Angola Power Industry Report,  2026 Outlook

Angola Power Industry Report,  2026 Outlook

Prepared: August 2026
Scope: Electricity generation, demand, supply constraints, energy resources, utilization, IPP/private investment, sector ownership and recommendations.

Angola presents an unusual power-sector situation: the country does not primarily suffer from a shortage of installed generation capacity. It suffers from insufficient transmission and distribution infrastructure, low electricity access, high network/commercial losses, weak utility finances, and large geographic mismatches between generation and demand. Angola has built several very large power plants, especially hydropower, but a substantial portion of their potential cannot yet be efficiently delivered and monetized.

The latest internationally comparable full-year dataset is for 2023, while this report incorporates project and sector developments through mid-2026.

Executive summary

Indicator	Latest useful figure	Assessment
National installed generating capacity	~7.6 GW in 2023	Large relative to presently served demand
Electricity generation	17.9 TWh in 2023	74% hydro
Electricity consumption / served demand	~16.2 TWh in 2023	Much lower than potential national demand
Average delivered load	~1.85 GW	Derived from annual consumption
Electricity access	~49% in 2022	Major latent/unserved demand
Urban electricity access	~76%	Relatively high
Rural electricity access	~7% in latest cited rural estimate	Extremely low
Hydro share of 2023 generation	74% / 13.3 TWh	Dominant
Natural-gas generation	9% / 1.7 TWh	Underdeveloped relative to resource base
Oil/other petroleum generation	14% / 2.6 TWh	Expensive, especially isolated diesel systems
Other renewables	~2% / 0.4 TWh	Solar is expanding rapidly from a low base
Approx. fleet-wide generation utilization	~27%	Low, mainly because capacity exceeds grid capability/served demand
Aggregate technical + commercial losses	>30% in recent World Bank assessment	Major structural problem
Collection rate	~60%	Major utility-finance problem
PRODEL share of generation assets	>95% according to PRODEL	Public sector overwhelmingly dominant
T&D operators	RNT and ENDE, state-owned	Public sector dominant
Major capacity under construction	Caculo Cabaça 2,172 MW	First unit expected around mid-2027
Major private solar investment	Quilemba: ~$40m, 35 MW first stage	Important IPP/private-sector precedent

The U.S. EIA reports that Angola had 7.6 GW of generation capacity and produced 17.9 TWh in 2023. Its generation mix was approximately 13.3 TWh hydro, 2.6 TWh petroleum products, 1.7 TWh natural gas and 0.4 TWh other renewables.

1. Total electricity generation

1.1 Installed generation capacity

The most recent comprehensive international figure places Angola’s installed electricity-generation capacity at approximately 7.6 GW in 2023. There are differences among published figures because sources refer to different years and sometimes count only assets belonging to the public electricity system or PRODEL. For example, PRODEL currently displays an installed-capacity figure of 6,249.51 MW on its transition page, whereas the EIA’s national figure includes the wider country generating fleet. (Prodel) This difference is important: installed national capacity, PRODEL-owned capacity and actually available/dispatchable capacity should not be treated as the same number.

Electricity actually produced in 2023

Source	Generation	Share
Hydroelectricity	13.3 TWh	74%
Petroleum/oil products	2.6 TWh	14%
Natural gas	1.7 TWh	9%
Renewables other than large hydro	0.4 TWh	2%
Coal/nuclear	~0	~0
Total	17.9 TWh	100%

Source: U.S. EIA International Energy Statistics.

Thus Angola already has a comparatively clean electricity mix from the carbon perspective because approximately three-quarters of grid generation comes from hydropower.

1.2 Major power stations

Laúca hydroelectric plant: Laúca is Angola’s largest operating hydroelectric station, with capacity of a little over 2 GW. It is one of the country’s principal sources of low-cost electricity and fundamentally changed the generation balance toward hydropower.

Cambambe: Expansion of the Cambambe hydro complex added approximately 700 MW, and PRODEL reports that the growth of hydroelectric capacity since 2016 played a major role in reducing thermal generation’s share. (Prodel)

Soyo combined-cycle plant: Soyo provides approximately 750 MW of gas-fired generation capacity. Gas generation is strategically important because it provides dispatchable power to complement hydro and future solar generation.

Caculo Cabaça – under construction: This is currently Angola’s most important generation expansion project. The plant will have:

• 2,172 MW total capacity;
• four main generating units of 530 MW each;
• one ecological unit of 52 MW;
• projected annual output historically estimated at around 8.6 TWh;
• first generation currently expected around mid-2027.

