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In The Spotlight

Puma Energy Ghana boosts LPG distribution through local partnerships.

Gas

In line with Ghana's goals to reach 50% liquefied petroleum gas (LPG) penetration by 2030, Puma Energy Ghana has formalised a strategic partnership with local LPG distributors -- Earth Energy, Sandhill Oil and Gas, Riet Company Ltd, Hamcom, and StepGas

The agreements fall in place with the Government’s Cylinder Recirculation Model (CRM), which advances the country's transition from traditional station refill methods toward a decentralised, community-based retail network that brings safe cooking gas directly to households, particularly across peri-urban and rural areas.

The initiative builds around Puma Energy’s 3y3 Good Exchange scheme, under which consumers can swap old gas cylinders for new, certified units at no initial cost. By removing the upfront financial barrier, the programme aims to encourage wider adoption of clean cooking, improve indoor air quality, and mitigate deforestation caused by wood and charcoal use. 

“We are introducing a new distribution philosophy today, bringing safe and affordable energy closer to Ghanaians. This initiative marks a significant step forward, and we are leveraging our capabilities to support the government’s goal of achieving 50% LPG penetration by 2030,” said Lanzeni Coulibaly, General Manager, Puma Energy Ghana. 

“Energy security and safety must be intrinsically linked. By collaborating with these five distributors, we are contributing to a more robust LPG value chain, providing Ghanaian homes and businesses with confidence in the safety, quality, and reliability of their supply,” added Coulibaly. 

“For years, we have observed LPG distribution from the sidelines. Today, Puma Energy has equipped us, as Ghanaian entrepreneurs, with the resources, cylinders, and technology to take the lead. We are ready to bring safe gas to every neighbourhood in Accra,” said Torgbigah Adamah III, StepGas Ltd.

 

 

 

 

Europa associate to farm out stakes offshore Equatorial Guinea.

Exploration

Europa Oil & Gas (Holdings) plc's associated entity, Antler Global Limited has secured a binding farmout agreement with Fuhai (Beijing) Energy Limited, a subsidiary of Fuhai Group New Energy Holding Co Ltd, to transfer a 40% stake in the offshore Equatorial Guinea EG-08 production sharing contract (PSC)

Following an initial announcement on 1 September 2026, the involved parties have agreed to extend the transaction's completion longstop date to 30 October 2026.

While the Ministry for Mining and Hydrocarbons Department of Equatorial Guinea has already given clearance, the deal is still awaiting Outbound Direct Investment (ODI) authorisation from the Beijing Municipal Development and Reform Commission.

New Chinese regulations introduced on 1 July 2026 have lengthened the overall processing period for outbound investments. Nonetheless, the MDRC confirmed that Fuhai's paperwork is being actively processed, and Chinese authorities remain satisfied with the submission.

Europa maintains a 42.9% equity stake in Antler. Once the deal closes, ownership of the EG-08 PSC will be split as follows:

- Antler Global Limited: 40% working interest (retaining operatorship)

- Fuhai (Beijing) Energy Limited: 40% working interest

- GEPetrol (National Oil Company of Equatorial Guinea): 20% state interest

Despite the regulatory slowdown, the planned timeline for the Barracuda-1 exploration well remains unchanged. Drilling operations are anticipated to begin during the first half of 2027.

William Holland, chief executive officer of Europa, said, “While ODI approval is taking longer than anticipated, the direction of travel is clear. Fuhai's application continues to be processed, and we remain encouraged that the approval is close. We have used this time to ensure that we are fully prepared to commence the drilling process for Barracuda-1 as soon as ODI approval is secured, and we look forward to testing what we believe is a very exciting prospect.”

SLB to deploy subsea production system for Rovuma development.

Technology

SLB’s OneSubsea joint venture has secured a subsea production systems contract from ExxonMobil Moçambique, Limitada, representing the Area 4 consortium (comprising ENH, CNPC, ENI, KOGAS, and XRG)

The agreement marks a major step forward for the initial phase of Mozambique’s offshore Rovuma LNG development.

Under the terms of the agreement, SLB OneSubsea will handle the engineering, procurement, manufacturing, and installation of subsea trees, manifolds, umbilicals, and control systems tailored for high-efficiency deepwater operation.

