Deepwater Exploration Blocks: Pre-Salt Potential and Key Concessions

Angola’s Deepwater Foundation

Angola’s oil production is overwhelmingly a deepwater story. The giant fields discovered in the late 1990s and early 2000s in water depths of 1,000-2,000 metres transformed the country into Africa’s largest producer. These fields — concentrated in Blocks 14, 15, 17, 18, 31, and 32 — still account for the majority of Angola’s 1.03 million barrels per day output. They are also the primary source of the decline, as mature deepwater reservoirs exhibit steep natural depletion rates of 15-25% per year once plateau production ends.

Key Producing Blocks

Block 17: TotalEnergies’ Flagship

Block 17, operated by TotalEnergies, is Angola’s most productive single concession. It hosts four major FPSO-based developments — Girassol, Dalia, Pazflor, and CLOV — plus the more recently sanctioned Begonia project on Block 17/06. The Begonia development, at USD 850 million, targets 30,000 barrels per day and was commissioned in late 2024. It exemplifies the subsea tie-back approach that extends the economic life of existing FPSO infrastructure by connecting satellite reservoirs.

Block 17’s importance extends beyond its production volumes. It is the benchmark for Angola’s deepwater capability, demonstrating that complex subsea developments in 1,400-metre water depths can be executed and operated successfully. The technical lessons learned on Block 17 inform every other deepwater operation in Angola.

Block 15/06: Agogo and Azule Energy

Block 15/06, operated by Azule Energy (the BP/Eni joint venture), is the site of the Agogo discovery — one of Angola’s most significant recent finds. The Agogo IWH (Integrated West Hub) project was recently launched, targeting production from the Agogo field complex through an integrated hub approach that aggregates multiple satellite reservoirs.

Azule Energy’s creation in 2022, combining BP’s and Eni’s Angolan operations, was specifically designed to create a more efficient platform for investing in Angola. The joint venture structure reduces overhead, pools technical expertise, and concentrates capital allocation decisions, making Azule a more committed Angola-focused operator than either parent company would be individually.

Block 31: Ultra-Deepwater Pioneer

Block 31, also operated by Azule Energy, pushed Angola into ultra-deepwater territory. The PSVM (Plutao, Saturno, Venus, Marte) development in water depths exceeding 2,000 metres demonstrated that Angola’s geology extends into the ultra-deepwater realm. This is significant for future exploration, as the pre-salt play is typically found at greater depths below the seabed, often in ultra-deepwater settings.

Block 32: Kaombo

Block 32, operated by TotalEnergies, hosts the Kaombo development — two FPSOs (Kaombo Norte and Kaombo Sul) with combined capacity exceeding 200,000 barrels per day at peak. Kaombo represented one of the largest deepwater development investments in Africa when sanctioned. Like other mature deepwater projects, production is now declining from plateau rates, contributing to the national decline curve.

The Pre-Salt Opportunity

Angola sits on the conjugate margin to Brazil’s Santos and Campos basins, where pre-salt discoveries have added tens of billions of barrels of recoverable oil. The geological analogy — similar rift basin architecture, carbonate reservoir rocks beneath thick salt layers — suggests that Angola’s pre-salt section could contain significant volumes.

For a detailed analysis of pre-salt prospectivity, see Pre-Salt Basin Potential.

Key considerations for Angola’s pre-salt exploration:

1. Geological similarity: The South Atlantic opened by rifting between Angola and Brazil, creating mirror-image geology on both margins
2. Limited drilling: Far fewer pre-salt wells have been drilled offshore Angola than offshore Brazil
3. Depth and cost: Pre-salt targets typically lie at total depths of 5,000-7,000 metres, requiring expensive drilling campaigns
4. Seismic data: Modern 3D seismic has improved imaging beneath salt bodies, but interpretation remains challenging
5. Fiscal terms: Pre-salt exploration requires frontier fiscal incentives given the high upfront capital and exploration risk

New Exploration Frontiers

Beyond the established deepwater plays, ANPG’s licensing programme is opening new frontiers:

Namibe Basin

The Namibe Basin in southern Angola shares geological characteristics with Namibia’s Orange Basin, where Shell and TotalEnergies have announced major discoveries (Venus, Graff). If the Namibian play extends northward into Angolan waters, the Namibe Basin could become a significant new production province. However, exploration drilling has been limited and the geology is less well constrained than in the Congo Basin to the north.

Kwanza Basin

The Kwanza Basin is the primary target for pre-salt exploration. ANPG has included Kwanza Basin blocks in both the 2024 and 2025 licensing rounds, seeking operators willing to commit exploration drilling programmes. The basin’s prospectivity is supported by regional seismic data and by geological models that extrapolate from Brazil’s pre-salt success.

Onshore Basins

The Etosha, Okavango, and Kassange basins represent genuinely frontier acreage with minimal well penetrations. These onshore basins have different geological settings from the deepwater plays that currently dominate production. Exploration interest has been limited, and commercial outcomes are uncertain.

Infrastructure Advantage

Angola’s deepwater exploration benefits from decades of infrastructure investment. The offshore environment has:

• Multiple FPSOs with processing capacity and storage
• Subsea production systems including manifolds, flowlines, and umbilicals
• Pipeline networks connecting to onshore terminals
• The Soyo LNG terminal for gas offtake
• Experienced Angolan and international workforce
• Established supply bases in Luanda, Soyo, and Cabinda

This infrastructure means that new discoveries near existing developments can be brought online faster and at lower cost through subsea tie-backs, rather than requiring standalone FPSO installations. The Begonia development on Block 17/06 exemplifies this approach.

