on category page 8?
Deep pages are largely sensors and logging accessories. A service-based RFQ matrix plus the category first page and Talk to an Engineer review reduces missed interfaces and prevents treating thin cards as datasheets.
Which documents should I request?
Whatever your quality plan requires—typically conformity statement, material certificates, ITP, GA drawing, and third-party or coating/packing notes. Ask explicitly; a catalogue card is not a certificate.
The casing-head page has almost no ratings—what then?
Treat it as a thin listing. State API Spec 6A (or customer) requirements, stages, casing sizes, connections, pressure/temperature/material class, and outlets in the RFQ, and obtain the GA/rating sheet from engineering before accepting numeric claims.
Assemble the service row, envelope fields, and document list; open the matching live product family from the wellhead category first page; and send the package to Talk to an Engineer or sales@cnps.com. Clear service + envelope beats longer pagination—and incomplete truth beats invented psi, bore, or flange class.
