Angola Drilling Campaigns 2026 — Active Rigs, Spud Count, Well Results & Exploration Success Rate
Angola Drilling Campaigns 2026 — Active Rigs, Spud Count, Well Results & Exploration Success Rate
The 2026 drilling season in Angola represents the most active exploration and development programme the country has mounted since the pre-2014 oil-price era. Driven by ANPG’s licensing programme, the incremental production decree, and improved operator confidence following successful Begonia and Agogo IWH commissioning, the number of active rigs and planned well spuds has increased materially relative to the 2020–2024 trough. This analysis provides a comprehensive tracker of Angola’s 2026 drilling activity, cataloguing every active rig, planned and completed well spuds, results where available, and historical success rates that provide context for expectations.
Rig Fleet Overview — Q1 2026
Angola’s active rig count has recovered from its pandemic-era nadir but remains well below the peak levels of 2012–2014, when up to 18 deepwater rigs operated simultaneously in Angolan waters. The current fleet comprises a mix of 6th and 7th generation ultra-deepwater drillships and semi-submersibles, supplemented by jack-up rigs for shallow-water operations on Block 0.
| Rig Name | Type | Generation | Water Depth Rating (m) | Operator / Client | Block Assignment | Contract Duration |
|---|---|---|---|---|---|---|
| Maersk Voyager | Drillship | 7th Gen | 3,600 | TotalEnergies | Block 17/06, Block 32 | Q1 2025 – Q4 2026 |
| Saipem 12000 | Drillship | 6th Gen | 3,650 | Azule Energy | Block 15/06 | Q2 2025 – Q2 2027 |
| Valaris DS-17 | Drillship | 7th Gen | 3,650 | Chevron | Block 14, Block 2 | Q3 2025 – Q3 2026 |
| Noble Globetrotter II | Drillship | 6th Gen | 3,050 | ExxonMobil | Block 15 | Q1 2026 – Q1 2027 |
| Transocean Endurance | Semi-sub | 6th Gen | 3,000 | TotalEnergies | Kwanza Basin (KWZ blocks) | Q1 2026 – Q4 2026 |
| Borr Drilling Norve | Jack-up | Modern | 120 | Chevron (CABGOC) | Block 0 | Ongoing |
| COSL Prospector | Semi-sub | 5th Gen | 2,300 | Sonangol | Block 3/05A | Q2 2026 – Q4 2026 |
| Seadrill Sonangol Libongos | Drillship | 7th Gen | 3,650 | Sonangol / Azule | Block 31, Block 18 | Q1 2026 – Q2 2027 |
| Diamond Offshore Courage | Semi-sub | 6th Gen | 2,400 | Equinor | Block 17/06 (partner ops) | Q2 2026 – Q4 2026 |
Total Active Rigs: 9 (7 deepwater/ultra-deepwater + 1 jack-up + 1 intermediate)
The 9-rig fleet represents a 50% increase over the 6 rigs active in 2024 and signals a meaningful recovery in drilling activity. However, it remains less than half the peak fleet size, reflecting both global rig market tightness (deepwater drillship day rates have risen above USD 450,000/day) and Angola’s competition with Guyana, Brazil, and Namibia for available rigs.
Rig Day Rates and Drilling Cost Trends
| Rig Category | 2020 Day Rate (USD) | 2022 Day Rate (USD) | 2024 Day Rate (USD) | 2026 Day Rate (USD) | Trend |
|---|---|---|---|---|---|
| 7th Gen Drillship | 180,000–220,000 | 280,000–350,000 | 380,000–450,000 | 450,000–520,000 | Rising (tight market) |
| 6th Gen Drillship | 150,000–200,000 | 250,000–300,000 | 320,000–380,000 | 380,000–440,000 | Rising |
| 6th Gen Semi-sub | 130,000–180,000 | 220,000–280,000 | 280,000–350,000 | 340,000–400,000 | Rising |
| Jack-up (Shallow) | 60,000–90,000 | 90,000–120,000 | 120,000–160,000 | 140,000–180,000 | Moderate increase |
The escalation in rig day rates significantly impacts per-well drilling costs. A typical ultra-deepwater exploration well in Angola, requiring 60–90 days of rig time plus completion and evaluation costs, now runs USD 100–180 million — roughly double the 2020 cost for equivalent operations.
