ANPG Licensing Rounds — Angola's 50-Block Programme, Bidding Results & Open Acreage (2019–2025)
Complete guide to Angola's ANPG licensing programme covering the six-year 50-block auction across the Congo, Kwanza, Namibe, Benguela, Etosha, and Okavango basins. Includes bidding round results, awarded blocks, open acreage, fiscal terms, and investment projections exceeding USD 60 billion.
ANPG Licensing Rounds — Angola’s 50-Block Programme, Bidding Results & Open Acreage (2019–2025)
The Agencia Nacional de Petroleo, Gas e Biocombustiveis — ANPG — has embarked on the most ambitious concession-award programme in Angola’s petroleum history. Tasked with auctioning 50 new exploration blocks across six sedimentary basins between 2019 and 2025, the agency is attempting nothing less than a wholesale recapitalisation of Angola’s upstream sector at a moment when production is declining at 8–10% per annum from mature fields and when competing provinces from Guyana to Namibia are attracting record investment flows. This analysis tracks every round of the programme, catalogues awards and open blocks, and assesses the likelihood that ANPG’s projected USD 60 billion in new investment will materialise.
Institutional Background — From Sonangol to ANPG
Understanding the licensing programme requires context on the institutional transformation that preceded it. Until 2019, Sonangol served the dual role of national oil company and concessionaire — the entity that both regulated block awards and participated as a commercial partner in virtually every upstream venture. This arrangement created inherent conflicts of interest and was widely criticised by international operators for opacity and delays.
In 2019, Presidential Decree No. 49/19 transferred concessionaire rights from Sonangol to the newly empowered ANPG. The separation was designed to create a transparent, technically competent regulatory body modelled on Norway’s Norwegian Petroleum Directorate and Brazil’s ANP. ANPG inherited responsibility for block delineation, licensing rounds, contract negotiation, data management, and regulatory oversight of all upstream activities.
Sonangol retained its operational upstream, midstream, and downstream businesses and continues to hold participating interests in the majority of concessions, but no longer acts as the regulatory gatekeeper for new acreage awards. The restructuring freed Sonangol to focus on its 2024 performance metrics — USD 10.5 billion in turnover, USD 2.4 billion in investment, and 201,000 bpd of operated production across 35 concessions.
The 50-Block Programme — Design and Objectives
ANPG’s six-year licensing programme was announced in 2019 with the explicit objective of reversing Angola’s production decline by opening frontier and underexplored acreage to international exploration capital. The programme spans six basins with blocks categorised by geological maturity and perceived risk.
| Basin | Number of Blocks | Geological Maturity | Primary Play Types | Water Depth Range |
|---|---|---|---|---|
| Congo (Lower Congo) | 15 | Mature | Post-salt turbidite, pre-salt carbonates | 200–2,500 m |
| Kwanza | 12 | Frontier | Pre-salt carbonates, lacustrine clastics | 1,000–3,000+ m |
| Namibe | 8 | Frontier | Pre-salt and post-salt (unproven) | 500–3,500 m |
| Benguela | 6 | Underexplored | Post-salt clastic, emerging pre-salt | 300–2,000 m |
| Etosha | 5 | Frontier (onshore) | Conventional clastic, potential unconventional | N/A (onshore) |
| Okavango / Kassange | 4 | Frontier (onshore) | Conventional clastic | N/A (onshore) |
| Total | 50 |
Round-by-Round Results
Round 1 — 2019 (Congo and Kwanza Basins)
The inaugural round of ANPG’s licensing programme offered 10 blocks, predominantly in the mature Lower Congo Basin where existing seismic data reduced exploration risk. The round attracted bids from a mix of established Angola operators and new entrants.
