In The Spotlight
The ESIA approval will help advance pilot production activities. (Image source: Adobe Stock)
Invictus Energy Limited has announced that the Zimbabwe Environmental Management Agency (EMA) has approved the Environmental Social Impact Assessment (ESIA) for pilot production activities at the Cabora Bassa Project
Pilot production activities include the Eureka Gold Mine Gas-to-power Project and incorporates gas extraction, liquefaction, and transport from the Mukuyu gas field, as well as future extraction operations.
The approval provides a clear pathway for the commercialisation of gas resources from the Cabora Bassa Basin. Following the approval, the Company was issued with License No: L10000062291.
Invictus Energy managing director Scott Macmillan said, “The ESIA approval is a critical milestone for Invictus, and paves the way for the future development of the Mukuyu gas field and broader exploration license areas. We will now finalise pilot production planning, secure all necessary permits, and advance discussions with additional potential offtake partners.
Invictus remains committed to unlocking Zimbabwe’s gas potential and delivering long-term value to shareholders and the broader region.
I look forward to providing further updates as we advance these pilot production activities.”
Gas-to-power projects
The ESIA approval is a pivotal step towards the commencement of pilot production activities, including the Eureka Gold Mine gas-to-power project. This project is being developed in collaboration with Dallaglio (owner of Eureka Mine) and Himoinsa SA (onsite power generation provider to Eureka), leveraging Mukuyu’s gas resources to supply reliable and cost-effective power to the mine.
Invictus and Himoinsa SA have been actively engaging with various technology providers for gas processing, liquefaction, and logistics solutions to feed into the feasibility study, which is progressing in tandem. These engagements are aimed at identifying optimal technologies to maximise efficiency and commercial viability for the pilot production phase and subsequent large-scale development.
Initial Eureka gas-to-power project feasibility study results indicate a high look-through gas price exceeding US$10/GJ for gas-fired power generation, based on current grid tariff rates. This underscores the economic viability of the Mukuyu gas field as a strategic energy source for power generation in Zimbabwe and the broader region.
The ESIA expands on the initial 2019 assessment, which was one of the most extensive environmental studies ever undertaken in Zimbabwe. The 2019 study included rigorous field surveys and baseline measurements across multiple disciplines, including hydrology, ecology, environmental and archaeological assessments, hydrogeological and soil surveys, as well as socioeconomic and community consultations. Key stakeholders engaged during the assessment process included local leaders, relevant government ministries, and government extension offices.
The ESIA approval reinforces Invictus Energy’s commitment to responsible and sustainable resource development, ensuring compliance with stringent environmental and social governance (ESG) standards while advancing Zimbabwe’s domestic energy security.
The new wells are expected to produce around 220bn cubic feet of gas and 7 million barrels of condensate. (Image source: bp)
bp has announced the start of production ahead of schedule from the second development phase of the Raven field, part of the West Nile Delta (WND) project offshore Egypt
The project involves the subsea tieback of additional Raven infill wells to its existing onshore infrastructure. The new wells are expected to produce around 220bn cubic feet of gas and 7mn barrels of condensate. bp, the operator, holds an 82.75% stake in the project, with Harbour Energy owning the remaining 17.25%.
The WND Gas Development comprises a series of gas condensate fields located offshore Egypt, within the North Alexandria and West Mediterranean Deepwater concessions. The Raven field, the final phase of the WND project, has been in production since early 2021. Its initial phase included the development of eight subsea wells, located up to 65 km offshore, at water depths ranging from 550 to 700 m.
Nader Zaki, bp regional president for the Middle East and North Africa, commented, "Since January 2024, we have not stopped drilling for one day. The focus of the Raven Infills project has been to fight natural decline and increase production while maximising our existing infrastructure to meet Egypt’s domestic market demand at pace. This further demonstrates bp’s commitment to investing in Egypt, enabled by the unparalleled support and partnership with the Ministry of Petroleum, EGPC, and EGAS."
