Wellhead Equipment Suppliers in Senegal (2026)

Wellhead equipment for Senegal is bought almost entirely abroad. Sangomar Phase 1 drilled 23 subsea wells, each carrying its own tree, connector, and control package, per the SPE Journal of Petroleum Technology field report, and a 24th well was later approved. As Woodside plans a second phase and GTA develops further wells, demand for trees, valves, and completion hardware keeps reopening.

That is the pattern most suppliers miss. Senegal went from a pre-production frontier to a producing hydrocarbons economy inside 18 months, and wellhead spend does not stop at first oil. It recurs with every well pair, every workover, and every spares cycle. This page maps where wellhead and Christmas-tree demand sits, who signs the orders, how the money settles, and which sales channels are quietly losing money. For the wider upstream picture across all five equipment lines, start with the Senegal oil and gas equipment suppliers guide, and for the macro and FX backdrop, the Senegal industrial and procurement guide.

Where the wellhead RFQ volume sits

Wellhead procurement in Senegal splits into four practical buckets, and a supplier should know which one its product serves before it writes a proposal.

Subsea trees and wellhead systems. Sangomar and GTA are deepwater subsea developments, so the core spend is subsea. That means horizontal and vertical trees to API 17D, tubing and casing hangers, subsea wellheads, connectors, and the control modules that sit on top. Sangomar Phase 1 subsea systems were built and installed by the Subsea Integration Alliance of Subsea7 and OneSubsea, so the tree and connector sub-tier flows through that kind of integrator rather than direct to the operator. Phase 1 hardware is in the water, but spares consumption is continuous and Phase 2 planning reopens tree demand.

Surface wellheads and API 6A equipment. Not every well tied to Senegal sits on the seabed. The onshore appraisal and drilling programme, plus the SAR refinery feed chain, calls for conventional surface wellheads, casing heads, tubing spools, and the gate, check, and safety valves that make up an API 6A stack. This is the segment where a mid-sized specialist can compete on delivery and price rather than on deepwater prequalification alone.

Valves, connectors, and flow control. A Christmas tree is a valve assembly at heart. Gate valves, choke valves, actuators, and connectors are consumed across both the subsea and surface fleets, and they wear, so they reorder. A valve or actuator maker holding API 6A or 17D certification has a recurring position here even without supplying a full tree.

Completion and intervention hardware. As wells are drilled out and later worked over, completion strings, hangers, and intervention equipment move with the rig programme. That demand tracks drilling activity rather than first oil, and Phase 2 work keeps the line live.

Who actually issues the wellhead RFQs

The buyer map is short, which suits a supplier that does its homework.

Woodside operates Sangomar with an 82 percent stake and confirmed first oil on 11 June 2024, documented in its Sangomar first-oil announcement. It runs operating-asset procurement for the subsea system and coordinates the Dakar supply base, and its planned second phase, which Woodside and PETROSEN have discussed as unlocking roughly 250 million additional barrels, is the next major tree-demand event.

PETROSEN, the national oil company, holds the other 18 percent of Sangomar and partners with bp, Kosmos, and Mauritania’s SMH on GTA. It is the state counterparty for local-content compliance and is building its own operated portfolio, which will issue direct RFQs over time.

bp operates GTA with Kosmos and PETROSEN. First gas came at the end of 2024 and, per Kosmos Energy’s Greater Tortue Ahmeyim project page, first LNG followed in 2025. GTA’s later wells and the Phase 2 concept keep subsea wellhead demand on the table.

Below the operators sit the people who buy most of the hardware. The SURF and subsea integrators such as Subsea7 and OneSubsea, and the tree and completion houses in the SLB, Baker Hughes, and TechnipFMC tier, place the actual orders. A component maker either prequalifies with those firms and the operator in parallel, or sells around them into spares. Societe Africaine de Raffinage (SAR), the state refiner running about 1.2 million tonnes a year and preparing a larger second plant, is a separate French-language buyer on the surface and downstream side.

FX, letters of credit, and ECA cover for wellhead orders

Wellhead spend in Senegal runs on two currencies, and getting that right protects your margin.

Offshore operating-asset contracts with Woodside, bp, and their integrators are dollar-denominated, matching global upstream norms, with USD letters of credit and payment terms benchmarked to international practice. The onshore and state-linked chain is where Senegal’s structural advantage shows. The West African CFA franc is hard-pegged to the euro at 655.957 through the BCEAO with full convertibility, a parity the French Treasury backs with an unlimited convertibility guarantee, so PETROSEN’s operated spend and SAR’s packages settle in euro-equivalent value without the devaluation risk that erodes margins in floating African markets. The macro programme behind that stability is tracked on the IMF Senegal country page. Documentary credits open through regional banks, typically Societe Generale Senegal, CBAO, Ecobank, Bank of Africa, and UBA, with a top-tier correspondent confirmation on the larger packages.