2026 Exploration Well Programme
The following table tracks all exploration wells planned or in progress during 2026 across Angola’s offshore basins.
| Well Name | Block | Basin | Operator | Target | Water Depth (m) | Planned TD (m) | Spud Date | Status (March 2026) |
|---|---|---|---|---|---|---|---|---|
| Canela-1X | Block 17/06 | Lower Congo | TotalEnergies | Post-salt turbidite | 1,800 | 4,500 | Jan 2026 | Drilling (reached intermediate casing) |
| Mavinga-2 | KWZ-1 | Kwanza | TotalEnergies | Pre-salt carbonate | 2,400 | 6,200 | Feb 2026 | Drilling (salt section) |
| Golfinho-1X | Block 15 | Lower Congo | ExxonMobil | Post-salt turbidite | 1,200 | 4,200 | Mar 2026 | Spudded; top-hole phase |
| Kuito-East-1X | Block 14 | Lower Congo | Chevron | Post-salt clastic | 800 | 3,800 | Apr 2026 (planned) | Pre-drill preparation |
| Orion-1X | KWZ-5 | Kwanza | Equinor | Pre-salt carbonate | 2,600 | 6,500 | Q2 2026 (planned) | Permit approved; rig mobilising |
| Ngoma-1X | Block 32 | Lower Congo | TotalEnergies | Post-salt / pre-salt | 2,100 | 5,500 | Q2 2026 (planned) | Seismic interpretation complete |
| Cameia-2 (Appraisal) | KWZ-2 | Kwanza | TotalEnergies | Pre-salt carbonate | 1,900 | 5,900 | Q3 2026 (planned) | Appraisal of 2012 discovery |
| Lebre-1X | Block 31 | Lower Congo | Azule Energy | Ultra-deep post-salt | 2,200 | 5,200 | Q3 2026 (planned) | Environmental impact approved |
| Sable-1X | BEN-2 | Benguela | TotalEnergies | Pre-salt / transitional | 1,400 | 5,000 | Q4 2026 (planned) | First Benguela Basin test |
| CON-7-1X | CON-7 | Lower Congo | TotalEnergies | Post-salt channel system | 900 | 3,900 | Q4 2026 (planned) | Mandatory work programme well |
Total 2026 Exploration Wells: 10 planned (2 in progress, 1 spudded, 7 planned)
The 10-well exploration programme represents a significant acceleration from the 6 exploration wells drilled in 2024. Notably, three wells target the pre-salt section in the Kwanza Basin — Mavinga-2, Orion-1X, and Cameia-2 — making 2026 the most active year for pre-salt exploration since Cobalt International’s 2012–2015 campaign.
2026 Development Well Programme
Development drilling — infill wells, production wells, and injection wells — constitutes the bulk of drilling activity and directly impacts near-term production.
| Block | Operator | Development Wells Planned (2026) | Well Types | Target Incremental Production (bpd) |
|---|---|---|---|---|
| Block 17 | TotalEnergies | 8 | 5 producers, 3 injectors | ~30,000 |
| Block 15 | ExxonMobil | 4 | 3 producers, 1 injector | ~15,000 |
| Block 15/06 | Azule Energy | 6 | 4 producers, 2 injectors | ~25,000 |
| Block 14 | Chevron | 3 | 2 producers, 1 injector | ~10,000 |
| Block 32 | TotalEnergies | 4 | 3 producers, 1 injector | ~15,000 |
| Block 31 | Azule Energy | 3 | 2 producers, 1 injector | ~10,000 |
| Block 18 | Azule Energy | 2 | 1 producer, 1 injector | ~5,000 |
| Block 0 | Chevron (CABGOC) | 6 | 4 producers, 2 injectors | ~8,000 |
| Block 3/05A | Sonangol | 3 | 2 producers, 1 injector | ~6,000 |
| Total | 39 | 26 producers, 13 injectors | ~124,000 |
The 39 development wells represent a combined investment of approximately USD 2.5–3.0 billion and are expected to deliver roughly 124,000 bpd of incremental production. Combined with the 10 exploration wells, Angola’s total 2026 spud count of 49 wells is the highest in over a decade.
