FPSO Fleet Operating in Angola — Complete Vessel Directory and Production Data

Angola operates one of the largest concentrations of Floating Production, Storage and Offloading (FPSO) vessels anywhere in the world. With over a dozen major FPSO units deployed across deepwater Blocks 14, 15, 17, 18, 31, and 32, these massive floating facilities form the backbone of the nation’s 1.1 million barrel-per-day crude oil production. Every barrel of Angolan deepwater crude passes through an FPSO before reaching export markets, making this fleet arguably the single most critical infrastructure asset in the country’s petroleum sector.

This page catalogs every major FPSO currently operating in Angolan waters, covering vessel specifications, production and storage capacities, operator details, field assignments, and the subsea architecture each unit supports. For context on the subsea equipment tied to these vessels, see the subsea infrastructure overview. For details on how crude moves from FPSOs to market, consult the crude oil export terminals page.

What Is an FPSO and Why Angola Relies on Them

An FPSO is a floating vessel used to process hydrocarbons produced from nearby subsea wells. The vessel receives crude oil and associated gas through risers and flowlines connected to subsea trees on the ocean floor. Onboard processing separates oil, gas, and water. Treated crude is stored in the vessel’s hull tanks until offloaded to shuttle tankers for export.

Angola’s deepwater fields sit in water depths ranging from 1,000 meters to over 2,000 meters, far too deep for conventional fixed platforms. FPSOs are the only practical production solution at these depths. They can be disconnected and relocated if needed, and their large storage capacity — often exceeding 1.5 million barrels — means production can continue even when export tankers are delayed.

The first FPSO deployed in Angola was the Girassol unit in 2001. Since then, the fleet has expanded to cover virtually every major deepwater block. As of 2026, Angola hosts more FPSOs than any other African nation and ranks among the top five globally by FPSO count.

Complete FPSO Fleet Register

The table below lists every major FPSO currently operating in Angolan waters, ordered by first oil date.

Notes: Capacities listed are nameplate design capacities. Actual production varies based on reservoir performance, maintenance schedules, and decline curves. Gas capacity figures include both associated and non-associated gas where applicable.

TotalEnergies Block 17 — The Flagship Cluster

Block 17, operated by TotalEnergies, is the single most productive block in Angola and hosts four of the country’s largest FPSOs. Together, these four vessels have a combined nameplate capacity exceeding 800,000 barrels per day, though actual output in 2025 averaged approximately 450,000 bbl/d due to natural decline from mature fields.

Girassol FPSO

The Girassol FPSO holds the distinction of being Angola’s first deepwater production unit. Delivered by Bouygues Offshore (now Saipem) and stationed on the Girassol field in Block 17, the vessel achieved first oil on December 4, 2001. The hull was converted from a Very Large Crude Carrier (VLCC) and measures 300 meters in length.

The Girassol complex now encompasses the original Girassol field, the Rosa satellite development (first oil 2007), and the Jasmin extension (first oil 2008). Together these fields are tied back to the single FPSO through a network of subsea flowlines and manifolds. The Rosa development alone added approximately 60,000 bbl/d of peak capacity through nine production wells connected via two subsea manifolds.

After more than two decades in service, the Girassol FPSO has undergone multiple life-extension programs. The most recent major turnaround, completed in 2024, included topside upgrades to water injection systems and gas compression capacity. TotalEnergies has indicated the vessel will remain operational beyond 2030, supported by infill drilling campaigns targeting remaining reserves estimated at 150 million barrels recoverable.

For details on how gas from Girassol feeds into the broader gas gathering network, see the pipeline network page.

Dalia FPSO

The Dalia FPSO commenced production in December 2006, becoming the second major production unit on Block 17. Unlike Girassol, the Dalia FPSO was purpose-built as a new-build hull rather than a VLCC conversion. The vessel was constructed at the Daewoo Shipbuilding and Marine Engineering (DSME) yard in South Korea and is 300 meters long with a beam of 60 meters.