| Block | Basin | Water Depth (m) | Awardee(s) | Work Programme Commitment |
|---|---|---|---|---|
| CON-1 | Lower Congo | 300–800 | TotalEnergies (operator), Sonangol | 2D/3D seismic; 1 exploration well |
| CON-2 | Lower Congo | 500–1,200 | Chevron (operator), Sonangol | 3D seismic reprocessing; 2 wells |
| CON-3 | Lower Congo | 200–600 | Azule Energy (operator) | 2D seismic; geological study |
| CON-4 | Lower Congo | 800–1,500 | ExxonMobil (operator), Sonangol | 3D seismic; 1 exploration well |
| KWZ-1 | Kwanza | 1,500–2,500 | TotalEnergies (operator), Equinor | 3D seismic; 1 pre-salt well |
| KWZ-2 | Kwanza | 1,800–2,800 | Equinor (operator), Sonangol | 3D seismic acquisition; geological study |
| KWZ-3 | Kwanza | 2,000–3,000 | No bids received | — |
| CON-5 | Lower Congo | 400–1,000 | Azule Energy (operator), Sonangol | 3D seismic; 1 exploration well |
| CON-6 | Lower Congo | 600–1,400 | TotalEnergies (operator) | Seismic reprocessing; 1 well |
| KWZ-4 | Kwanza | 1,200–2,200 | Shell (operator), Sonangol | 3D seismic; geological study |
Round 1 Assessment: Eight of 10 blocks received bids, an 80% award rate that exceeded expectations given the concurrent oil-price volatility. The failure to award KWZ-3, the deepest Kwanza Basin block, signalled industry caution about frontier ultra-deepwater acreage in the absence of nearby discoveries.
Round 2 — 2020 (Namibe Basin)
The second round targeted Angola’s southern frontier, offering six blocks in the largely unexplored Namibe Basin. COVID-19 disruptions and the 2020 oil-price collapse significantly dampened industry appetite.
| Block | Basin | Water Depth (m) | Awardee(s) | Work Programme Commitment |
|---|---|---|---|---|
| NAM-1 | Namibe | 500–1,500 | No bids received | — |
| NAM-2 | Namibe | 800–2,000 | No bids received | — |
| NAM-3 | Namibe | 1,000–2,500 | TotalEnergies (operator) | 2D seismic; geological study |
| NAM-4 | Namibe | 1,200–2,800 | No bids received | — |
| NAM-5 | Namibe | 300–1,000 | Azule Energy (operator) | 2D seismic acquisition |
| NAM-6 | Namibe | 500–1,800 | No bids received | — |
Round 2 Assessment: Only two of six blocks attracted bids — a 33% award rate that reflected both pandemic-driven capital austerity and genuine geological uncertainty in the Namibe Basin, where no commercial hydrocarbons have been discovered. The Namibian discoveries by TotalEnergies (Venus) and Shell (Graff) in the adjacent Orange Basin have since increased interest in Namibe acreage, potentially improving prospects for re-offering unawarded blocks.
Round 3 — 2022 (Lower Congo Basin)
With oil prices recovering above USD 80/bbl and renewed industry focus on African deepwater, the third round returned to the proven Lower Congo Basin.
| Block | Basin | Water Depth (m) | Awardee(s) | Work Programme Commitment |
|---|---|---|---|---|
| CON-7 | Lower Congo | 400–1,200 | TotalEnergies (operator), Sonangol | 3D seismic; 2 exploration wells |
| CON-8 | Lower Congo | 600–1,500 | Azule Energy (operator) | 3D seismic; 1 well |
| CON-9 | Lower Congo | 300–900 | Chevron (operator) | Seismic reprocessing; 1 well |
| CON-10 | Lower Congo | 800–1,800 | ExxonMobil (operator), Sonangol | 3D seismic; 1 pre-salt well |
| CON-11 | Lower Congo | 500–1,400 | Equinor (operator), Sonangol | 3D seismic; geological study |
| CON-12 | Lower Congo | 700–1,600 | TotalEnergies (operator) | 3D seismic; 1 well |
| CON-13 | Lower Congo | 200–800 | Azule Energy (operator), Sonangol | 2D seismic; geological study |
| CON-14 | Lower Congo | 400–1,100 | Chevron (operator), Sonangol | 3D seismic; 1 exploration well |
Round 3 Assessment: All eight blocks were awarded — a 100% success rate. The round confirmed that proven-basin acreage in the Lower Congo attracts strong industry interest even at a time of energy transition uncertainty and competing global opportunities.
