Upstream Investment Outlook: IOC Strategies and New Exploration

The Investment Imperative

Angola’s upstream petroleum sector requires sustained, large-scale investment to arrest the production decline from 1.88 million barrels per day in 2008 to 1.03 million barrels per day by December 2024. ANPG projects that new investment exceeding USD 60 billion over the next five years is needed to maintain output above 1.1 million barrels per day through 2027 and to build a pipeline of new developments that can deliver incremental production into the 2030s.

This is not aspirational rhetoric. Without investment at this scale, Angola’s production trajectory points toward sub-one-million barrels per day within the next several years, with severe consequences for government revenue, foreign exchange reserves, and the ability to finance economic diversification.

Breakeven Economics: Angola vs. Competitors

Angola’s deepwater breakeven cost of approximately USD 40 per barrel places it at a competitive disadvantage relative to the most attractive new basins:

The breakeven comparison matters because international oil companies allocate capital globally. Every dollar invested in Angola is a dollar not invested in Guyana, Brazil, or Namibia. Angola’s advantage is its established infrastructure — FPSOs, subsea systems, pipelines, and the Soyo LNG terminal — which reduces time-to-first-oil and capital intensity for developments near existing fields. Its disadvantage is fiscal terms that capture a larger share of project economics for the state.

IOC Investment Strategies in Angola

The five major IOCs operating in Angola each have distinct investment strategies:

TotalEnergies

The largest IOC operator in Angola, TotalEnergies committed USD 850 million to the Begonia development on Block 17/06, targeting 30,000 barrels per day with commissioning in late 2024. TotalEnergies operates Blocks 17 and 32, two of Angola’s most productive deepwater concessions. The company’s strategy focuses on extending the plateau life of existing developments through infill drilling and subsea tie-backs while selectively investing in new projects where economics are compelling.

Chevron

Chevron operates Block 0 in Cabinda (Angola’s longest-producing area) and Block 14 in deepwater. Chevron also leads the Angola LNG consortium at Soyo. The company’s investment posture is weighted toward gas monetisation and maintaining existing production rather than frontier exploration.

Azule Energy (BP/Eni)

Azule Energy, the joint venture between BP and Eni, operates Blocks 18 and 31. The recently launched Agogo IWH project demonstrates continued investment appetite. Azule brings the combined deepwater expertise of both parent companies, and its creation signalled long-term commitment to Angola despite BP’s broader portfolio rationalisation.

ExxonMobil

ExxonMobil maintains non-operating interests in several Angolan blocks. The company’s global strategy has shifted toward lower-cost basins (Guyana, Permian), which may limit its appetite for incremental investment in Angola unless fiscal terms improve.

Equinor

Equinor (formerly Statoil) holds interests in Angolan deepwater blocks. The company’s recent strategic focus on its home basin (Norwegian Continental Shelf) and selective international portfolio may constrain incremental capital allocation to Angola.

The Marginal Field Opportunity

While major IOCs drive the bulk of production, there is growing recognition that Angola’s marginal and mature fields represent an underexploited investment category. These blocks — typically smaller, shallower, or more geologically complex than the giant deepwater fields — can be economic under different operating models:

• Smaller, more agile operators with lower overhead
• Enhanced recovery techniques not justified at field-by-field scale by major IOCs
• Fiscal incentives specific to incremental production (such as the November 2024 decree)
• Technology-driven approaches to extending field life

New Exploration: Where the Barrels Are

Near-term production stabilisation depends on development of known resources, but medium-term growth requires new discoveries. The ANPG licensing programme is targeting exploration across six basins, with the most prospective acreage in:

1. Lower Congo Basin: Proven geology, infrastructure proximity, incremental risk
2. Kwanza Basin: Pre-salt potential analogous to Brazil’s major discoveries
3. Namibe Basin: Frontier area with geological similarities to Namibia’s Orange Basin, where Shell and TotalEnergies have made significant discoveries
4. Benguela Basin: Underexplored offshore acreage being tendered in 2025

The pre-salt play is particularly significant. Brazil’s pre-salt discoveries transformed that country’s production outlook, and Angola’s conjugate margin geology suggests similar potential. However, exploration drilling is expensive and outcomes are uncertain — not every geological analogue delivers commercial hydrocarbons.

