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A decade ago, Ghana had no commercial natural gas production. Today, natural gas has become the backbone of the country's power sector, supplying the majority of thermal electricity generation and supporting reliable power for households, industries and mining operations. Domestic gas production from the Jubilee and Sankofa fields, complemented by imports through the West African Gas Pipeline, continues to play a critical role in strengthening Ghana's energy security and reducing reliance on more expensive liquid fuels. In 2026, natural gas is expected to account for more than 85% of the country's total gas consumption, with demand continuing to outpace available supply.
As electricity demand continues to grow alongside economic expansion and urbanisation, Ghana faces increasing pressure to expand its upstream production, processing capacity, transmission infrastructure and storage capabilities. While recent financial reforms and debt repayments have strengthened confidence across the energy sector, ensuring long-term gas security will require continued investment in new upstream developments, midstream infrastructure and domestic gas monetisation projects to support sustainable industrial growth and future power generation
GDP (2024)
Proven Gas reserves
Gas production (2023)
Population (2023)
Population in 2050
Gas monetized (2023)
Main Infrastructure Projects
Offshore Western Region, approximately 60 km south of Sanzule.
2018-01-01
Atuabo, Ellembelle District, Western Region.
2015-01-01
Atuabo, Western Region.
2025-01-01
2018-01-01
Offshore Western Region, approximately 60 km south of Sanzule.
2015-01-01
Atuabo, Ellembelle District, Western Region.
2025-01-01
Atuabo, Western Region.
President
Minister for Energy and Green Transition
Chief Executive Officer of the Ghana National Petroleum Corporation (GNPC)
Chief Executive Officer of the Ghana National Gas Company (Ghana Gas)
Ghana's offshore basins hold substantial proven gas serves allowing the country to pursue enhanced exploration and production to meet domestic demand.
Ghana’s gas journey began in 2014 with the commissioning of Tullow Oil’s Jubilee field although gas connection had been established with Nigeria via the West African Gas Pipeline (WAGP) since the end of 2008.
Domestic production, which started with Jubilee, further grew with the commissioning of Tullow Oil’s TEN fields in 2016 and Eni’s Sankofa Gye-Nyame (SGN) fields in 2017. From its Offshore Cape Three Points (OCTP) block operations, the Italian major has become Ghana’s biggest supplier. In 2023, it supplied 65% of all commercialized gas, as Tullow Oil fields continue to reinject or flare most of their produced gas.
Ghana’s domestic supply stood at almost 700 MMscf/d in 2023, with some 288 MMscf/d commercialized for power generation and industrial use while the rest is reinjected or flared. Natural gas production plateaued in 2021 with efforts currently focused on commercializing additional gas produced while brownfield investments and new fields development are maturing.
Imports from Nigeria via WAGP have remained under-utilised, with 60-70 MMscf/d imported from the West African giant against a contractual flow of 120 MMscf/d depending on payment guarantees.
Ghana’s gas journey began in 2014 with the commissioning of Tullow Oil’s Jubilee field although gas connection had been established with Nigeria via the West African Gas Pipeline (WAGP) since the end of 2008.
Domestic production, which started with Jubilee, further grew with the commissioning of Tullow Oil’s TEN fields in 2016 and Eni’s Sankofa Gye-Nyame (SGN) fields in 2017. From its Offshore Cape Three Points (OCTP) block operations, the Italian major has become Ghana’s biggest supplier. In 2023, it supplied 65% of all commercialized gas, as Tullow Oil fields continue to reinject or flare most of their produced gas.
Ghana’s domestic supply stood at almost 700 MMscf/d in 2023, with some 288 MMscf/d commercialized for power generation and industrial use while the rest is reinjected or flared. Natural gas production plateaued in 2021 with efforts currently focused on commercializing additional gas produced while brownfield investments and new fields development are maturing.
Imports from Nigeria via WAGP have remained under-utilised, with 60-70 MMscf/d imported from the West African giant against a contractual flow of 120 MMscf/d depending on payment guarantees.
Ghana’s producing offshore gas fields are located on its Western border with Côte d'Ivoire, while its capital Accra and its industrial suburb Tema are located in the East. As a result, investments had to be made both in processing gas domestically, but also in making it available across the coastline to the power enclaves of Takoradi (West) and Tema (East).
To process domestic gas, state-owned GhanaGas commissioned the 150 MMscf/d Atuabo Gas Processing Plant in 2015, connecting to a national gas grid running to Takoradi and Prestea. The plant processes gas from Tullow Oil’s Jubilee and TEN fields. In 2017, Eni commissioned Sanzule’s 405 MMscf/d Onshore Receiving Facilities (ORF) to process its own gas from Sankofa Gye-Nyame before injecting it into GhanaGas’ network. Availability of domestic supply enabled the Takoradi power enclave to decarbonize and grow as a stable electricity supply base.
To make gas available in the West, Ghana established in 2019 a reverse flow on the existing West African Gas Pipeline. The project ensures that imported gas can flow from Nigeria to Tema and Takoradi but also enables domestic gas to flow back from Takoradi to Tema.