Earlier this month, bp announced it had successfully completed the drilling activity at the “El King-2” exploration well in the North King Mariout Offshore Concession as part of its WND drilling campaign. The well encountered two prospective Messinian reservoirs at a measured depth of approximately 2,400 m. Zaki commented at the time that bp is well-positioned to fast-track the development of the discovery with its existing infrastructure, execution capabilities and strategic partnerships with the Ministry of Petroleum.
bp is a leading energy investor in Egypt, where it has been operating for almost 60 years, with an investment of more than US$35bn. With its partners, it currently produces around 70% of Egypt’s gas through its gas development projects in the West and East Nile Delta.
bp says it is committed to maximising production from existing resources, exploring new opportunities to add new resources, and leveraging its existing infrastructure to support gas supply that meets growing domestic demand while strengthening Egypt’s position as a key energy partner in the region.
In December, bp and XRG (ADNOC’s international energy investment company) announced they had formed a new joint venture Arcius Energy (51% bp, 49% XRG). The JV will initially focus on gas development in Egypt, and includes interests assigned by bp across two development concessions, as well as exploration agreements.
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With this acquisition, UEG's current production will reach 39,000 boepd. (Image source: Adobe Stock)
To further expand its footprint in Egypt since Kuwait Energy acquisition in 2019, United Energy Group has signed a sale and purchase agreement with Apex International Energy LP to acquire its entire upstream assets via United Energy (MENA) Limited
A significant producer in the Western Desert of Egypt, Apex's area of operations spanned beyond 3,500 sq km, including eight onshore concessions. Its gross production count for 2024 stands at 11,000 barrels of oil equivalent per day (boepd).
Apex had acquired six of these concessions in 2023 from IEOC Production, a unit of Eni. It included IEOC’s interests in the Ras Qattara, West El Razzak, East Kanayis, and the West Abu Gharadig concessions. The company had made the acquisition to see its first gas production, and become a front runner in the booming Egyptian natural gas industry.
With this acquisition, UEG's current production count of 22,000 boepd will shoot up to 39,000 boepd, adding to its existing interests in five concessions. Besides production optimisation, this move also highlights the company's focus on asset integration to have greater control over field development before exploration. Enhanced oil recovery with strong technical support will be the company's watchword to chase growth potential in its Egyptian acreage. The acquisition will allow UEG to advance regional integration to solidify its global energy supply chain, which will also benefit Egypt's energy industry.
With the merger agreements now approved by the Egyptian Cabinet, UEG is looking forward to better fiscal terms, increased investment, greater economic potential and long-term value creation.
Extensive deepwater data from PGS
Egypt continues to be a coveted exploration spot globally, especially to harness its gas resources. Last year, geoscience data provider PGS had released 3D seismic data over the deepwater area between the Nile delta and the Herodotus Basin as part of its EGY23 Merneith & Luxor survey.
Acquired with Ramform vessels and GeoStreamer broadband technology, the 6,175 sq km EGY23 Merneith & Luxor survey draws on the expertise of PGS's partners the Egyptian Natural Gas Holding Company (EGAS). The GeoStreamer-acquired data covers both low and high-frequency information that can make a huge difference in interpreting structures and analysing rock property.
The survey cracked into an underexplored and unlicensed deepwater area and extracted 3D data from the region, marking a significant upgrade from the currently available 2D data.
A Messinian evaporite layer of variable thickness extends across most of the area. The survey is tied to the Kiwi-1 well, one of the few wells in this deepwater area, and primary targets are likely to be presalt Oligo-Miocene structures with clastic reservoirs.
Cutting emissions from flaring significantly reduces Algeria’s contribution to global warming. (Image source: Adobe Stock)
The implementation of advanced flare gas measurement systems unlocks numerous opportunities for Algeria that could enhance its economic and environmental standing
Among these benefits are:
• Capturing and exploiting flared gas could contribute an estimated US$3bn annually to Algeria’s economy, according to sources such as the World Bank and the International Energy Agency. This substantial revenue has the potential to support renewable energy projects, infrastructure development, and public services, creating both immediate and long-term benefits for the nation.
• Compliance with international sustainability standards ensures Algeria’s gas remains competitive in export markets, particularly Europe. Non-compliance with CBAM regulations could lead to higher tariffs, undermining Algeria’s position.