"This award reflects our ability to deliver integrated subsea solutions that help customers accelerate development and maximize value from deepwater resources," said Mads Hjelmeland, chief executive officer, SLB OneSubsea. "The Rovuma project represents a significant opportunity for Mozambique’s growing LNG sector, and we look forward to continuing our long-standing relationship with ExxonMobil operations in Africa, bringing our proven technology and expertise to this important phase of the development and beyond."

To assist regional operations and support the project, SLB OneSubsea plans to build a dedicated services facility in Mozambique. This hub is expected to boost local supply chains while generating regional job and training opportunities. 

Previously, the Eni-led Mozambique Rovuma Venture signed a significant contract with Technip Energies, JGC and Samsung Heavy Industries to secure their ongoing project delivery services for the long term on the Coral Norte Floating Liquefied Natural Gas project offshore Mozambique.

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The concession's advance sustainability scopes are one of the prime reasons that locked the deal for ADNOC. (Image source: Adobe Stock)

In its first strategic investment in Mozambique, ADNOC has acquired 10% of Galp’s interest in the Area 4 concession of the Rovuma basin in Mozambique

The acquisition will allow ADNOC a share of the liquefied natural gas (LNG) produced from the concession.

With the operational Coral South Floating LNG (FLNG) facility, the planned Coral North FLNG development and the planned Rovuma LNG onshore facilities, the concession has a combined production capacity of more than 25 mn tonnes per annum. It is one of the world’s largest gas discoveries in 15 years. 

A one-of-a-kind facility in Africa, the Coral South development is currently in operation, with a production capacity of up to 3.5 mtpa of LNG. Once up and running, the Coral North development is capable of adding another 3.5 mtpa of LNG to that. It will have a FLNG facility to process and liquefy natural gas for export. 

The Coral south development is already yeilding vegetable oil to serve as feedstock in Eni's biorefineries. 

The modular, electric-drive design of the 18-mtpa Rovuma Onshore LNG development is capable of challenging industry standards when it comes to carbon intensity reduction from LNG production. 

The concession's advance sustainability scopes are one of the prime reasons that locked the deal for ADNOC, which aims to achieve a just transition-driven net zero by 2045. 

Integrated global gas business 

Musabbeh Al Kaabi, ADNOC executive director for low carbon solutions and international growth, said, “For over fifty years, ADNOC has been a reliable and responsible global provider of LNG and we are building on this role with this landmark investment in the world-class Rovuma supergiant gas basin in Mozambique as we deliver on our international growth strategy. Natural gas plays an important role to meet growing global demand with lower emissions compared to other fossil fuels and this acquisition supports our efforts to build an integrated global gas business to ensure we continue providing a secure, reliable and responsible supply of natural gas.”

 

 

 

 

 

The signing ceremony included the CEOs of Baker Hughes, SONATRACH and MAIRE, and the Minister of Energy and Mines. (Image source: Baker Hughes)

In an effort to boost production from Hassi R’Mel gas field 550 km south of Algiers, SONATRACH has signed a contract with Baker Hughes

The energy technology company will supply 20 compression trains based on Frame 5 gas turbine and BCL compressor technology will be installed across three gas boosting stations within the Hassi R’ Mel gas field. 

This comes as part of the Mattei Plan, a broader strategic collaboration across industries between Algeria and Italy. Italy has assured financial support for Algeria's gas production, which is the European nation's biggest single source of import. 

In 2023, Bloomberg NEF recognised Algeria as the second-largest gas supplier to Europe. The country has introduced multiple gas boosting stations to hold its title on the global energy market, while embracing natural gas as its prime energy source for socio-economic development. In June last year, TotalEnergies signed contract with SONATRACH to develop gas resources in the north-east Timimoun region. The oil major has also extended its LNG contract with SONATRACH till 2025 to access 2 mn tonnes of LNG for France and Europe.  

The largest gas field in Algeria, Hassi R’ Mel is equipped to not just meet domestic demands but also serves as key source of energy supply for Europe. At more than 20 trillion cu/m, shale gas is a lucrative investment opportunity for Algeria which falls under SONATRACH's long-term development plans as the company's vice president for planning and strategy, Rachid Zerdani noted last year. 

