Gas Flaring Reduction in Angola: Technologies and Regulatory Push

The Flaring Problem: Scale, Cost, and Consequences

Gas flaring, the combustion of natural gas that is not captured for commercial use, has been one of the most visible and consequential features of Angola’s petroleum sector. The country has historically ranked among the world’s top ten gas-flaring nations, burning approximately 3 to 4 billion cubic metres (bcm) of natural gas annually, equivalent to roughly 7 to 10 million tonnes of CO2 emissions and the destruction of gas worth an estimated $1 to $2 billion at international market prices.

The economic and environmental costs of flaring are substantial and compound over time. Every cubic metre of gas flared represents revenue forgone, carbon emitted, and a resource permanently destroyed. For a country facing declining oil production, mounting fiscal pressure, and growing climate accountability, the imperative to reduce flaring is both economic and strategic.

Angola’s approach to flaring reduction combines regulatory mandates, infrastructure investment, technology deployment, and international partnership. This article assesses the current state of flaring in Angola, the regulatory framework driving reduction, the technologies being deployed, and the progress being made.

Regulatory Framework for Flaring Reduction

International Commitments

Angola is a signatory to the World Bank’s Global Gas Flaring Reduction Partnership (GGFR), which coordinates international efforts to reduce routine flaring. Through GGFR, Angola has committed to the Zero Routine Flaring by 2030 initiative, a voluntary pledge that commits endorsing governments and companies to eliminate routine flaring from new oil field developments and to phase out existing routine flaring no later than 2030.

Additionally, Angola has committed to emissions reduction targets under the Paris Agreement, with gas flaring reduction identified as a key mitigation measure in the country’s Nationally Determined Contribution (NDC).

Domestic Regulations

The domestic regulatory framework for flaring reduction is anchored by several instruments:

Petroleum Activities Law (Law 10/04, as amended): Establishes the general principle that gas should be commercialised rather than flared and authorises ANPG to impose conditions on gas utilisation in production sharing agreements and operating licences.

Gas Utilisation Master Plan: ANPG has developed a gas utilisation master plan that sets targets for gas capture, processing, and commercialisation across the upstream sector. The plan establishes block-level gas utilisation targets that operators must meet as a condition of their PSA compliance.

Flaring penalties: Angola has implemented escalating financial penalties for routine gas flaring that exceeds permitted levels. While historically these penalties were modest (insufficiently punitive to drive behaviour change), recent regulatory revisions have increased penalty rates to create a more meaningful economic disincentive for flaring.

Environmental Impact Assessment (EIA) requirements: New field developments and significant modifications to existing operations require EIAs that specifically address gas management plans. ANPG reviews and approves these plans as a condition of development authorisation.

Operator Reporting Obligations

Operators are required to report gas flaring volumes to ANPG on a monthly basis, with data disaggregated by source (routine flaring, safety flaring, process upset flaring) and block. ANPG aggregates this data for national-level reporting to international bodies including the GGFR and the OPEC Secretariat.

The distinction between routine flaring (continuous flaring during normal operations, which should be eliminated) and non-routine flaring (safety-related flaring during process upsets, start-ups, or emergencies, which is accepted as necessary) is critical. The Zero Routine Flaring by 2030 target applies to routine flaring only.

Technologies for Gas Capture and Utilisation

Reducing gas flaring requires either capturing the gas for commercial use or deploying alternative utilisation technologies at or near the production facility. The principal technologies deployed or under evaluation in Angola include:

Gas Compression and Pipeline Export

The most effective flaring reduction measure is capturing associated gas at the production facility, compressing it to pipeline pressure, and transporting it to a gas processing or liquefaction facility for commercial utilisation. This approach has been implemented across much of Angola’s offshore production infrastructure:

• Subsea gas pipelines connect offshore platforms and FPSO riser bases to the onshore gas gathering system
• Gas compression on FPSOs and platforms boosts gas pressure for pipeline transport
• The Sanha Lean Gas Connection (first gas December 2024) is the most significant recent infrastructure investment enabling gas capture from the Cabinda area

The investment required for comprehensive gas compression and pipeline infrastructure is substantial, typically $500 million to $2 billion per major field complex. However, the revenue from gas commercialisation and the avoidance of flaring penalties can provide attractive returns on this investment. For infrastructure details, see our gas processing plant construction article.

Gas Re-injection

Where pipeline infrastructure to shore is not available or economically justified, gas re-injection into the reservoir provides an alternative to flaring. Re-injected gas serves dual purposes:

• Reservoir pressure maintenance: Injected gas restores reservoir pressure lost through production, improving oil recovery
• Gas storage: Gas can potentially be produced in a future period when infrastructure for commercialisation becomes available

Gas re-injection requires compression equipment on the production facility and injection wells in the reservoir. Most of Angola’s deepwater FPSOs are equipped with gas re-injection capability, though capacity constraints sometimes limit the volume of gas that can be re-injected.