By June 2026, the Angolan government reported that physical construction had exceeded 50%. (Ciam) Once completed, Caculo Cabaça alone could increase Angola’s present annual electricity output very substantially, provided transmission networks and demand develop alongside it.

2. Total electricity demand

Demand needs to be considered in two different ways in Angola: served/grid demand is electricity currently consumed by connected customers, while economic or latent demand includes millions of people, businesses and industrial projects that currently have no grid connection or an unreliable connection.

2.1 Served electricity demand

Electricity consumption in 2023 was approximately 16.214 TWh. Transmission and distribution losses were reported at approximately 1.725 TWh, broadly reconciling consumption with total generation of roughly 17.9 TWh. (The World Factbook) An annual consumption of 16.214 TWh corresponds to an average served load of approximately:

16.214 TWh ÷ 8,760 hours ≈ 1.85 GW

That figure should not be confused with peak demand. In October 2022, Southern African regional data reported:

• installed capacity: 6,019.7 MW
• operating capacity: 4,947 MW
• peak demand: 2,186 MW

for Angola. (SACREEE Community) The crucial observation is therefore that available generation capacity has historically been substantially higher than measured peak demand.

2.2 Angola’s hidden or unserved demand

Only about 49% of Angolans had electricity access in 2022. Urban access was around 76%, whereas the latest rural estimate quoted by EIA was only about 7%.

Consequently, the current ~16 TWh consumption figure severely understates how much electricity Angola could use if:

• rural communities were connected;
• provincial grids were expanded;
• mines and industrial projects received dependable electricity;
• households shifted from diesel, biomass and informal electricity sources to the grid;
• commercial customers had reliable 24-hour supply.

Angola therefore simultaneously has generation surplus in some grid areas and severe electricity scarcity among the population.

2.3 Earlier demand forecasts illustrate the gap

The SAPP/RNT planning forecast once expected 2025 peak demand of approximately:

Region	Forecast 2025 peak
North	3,144 MW
Central	1,405 MW
South	845 MW
Total	5,394 MW

Forecast energy demand was approximately 52.6 TWh. (SAPP)

Actual demand has developed much more slowly because network expansion and electrification did not occur as rapidly as envisioned. The difference between those projections and present consumption illustrates how strongly grid infrastructure and customer connections have constrained demand growth.

3. Reasons for power shortfalls and unreliable electricity

The central issue in Angola is therefore not simply “too little generation.”

Transmission bottlenecks: Historically Angola operated several geographically separated systems rather than one fully integrated national grid. Large generating stations are concentrated mainly around specific river basins and the northern system, while many areas requiring electricity are distant from them. This can produce a situation in which a power station has spare generating capacity but customers elsewhere still experience shortages. The World Bank has noted that Angola’s transmission system historically consisted of separate northern, central and southern systems and that distribution coverage was largely concentrated around provincial capitals. (World Bank)

Distribution-network weakness: Adding another 2 GW generating station does not automatically electrify households. The last several stages remain underdeveloped in much of Angola.

Very high technical and commercial losses: A recent World Bank assessment states that aggregate technical and commercial losses have remained above 30%. (World Bank) Losses arise from:

• overloaded and aging distribution equipment;
• long or poorly configured networks;
• transformer and conductor losses;
• unmetered connections;
• electricity theft;
• inaccurate billing;
• damaged meters;
• billing/database weaknesses.

A previous World Bank project baseline was even higher, around 39% system losses, with a target to reduce them to 29%. (World Bank)

Low bill collection: The World Bank estimates the electricity collection rate at around 60%. (World Bank) That means a material portion of electricity billed does not convert into cash. This prevents ENDE, RNT and PRODEL from independently financing maintenance and expansion.

Tariffs below cost: One of the most important structural problems is electricity pricing. The World Bank reported an average end-user tariff of approximately 12.8 kwanza/kWh, about US1.5 cents/kWh, versus an estimated cost-recovery tariff of roughly US7.8 cents/kWh. (World Bank) Low tariffs help consumers in the short term but create a financial cycle in which utilities:

1. sell electricity below economic cost,
2. experience cash deficits,
3. defer maintenance,
4. depend on state transfers,
5. cannot fund grid expansion,
6. become less attractive counterparties for IPPs.