Baker Hughes responsibilities on Hassi R’ Mel will include boosting and stabilising the pressure of natural gas to increase production at site. Its facility in Italy will be the base for all project activity from compressor trains packaging and manufacturing to trains testing. This comes as a sub-contract of an order awarded to a consortium between Baker Hughes and technology and engineering group MAIRE-subsidiary Tecnimont. 

Reliable energy source for Europe

“We have long believed that it is critical to increase gas within the overall global energy mix to help achieve a lower-carbon economy. This project helps to solve for energy producers’ multi-faceted challenge of driving sustainable energy development as energy demand increases. We are proud to support such a critical energy project in partnership with Tecnimont,” said Lorenzo Simonelli, chairman and CEO of Baker Hughes. 

“Today’s announcement marks a notable milestone in our historical collaboration with SONATRACH for key energy projects in Algeria that have played a crucial role in supplying reliable energy to Europe,” said Simonelli on the occasion of contract signing, which also included Rachid Hachichi, CEO, SONATRACH; Alessandro Bernini, CEO, MAIRE, and the Minister of Energy & Mines, Mohamed Arkab.

 

 

 

 

There is a potential for an uptick in E&A drilling activity. (Image source: Westwood)

Mozambique can still lead production and drilling in the East African Ruvuma-Rufiji (EARR) Gas Basin through to 2030, if the government continues to take strides to guarantee rapid progression of projects off Cabo Delegado province, writes Michela Francisco, analyst - onshore energy services, Westwood Global Energy Group

According to bp's 2024 Energy Outlook, global liquefied natural gas (LNG) traded volumes are forecast to grow 43% by 2030 from the 543 bn cu/m recorded in 2022

In recent years, LNG exports have been dominated by the United States, Australia and Qatar, which, according to the Energy Information Administration (EIA), held a combined LNG export capacity of approximately 257 mmtpa in 2023 (60% of total global LNG capacity). By 2030, Qatar and the US are projected to add approximately 150 mmtpa in LNG feedstock, securing the top two positions in global LNG export capacity. New additions are anticipated to stem from LNG facilities currently under construction in the US (84.1 mmtpa) and expansion phases of QatarEnergy’s North Field (65mmtpa). Despite this, there is still an appetite for additional LNG supply, given current demand expectations, making the business case for developing long-stalled gas projects from frontier areas stronger.

Mozambique and Tanzania, which house the EARR Gas Basin, could potentially be major beneficiaries of this projected demand, given abundant gas reserves (165.7 trillion cu/ft) and the basin's proximity to South-Asian import markets. However, the burning question remains – how soon can the world expect the EARR Gas Basin to roar amid an increasingly thirsty LNG demand environment?

It is pertinent to state that the EARR Gas Basin has failed to live up to its full potential due to a series of endemic bottlenecks faced in the host countries. In Tanzania, the US$40bn Tanzania LNG project, which aims to receive gas feedstock from six fields across Blocks 1 and 4 (Shell) and Block 2 (Equinor), has been subject to extensive delays due to protracted negotiations rooted in unattractive fiscal terms due to high domestic supply obligations.

The story behind undeveloped gas reserves is quite different for the reserves offshore Mozambique, with the main culprit being the Islamist insurgency in Cabo Delgado province. The conflict has led to delays in final investment decisions (FIDs) and project start-ups, given declarations of force majeure for key projects. An example is TotalEnergies’ enforcing force majeure on the 13 mmtpa Mozambique LNG project, hereby delaying production start from the operator's Golfinho-Atum field into 2028, nine years post sanction.

On a similar note, ExxonMobil's Rovuma LNG project also felt the knock-on effect following the declaration of force majeure by TotalEnergies, given that it plans to share some facilities belonging to the Mozambique LNG project. ExxonMobil, however, seized this as an opportunity to cut costs by heavily reconfiguring the design plan from its initial two-train 15.2 mmtpa stick-build facility to an 18 mmtpa facility now being constructed using a modular approach whilst putting some emphasis on mitigating greenhouse gas emissions from the project. To date, ExxonMobil has launched tenders for a front-end engineering and design (FEED) contract and an engineering, procurement, construction and installation (EPCI) option for the subsea-to-shore gas gathering facilities.