Dalia produces from reservoirs in the Miocene geological formation, which presented unique challenges due to the heavy, viscous nature of the crude (approximately 23 degrees API). The FPSO’s topside processing was specifically designed to handle this heavy crude, with enhanced heating and separation systems. Peak production reached 240,000 bbl/d shortly after startup.

The Camelia satellite development, tied back to the Dalia FPSO in 2014, added four production wells and extended the field’s production plateau. Current combined output from Dalia and Camelia averages approximately 100,000 bbl/d.

Pazflor FPSO

Pazflor marked a significant technological milestone when it achieved first oil in August 2011. The FPSO was the first vessel in the world designed to simultaneously process crude from multiple reservoir types with significantly different fluid characteristics. The Pazflor development encompasses three distinct oil pools — Acacia (heavy oil, 17 degrees API), Hortensia (medium oil, 26 degrees API), and Perpetua (light oil, 33 degrees API) — each requiring different processing conditions.

The vessel was built by Samsung Heavy Industries and measures 325 meters in length, making it one of the largest FPSOs in Africa. The subsea architecture includes 49 wells connected through 10 manifolds and over 200 kilometers of flowlines and umbilicals. For more on these subsea components, see the subsea infrastructure page.

CLOV FPSO

CLOV, named for the four fields it serves — Cravo, Lirio, Orquidea, and Violeta — began production in June 2014. The FPSO was built at the Hyundai Heavy Industries yard in Ulsan, South Korea and has a hull length of 305 meters.

The CLOV development spans an area of approximately 380 square kilometers in the southeastern portion of Block 17. The subsea network consists of 34 wells (initially) connected through eight production manifolds and four water injection manifolds. Crude from CLOV ranges from 28 to 35 degrees API depending on the reservoir.

CLOV represented TotalEnergies’ strategy of developing multiple smaller accumulations through a single shared FPSO, reducing unit development costs. Total investment for the CLOV project was approximately $8 billion. Since first oil, TotalEnergies has pursued infill drilling opportunities, adding wells to both the Cravo and Violeta fields.

ExxonMobil Block 15 — The Kizomba Trilogy

ExxonMobil’s Angolan subsidiary, Esso Exploration Angola, operates Block 15 through three FPSO units collectively known as the Kizomba complex. Block 15, located approximately 350 kilometers northwest of Luanda, was the first ultra-deepwater block to be developed in Angola.

Kizomba A

Kizomba A achieved first oil in August 2004 from the Hungo and Chocalho fields. The FPSO was converted from the VLCC Constellation, built at Jurong Shipyard in Singapore. At commissioning, Kizomba A had the largest oil processing capacity of any FPSO in the world at 250,000 bbl/d.

The Hungo field alone delivered peak production of approximately 200,000 bbl/d in 2005, making it one of the most prolific single-field developments in Angolan history. Production has since declined as the reservoir matures, with combined Hungo-Chocalho output averaging approximately 70,000 bbl/d in 2025.

Kizomba B

Kizomba B followed in July 2005, producing from the Kissanje and Dikanza fields. The vessel is a near-sister to Kizomba A, converted from the VLCC Esmeraldas. Both vessels share similar specifications, though Kizomba B’s topside modules were configured for the slightly different fluid properties of the Kissanje and Dikanza reservoirs.

Peak production from Kizomba B reached approximately 230,000 bbl/d, driven primarily by the prolific Kissanje field. As with Kizomba A, natural decline has reduced output to approximately 60,000 bbl/d by 2025.

Kizomba C (Mondo FPSO)

The third Kizomba development took a different approach. Rather than a full-scale FPSO, ExxonMobil deployed the smaller Mondo FPSO to develop the Mondo, Saxi, and Batuque fields in the shallower eastern portion of Block 15. The vessel achieved first oil from the Saxi field in June 2008 and subsequently added production from Mondo and Batuque.