Enhanced Recovery: Extending Field Life

While exploration targets new resources, enhanced oil recovery (EOR) techniques can extend the productive life of existing deepwater fields. Technologies applicable to Angola’s geology include:

• Water-alternating-gas (WAG) injection
• Polymer flooding
• Infill drilling to access bypassed reserves
• Advanced well completion designs
• Digital oilfield monitoring and optimisation

The November 2024 incremental production decree provides fiscal incentives for EOR investment, recognising that existing fields offer faster, lower-risk production additions than frontier exploration.

The Decline Management Challenge

Managing decline across multiple large deepwater developments is operationally complex. Each field has unique reservoir characteristics, decline rates, and investment requirements. Operators must balance:

• Capital allocation between decline mitigation and new development
• FPSO life extension versus replacement decisions
• Subsea equipment integrity in ageing systems
• Well intervention programmes across geographically dispersed fields
• Gas handling as gas-oil ratios change during depletion

Outlook

Angola’s deepwater blocks remain the foundation of national production. The near-term trajectory depends on brownfield investment by TotalEnergies, Azule Energy, and Chevron in their existing concessions, combined with new project startups like Begonia and Agogo IWH. The medium-term outlook hinges on exploration success, particularly in the pre-salt and frontier basins. The long-term future will be determined by whether Angola can attract a new generation of investment to complement — and eventually replace — the discoveries that built its deepwater industry.

For the latest exploration developments, see the brief on Deepwater Discovery Prospects.

Data Sources

Block data from ANPG and operator corporate disclosures. Production data from FocusEconomics. Begonia project details from US ITA. Pre-salt geological context from EIA international analysis.

ANPG Licensing Program and Block Availability

Angola’s deepwater exploration program is driven by ANPG’s six-year licensing round (2019-2025), which targets the auction of 50 new blocks across six sedimentary basins: Congo, Namibe, Benguela, Etosha, Okavango, and Kassange. In March 2024, winners were announced for a 12-block tender covering the Lower Congo and Kwanza basins, while the 2025 limited public tender offers up to 10 offshore blocks in the Kwanza and Benguela basins.

Pre-Salt Basin Potential

Angola’s pre-salt basin represents the most significant frontier exploration opportunity, drawing comparisons to Brazil’s prolific pre-salt discoveries that transformed that country’s production trajectory. The geological similarity of the South Atlantic margin, where Angola and Brazil were once joined before continental drift separated them, suggests substantial hydrocarbon potential beneath the salt layer in Angola’s offshore basins. Successful pre-salt exploration could significantly alter Angola’s production outlook, which currently forecasts crude production rising in 2026 and gradually gaining momentum through 2029 but remaining below the 2015-2024 average of 1.39 million b/d until at least 2030.

Operator Activity and New Discoveries

The major IOCs active in Angola’s deepwater include TotalEnergies, whose Begonia project on Block 17/06 (USD 850 million, 30,000 b/d) commissioned in late 2024; Azule Energy (BP/Eni joint venture) with the recently launched Agogo IWH Project; and Chevron, which operates the Angola LNG facility at Soyo. The November 2024 Incremental Production Decree complements new exploration by improving fiscal terms for reinvestment in mature deepwater blocks, addressing the competitive challenge posed by lower-cost provinces like Guyana and Brazil where breakeven costs run USD 30-35/barrel.

The PDN 2023-2027 targets maintaining production above 1.1 million b/d through 2027, with deepwater exploration providing the long-term production replacement pipeline. The Estrategia de Longo Prazo Angola 2050’s projection of USD 900 billion in total implementation costs over 27 years depends on sustained oil revenue to finance the transition to a diversified economy.

Broader Economic and Institutional Context

Angola’s petroleum sector operates within the institutional framework established by the PDN 2023-2027, which targets total GDP of 62 trillion kwanzas, annual growth of approximately 3.3%, and non-oil GDP growth of approximately 5% annually. The plan’s three fundamental pillars of human capital development, infrastructure modernization, and economic diversification all depend on sustained petroleum revenue. Public debt reduction from over 100% of GDP in 2020 to just above 60% in 2024 demonstrates fiscal discipline, while agriculture’s share of GDP more than doubled from 6.2% in 2010 to 14.9% in 2023, showing that diversification is progressing alongside oil sector development. The Estrategia de Longo Prazo Angola 2050 envisions growing non-oil GDP from USD 84 billion to USD 275 billion and non-oil exports from USD 5 billion to USD 64 billion by 2050, with the petroleum sector providing the transitional revenue base for this transformation. The Kwenda social program, which distributed USD 420 million to 251,000 families under the previous PDN, illustrates how oil revenue translates into direct social investment that builds the human capital foundation for long-term economic diversification. The current plan’s alignment with the African Union Agenda 2063 and the UN Sustainable Development Goals 2030 further reinforces the connection between petroleum sector performance and broader development outcomes, with 75% of the PDN’s 284 action priorities directly impacting the 17 SDGs.

Downstream Integration and Refinery Development

Angola’s petroleum sector strategy increasingly links upstream production to downstream processing through three major refinery projects. The Cabinda Refinery, inaugurated on 1 September 2025, operates at 30,000 b/d Phase 1 capacity with Phase 2 expansion to 60,000 b/d expected within 18-24 months, representing a USD 550 million investment with Gemcorp holding 90% and Sonangol 10%. The Lobito Refinery, at approximately 12% completion, targets 200,000 b/d capacity with a total investment of USD 6.6 billion and a USD 4.8 billion financing gap being discussed with ICBC, Societe Generale, Standard Chartered, and Afreximbank. The Soyo refinery remains on hold with an earliest expected online date of 2028. Together, these projects address Angola’s approximately 72% import dependency for refined petroleum products, equivalent to roughly 3.3 million metric tons annually.