The World Bank estimated the utilities’ operating cash shortfall at about US$220 million in 2022. (World Bank)

Diesel dependence in isolated systems: Areas disconnected from major hydro generation have traditionally depended on diesel generation. Diesel electricity is:

• substantially more expensive than hydro;
• exposed to fuel logistics;
• vulnerable to international fuel-price movements;
• maintenance intensive;
• less environmentally sustainable.

Solar-plus-storage and grid extensions can progressively displace these generators.

Maintenance and plant availability: Angola’s older thermal generators do not operate at their nameplate capacity continuously. Planned maintenance, failures, fuel availability and spare-parts requirements reduce dependable capacity. This partly explains why historical studies report substantial differences between installed MW and operating MW.

Hydrological variability: Heavy dependence on hydro exposes Angola to:

• drought;
• changes in rainfall;
• reservoir inflows;
• seasonal river flows;
• longer-term climate variability.

Angola’s hydro system on the Kwanza is significant, but relying excessively on a single resource and river system creates concentration risk.

Lack of regional power trading

Angola belongs to the Southern African Power Pool but has not historically been physically integrated as a fully operating interconnected member. The World Bank recently described Angola as the only SAPP country without firm interconnection projects as an operating member at that point. (World Bank) Interconnection would allow Angola eventually to:

export surplus hydro power when available and import electricity during droughts, maintenance periods or regional imbalances.

4. Energy resources available in Angola

Angola has one of the most diversified energy-resource bases in sub-Saharan Africa.

Hydropower: Hydropower is Angola’s strongest power-generation resource. SACREEE estimates identified hydroelectric potential of approximately 18 GW. (SACREEE Community) Major river systems include:

• Kwanza;
• Queve;
• Catumbela;
• Cunene;
• Cubango and tributaries.

Existing large hydro development demonstrates that the resource is technically viable.

Current utilization: With ~13.3 TWh of hydro generation in 2023, hydro already dominates the power mix. However, considerable undeveloped potential remains.

Solar power: Angola has excellent irradiation in large areas, particularly the south. SACREEE identifies approximately 16.3 GW of solar potential. (SACREEE Community) Solar is particularly attractive for:

• southern Angola;
• remote towns;
• rural mini-grids;
• mines;
• telecommunications;
• water pumping;
• commercial and industrial facilities;
• diesel displacement.

Utility-scale solar has started to become material, but it remains very small compared with the theoretical resource.

Wind: Estimated wind potential is around 3.9 GW, according to SACREEE. (SACREEE Community) Potential locations include coastal and selected elevated areas. Wind has received far less development than hydro or solar and should be preceded by detailed multi-year resource measurements.

Natural gas: Angola has historically produced substantial associated gas from offshore oil operations. Natural gas offers an opportunity for:

• combined-cycle generation;
• industrial heat;
• fertilizer;
• petrochemicals;
• balancing intermittent renewables.

An important recent development occurred in March 2026, when production started from the Quiluma field under the New Gas Consortium, the country’s first non-associated gas development. Production is expected to reach approximately 330 million cubic feet/day at plateau. (TotalEnergies.com)

Although much of the gas supports Angola LNG exports, increasing domestic gas availability strengthens the possibility of reducing diesel consumption and supporting gas-fired electricity.

Petroleum: Angola remains one of Africa’s major petroleum producers and held approximately 2.6 billion barrels of proved crude reserves at the beginning of 2025. Oil therefore provides strong energy security in the physical-resource sense. However, burning refined petroleum for electricity is generally economically inefficient compared with using:

• hydro;
• gas;
• solar;
• wind.

Oil products should increasingly serve as emergency/backup rather than the principal source for remote generation.

Biomass: Potential resources include:

• agricultural residues;
• forestry waste;
• municipal waste;
• sugar-industry residues;
• other organic waste.

The original renewable-energy strategy envisioned substantial biomass development, although actual deployment has lagged solar and hydro planning.

5. Utilization of Angola’s generation assets

Installed generation does not mean electricity actually generated. Using the EIA figures:

Installed capacity = 7.6 GW

Maximum theoretical annual production: 7.6 GW × 8,760 hours = 66.6 TWh/year

Actual generation: 17.9 TWh

Approximate whole-fleet utilization or aggregate capacity factor: 17.9 ÷ 66.6 ≈ 26.9%

So on a simplified national basis, Angola utilized only around 27% of the theoretical energy capability of its installed power fleet in 2023. This figure should not be interpreted to mean that 73% of plants were “broken.” Hydro plants are not expected to operate at 100% capacity continuously, solar output varies with sunlight, plants require reserves and maintenance, and demand fluctuates. Nevertheless, the number is a useful indication that generation capacity is currently very large relative to electricity actually consumed through the system. This is one of the most important conclusions of the report.