The Mondo FPSO has a nameplate capacity of 100,000 bbl/d, reflecting the smaller reserves in these accumulations. Unlike the deepwater Hungo and Kissanje fields, the Saxi-Batuque reservoirs sit in water depths of 730 to 1,350 meters and produce lighter crude.

ExxonMobil has studied options for sustaining Block 15 production through additional tiebacks and potential new satellite developments. The upstream section covers Block 15 exploration and reserves in more detail.

BP Blocks 18 and 31

BP operates two Angolan deepwater blocks with FPSOs — Block 18 (Greater Plutonio) and Block 31 (PSVM).

Greater Plutonio FPSO

The Greater Plutonio FPSO, stationed on Block 18, achieved first oil in October 2007. The vessel serves the Plutonio, Galio, Cromio, Paladio, Cobalto, and Platina fields — six accumulations developed through a single hub FPSO connected to a complex subsea network.

The FPSO was converted from the tanker Espirito Santo and has a processing capacity of 150,000 bbl/d. The vessel’s topside includes three-stage separation, gas compression, water treatment, and injection systems. Associated gas is partly reinjected for pressure maintenance and partly exported via the gas gathering system toward Soyo (see gas processing facilities).

Peak production from Greater Plutonio reached approximately 140,000 bbl/d in 2009. By 2025, output had declined to approximately 45,000 bbl/d. BP has investigated infill drilling and tieback opportunities to sustain production through the late 2020s.

PSVM FPSO

PSVM (Plutao, Saturno, Venus, Marte) represents BP’s ultra-deepwater development on Block 31, located in waters exceeding 2,000 meters depth. The FPSO achieved first oil in December 2013 after a construction period that encountered significant cost overruns, with total project investment exceeding $10 billion.

The PSVM FPSO was built by Hyundai Heavy Industries and operates in some of the deepest water of any production facility in Africa. The subsea architecture connects 40 wells across the four fields through a network of manifolds, flowlines, and steel catenary risers.

The ultra-deepwater location of PSVM presented unique engineering challenges, including the design of high-pressure, high-temperature subsea equipment and the management of flow assurance issues such as hydrate formation and wax deposition. These challenges are discussed further on the subsea infrastructure page.

TotalEnergies Block 32 — The Kaombo Twin FPSOs

Block 32 is TotalEnergies’ newest deepwater development in Angola, producing through a pair of identical twin FPSOs — Kaombo Norte and Kaombo Sul. This innovative approach used two converted VLCC hulls with identical topsides to develop six separate oil accumulations that were individually too small to justify standalone FPSO developments.

Kaombo Norte

Kaombo Norte achieved first oil in July 2018 from the Gengibre, Gindungo, and Caril fields. The FPSO was converted from a Suezmax tanker at the COSCO Dalian shipyard in China, with topsides modules fabricated at multiple yards in Asia and Africa.

The vessel has a processing capacity of 115,000 bbl/d and incorporates several technological innovations, including a new-generation gas treatment system and advanced water injection capabilities. Kaombo Norte connects to 27 subsea wells through an integrated manifold and flowline network.

Kaombo Sul

Kaombo Sul followed with first oil in March 2019, serving the Mostarda, Canela, and Louro fields. The vessel is dimensionally identical to Kaombo Norte, with the same 115,000 bbl/d oil processing capacity. Combined, the twin FPSOs give the Kaombo development a total capacity of 230,000 bbl/d.

The Kaombo development represented an investment of approximately $16 billion, making it one of the largest single-project investments in Angolan petroleum history. The twin-FPSO concept has been studied as a potential model for future developments of marginal deepwater accumulations elsewhere in Angola and across West Africa.

Fleet Maintenance and Life Extension

Maintaining an aging FPSO fleet is one of the most significant operational challenges facing Angola’s petroleum sector. Several of the older vessels — Girassol, Kizomba A, and Kizomba B — have been operating for two decades or more and require continuous investment to maintain production reliability.