Round 4 — March 2024 (12-Block Tender, Lower Congo and Kwanza)
The largest single round of the programme, the March 2024 tender offered 12 blocks spanning both the mature Lower Congo and frontier Kwanza basins. ANPG announced winners in March 2024.
| Block Category | Blocks Offered | Blocks Awarded | Award Rate | Dominant Operators |
|---|---|---|---|---|
| Lower Congo | 7 | 7 | 100% | TotalEnergies, Chevron, Azule Energy |
| Kwanza | 5 | 4 | 80% | TotalEnergies, Equinor, ExxonMobil |
| Total | 12 | 11 | 92% |
Round 4 Assessment: The 92% award rate across a mixed portfolio of mature and frontier blocks was ANPG’s strongest signal yet that the licensing programme is generating meaningful industry engagement. The award of four Kwanza Basin blocks indicates growing confidence in Angola’s pre-salt potential, likely influenced by positive drilling results in analogous geological settings in Namibia and Brazil.
Round 5 — 2025 (Limited Public Tender, Kwanza and Benguela)
The 2025 limited public tender offers up to 10 offshore blocks in the Kwanza and Benguela basins. This round is specifically designed to advance pre-salt exploration in the underexplored southern portion of Angola’s offshore acreage.
| Parameter | Detail |
|---|---|
| Blocks Offered | Up to 10 |
| Basins | Kwanza, Benguela |
| Primary Target | Pre-salt carbonates and lacustrine reservoirs |
| Bidding Format | Limited public tender (pre-qualified bidders) |
| Status (March 2026) | Bidding open; results pending |
| Anticipated Work Programmes | Mandatory 3D seismic; optional exploration drilling |
Cumulative Programme Statistics
| Metric | Running Total (as of March 2026) |
|---|---|
| Total Blocks Offered | 46 of 50 planned |
| Total Blocks Awarded | 33 |
| Overall Award Rate | 72% |
| Blocks Without Bids | 7 (primarily Namibe frontier) |
| Blocks Pending (Round 5) | Up to 10 |
| Remaining Programme Blocks | ~4 (Etosha, Okavango, Kassange) |
| Cumulative Signature Bonuses | Est. USD 800M–1.2B |
| Committed Exploration Investment | Est. USD 4–6B in work programmes |
Current Concession Portfolio
Beyond the new licensing rounds, Angola maintains a portfolio of over 40 concessions in various stages of activity.
| Concession Status | Number | Key Characteristics |
|---|---|---|
| In Production | 6 | Mature fields; declining base production |
| Under Exploration | 27 | Mix of legacy and newly awarded blocks |
| Under Development | 4 | Begonia, Agogo IWH, Ndungu, Quiluma |
| Under Negotiation | 7 | Contract renegotiations or extensions |
| Total | 44+ |
The USD 60 Billion Investment Target
ANPG projects over USD 60 billion in new upstream investment over the next five years, a figure that includes both committed work programmes from licensing rounds and anticipated development expenditure on discovered resources. Achieving this target would represent a dramatic step-change from historical investment levels.
| Period | Annual Upstream Investment (est.) | Cumulative 5-Year Total |
|---|---|---|
| 2015–2020 (Actual) | USD 4.5B/yr average | USD 27B |
| 2021–2025 (Estimated Actual) | USD 5.5B/yr average | USD 27.5B |
| 2026–2030 (ANPG Target) | USD 12B/yr average | USD 60B |
The gap between the USD 5.5 billion annual average of recent years and the USD 12 billion target is substantial. Bridging it requires not only successful licensing rounds but also the conversion of exploration success into development sanctioning decisions — a process that typically takes 5–8 years from discovery to first oil in deepwater Angola.
Fiscal Terms and Competitiveness
ANPG’s ability to attract the targeted investment depends critically on the competitiveness of Angola’s fiscal terms relative to other deepwater provinces. The November 2024 incremental production decree was specifically designed to improve economics for mature-field reinvestment, but the broader fiscal framework governing new exploration blocks remains a key factor.
| Fiscal Parameter | Angola (Typical PSA) | Guyana (Stabroek PSA) | Brazil (Pre-Salt Regime) | Namibia (Emerging Terms) |
|---|---|---|---|---|
| Government Take | 65–75% | 52–58% | 70–80% | 55–65% (estimated) |
| Cost Recovery Limit | 50–65% of revenue | 75% of revenue | N/A (concession) | 60–70% (estimated) |
| Signature Bonus | USD 10M–100M+ | Minimal | Variable by round | Moderate |
| Royalty Rate | 15–20% | 2% | 15% (sliding scale) | 5% (estimated) |
| Corporate Tax | 25–50% (progressive) | 25% | 34% | 35% |
| Breakeven (Deepwater) | ~USD 40/bbl | ~USD 30–35/bbl | ~USD 35–40/bbl | USD 35–45/bbl (est.) |
Angola’s deepwater breakeven of approximately USD 40 per barrel compares unfavourably with Guyana’s USD 30–35 per barrel but is broadly competitive with Brazil’s pre-salt and the emerging Namibian plays. The government take of 65–75% is at the higher end of the global spectrum, which partly explains why Angola has struggled to attract the same pace of exploration investment as lower-tax jurisdictions.