• Cutting emissions from flaring significantly reduces Algeria’s contribution to global warming. This is particularly vital for Algeria, which has already faced documented environmental challenges such as prolonged droughts, advancing desertification, and diminishing water resources. By addressing these environmental pressures, Algeria is not only safeguarding its natural ecosystems but also ensuring a more sustainable future for its population.
• Reducing flaring enhances local air quality by lowering exposure to pollutants. Studies by organisations such as the World Health Organization (WHO) have linked the impact of volatile organic compounds (VOCs) from flaring on the degradation of air quality leading to higher rates of long-term respiratory and cardiovascular illnesses for nearby populations.
Turning Algeria’s ambitions into action requires collaboration, and one tangible aspect of this is Fluenta’s partnership with Segitec, a leading provider of instrumentation solutions in North Africa. Segitec’s deep regional expertise ensures Fluenta’s technology is accessible and supported across Algeria.
Together, Segitec and Fluenta play a vital role in supporting Algeria’s operators to meet emissions goals and positioning the country as a regional leader in sustainable energy practices. With third-party investment playing a crucial role in funding flare reduction projects, partnerships like these provide the infrastructure and credibility Algeria needs to attract private capital.
Algeria’s ambitious climate targets and hands-on approach to emissions reduction position it as a clear leader in North Africa’s energy transition. Embracing innovative technologies, strengthening regulatory frameworks, and fostering strategic partnerships sets a benchmark for how oil and gas-producing nations can align economic development with environmental stewardship.
The long-term benefits of sustainable energy practices is significant not just for the environment but also for the country’s economic resilience. As one of Africa’s leading energy producers, Algeria’s progress shows that even resource-dependent economies can combine greener, more efficient practices with lofty industrial ambitions.
Sustainability and competitiveness are no longer mutually exclusive. The ability to balance a high growth in energy production with stringent environmental standards underscores Algeria's position as a key player in the transition to a low-carbon future.
This is the second of a two-part article. Read the first part here.
Fluenta is able to function in extreme environments. (Image source: Adobe Stock)
Algeria, the fifth-largest gas flaring country in the world, is taking significant steps to transform its energy sector and meet its Paris Agreement pledge to cut greenhouse gas (GHG) emissions by 22% by 2030
Gas flaring alone accounts for an annual loss of 9.3 bn cu/m — equivalent to 1% of Algeria’s GDP, according to a World Bank report. The stakes are both environmental and economic, placing the country at a pivotal moment as it seeks to balance energy production with sustainability in a way that could redefine regional standards.
Flaring in Algeria produces approximately 150 million tonnes of CO₂-equivalent gases annually, according to FlareIntel, which exceeds that of many neighbouring countries, emphasising the urgency for reform.
Historically, Algeria has struggled to curb flaring due to limited infrastructure and inconsistent enforcement of regulations. However, global pressures, rising scrutiny on methane emissions, and self-policing initiatives have created fresh incentives to accelerate decarbonisation.
In 2023, Algeria achieved the largest reduction in flaring globally, cutting flare volumes by 0.4bn cu/m — a 5% decrease. While oil production fell by 2%, flaring intensity dropped by 3%, continuing a three-year trend of improvement.
SONATRACH, Algeria’s national oil company, has played a pivotal role by implementing flare gas recovery projects in Hassi Messaoud, the country’s largest oil field. In 2023, the company expanded its initiatives to include new projects in Tiguentourine, Ohanet, and Tin-Fouye-Tabankort, laying the groundwork for further reductions in flare volumes.
Algeria is turning to advanced technologies like Fluenta’s ultrasonic flare gas measurement systems, which provide reliable and actionable data. These systems enable operators to close the loop on mass balance calculations, and deliver accurate and reliable emissions reporting, including flare gas destruction removal efficiency (DRE).
Traditional metering systems such as thermal mass and others struggle with flare gas due to its unpredictable composition, rapid velocity changes, and extreme temperatures. Fluenta’s technology is specifically designed to overcome these challenges, delivering accurate measurement even in the most volatile conditions. By integrating flow rate data with gas composition analysis, operators gain deeper insight into their emissions profiles, allowing for more effective management and reduction strategies.