Gas-to-Power (On-Platform)

Some operators generate electrical power on production platforms or FPSOs using associated gas that might otherwise be flared. While all FPSOs use gas for onboard power generation, the potential exists to install additional gas-fired generation capacity to supply power to nearby facilities through submarine power cables.

Small-Scale LNG and CNG

Emerging technologies for small-scale LNG production or compressed natural gas (CNG) systems could potentially enable gas commercialisation from facilities that cannot economically connect to pipeline infrastructure. Mini-LNG units with capacities of 0.1 to 0.5 mtpa can be installed on large FPSOs or dedicated gas processing vessels.

Carbon Capture and Storage (CCS)

For facilities where CO2-rich gas streams are produced (particularly relevant for Kwanza Basin pre-salt developments), carbon capture and geological storage provides a pathway to manage CO2 that would otherwise be vented or contribute to flaring emissions. The Kaminho FPSO is being designed with CO2 capture and re-injection capability. For Kaminho details, see our deepwater field development pipeline.

Operator Performance and Progress

TotalEnergies

TotalEnergies has been the most proactive major operator in Angola on flaring reduction. The company’s Block 17 operations have progressively reduced routine flaring through gas compression upgrades, pipeline capacity expansions, and operational optimisation. TotalEnergies has committed to zero routine flaring across its global portfolio by 2030 as part of its corporate climate strategy.

The company’s newer developments (CLOV, Kaombo, Begonia) have been designed from inception with zero routine flaring capability, incorporating sufficient gas handling and export capacity to commercialise all produced gas.

Chevron

Chevron’s investment in the Sanha Lean Gas Connection represents the most significant single flaring reduction infrastructure investment in Angola. By creating a dedicated pipeline system to transport gas from the Cabinda concession area to the Soyo gas hub, Chevron has enabled the commercialisation of gas volumes that were previously flared or re-injected.

Azule Energy

Azule Energy is developing the Quiluma and Maboqueiro non-associated gas fields in Block 15/06, which connect to the Sanha pipeline system. The company’s gas development strategy directly addresses flaring reduction by providing dedicated infrastructure for gas capture from producing oil fields.

ExxonMobil

ExxonMobil’s Block 15 operations have implemented gas compression and re-injection programmes to reduce flaring from the Kizomba complex. The company is evaluating additional gas export infrastructure to further reduce flaring and enable gas commercialisation.

Progress Tracking: Angola’s Flaring Trajectory

Data from the GGFR and satellite-based flaring monitoring (using VIIRS nighttime light data from NOAA) indicates that Angola’s flaring volumes have declined significantly from peak levels:

The acceleration of flaring reduction in 2024-2025 reflects the commissioning of the Sanha Lean Gas Connection and the NGC facility, which together provide substantial new gas capture and processing capacity.

Achieving the Zero Routine Flaring by 2030 target will require continued infrastructure investment, operational excellence, and regulatory enforcement. The remaining routine flaring is concentrated in specific facilities and blocks where gas capture infrastructure is incomplete, requiring targeted investment to address.

Economic Analysis: The Cost of Flaring vs. Investment in Capture

The economic case for flaring reduction investment is compelling:

Value of flared gas: At $10/MMBtu, 2.5 bcm of flared gas has a potential market value of approximately $880 million per year.

Carbon cost: At $50/tonne CO2 (a representative mid-range carbon price), the CO2 emissions from 2.5 bcm of flaring carry an implied carbon cost of approximately $300 to $400 million per year.

Flaring penalties: ANPG’s escalating penalty framework imposes financial costs that further erode the economics of continued flaring.

Capture infrastructure cost: While gas capture infrastructure requires upfront investment of $500 million to $2 billion per major system, the revenue from gas commercialisation typically generates payback periods of 3 to 7 years at current gas prices.

The analysis demonstrates that for most remaining flaring sources in Angola, the investment in gas capture infrastructure is economically justified by the combination of gas sales revenue, avoided flaring penalties, and the intangible benefits of environmental compliance and social licence to operate.

Implications for Investors and Service Companies

Gas flaring reduction creates commercial opportunities for:

• Gas compression equipment suppliers (reciprocating and centrifugal compressor manufacturers)
• Pipeline contractors (subsea and onshore gas pipeline installation)
• Gas processing technology providers (acid gas removal, dehydration, NGL extraction)
• Environmental monitoring companies (flaring measurement, emissions accounting)
• Carbon credit developers (monetising verified emissions reductions)

For the broader gas sector opportunity, see our natural gas monetisation strategy and Angola LNG terminal articles.

External resources: World Bank GGFR | ANPG Official Website | IEA Flaring Emissions