Open Blocks and Upcoming Opportunities
For operators evaluating entry into Angola, the following blocks are currently available or expected to be offered in upcoming rounds.
| Block / Area | Basin | Status | Water Depth | Key Attraction |
|---|---|---|---|---|
| KWZ-3 (re-offered) | Kwanza | Open | 2,000–3,000 m | Pre-salt; adjacent to Cameia discovery |
| NAM-1, 2, 4, 6 | Namibe | Open | 500–2,800 m | Frontier; Namibia analogue potential |
| BEN-1 through BEN-6 | Benguela | Round 5 tender | 300–2,000 m | Emerging pre-salt fairway |
| Etosha blocks | Etosha | Future offering | Onshore | Conventional clastic potential |
| Okavango blocks | Okavango | Future offering | Onshore | Frontier; limited data |
Challenges and Risks
Despite the programme’s ambitious scope, several risks could prevent ANPG from achieving its objectives.
Exploration Risk in Frontier Basins. The Kwanza, Namibe, and Benguela basins remain geologically unproven at commercial scale. The Cobalt International pre-salt wells of 2012–2015 encountered hydrocarbons but failed to establish commercial flow rates, and no pre-salt development project has been sanctioned in Angola.
Fiscal Competitiveness. Angola’s government take remains high relative to competing jurisdictions. While the incremental production decree addresses mature-field economics, new exploration blocks are governed by standard PSA terms that may deter capital that could flow to lower-tax alternatives.
Infrastructure Deficit. Frontier basins lack the pipeline, processing, and FPSO infrastructure that reduces development costs in the mature Lower Congo Basin. Any commercial discovery in the Namibe or Benguela basins would require standalone development infrastructure, significantly increasing breakeven costs.
Geopolitical and Regulatory Continuity. The success of the licensing programme depends on ANPG maintaining regulatory credibility and contract sanctity over multi-decade concession periods. Any perceived instability in the regulatory framework could deter the long-cycle investment that deepwater exploration requires.
Data Management and Transparency Initiatives
ANPG has invested significantly in modernising its data management and transparency practices as part of the licensing programme. The agency has established a national petroleum data repository containing seismic surveys, well logs, core data, and production records from over four decades of upstream activity. This data is made available to prospective bidders during licensing rounds, reducing exploration risk and improving the quality of bid submissions.
In parallel, ANPG has adopted digital bidding platforms that allow international operators to submit licence applications, work programme commitments, and financial guarantees electronically. These platforms have reduced the administrative burden of participation and shortened the time between bid submission and award announcement from 12–18 months (under the Sonangol-administered system) to 6–9 months under ANPG.
The agency’s commitment to transparency extends to post-award disclosure. Block award summaries, including the identity of successful bidders, the outline of committed work programmes, and the estimated signature bonus ranges, are published on ANPG’s official communications channels. This level of disclosure, while still less comprehensive than Norway’s or Brazil’s fully transparent licence systems, represents a significant improvement over the opaque award processes of the pre-2019 era and has been positively received by the international investment community.
Related Analysis
- Deepwater Exploration Blocks — technical overview of Angola’s offshore acreage
- Pre-Salt Basin Potential — Kwanza Basin geology and Brazil comparisons
- Production Sharing Agreements — fiscal terms governing operator returns
- Production Data Analysis — the decline curve driving the licensing urgency
- Cost of Supply Analysis — breakeven economics across competing provinces
- Drilling Campaigns 2026 — exploration wells targeting newly awarded blocks
- Reserves Assessment — resource base underpinning investment projections
- Regulators & ANPG — institutional overview of Angola’s upstream regulator
- Company Profiles — operator strategies in Angola
- Financial Overview — investment flows and fiscal revenue analysis