Another factor contributing to the untimely development of resources in Mozambique is complicated project economics. TotalEnergies highlighted this in 2023 when it reported that supply chain inflationary pressures further complicated the resumption of the US$20bn Mozambique LNG project. However, there have been signs of positive developments given that TotalEnergies communicated in the company’s April 2024 earnings call that contractors have agreed to reverse contract inflation plans; thus, this is no longer an obstacle to the project’s sanctioning decision.earr gas basin

Despite these challenges, the Basin's inaugural project, Eni's 75,000 boepd Coral South floating liquified natural gas (FLNG) project, came onstream in 2022, signalling that complex, multi-billion-dollar developments could work offshore Mozambique. Output in Mozambique is forecast to remain stable at around 75,000 boepd until 2027 before growing to a peak of 295,000 boepd by 2030, up 296%, driven by TotalEnergies’ Golfinho-Atum and Eni's Coral Phase II fields.

Additionally, Tanzania's inaugural field in the Basin should come onstream in 2026 from Aminex's 7000 boepd Ntorya onshore gas field, boosting total output across the Basin to a peak of approximately 302,000 boepd by 2030, up 305% on 2023. Although there are positive signs for production, the spectre of delays that have been haunting projects remains strong, potentially diluting the positive picture prior to 2030, especially since only one of the three projects expected onstream by 2030 has passed sanctioning (TotalEnergies’ Golfinho-Atum). 

Drilling activity across both countries has been negligible, averaging one well per annum over the 2019-2024 period. Activity is anticipated to liven up over the forecast, driven by approximately 50 wells to be drilled to support upcoming LNG projects in Mozambican deepwater. Of these, 27 subsea trees have already been awarded between 2017 and 2019 for Eni’s Coral South and TotalEnergies’ Golfinho-Atum fields. 30 additional subsea trees are forecast to be awarded, with six awards anticipated for Eni’s Coral North field, scheduled to reach FID before the end of 2024. Onshore drilling activity will remain negligible, with only Aminex’s Chikumbi-1 exploration well set to be spud in 2024, the only onshore E&A well spud in the basin since 2016.

Post 2030, the outlook from the EARR Basin could be more promising, given continued interest from international energy companies (IECs), as well as licencing rounds and concession award announcements made across both countries since 2023. Although projects are few and far between in Tanzania, Shell and Equinor proposed a US$42bn LNG project from three deepwater blocks in March 2023, and this was later followed by CNOOC’s expression of interest in developing a FLNG deepwater project in blocks 4/1B and 4/1C in June 2023. From a regulatory standpoint, the current administration has increased optimism, given ongoing negotiation on fiscal terms with joint venture companies; however, nothing has materialised thus far.

Additionally, it is noteworthy to highlight the potential for an uptick in E&A drilling activity beyond Westwood’s current forecasts. This is due to the semi-autonomous Government of Zanzibar, off-Tanzania, launching its inaugural five-year licensing round in March of 2024, inviting IECs to explore eight offshore blocks.

earr gas basinsE&A drilling could also occur in Mozambique, given that the National Hydrocarbon Company approved a concession contract for oil exploration and production in the Angoche A6-C Area in July 2024. However, Westwood is bearish on these progressing into any E&A drilling activity before the second half of the forecast.

When dissecting current developments in the EARR Basin, it is evident that by the onset of the next decade, the Basin could contribute about 295,000 boepd of gas to meet global LNG demand. Westwood anticipates that Mozambique will continue to lead production and drilling in the EARR Basin through to 2030. However, it remains crucial for the Mozambican government to continue to take strides towards eradicating the insurgency to guarantee rapid progression of projects off Cabo Delegado province, which are currently mainly in the FEED stage.

Contrarily, on the Tanzanian side of the Basin, the portrait is more promising than in the hindcast, albeit there is still a need to focus on improving fiscal terms to attract more near-term investment and ensure that current interest from IECs is maintained. Overall, Westwood believes that by 2030, the EARR Gas Basin might start to live up to its potential as projects finally move from potential to reality.