Payments follow the usual milestone shape: an advance against a bank guarantee, the bulk against shipment documents, and a final tranche against commissioning, with a retention holdback released after the warranty period. Where your home country runs an export-credit agency, bring the financing wrap into the bid early. Sinosure backs Chinese kit, and Bpifrance Assurance Export, SACE, UKEF, US EXIM, and Euler Hermes cover Western supply. ECA-backed terms have decided more than one recent West African energy award.

Tender platforms and procurement entry points

Wellhead procurement does not run through a single portal, so a supplier works several doors at once. The first is operator and integrator prequalification. Woodside, bp, Subsea7, OneSubsea, and the tree houses run vendor-registration systems, and a place on the approved vendor list is what turns interest into an invitation to tender. The second is Senegal’s Petroleum Code of 2019, which asks operators and contractors to prioritise qualified Senegalese suppliers in defined categories and to meet training and joint-venture thresholds on larger scopes. A foreign supplier answers that by pairing with a registered local partner or offering technology transfer rather than reading it as a wall. The third door is the state and downstream side, where PETROSEN’s operated buying and SAR’s tenders publish in French on the national SYGMAP portal under the DCMP desk, with APIX handling investor setup and the large-works customs relief on imported capital goods. French is not optional there, even though English works at the Tier 1 operator level.

Dying conventional channels for wellhead sales

Several traditional routes into Senegalese wellhead procurement are losing their return in 2026.

Sector trade fairs no longer justify their cost as a primary lead channel. MSGBC Oil, Gas and Power in Dakar is the flagship regional event and still reads which projects are moving, and some buyers travel to Africa Oil Week in Cape Town, but the all-in cost per qualified lead has climbed past 300 to 900 dollars once booth, freight, travel, and months of follow-up are counted. Senior operator and PETROSEN buyers increasingly send junior engineers while the decision-makers stay in Dakar, so a three-day stand yields a thin list.

Expatriate field reps are hard to justify. A fully loaded European or American technical rep in Dakar runs well over 120,000 dollars a year once housing and the post-2024 cost-of-living premium are counted, against a handful of closed deals, which puts cost per qualified lead in the 500 to 1,200 dollar band and pins coverage to one person.

Distributor and legacy-channel lock-in is fragmenting too. Surface wellhead and Christmas-tree systems are a global business shared between established Western houses, from Canadian oilfield equipment manufacturers to the Shandong valve clusters that increasingly supply Africa, and much of that volume historically routed through Dakar importer-distributors and the older French and Chinese channels. As larger buyers pull procurement in-house, suppliers that placed all their Senegal volume through one legacy distributor find themselves under-penetrated on the real buying centres.

Against those linear-cost channels, a modern outbound engine tuned for Senegalese upstream runs at 150 to 300 dollars per qualified lead at the start and gets cheaper as it learns, reaching named procurement contacts at Woodside, bp, PETROSEN, SAR, and the SURF and tree integrators in both French and English, every week rather than once a year.

FAQ

Who supplies wellhead equipment to Senegal today?

Almost all of it is imported. Subsea trees and wellheads flow through the SURF and subsea integrators, Subsea7 and OneSubsea on Sangomar, and the tree houses in the SLB, Baker Hughes, and TechnipFMC tier, working for operators Woodside and bp. PETROSEN and SAR buy on the state and surface side.

What standards do wellheads need for Sangomar and GTA?

Subsea trees and wellhead systems follow API 17D for subsea equipment, while surface wellheads, casing heads, and valve stacks follow API 6A. Deepwater packages also carry strict prequalification and material-traceability requirements, so certification and documentation are checked before any technical bid is accepted.

What currency are Senegal wellhead contracts paid in?

Offshore operating-asset orders with Woodside, bp, and their integrators are dollar-denominated to match global upstream practice. Onshore and state-linked spend through PETROSEN and SAR uses the euro-pegged CFA franc at 655.957 to the euro through the BCEAO, so euro contracts settle without devaluation risk.

Do I need French to sell wellheads into Senegal?

English works at the Tier 1 operator level with Woodside, bp, and Kosmos. But PETROSEN state procurement, SAR tenders, and any public route through SYGMAP and the DCMP desk run in French. Bilingual proposal and documentation capability is the safe standard for a full Senegal programme.

Where to go next

Senegal’s wellhead market is small on names and deep on value, and the spend recurs with every well pair, workover, and spares cycle rather than ending at first oil. The suppliers that win pick their segment, prequalify with the operator and the integrator early, and keep a line open to the buying centres all year.

If you build subsea trees, surface wellheads, valves, or completion hardware and want a Senegal-focused outbound programme across the PETROSEN, operator, and integrator buying centres, send your spec, drawings, pressure ratings, and target tonnage through our contact page or reach me directly at burak@papaverai.com, and we will route it to the right buyers. For the full upstream buyer map, see the Senegal oil and gas equipment suppliers guide.