In anticipation future gas supply gaps, Ghana is now planning an additional onshore gas pipeline from Tema to Takoradi, thereby reinforcing flow capacity between its western and eastern industrial and power hubs.
Ghana’s producing offshore gas fields are located on its Western border with Côte d'Ivoire, while its capital Accra and its industrial suburb Tema are located in the East. As a result, investments had to be made both in processing gas domestically, but also in making it available across the coastline to the power enclaves of Takoradi (West) and Tema (East).
To process domestic gas, state-owned GhanaGas commissioned the 150 MMscf/d Atuabo Gas Processing Plant in 2015, connecting to a national gas grid running to Takoradi and Prestea. The plant processes gas from Tullow Oil’s Jubilee and TEN fields. In 2017, Eni commissioned Sanzule’s 405 MMscf/d Onshore Receiving Facilities (ORF) to process its own gas from Sankofa Gye-Nyame before injecting it into GhanaGas’ network. Availability of domestic supply enabled the Takoradi power enclave to decarbonize and grow as a stable electricity supply base.
To make gas available in the West, Ghana established in 2019 a reverse flow on the existing West African Gas Pipeline. The project ensures that imported gas can flow from Nigeria to Tema and Takoradi but also enables domestic gas to flow back from Takoradi to Tema.
In anticipation future gas supply gaps, Ghana is now planning an additional onshore gas pipeline from Tema to Takoradi, thereby reinforcing flow capacity between its western and eastern industrial and power hubs.
The availability of domestic gas in Ghana has supported the displacement of diesel and oil in the country’s electricity mix. All grid-connected thermal power plants have gas as their primary fuel, with only Aksa’s 370 MW HFO power station in Tema left to be converted a work already well in progress.
Gas represents over 3.3GW of grid-connected capacity and currently accounts for some 65% of electricity generated in the country. Domestic availability also supported the growth of a private distribution business led by Genser Energy. The company has developed an extensive pipeline network of 425km in Western Ghana to supply gas to gold mines where it is used for embedded power generation with a current capacity of 115 MW split across several facilities. In 2024, the company commissioned its latest extension to Kumasi – Ghana’s second largest city where state utility VRA was able to relocate the 150 MW Kumasi 1 Thermal Power Plant (K1TPP).
Ghana’s power plants consume 98% of the gas commercialized in the country (369 Mmscf/d), with the rest left for industries. Industrial demand, estimated at some 38 MMscf/d, has been growing in recent years as more factories require heat for their ceramics and crude oil refining. These include Twyford, Wankang, Plot Enterprise, Marco Polo Gh Ltd, Jintao who all use gas in the Western enclave for their industrial processes. The country’s Energy Commission expects industrial demand to peak at 39 MMscf/d in 2025 as new ceramics industries such as Continental Blue Investment Gh, and CIMPOR Gh. Ltd begin production.
The availability of domestic gas in Ghana has supported the displacement of diesel and oil in the country’s electricity mix. All grid-connected thermal power plants have gas as their primary fuel, with only Aksa’s 370 MW HFO power station in Tema left to be converted a work already well in progress.
Gas represents over 3.3GW of grid-connected capacity and currently accounts for some 65% of electricity generated in the country. Domestic availability also supported the growth of a private distribution business led by Genser Energy. The company has developed an extensive pipeline network of 425km in Western Ghana to supply gas to gold mines where it is used for embedded power generation with a current capacity of 115 MW split across several facilities. In 2024, the company commissioned its latest extension to Kumasi – Ghana’s second largest city where state utility VRA was able to relocate the 150 MW Kumasi 1 Thermal Power Plant (K1TPP).
Ghana’s power plants consume 98% of the gas commercialized in the country (369 Mmscf/d), with the rest left for industries. Industrial demand, estimated at some 38 MMscf/d, has been growing in recent years as more factories require heat for their ceramics and crude oil refining. These include Twyford, Wankang, Plot Enterprise, Marco Polo Gh Ltd, Jintao who all use gas in the Western enclave for their industrial processes. The country’s Energy Commission expects industrial demand to peak at 39 MMscf/d in 2025 as new ceramics industries such as Continental Blue Investment Gh, and CIMPOR Gh. Ltd begin production.
As Ghana's gas sector enters its second decade, it must balance domestic needs with regional trade ambitions as it pushes to capitalize on gas to establish itself as regional energy hub. Meeting these objectives depends on developing new supply sources and expanding the use of gas across the country. As upstream activity recovers following the 2024 General Elections, momentum is also building up midstream and downstream. In Tema, a long-awaited LNG import terminal could finally progress towards commissioning while plans are in motion to build a gas distribution network across the Tema industrial zones where aluminum, steel, cement and processing industries are in need of energy for both power and heat. Drag Ghana also has opportunities to participate in more transformational projects, first by maximizing import capacity from Nigeria and second by leveraging off its trade relations with West African neighbours to anchor energy trade corridors meeting the needs of a growing region.
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ASEC has urged the Government of Ghana to retain full ownership of the planned Second Gas Processing Plant, arguing that the project is a strategic asset for domestic gas processing, energy security and industrial development.
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