Historical Exploration Success Rates
Angola’s exploration track record provides important context for evaluating the likely outcomes of the 2026 programme.
| Period | Exploration Wells Drilled | Discoveries | Commercial Discoveries | Technical Success Rate | Commercial Success Rate |
|---|---|---|---|---|---|
| 1996–2000 | 42 | 28 | 18 | 67% | 43% |
| 2001–2005 | 55 | 35 | 22 | 64% | 40% |
| 2006–2010 | 48 | 25 | 14 | 52% | 29% |
| 2011–2015 | 35 | 15 | 6 | 43% | 17% |
| 2016–2020 | 18 | 8 | 4 | 44% | 22% |
| 2021–2025 | 32 | 14 | 7 | 44% | 22% |
| Cumulative | 230 | 125 | 71 | 54% | 31% |
The data reveals a declining success rate over time, which is characteristic of a maturing exploration province where the largest and most obvious prospects have been drilled. The 1996–2005 period, which captured the giant turbidite discoveries on Blocks 15, 17, and 18, achieved commercial success rates above 40%. The post-2010 period, focused on smaller targets and emerging pre-salt plays, has averaged a commercial success rate of approximately 20%.
For the 2026 programme, a reasonable expectation is that 4–5 of the 10 exploration wells will encounter hydrocarbons (technical success), while 2–3 may prove commercial. The pre-salt wells carry higher individual risk but also higher potential reward given the large structural targets available in the Kwanza Basin.
Success Rate by Basin and Play Type
| Basin / Play | Wells Drilled (All Time) | Commercial Success Rate | Average Discovery Size (MMbbl) | Largest Discovery |
|---|---|---|---|---|
| Lower Congo (Post-Salt Turbidite) | 150+ | 35% | 250 | Girassol (~1B bbl OOIP) |
| Lower Congo (Pre-Salt) | 10 | 10% | Unknown (no commercial) | Lontra (subcommercial) |
| Kwanza (Pre-Salt) | ~15 | 0% (no commercial yet) | N/A | Cameia (200m pay; subcommercial) |
| Block 15/06 (Deep Post-Salt) | 15 | 40% | 350 | Agogo (~2B bbl OOIP) |
| Shallow Water (Post-Salt Clastic) | 40+ | 45% | 80 | Takula (~600M bbl OOIP) |
Well Duration and Performance Metrics
| Well Type | Average Duration (days) | Average Cost (USD M) | Success Criteria |
|---|---|---|---|
| Deepwater Exploration (Post-Salt) | 60–90 | 100–150 | Hydrocarbon encounter; flow test >2,000 bpd |
| Ultra-Deepwater Exploration (Pre-Salt) | 90–150 | 150–250 | Hydrocarbon encounter; reservoir quality confirmation |
| Deepwater Development (Producer) | 45–70 | 60–90 | Connected to production; >5,000 bpd initial rate |
| Deepwater Development (Injector) | 40–60 | 50–75 | Injection rate >10,000 bwpd |
| Shallow Water Development | 20–35 | 15–30 | Production contribution; well integrity |
Drilling Technology Advances
Several technological advances are being deployed in Angola’s 2026 drilling campaigns.
Managed Pressure Drilling (MPD). MPD technology, which allows precise control of downhole pressure during drilling, is being used on pre-salt wells in the Kwanza Basin to manage the narrow pore-pressure/fracture-gradient window characteristic of sub-salt formations. MPD reduces the risk of lost circulation and wellbore instability — the two most common causes of deepwater well cost overruns.
Rotary Steerable Systems (RSS). All deepwater wells in the 2026 programme employ rotary steerable bottomhole assemblies, enabling the drilling of complex well trajectories (S-profiles, extended-reach laterals, multilaterals) from a single surface location. RSS technology is particularly important for infill drilling, where new wells must navigate around existing completions.
Real-Time Geosteering. Logging-while-drilling (LWD) tools with real-time data transmission allow geologists and drilling engineers to adjust well trajectories during drilling to maximise reservoir exposure. This technology has improved the productivity of development wells by 15–25% relative to conventionally steered wells.
Casing-While-Drilling (CwD). For sections prone to wellbore instability — particularly the shallow sub-salt zone — casing-while-drilling technology eliminates the open-hole exposure time between drilling and running casing, reducing the risk of hole collapse and stuck pipe.
Operator Drilling Strategies — 2026
TotalEnergies is running the largest drilling programme in Angola, with two rigs (Maersk Voyager and Transocean Endurance) committed through year-end. The programme balances development drilling on Block 17 and Block 32 with high-impact exploration on Block 17/06 and in the Kwanza Basin. TotalEnergies’ pre-salt exploration effort is particularly significant, as the company’s success in the Santos Basin and Namibia’s Orange Basin positions it as the most experienced pre-salt operator active in Angola.