6. Why utilization is low

The low utilization rate is principally explained by a combination of the following factors.

Grid capacity has not expanded as quickly as generation: Angola invested heavily in large generating stations before completing all the transmission and distribution infrastructure required to use their output.

Electricity access remains below 50%: Nearly half the population is still effectively outside formal electricity service, meaning capacity exists without corresponding connected demand.

Distribution losses reduce useful output: If more than 30% of power entering parts of the system is technically or commercially lost, additional generation does not translate proportionally into paying consumption. (World Bank)

Low industrial electricity demand

Angola’s economy remains heavily dependent on petroleum extraction. Manufacturing and other electricity-intensive industrial demand are smaller than would be expected for a country with this level of power capacity. Developing:

• mining;
• steel;
• cement;
• fertilizer;
• refining;
• agro-processing;
• cold chains;
• data centres;

could significantly improve power-system utilization.

Regional imbalance: The generating resource and the electrical load are not always in the same part of the country.

Financial constraints: Utilities cannot easily finance the distribution expansion needed to convert power capacity into paying customers.

Limited regional exports: Angola cannot yet fully monetize excess capacity by selling large volumes into SAPP markets.

7. IPP investments in Angola

What is an IPP?

An Independent Power Producer (IPP) is a company other than the traditional state utility that:

1. finances or raises finance for a power station;
2. constructs it;
3. owns and/or operates it;
4. sells electricity through a long-term Power Purchase Agreement (PPA).

In Angola this concept is usually linked to a Contrato de Aquisição de Energia, CAE. Angola formally strengthened the IPP framework through Presidential Decree 43/21 of 17 February 2021, which regulates independent electricity production and allows independent generators to connect to the public electricity system and sell power under an electricity-purchase agreement. (lex.ao)

Quilemba Solar: key private-sector example

Quilemba is particularly significant because it represents one of the clearest emerging private power projects in Angola. Current structure:

Item	Quilemba
First phase	35 MWp
Planned eventual capacity	80 MWp
Investment	~US$40 million
TotalEnergies	51%
Sonangol	30%
Maurel & Prom	19%
First electricity currently planned	April 2026 stated at groundbreaking; schedule should be treated as project target

Sonangol described Quilemba at its 2025 groundbreaking as the country’s largest private solar plant, intended to supply around 40,000 homes and avoid around 29 million litres of diesel annually. (sonangol.co.ao) A power purchase arrangement with the transmission entity was advanced in January 2025. (sonangol.co.ao)

Caraculo Solar

Caraculo is another important public-private renewable project. It is being developed by Solenova, a 50:50 joint venture between Sonangol and Azule Energy. Phase 1:

• 25 MW, operating since 2023.
• Ultimate project concept: 50 MW. (sustentabilidade.sonangol.co.ao)

Sonangol’s 2025 annual report states that the 25-MW Caraculo plant delivered 39,363 MWh during 2025, illustrating that private/JV renewables are beginning to produce measurable grid electricity. (sonangol.co.ao)

Overall IPP investment assessment

Angola has therefore established the legal architecture for IPPs, and several public-private renewable partnerships are appearing. However, the IPP market remains relatively early-stage compared with markets such as:

• South Africa;
• Morocco;
• Egypt;
• Kenya.

The principal challenge is no longer simply permitting private ownership; it is establishing a bankable commercial structure. Investors need confidence regarding:

• the credit quality of the electricity buyer;
• timely PPA payments;
• tariff adjustment;
• foreign-exchange convertibility;
• grid connection;
• curtailment compensation;
• contract enforcement;
• government guarantees;
• availability of political-risk insurance.

8. Public versus private share of Angola’s power sector

The power industry remains overwhelmingly state controlled.

Generation

State-owned PRODEL, Empresa Pública de Produção de Electricidade is the central public generation company. PRODEL states that its assets provide more than 95% of Angola’s electricity generation. (Prodel) Therefore, operational private/JV generation remains a small minority. Because some newer renewable projects are joint ventures involving Sonangol, a state-owned company, the precise division between “public” and “private” capital is more complicated than simply categorizing power stations.