One of Fluenta’s key advantages is its ability to function in extreme environments, such as Algeria’s high-temperature oil and gas fields. This resilience ensures uninterrupted accuracy, even during peak operations or equipment stress. With access to real-time data, operators can optimise combustion efficiency, identify inefficiencies, and reduce unnecessary flaring.
Improved flare gas measurement strengthens Algeria’s position in global energy markets. As international buyers increasingly demand transparency and sustainability, advanced monitoring systems help ensure Algeria’s gas remains competitive—particularly in Europe, where emissions regulations are tightening. This is especially crucial in the wake of geopolitical shifts that have reshaped global energy supply chains.
Fluenta’s ultrasonic measurement systems enable operators to move beyond regulatory compliance toward proactive emissions management. By combining flow rate and gas composition data, they help identify fugitive emissions, detect inefficiencies across upstream processes, and optimise overall plant performance. Rather than simply minimising flaring, these insights allow operators to improve resource efficiency, reduce waste, and enhance production throughput—advancing both Algeria’s sustainability goals and its economic ambitions.
This is the first of a two-part article. Read the second part here.
Tullow will use Opsealog's tools to track vessels. (Image source: Opsealog)
Tullow Oil has initiated a digitalisation drive for its offshore assets in Ghana with the support of Opsealog, a data integration and analysis services provider
“This partnership with Opsealog marks an important step in the digitalisation of our marine operations, equipping our teams with granular, data-driven insights to improve the performance of our fleet and reduce our environmental footprint. This ability to leverage data to benchmark, report and boost our efficiency is essential to our strategic vision of building a better future through responsible oil and gas development in Africa,” said Samuel Kwesi Dickson, head of logistics, Tullow.
Tullow's offshore assets in Ghana include four platform supply vessels (PSVs) and anchor handling tug supply (AHTS) vessels. With Opsealog's data integration and performance platform, Marinsights, Tullow can accurately track the vessels on multiple levels, from fuel to freshwater, and also monitor crew certificates. The data aqcuired following these trackings will help Tullow to not only optimise fuel consumption, but also reduce greenhouse gas emissions.
Digital monitoring with Opsealog's Streamlog will eliminate the risks of duplicated input, while streamlining data collection for weekly, monthly, and yearly reports. This will save Tullow crew time, and ensure forecasting and cost tracking.
“This project is a great example of how data and fuel efficiency expertise can work together towards sustainability objectives. It empowers Tullow Oil Ghana’s onshore teams with the right data to deliver high-value analysis and inform strategic decision-making to improve the utilisation of their assets. We are proud to be part of this initiative, which optimises several operational aspects, from fuel efficiency to crew management,” said Briac Lemee, business development manager at Opsealog.
4D seismic monitoring in Jubilee
Tullow's assets in Ghana includes the Jubilee and TEN fields, in both of which it holds interests with operatorship status.
In Jubilee, the company has initiated 4D seismic monitoring under a contract with Shearwater Geoservices Holding AS.
The two-month survey is set to begin this year, utilising capacity from Shearwater’s high-end fleet, supported by the company’s state-of-the-art technology offering and extensive operational experience. This will be the first contract conducted by Shearwater Ghana, in conjunction with local partner Destra Energy; and will include considerable local content participation.
“Our leading towed streamer technology is an ideal fit for the Jubilee field, enabling repeatable surveys to provide Tullow and partners with high-quality data in support of better-informed reservoir optimisation. We look forward to executing this project as part of our long-standing commitment to our clients in Ghana and West Africa,” said Irene Basili, CEO of Shearwater.
Africa will see significant frontier drilling this year. (Image source: Westwood)
Energy intelligence provider, Westwood, has identified Namibia's Orange Basin to remain the most anticipated region as high-impact exploration continues in 2025
The research indicates this year to be stable in terms of global high-impact exploration drilling, with 65-75 wells expected to be completed, compared to the 69 completed in 2024.
Of the 21 frontier wells that are expected this year, a considerable number will come from Africa. With 19 such wells drilled in 2024, frontier drilling is set to see a slight increase in 2025.