Azule Energy (the BP/Eni joint venture) is focused on Block 15/06 development drilling around the Agogo hub and exploration targets on Block 31. The Saipem 12000 drillship is dedicated to Block 15/06 through 2027, enabling a continuous drilling programme that should sustain Agogo production through the plateau phase.
Chevron continues its long-standing presence on Blocks 0 and 14, with the Valaris DS-17 conducting deepwater operations and the Borr Norve jack-up handling shallow-water work on Block 0. Chevron’s programme emphasises development drilling and infill opportunities rather than frontier exploration.
ExxonMobil has returned a rig to Angola after a multi-year hiatus, with the Noble Globetrotter II targeting both development infill on Block 15 and the Golfinho-1X exploration prospect. This represents renewed commitment to the Angola portfolio following a period of capital reallocation toward Guyana and the US Permian Basin.
Sonangol is deploying the COSL Prospector on its operated acreage, focusing on development and workover activity at Block 3/05A. The programme is modest relative to the IOCs but represents continued investment in Sonangol’s operated portfolio.
Supply Chain and Logistics Considerations for 2026 Drilling
The scale of the 2026 drilling campaign places significant demands on Angola’s supply chain and logistics infrastructure. Key bottlenecks include mud and cement supply, casing and tubing inventories, and marine vessel availability for rig moves and subsea installation support.
Rig Mobilisation. Three of the nine active rigs in 2026 were mobilised from outside Angola — the Transocean Endurance from the Gulf of Mexico, the Diamond Offshore Courage from West Africa (Nigeria), and the Noble Globetrotter II from Brazil. Mobilisation costs typically range from USD 15–25 million per rig, including transit, customs clearance, and regulatory inspection, adding to the overall cost of the drilling programme.
Drill Pipe and Casing. The 49-well programme requires approximately 150,000 metres of drill pipe and 200,000 metres of casing string, representing a procurement value of approximately USD 250–350 million. Lead times for specialised high-grade casing (required for HPHT pre-salt wells) extend to 9–12 months, requiring forward planning that began in 2025.
Drilling Fluids and Completion Chemicals. Deepwater wells consume 2,000–4,000 barrels of synthetic-based drilling fluid per well, with the total 2026 programme requiring approximately 120,000–200,000 barrels of mud. Local blending capacity at the Sonils Base has been expanded to support the increased demand, but speciality additives for pre-salt wells (including high-temperature polymer systems) must be imported.
Marine Vessel Requirements. Each active drilling rig requires 2–3 dedicated platform supply vessels (PSVs) and periodic access to anchor-handling tug supply vessels (AHTS) for rig positioning. The 9-rig campaign requires approximately 20–25 PSVs on charter, straining the available fleet in West African waters and driving day rates to USD 25,000–35,000 for modern PSVs.
Safety and Environmental Performance
Angola’s deepwater drilling operations maintain safety standards aligned with International Association of Drilling Contractors (IADC) reporting protocols. Key performance metrics for the 2025 drilling campaign (the most recent full-year data) provide a baseline for 2026 expectations.
| Safety Metric | Angola 2025 | Global Deepwater Average | Target |
|---|---|---|---|
| Total Recordable Incident Rate (TRIR) | 0.45 | 0.52 | <0.40 |
| Lost Time Incident Frequency (LTIF) | 0.12 | 0.15 | <0.10 |
| Non-Productive Time (% of total rig days) | 8.5% | 9.2% | <7.0% |
| Well Control Events (Level 1+) | 1 | N/A | 0 |
| Environmental Spills (>1 bbl) | 2 | N/A | 0 |
The safety data indicates that Angola’s drilling operations perform slightly better than the global deepwater average on TRIR and LTIF metrics, reflecting the maturity of the operator base and the established safety management systems. The non-productive time rate of 8.5% — representing approximately 1,400 rig days lost across all operations — is an area for improvement, as each lost rig day at current day rates costs USD 400,000–520,000.
Related Analysis
- Production Data Analysis — how drilling activity translates to output
- Deepwater Exploration Blocks — the acreage being drilled
- Pre-Salt Basin Potential — geological targets for Kwanza Basin wells
- ANPG Licensing Rounds — mandatory work programmes driving drilling
- Marginal Fields Programme — infill drilling and EOR campaigns
- Field Development Plans — development wells tied to approved FDPs
- Cost of Supply Analysis — drilling cost impact on breakeven
- Reserves Assessment — resource additions from exploration success
- Company Profiles — operator strategies and drilling commitments
- Data & Statistics — well count and rig utilisation datasets