Fiscal Reform as Investment Catalyst

The November 2024 incremental production decree is the most concrete fiscal reform targeting upstream investment. Its provisions aim to:

• Reduce government take on incremental production from mature blocks
• Provide clarity on fiscal terms for enhanced recovery investments
• Create a predictable framework that IOCs can model over project lifetimes
• Attract capital that would otherwise flow to competing jurisdictions

Additional fiscal reforms under discussion include:

• Reduced signature bonuses for frontier acreage
• Gas-specific fiscal terms to support monetisation investments
• Tax holidays for first oil from new exploration blocks
• Streamlined approval processes for development plan amendments

The Capital Allocation Decision

IOCs make investment decisions by comparing risked returns across their global portfolio. Angola competes for capital against:

Angola’s strongest value proposition is brownfield investment in existing producing areas, where infrastructure is in place, geology is well-understood, and incremental barrels can be brought online quickly. Frontier exploration requires more competitive fiscal terms and geological de-risking through seismic programmes and farmout arrangements.

Sonangol’s Investment Role

Sonangol invested USD 2.4 billion in 2024, directed primarily at equity participation in IOC-operated developments, direct operations on its nine operated blocks, and contributions to LNG operations. As a non-operating partner in most major deepwater blocks, Sonangol’s investment decisions are largely driven by IOC operators’ capital programmes — making IOC investment appetite directly material to Sonangol’s own performance.

Outlook: USD 60 Billion — Achievable?

The USD 60 billion five-year investment target is ambitious. Achieving it requires:

1. Sustained Brent crude prices above USD 60 per barrel
2. Fiscal reforms that demonstrably improve project returns
3. Successful ANPG licensing rounds attracting credible operators
4. At least one major new discovery in a frontier basin to generate exploration momentum
5. Continued commitment from existing IOC operators to brownfield investment
6. Resolution of the Lobito Refinery financing to demonstrate Angola’s ability to attract mega-scale capital

Consensus forecasts suggest crude production may rise modestly in 2026 and gain momentum through 2029, but output will remain below the 2015-2024 average until at least 2030.

Data Sources

Breakeven costs from OilPrice.com. Investment projections from US ITA. Project data from Sonangol, TotalEnergies, and Chevron corporate disclosures. Incremental production decree from ANPG.

Investment Pipeline and Fiscal Incentives

Angola’s upstream investment outlook is anchored by ANPG’s six-year licensing program (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 a 2025 limited public tender targets up to 10 offshore blocks in the Kwanza and Benguela basins.

The investment outlook is further strengthened by the Incremental Production Decree introduced in November 2024, designed to attract capital back into mature offshore blocks through fiscal reform. This regulatory innovation responds to the challenge of declining production from aging fields, where geological constraints rather than quota limitations have been the primary driver of output decline.

Key New Projects Driving Growth

The near-term production outlook depends on several major projects. TotalEnergies’ Begonia Oil Project on Block 17/06 represents a USD 850 million investment adding 30,000 b/d of new production, with commissioning in late 2024. Azule Energy’s (BP/Eni joint venture) Agogo IWH Project has recently launched, contributing additional volumes from deepwater assets. These projects, combined with the new gas connections at the Soyo LNG complex, support the consensus forecast of crude production rising in 2026 and gradually gaining momentum through 2029.

However, Angola faces competitive pressure from lower-cost deepwater provinces. Angola’s deepwater breakeven of approximately USD 40/barrel compares unfavorably to Guyana and Brazil at approximately USD 30-35/barrel, requiring continued fiscal innovation to attract the major IOCs including Chevron, TotalEnergies, and BP/Azule Energy that dominate Angola’s upstream sector.

Alignment with National Development Strategy

The PDN 2023-2027 targets maintaining oil production above 1.1 million b/d through 2027 while simultaneously growing non-oil GDP to approximately 79% of total GDP. The plan projects total GDP of 62 trillion kwanzas with annual growth of approximately 3.3%, supported by the upstream sector’s role as the primary source of government revenue. The Estrategia de Longo Prazo Angola 2050 envisions a 27-year transition from oil dependency to a diversified economy, with the upstream sector’s USD 60 billion investment pipeline providing the fiscal foundation for this transformation. Sonangol’s restructuring, which separated its former concessionaire role to ANPG, positions the national oil company to focus on operational excellence in its retained 35 oil concessions and 9 directly operated blocks.

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.

Investment Pipeline

ANPG projects over USD 60 billion in new upstream investment over the next five years, with the November 2024 incremental production decree providing fiscal incentives for mature block reinvestment.