Major maintenance activities include:

• Hull integrity inspections — underwater surveys using remotely operated vehicles (ROVs) to assess corrosion, marine growth, and structural integrity
• Topside turnarounds — periodic shutdowns (typically every 3-5 years) for major equipment overhaul, including compressors, separators, pumps, and safety systems
• Mooring system inspections — assessment of anchor chains, turret bearings, and swivel systems that allow the vessel to weathervane
• Riser integrity management — monitoring of flexible risers for fatigue, corrosion, and outer sheath damage

The Angolan national oil company, Sonangol, through its subsidiary Sonangol EP, participates as a concessionaire partner in all FPSO operations and has increasingly pushed operators to maximize the operational life of existing assets rather than investing in new greenfield developments.

Production Performance and Decline Trends

Angola’s total FPSO-based production has been declining since reaching a national peak of approximately 1.8 million bbl/d in 2008-2010. By 2025, total production across all FPSOs averaged approximately 1.0-1.1 million bbl/d. The decline reflects natural reservoir depletion across mature fields, partially offset by new developments like Kaombo.

Operators have responded to declining output through several strategies: infill drilling to access bypassed reserves, waterflood optimization to improve sweep efficiency, and gas-lift optimization to maximize well deliverability. These reservoir management techniques are complemented by topside debottlenecking projects that increase the capacity of water injection and gas compression systems.

For a broader view of Angola’s production data and forecasts, see the data section of this site.

Future FPSO Deployments

As of early 2026, no new FPSO final investment decisions (FIDs) have been announced for Angola, though several prospects are under evaluation:

• Block 15/06 (Eni) — Eni is studying a potential FPSO deployment for the Agogo discovery, which has estimated recoverable reserves of 1 billion barrels. A decision is expected by late 2026 or early 2027.
• Block 17 extensions — TotalEnergies has evaluated additional satellite tiebacks to the existing Girassol and CLOV FPSOs rather than deploying new vessels.
• Block 20 (BP) — BP’s pre-salt discoveries in Block 20 could potentially support a new FPSO, though development timelines remain uncertain.

The economics of new FPSO deployments in Angola are influenced by the country’s fiscal terms, discussed in the finance section, and by the regulatory framework administered by ANPG (Agencia Nacional de Petroleo, Gas e Biocombustiveis), covered in the regulators section.

Technical Comparison: VLCC Conversions vs. New-Build FPSOs

Angola’s fleet includes both converted tankers and purpose-built FPSOs, reflecting the evolution of industry practice over the past two decades.

The trend in Angola has shifted toward new-build FPSOs for major developments, while VLCC conversions have been preferred for fast-track projects and smaller accumulations. The Kaombo twin FPSOs used a hybrid approach — VLCC hulls with purpose-designed topsides — to balance cost and schedule.

Workforce and Local Content

Each FPSO operating in Angola employs between 100 and 200 personnel on board at any given time, working in rotation (typically 28 days on, 28 days off). Total offshore employment across the FPSO fleet is estimated at 2,500-3,000 positions, with an equivalent number of support roles onshore.

Angola’s local content regulations require operators to prioritize Angolan nationals in staffing, with targets of 70% or higher Angolan workforce on mature installations. Training programs operated by Sonangol, TotalEnergies, and ExxonMobil have developed a substantial pool of Angolan petroleum engineers, marine officers, and process technicians.

The companies section of this site profiles the major operators and their local content commitments in more detail.

Conclusion

Angola’s FPSO fleet represents a cumulative investment exceeding $80 billion and constitutes the industrial backbone of the nation’s petroleum sector. From the pioneering Girassol deployment in 2001 to the cutting-edge Kaombo twins, each vessel tells a story of technological advancement, commercial ambition, and the relentless challenge of extracting oil from some of the deepest waters on the planet. As mature fields decline and new discoveries demand ever more creative development solutions, the fleet will continue to evolve — but for the foreseeable future, FPSOs remain the defining infrastructure of Angolan oil production.

For related midstream topics, explore the full midstream section, including oil storage terminals, LNG shipping logistics, and offshore marine services.