APT has a gas sales agreement with TPDC. (Image source: Adobe Stock)

ARA Petroleum Tanzania and its development partner Aminex Plc have received a 25-year development licence over the Ntorya Gas discovery in Tanzania from the Deputy Prime Minister and Minister for Energy of Tanzania, Doto Mashaka Biteko

“We were honoured to receive this licence from Deputy Prime Minister Doto Biteko at such a prestigious event. This ceremony marked a significant milestone in our commitment to harness Tanzania’s gas resources for the benefit of its people. Our ambition for this serious endeavour is that it results in boosting economic development, alleviating energy poverty and supporting the country’s energy transition,” said Erhan Saygi, general manager, ARA Petroleum Tanzania, commenting on the handover ceremony that took place in Mtwara.

APT has acquired land for the installation of upstream processing facilities, and the Chikumbi-1 appraisal well location, while expanding an adjacent site to accommodate the construction of a camp and storage yard. It is also putting into place the logistics necessary to conduct the subsurface work that will lead to first gas production. This includes conducting a well-test on Ntorya-2 and converting it to a producing well, drilling the Chikumbi-1 appraisal well with a view to converting it to a producing well and carrying out a well workover at Ntorya-1, before turning it into a producing well. 

The company is aiming the completion of pipeline placement from Ntorya to Madimba by early next year, working in line with the Tanzanian government's ambitions to enable gas delivery for electricity generation in the Mtwara region. 

According to a Gas Sales Agreement signed with the Tanzanian Petroleum Development Corporation (TPDC) earlier this year, APT expects an initial yield of 40 to 60 mn st cu/ft a day in the first year, gradually boosting production to 140 mn st cu/ft over the next few years. 

This estimate is backed by strikingly positive 3D seismic datasets from the region, indicating significant potential gas volumes in other untested structures over the wider licence area. To emphasise just how significant the potential gas volumes might be, Charles Santos, the executive chairman of Aminex, has said that the Ntorya accumulation can become the largest onshore gas discovery in East Africa. 

This, however, will require investment in a phased development of the Ntorya gas field and the maturing of domestic industries as gas offtakers, such as fertiliser, cement and plastics production plants, vehicle CNG stations, domestic LPG suppliers and additional gas-fired power stations for industrial and residential use.

Ntorya gas hub

“We are excited about further exploration and appraisal work in this area as we consider it to hold truly enormous volumes of gas. We believe this could be game-changing for Tanzania’s energy security, for Mtwara’s industrial development and for Tanzanians’ prosperity. We look forward to building strong partnerships with local businesses and entrepreneurs to share knowledge, impart expertise and build a home-grown industry around a Ntorya gas hub,” said Saygi.

APT has been actively involved in the Ruvuma Asset since 2020, before its interests in the region accumulated to 75% post acquisition from Scirocco Energy last year. The remaining 25% interest in the Ruvuma Asset is held by Aminex.

 

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Exploration

Europa associate to farm out stakes offshore Equatorial Guinea.

Exploration

Europa Oil & Gas (Holdings) plc's associated entity, Antler Global Limited has secured a binding farmout agreement with Fuhai (Beijing) Energy Limited, a subsidiary of Fuhai Group New Energy Holding Co Ltd, to transfer a 40% stake in the offshore Equatorial Guinea EG-08 production sharing contract (PSC)

Following an initial announcement on 1 September 2026, the involved parties have agreed to extend the transaction's completion longstop date to 30 October 2026.

While the Ministry for Mining and Hydrocarbons Department of Equatorial Guinea has already given clearance, the deal is still awaiting Outbound Direct Investment (ODI) authorisation from the Beijing Municipal Development and Reform Commission.

New Chinese regulations introduced on 1 July 2026 have lengthened the overall processing period for outbound investments. Nonetheless, the MDRC confirmed that Fuhai's paperwork is being actively processed, and Chinese authorities remain satisfied with the submission.

Europa maintains a 42.9% equity stake in Antler. Once the deal closes, ownership of the EG-08 PSC will be split as follows:

- Antler Global Limited: 40% working interest (retaining operatorship)

- Fuhai (Beijing) Energy Limited: 40% working interest

- GEPetrol (National Oil Company of Equatorial Guinea): 20% state interest

Despite the regulatory slowdown, the planned timeline for the Barracuda-1 exploration well remains unchanged. Drilling operations are anticipated to begin during the first half of 2027.