Africa is predicted to see heightened drilling activity, with 14 wells lined up for the year. Around 7-10 wells that will be drilled in the Orange Basin in 2025 will seal the fate for the region which has been generating huge global anticipation since the Venus discovery in 2022. Some of the key wells from the region include Olympe-1X and Sagittarius-1X, among others.
While Chevron stands second right after QatarEnergy as the most active explorer for the year, targetting seven wells, it was off to a bumpy start with the first two wells – Egypt (Khendjer) and Namibia (Kapana) – turning up dry holes.
Shell, too, seemed to have little luck in petroleum exploration license 39 (PEL39) in Orange Basin, which the company declared a write down of approximately US$400mn. 'While we recognise that extracting the discovered resources presents challenges, the extensive data collected shows that there remain opportunities. Together with our partners, we are continuing to explore potential commercial pathways to development, while actively looking for further exploration opportunities in Namibia', read a statement from the company.
The back-to-back unsuccessful experiences in the Orange Basin by two majors have left the rest of the players in the region apprehensive, awaiting the next turn of events with bated breath.
Growing interests from global exploration and production companies, however, have set off a whole new oil & gas ecosystem in the region, with tech giants Halliburton and Baker Hughes opening facilities, and high stakes logistics contracts coming into effect.
Key wells to watch
In other parts of Africa, Azule Energy will be drilling the Kianda-1 well in the outboard area of the Congo Basin, Angola in the second half of the year, with other potentially high impact wells being drilled offshore in the Namibe, Rio Muni and Tano basins, as well as potential frontier onshore tests in the Cabora Bassa and Kavango basins.
Elektra is currently drilling, and testing a significant extension of the Nile Delta Miocene play and Pegasus is testing the emerging Cretaceous carbonate play. Matsola offshore Libya, which lies at an extension of the Sirte Basin, is also an important well that will undergo testing.
Westwood is closely watching the developments in Herodotus Basin offshore Egypt as well.
With this acquisition, UEG's current production will reach 39,000 boepd. (Image source: Adobe Stock)
To further expand its footprint in Egypt since Kuwait Energy acquisition in 2019, United Energy Group has signed a sale and purchase agreement with Apex International Energy LP to acquire its entire upstream assets via United Energy (MENA) Limited
A significant producer in the Western Desert of Egypt, Apex's area of operations spanned beyond 3,500 sq km, including eight onshore concessions. Its gross production count for 2024 stands at 11,000 barrels of oil equivalent per day (boepd).
Apex had acquired six of these concessions in 2023 from IEOC Production, a unit of Eni. It included IEOC’s interests in the Ras Qattara, West El Razzak, East Kanayis, and the West Abu Gharadig concessions. The company had made the acquisition to see its first gas production, and become a front runner in the booming Egyptian natural gas industry.
With this acquisition, UEG's current production count of 22,000 boepd will shoot up to 39,000 boepd, adding to its existing interests in five concessions. Besides production optimisation, this move also highlights the company's focus on asset integration to have greater control over field development before exploration. Enhanced oil recovery with strong technical support will be the company's watchword to chase growth potential in its Egyptian acreage. The acquisition will allow UEG to advance regional integration to solidify its global energy supply chain, which will also benefit Egypt's energy industry.
With the merger agreements now approved by the Egyptian Cabinet, UEG is looking forward to better fiscal terms, increased investment, greater economic potential and long-term value creation.
Extensive deepwater data from PGS
Egypt continues to be a coveted exploration spot globally, especially to harness its gas resources. Last year, geoscience data provider PGS had released 3D seismic data over the deepwater area between the Nile delta and the Herodotus Basin as part of its EGY23 Merneith & Luxor survey.
Acquired with Ramform vessels and GeoStreamer broadband technology, the 6,175 sq km EGY23 Merneith & Luxor survey draws on the expertise of PGS's partners the Egyptian Natural Gas Holding Company (EGAS). The GeoStreamer-acquired data covers both low and high-frequency information that can make a huge difference in interpreting structures and analysing rock property.
The survey cracked into an underexplored and unlicensed deepwater area and extracted 3D data from the region, marking a significant upgrade from the currently available 2D data.