A reasonable current structural assessment is:

Segment	Public-sector position	Private-sector position
Large hydro generation	Dominant	Very small
Conventional thermal	Dominant	Limited
Utility solar	Large public involvement; growing JVs	Growing
Transmission	RNT, public	Essentially no network ownership competition
Distribution/retail	ENDE, public	Essentially no national retail competition
New IPP development	Government/PPA counterparty	Emerging
Off-grid/C&I solar	Mixed	Potentially significant and growing

Accordingly, over 95% of the main generation base remains under PRODEL according to the company, while transmission and mainstream distribution remain state enterprises.

This makes Angola’s electricity market fundamentally a public-utility model with an emerging IPP layer, rather than a competitive wholesale electricity market.

9. Recommendations for improving Angola’s power industry

Angola’s next phase should emphasize using the capacity already built, rather than treating additional generation MW as the only indicator of progress.

Priority 1:  Shift investment toward transmission

Caculo Cabaça will introduce another 2.172 GW beginning around 2027. Without transmission expansion, part of this investment risks becoming underutilized. Priority projects should connect north to central, central to south or vise versa and strengthen high-capacity routes between Kwanza hydro generation, Luanda, industrial zones and southern demand centres.

Priority 2:  Make distribution expansion the national electricity-access priority

Investment should increasingly be judged by: new reliable customer connections per dollar, not simply new MW installed. ENDE needs:

• more LV and MV networks;
• distribution transformers;
• modern substations;
• feeder automation;
• prepaid and smart meters;
• customer databases;
• remote disconnection/reconnection;
• theft detection.

This simultaneously increases electricity access and power-plant utilization.

Priority 3: Reduce losses below 20%

The present >30% level represents a substantial economic loss. A staged target would be approximately below 15%. Every percentage point saved effectively creates additional saleable electricity without building another power station.

Priority 4:  Improve revenue collection

Moving from a collection rate of ~60% toward 90%+ would materially improve the financial position of ENDE and the entire electricity value chain. Priority measures include:

• prepaid meters;
• digital billing;
• mobile-money payment;
• large-customer smart metering;
• government-agency payment discipline;
• meter audits;
• anti-tampering measures.

Priority 5:  Reform tariffs gradually

Moving immediately from highly subsidized tariffs to full cost recovery would be socially disruptive. A better strategy would be:

• retain a subsidized lifeline block for poor households;
• gradually increase tariffs for larger residential consumers;
• implement cost-reflective industrial and commercial tariffs;
• automatically adjust selected tariff components for inflation;
• transparently fund social subsidies through the national budget rather than utility deficits.

The objective should be to make electricity affordable for poor consumers but commercially viable for the utility.

Priority 6:  Accelerate bankable IPP auctions

Instead of negotiating each renewable project independently, Angola could establish transparent competitive auctions for:

• utility solar;
• solar plus batteries;
• wind;
• small hydro;
• biomass.

Government should provide standardized: PPA, grid connection agreement, government support agreement, land framework, and environmental approval framework. Competition can reduce tariffs and financing costs.

Priority 7:  Solarize isolated diesel systems

This is one of the highest-value opportunities. For remote systems: Existing diesel generator, solar PV, battery and modern controller can dramatically reduce fuel consumption while retaining diesel for backup. Caraculo demonstrates this diesel-displacement logic at larger scale.

Priority 8:  Add battery energy storage

As solar expands, BESS should be installed around:

• weak southern networks;
• isolated grids;
• congested substations;
• large solar plants;
• critical industrial areas.

Batteries can provide:

• peak shaving;
• voltage support;
• frequency regulation;
• spinning-reserve replacement;
• renewable-energy shifting.

Priority 9:  Use gas strategically rather than diesel

Soyo and additional efficient gas generation can provide flexible capacity to complement hydro and solar. The start-up of Angola’s first non-associated gas production in 2026 strengthens long-term gas availability. (TotalEnergies.com) Gas generation should primarily serve as: balancing / firm capacity, not crowd out cheaper hydro and solar energy.

Priority 10:  Connect Angola to SAPP

This could fundamentally improve asset economics. When Angola has excess hydroelectricity it could export power toward:

• Namibia;
• Zambia;
• DRC and the wider SAPP network.

During drought or major outages Angola could import electricity. Regional interconnection would convert excess generation from a problem into a revenue source.