William Holland, chief executive officer of Europa, said, “While ODI approval is taking longer than anticipated, the direction of travel is clear. Fuhai's application continues to be processed, and we remain encouraged that the approval is close. We have used this time to ensure that we are fully prepared to commence the drilling process for Barracuda-1 as soon as ODI approval is secured, and we look forward to testing what we believe is a very exciting prospect.”

Petralon 54 has revamped its production capacity significantly.

Perenco started a new five well drilling campaign on the Masseko field.

Geology & Geophysics

The survey will span across 34,000 kms offshore Egypt. (Image source: TGS)

Geology & Geophysics

Energy data and intelligence provider, TGS, has partnered with Egyptian Natural Gas Holding Company (EGAS), to initiate a large-scale 2D seismic reimaging campaign, the EGY-2DRE2026 project 

The survey will span across 34,000 kms offshore Egypt, which will be further integrated to the GeoStreamer 2016, 2018 and 2023 surveys. The compilation will comprise other available conventional 2D data as well, building single and consistent regional framework for interested operators to refer to across the offshore basins. The vast and insightful dataset will be fed into an advanced velocity model building and pre-stack depth migration workflow, including TGS' proprietary DM-eFWI technology, to generate credible images of pre-, intra- and post-Messinian salt intervals in high definition. 

The reimaged dataset that spans offshore Nile Delta, Herodotus Basin, and wider Eastern Mediterranean Basin will support clients to better resolve these intervals, giving a sharper, basin-wide structural framework to support prospect identification and maturation. This will play a significant role in decision making for operators to channelise exploration budgets in the right direction ahead of upcoming licensing rounds.

To support resource development, TGS has lately been taking up region-specific projects in Africa that aligns with a rising global demand for basin-wide reimaging and data integration across frontier and mature basins globally.

Final products for a priority subset of 2D lines are scheduled for delivery in Q2 2027, with the remaining full project scheduled for completion in Q1 2028.

"EGY-2DRE2026 will give our customers a modern, regionally consistent view of a basin that has historically been difficult to image beneath its complex Messinian section," said David Hajovsky, Executive Vice President, Multi-Client at TGS. "By combining our latest imaging technology with the depth and breadth of our existing coverage, we're able to de-risk exploration decisions and support our customers as they evaluate future opportunities in this highly prospective part of the Egyptian offshore."

The project is supported by industry funding.

Offshore Sao Tome and Príncipe is a challenging subsurface environment. (Image source: TGS)

Technology

The TESCOM RC-X motorised injection rate control valve. (Image source: Emerson)

Technology

Emerson has launched the TESCOM RC-X motorised injection rate control valve, which helps offshore refineries achieve accurate, repeatable chemical injection, reducing chemical waste, downtime and overall operating costs

Flow assurance is critical for offshore production facilities, especially as the industry moves to deeper water, longer tiebacks, deeper wells and higher temperature and pressure reservoirs, where conditions such as hydration, corrosion or the buildup of wax, asphaltene, scale and emulsion can restrict flow.

Chemical treatment can help mitigate these blockages, but there are dangers with over or under injection of chemicals. Over injection increases chemical consumption and resulting costs as well as additional field trips to replenish chemical storage tanks. It can also adversely impact downstream processing or treatment programmes and result in contamination penalties. Under injection can be ineffective, risking mechanical integrity and production output.

“Proper chemical dosing in deepwater and high-pressure/high-temperature refining environments can prevent blockages and flow instability, helping to ensure optimum fluid behaviour, protect asset integrity and stimulate production,” said Julia Villa, product marketing manager with Emerson´s fluid and motion control business, noting the TESCOM RC-X control valves enable accurate dosing that reduces downtime and chemical waste associated with over injection.

The value is specifically designed to work with Micro Motion Coriolis flow meters in offshore chemical injection processes, which deliver reliable flow measurement for liquids, gas or slurries.