A Messinian evaporite layer of variable thickness extends across most of the area. The survey is tied to the Kiwi-1 well, one of the few wells in this deepwater area, and primary targets are likely to be presalt Oligo-Miocene structures with clastic reservoirs.
Africa will see significant frontier drilling this year. (Image source: Westwood)
The upcoming licensing round will promote new acreage. (Image source: Adobe Stock)
The Seismic License provides Woodside ongoing rights to the PEL 87 3D seismic data. (Image source; Adobe Stock)
Pancontinental Energy NL has delivered the Seismic License for PEL 87 offshore Namibia to Woodside Energy following relevant approval from the Namibian authority
The Seismic License provides Woodside ongoing rights to the PEL 87 3D seismic data, the acquisition and processing of which was funded by it. While Pancontinental Orange Pty Ltd holds 75% operatorship in the PEL 87 Joint Venture, there is an exclusive scope for Woodside to derive over a 56% participating interest from Pancontinental’s shares.
Pancontinental, on the other hand, has an option over a 1% participating interest to be derived from the 15% share exercised by Custos Investments (Pty) Ltd.
The Seismic License delivery marks the origin of the 180 days-long Long Stop Date which is 18 May 2025, when Woodside Energy may exercise its option to farmin to PEL 87.
Orange Basin
Besides Pancontinental and Custos, the National Petroleum Corporation of Namibia (NAMCOR) owns a 10% interest in the PEL 87 Joint Venture.
PEL 87 belongs in the Orange Basin which keeps giving, with latest light oil discovery reported in March from Mopane in PEL 83.
PetroVision will facilitate operations within Nigeria using DUG Insight software. (Image source: Adobe Stock)
This expansion will add 2,248 sq km of 3D data. (Image source: TGS)
Tullow will use Opsealog's tools to track vessels. (Image source: Opsealog)
Tullow Oil has initiated a digitalisation drive for its offshore assets in Ghana with the support of Opsealog, a data integration and analysis services provider
“This partnership with Opsealog marks an important step in the digitalisation of our marine operations, equipping our teams with granular, data-driven insights to improve the performance of our fleet and reduce our environmental footprint. This ability to leverage data to benchmark, report and boost our efficiency is essential to our strategic vision of building a better future through responsible oil and gas development in Africa,” said Samuel Kwesi Dickson, head of logistics, Tullow.
Tullow's offshore assets in Ghana include four platform supply vessels (PSVs) and anchor handling tug supply (AHTS) vessels. With Opsealog's data integration and performance platform, Marinsights, Tullow can accurately track the vessels on multiple levels, from fuel to freshwater, and also monitor crew certificates. The data aqcuired following these trackings will help Tullow to not only optimise fuel consumption, but also reduce greenhouse gas emissions.
Digital monitoring with Opsealog's Streamlog will eliminate the risks of duplicated input, while streamlining data collection for weekly, monthly, and yearly reports. This will save Tullow crew time, and ensure forecasting and cost tracking.
“This project is a great example of how data and fuel efficiency expertise can work together towards sustainability objectives. It empowers Tullow Oil Ghana’s onshore teams with the right data to deliver high-value analysis and inform strategic decision-making to improve the utilisation of their assets. We are proud to be part of this initiative, which optimises several operational aspects, from fuel efficiency to crew management,” said Briac Lemee, business development manager at Opsealog.
4D seismic monitoring in Jubilee
Tullow's assets in Ghana includes the Jubilee and TEN fields, in both of which it holds interests with operatorship status.
In Jubilee, the company has initiated 4D seismic monitoring under a contract with Shearwater Geoservices Holding AS.
The two-month survey is set to begin this year, utilising capacity from Shearwater’s high-end fleet, supported by the company’s state-of-the-art technology offering and extensive operational experience. This will be the first contract conducted by Shearwater Ghana, in conjunction with local partner Destra Energy; and will include considerable local content participation.
“Our leading towed streamer technology is an ideal fit for the Jubilee field, enabling repeatable surveys to provide Tullow and partners with high-quality data in support of better-informed reservoir optimisation. We look forward to executing this project as part of our long-standing commitment to our clients in Ghana and West Africa,” said Irene Basili, CEO of Shearwater.