Priority 11:  Develop productive electricity demand

The goal should not merely be household consumption. Angola should link power infrastructure with economic-development zones supporting:

• mining;
• fertilizer;
• green ammonia;
• food processing;
• refrigeration;
• irrigation;
• cement;
• metals;
• industrial parks;
• ports;
• logistics hubs;
• data centres.

Higher productive demand improves power-plant load factors and utility revenue while contributing to economic diversification away from crude oil.

Priority 12:  Diversify hydro risk

Hydro will remain the backbone of the power sector, but increasing: will protect Angola against dry hydrological years.

Overall assessment

Angola has accomplished one of the most capital-intensive parts of power-sector development: building several gigawatts of generation. Its principal challenge has now moved downstream. The country has approximately 7.6 GW of installed capacity but produced only 17.9 TWh in 2023, equivalent to an approximate fleet-wide utilization of 27%. At the same time, only about half the population has electricity access.

That apparent contradiction defines the Angolan electricity industry:

Angola has substantial electricity-producing capability, but insufficient infrastructure and commercial capacity to deliver, sell and collect revenue for all the electricity it could generate. Therefore, the highest economic return over the coming years is likely to come not simply from building more generation, but from transmission integration, distribution expansion, metering, loss reduction, utility reform and productive demand creation.

Caculo Cabaça’s additional 2,172 MW, scheduled to begin entering service around mid-2027, makes these reforms increasingly urgent. (Ciam) If Angola successfully combines its large hydro base with solar, domestic gas, batteries, IPP capital and SAPP interconnection, it could move from an electricity-deficit/access-constrained economy toward becoming a low-cost regional power producer and exporter.

References and sources

The principal data, government documents and industry/news sources consulted for this report are:

1. U.S. Energy Information Administration ,  Angola Country Analysis, updated February 2025. Primary source for 2023 electricity generation, generation mix, national capacity, oil reserves and electricity-access discussion. EIA Angola country analysis
2. World Bank ,  Angola electricity-sector assessments and project documents. Used for tariffs, cost recovery, utility cash deficit, losses, collection rates, distribution constraints and sector structure. (World Bank)
3. World Bank ,  Electricity Sector Improvement and Access Project, 2026 implementation documentation. Used to verify continuing sector-reform and distribution-modernization activities. (World Bank)
4. PRODEL ,  Empresa Pública de Produção de Electricidade. Used for state-generation position, energy-transition strategy and company generation assets. (Prodel)
5. Southern African Centre for Renewable Energy and Energy Efficiency ,  Angola profile. Used for 2022 installed/operating capacity, peak demand, renewable-resource estimates and access figures. (SACREEE Community)
6. SAPP Pool Plan / RNT demand forecast. Used for historical national and regional electricity-demand forecasts. (SAPP)
7. Government of Angola / CIAM / Ministry of Energy and Water information on Caculo Cabaça. Used for project size, construction progress and current commissioning schedule. (Ciam)
8. Presidential Decree No. 43/21 ,  Independent Electricity Production Regulation. Used to analyze Angola’s IPP regulatory framework and electricity purchase agreements. (lex.ao)
9. Sonangol ,  Quilemba Solar announcements. Used for project ownership, capacity, PPA/CAE development, approximately US$40 million investment and construction status. (sonangol.co.ao)
10. Sonangol / Azule Energy ,  Caraculo Solar. Used for operational capacity, JV ownership and expansion plan. (sustentabilidade.sonangol.co.ao)
11. Sonangol Annual Report & Accounts 2025. Used for actual 2025 Caraculo electricity production and current renewable-project activity. (sonangol.co.ao)
12. TotalEnergies ,  New Gas Consortium / Quiluma first gas, March 2026. Used for the latest development in Angola’s non-associated natural-gas resource and expected plateau production. (TotalEnergies.com)
13. U.S. International Trade Administration ,  Angola Energy Country Commercial Guide. Used for historical capacity-utilization context, power-sector investment opportunities and government strategy. (Trade.gov)
14. World Bank Data / IEA Energy Statistics ,  Transmission and distribution loss indicator. Used to cross-check definitions and historical loss data. (World Bank Open Data)

Data caution: Angola’s published electricity statistics differ between sources because reporting years and definitions vary, for example, countrywide installed capacity versus PRODEL assets versus operating capacity. For that reason, I have used 2023 EIA data as the main internally consistent national generation/consumption baseline, supplemented by 2025–2026 project and policy updates rather than mixing figures from different reporting systems without explanation.