Product features

  • Precise flow assurance - With a short-stroke design (less than 1/8 of an inch), TESCOM RC-X control valves are accurate up to 15,000 pounds per square inch (psi) and offer ultra-low flow rates of 0.02-500 liters per hour and repeatable function with 4-20 milliampere (mA) control
  • Electric actuation eliminates air requirements, an advantage when compressed air is unavailable or unreliable.
  • Available in medium- and high-pressure models
  • Lightweight and compact
  • Fewer moving parts than comparable products, reducing risk of mechanical failure over time, performing more consistently and requiring less maintenance.
  • Explosion-proof, waterproof (IP67-rated) and corrosion resistant (compliant to NACE MR0175).

 

SLB to deploy subsea production system for Rovuma development.

The new standard represents an important step towards optical modem interoperability for subsea systems. (Image source: SWiG)

Gas

First gas from NT-1 and NT-2 is targeted for December.

Gas

The giant Ntorya gas field development in Tanzania is anticipated to deliver vital domestic energy supplies, alleviate local energy poverty, and drive long-term industrial and economic growth for the country

Tanzanian government authorities have recognised the urgency of the project's advancement and to make sure there is no delay, an optimised timetable has been established in consultation with the joint venture partners involved in the field's development. Designed with an aim to achieve first gas production by December, the packed schedule includes critical well workovers, testing, and accelerated drilling. Fully funded field operations and pipeline infrastructure integration will prepare the site for production generation.

Aminex has reached an agreement on the sequencing and implementation of the Ntorya gas development following a meeting convened by the Tanzanian Ministry of Energy

Key stakeholders convene

Representatives of the Ministry of Energy, the Petroleum Upstream Regulatory Authority (PURA), the Tanzania Petroleum Development Corporation (TPDC), ARA Petroleum Tanzania Limited (APT), the operator of the Ruvuma PSA, and Aminex's wholly owned subsidiary, Ndovu Resources Limited (Ndovu) were present at the meeting.

While the government did not approve the operator's proposal to extend and delay the project timetable, it did confirm a revised implementation schedule with all the parties involved. This schedule comprises workover of the Ntorya-1 well (NT-1) in October, the testing of the Ntorya-2 well (NT-2) in November and the drilling of a newly planned NT-Central well (NT-C) in December.

First gas from NT-1 and NT-2 is targeted for December. Drilling of the Chikumbi-1 well (CH-1) is to proceed after NT-C is drilled. Following the change of management at ARA Petroleum LLC and a technical reappraisal of the Ntorya project, APT had proposed bringing forward NT-C, previously planned as a development well for a later phase of field development, in place of CH-1, with the drilling of CH-1 deferred. The revised implementation schedule plans to drill the NT-C first, followed by the drilling of CH-1.

It was also confirmed at the meeting that the Ntorya to Madimba pipeline will be completed in time to receive first gas from the Ntorya field in December 2026.

APT confirmed to the parties that it had all necessary funds to carry out the revised programme for the development of the Ntorya field.

The parties agreed that APT should execute the planned activities in accordance with the revised implementation schedule and without unnecessary delay. The revised programme will now be progressed through the formal Joint Venture approval process in accordance with the Joint Operating Agreement.

Economic impact of the project

Charles Santos, executive chairman of Aminex, said, "I would like to thank Dr James Mataragio, Permanent Secretary for Petroleum at the Ministry of Energy, for convening the meeting last week and for the constructive approach taken by all parties. Our focus now is on working together to implement the agreed programme and deliver first gas without further delay.

"The revised implementation programme establishes clear near-term operational milestones, targets first gas for December 2026 and provides for the drilling of a newly planned well, NT-Central, while ensuring that the CH-1 well is also drilled.

"Together, these activities form just the beginning of the development of the giant Ntorya field which is expected to deliver large volumes of gas supplies to Tanzanians, helping alleviate energy poverty, boost industrial development and fuel Tanzania's economic growth."

Puma Energy Ghana boosts LPG distribution through local partnerships.

The coming months will see a significant increase in operational activity at Ntorya.

Downstream

The consistent market launches come from optimised production.

Downstream

In line with Nigeria's strategy to expand reach in export market, the Nigerian National Petroleum Company Limited has globally released its new crude grade – Cawthorne 

With an API gravity of 36.4 that denotes the light and sweet kind, the Cawthorne crude rules global market demand because of its unmatched petrol and diesel yields. Comparable to Bonny Light, Cawthorne crude blend is the latest from Nigeria’s basket of crude grades, building on recent additions such as Nembe and Utapate. 