Leucipa will help optimise well performance. (Image source: Baker Hughes)
Africa Performance Centre is a collaborative hub. (Image source:
The ESIA approval will help advance pilot production activities. (Image source: Adobe Stock)
Invictus Energy Limited has announced that the Zimbabwe Environmental Management Agency (EMA) has approved the Environmental Social Impact Assessment (ESIA) for pilot production activities at the Cabora Bassa Project
Pilot production activities include the Eureka Gold Mine Gas-to-power Project and incorporates gas extraction, liquefaction, and transport from the Mukuyu gas field, as well as future extraction operations.
The approval provides a clear pathway for the commercialisation of gas resources from the Cabora Bassa Basin. Following the approval, the Company was issued with License No: L10000062291.
Invictus Energy managing director Scott Macmillan said, “The ESIA approval is a critical milestone for Invictus, and paves the way for the future development of the Mukuyu gas field and broader exploration license areas. We will now finalise pilot production planning, secure all necessary permits, and advance discussions with additional potential offtake partners.
Invictus remains committed to unlocking Zimbabwe’s gas potential and delivering long-term value to shareholders and the broader region.
I look forward to providing further updates as we advance these pilot production activities.”
Gas-to-power projects
The ESIA approval is a pivotal step towards the commencement of pilot production activities, including the Eureka Gold Mine gas-to-power project. This project is being developed in collaboration with Dallaglio (owner of Eureka Mine) and Himoinsa SA (onsite power generation provider to Eureka), leveraging Mukuyu’s gas resources to supply reliable and cost-effective power to the mine.
Invictus and Himoinsa SA have been actively engaging with various technology providers for gas processing, liquefaction, and logistics solutions to feed into the feasibility study, which is progressing in tandem. These engagements are aimed at identifying optimal technologies to maximise efficiency and commercial viability for the pilot production phase and subsequent large-scale development.
Initial Eureka gas-to-power project feasibility study results indicate a high look-through gas price exceeding US$10/GJ for gas-fired power generation, based on current grid tariff rates. This underscores the economic viability of the Mukuyu gas field as a strategic energy source for power generation in Zimbabwe and the broader region.
The ESIA expands on the initial 2019 assessment, which was one of the most extensive environmental studies ever undertaken in Zimbabwe. The 2019 study included rigorous field surveys and baseline measurements across multiple disciplines, including hydrology, ecology, environmental and archaeological assessments, hydrogeological and soil surveys, as well as socioeconomic and community consultations. Key stakeholders engaged during the assessment process included local leaders, relevant government ministries, and government extension offices.
The ESIA approval reinforces Invictus Energy’s commitment to responsible and sustainable resource development, ensuring compliance with stringent environmental and social governance (ESG) standards while advancing Zimbabwe’s domestic energy security.
The new wells are expected to produce around 220bn cubic feet of gas and 7 million barrels of condensate. (Image source: bp)
Cutting emissions from flaring significantly reduces Algeria’s contribution to global warming. (Image source: Adobe Stock)
Diesel, petrol and kerosene were delivered. (Image source: NNPC)
The Nigerian National Petroleum Company (NNPC) Ltd has restreamed the Port Harcourt Refining Company (PHRC), commencing crude oil processing from the plant for the delivery of petroleum products into the market
The NNPC group chief executive officer, Mele Kyari, announced the development, expressing his gratitude to all stakeholders involved, and marked the occasion as an era of energy independence and economic growth for the country.
Products delivered included premium motor spirit (PMS), automotive gas oil (AGO) and household kerosene (HHK), among others.
The PHRC rehabilitation project, is an engineering, procurement, construction, installation and commissioning (EPCIC) project that is aimed at restoring the refinery to full functionality and renewal.
Claus Reimers, chief product and technology officer at Akselos. (Image source: Adobe Stock)
The Cabinda Refinery aims to double capacity to 60,000 bpd. (Image source: Adobe Stock)
The event will delve into regional success stories. (Image source: EAECS)
The East Africa Energy Cooperation Summit (EA-ECS), taking place 29-30 January in Arusha, Tanzania, will be uniting the region's energy independent poiwer producers (IPPs) and engineering, procurement, construction and financing contract (EPCF) stakeholders to discuss the region's investment potential and innovations taking place in the industry
The event will delve into the success stories, including the Ethiopia-Kenya electricity highway, highlighting the role of cross-border collaboration for economic and social development.
Led by Ministers from across the EAC and large-scale energy users, over two days, the Arusha Summit will deep dive into opportunities for the private sector, advocating for a diversified energy mix to maintain grid stability to support major industrial growth, as well as C&I generation.
“Energy is a pillar for development and growth and is crucial for the functioning of the economies of the EAC Partner States. The East Africa Energy Cooperation Summit will serve as the ideal platform for advancing projects and bringing tangible changes in the industry,” said Andrea Malueth, deputy secretary general (Infrastructure, Productive, Social & Political Sectors), East African Community Secretariat.
“Ten years from now, the EAC’s middle classes will have more job stability, more opportunities, and more disposable income than ever before. New railways, industries, ports, and tourism will position the region as the number one investment destination globally, taking the title back from both parts of Asia and Latin America,” said Elisa Palmioli, producer, EnergyNet, which is organising the event.
Libya is the next investment destination. (Image source: African Energy Chamber)
ADSW Summit 2025 to accelerate global sustainable development. (Image source: ADSW)
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Umar Ajiya, chief financial officer, NNPC. (Image source: NNPC)
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Latest news
The ESIA approval will help advance pilot production activities. (Image source: Adobe Stock)
The new wells are expected to produce around 220bn cubic feet of gas and 7 million barrels of condensate. (Image source: bp)
With this acquisition, UEG's current production will reach 39,000 boepd. (Image source: Adobe Stock)
Cutting emissions from flaring significantly reduces Algeria’s contribution to global warming. (Image source: Adobe Stock)
Fluenta is able to function in extreme environments. (Image source: Adobe Stock)
Tullow will use Opsealog's tools to track vessels. (Image source: Opsealog)
Africa will see significant frontier drilling this year. (Image source: Westwood)
The upcoming licensing round will promote new acreage. (Image source: Adobe Stock)
68% of methane emissions stem from upstream facilities. (Image source: Adobe Stock)
2025 brings an exciting programme of exploration activities for Impact. (Image source: Impact Oil & Gas)
Leucipa will help optimise well performance. (Image source: Baker Hughes)
The acquisition in Algeria will enhance PTTEP’s petroleum reserves. (Image source: PTTEP)
NAOC acquisition has been a key highlight for the company in 2024. (Image source: Adobe Stock)
The Naingopo well has reached a total depth of 4,184 metres. (Image source: Adobe Stock)
The partners will explore the Damara Fold Belt and Rift Basin plays. (Image source: Adobe Stock)
Africa Performance Centre is a collaborative hub. (Image source:
Congo's Hydrocarbons Code which puts Congolese nationalists first. (Image source: Adobe Stock)
The event will delve into regional success stories. (Image source: EAECS)
Algeria has six onshore blocks currently in offer. (Image source: Adobe Stock)
The new Trump regime might see increased US reach in Africa's oil and gas scene. (Image source: Energy Capital & Power)
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Tullow will use Opsealog's tools to track vessels. (Image source: Opsealog)
Leucipa will help optimise well performance. (Image source: Baker Hughes)
Africa Performance Centre is a collaborative hub. (Image source:
Virtual reality has emerged as a cost-effective option. (Image source: Adobe Stock)
According to Expro, the contract demonstrates its ability to provide technical solutions across the entire well lifecycle. (Image source: Expro)
This is the first project to use Subsea 2.0 configure-to-order solution. (Image source: Adobe Stock)
The new solution extends SLB's autonomous drilling capabilities. (Image source: SLB)
Intelli suite of diagnostic well intervention wireline logging services. (Image source: Halliburton)
The high-pressure radial shaft seal portfolio. (Image source: Trelleborg Sealing Solutions)
The agreement signing. (Image source: Kent)
The facilities employ company-trained local workers. (Image source: Adobe Stock)
Soudotec will initiate an inventory programme. (Image source: Svanehoj)