The consistent market launches come from optimised production, helping Nigeria to solidify its base in the export market with diverse offerings. The Cawthorne Floating Storage and Offloading (FSO) vessel, which is strategically positioned offshore Bonny, Rivers State for enhanced energy security and operational efficiency in easy crude evacuation from OML18, comprised the maiden 950,000 barrels cargo for export. Loaded on an MT Eburones vessel, it headed to the Netherlands, and unto the global market. 

As Nigeria aims to attain crude production of three million barrels per day and gas output to 12 billion cubic feet per day by 2030, the international launch of Cawthorne will unlock value from its asset base and deepen market competitiveness.

“This milestone reflects the direction we have set for NNPC Limited—one anchored on execution, partnership, and value creation. We are moving decisively from resource potential to resource monetisation, ensuring that every asset delivers measurable commercial outcomes.

"The successful export of the Cawthorne crude grade is not an isolated achievement; it is part of a broader, deliberate strategy to grow production, deepen market relevance, and strengthen Nigeria’s position as a reliable global energy supplier. We remain firmly focused on delivering sustainable growth in line with national objectives and global market expectations,” said Bashir Bayo Ojulari, Group Chief Executive Officer of NNPC Ltd, as he acknowledged President Bola Ahmed Tinubu’s leadership and OML 18 partners' strong collaboration in achieving the milestone. 

Technological innovation, strategic partnerships, and operational discipline will remain central to NNPC Limited's vision as the organisation works towards value creation from Nigeria's vast hydrocarbons resources.

 

 

The MoU was signed in China. (Image source: NNPC)

Africa’s refining landscape is diverging.

Event News

Energy leaders from across Africa will participate in the Strategic Conference. (Image source: dmg events)

Event News

The upcoming edition of ADIPEC 2026 will feature a strong contingent of African government leaders, underlining the continent's growing importance in shaping the future of global energy markets

Held under the patronage of His Highness Sheikh Mohamed Bin Zayed Al Nahyan, President of the United Arab Emirates, and hosted by ADNOC, ADIPEC 2026 will take place in Abu Dhabi from 2 to 5 November 2026, convening policymakers, industry executives, technology innovators and investors from around the world.

Senior ministers and energy leaders from across Africa are expected to participate in the event's Strategic Conference and high-level discussions, bringing perspectives from some of the world's fastest-growing energy markets. Their participation reflects increasing collaboration between African nations, the Middle East and international partners to expand energy access, attract investment and advance sustainable economic development.

Among the confirmed speakers are: Rt. Honourable Ekperikpe Ekpo, Nigeria's Minister of State for Petroleum Resources (Gas); Honourable James Opiyo Wandayi, Kenya's Cabinet Secretary for Energy and Petroleum; Honourable July Moyo, Zimbabwe's Minister of Energy and Power Development; and His Excellency Dr. Khalifa Rajab Abdulsadek, Libya's Minister of Oil and Gas.

Also participating are: His Excellency El Hadji Abdourahmane Diouf, Senegal's Minister of Energy and Petroleum; His Excellency Tiémoko Traoré, Mali's Minister of Energy and Water; and His Excellency Karim Badawi, Egypt's Minister of Petroleum and Mineral Resources. They will be joined by Proscovia Nabbanja, Chief Executive Officer of Uganda National Oil Company (UNOC), representing one of Africa's most closely watched emerging energy companies.

Africa is home to vast oil, gas and renewable energy resources and is expected to play a pivotal role in meeting rising global energy demand while supporting economic growth across the continent. Many countries are pursuing strategies that balance energy security, industrial development and emissions reduction, creating new opportunities for investment, technology deployment and cross-border collaboration.

At ADIPEC 2026, African leaders will engage with global decision-makers on topics including energy security, gas development, infrastructure investment, energy access, digitalisation and the pathways to a lower-carbon future. Their presence will reinforce ADIPEC's role as a leading platform for international dialogue and partnership, bringing together governments and industry to accelerate progress toward a more secure, affordable and sustainable energy system.

To register to attend ADIPEC 2026, visit https://www.adipec.com/

The event will convene the global energy industry in Abu Dhabi. (Image source: dmg events)

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