In The Spotlight
The sale of its Kenya subsidiary marks Tullow’s exit from the country after 14 years.
Tullow Oil plc has completed the sale of its entire working interest in Kenya to Auron Energy E&P Limited, an affiliate of Gulf Energy Ltd, following satisfaction of all conditions precedent under the previously announced Sale and Purchase Agreement
Tullow has received the full proceeds of Tranche A (US$40mn) under the terms of the SPA. The transaction represents the sale of 100% of the shares in Tullow’s subsidiary Tullow Kenya BV, which holds Tullow’s entire working interests in Kenya, for a minimum cash consideration of US$120mn, subject to customary adjustments. The transaction proceeds will be used to strengthen Tullow’s balance sheet.
The sale of its Kenya subsidiary marks Tullow’s exit from the country after 14 years. Tullow retains royalty payments, subject to certain conditions, and a no cost back-in right for a 30% participation in potential future development phases.
Ian Perks, CEO of Tullow, said, “The successful completion of this transaction marks a significant milestone for the company and the achievement of another one of our key 2025 strategic priorities. The use of proceeds helps to further strengthen our balance sheet and I would like to thank the team for their hard work and commitment, which have helped position the company strongly as we look to refinance our capital structure this year.
"On behalf of everyone at Tullow, I extend our best wishes to the people and Government of Kenya and wish Gulf Energy every success as they advance this project.”
Paul Limoh, CEO, Gulf Energy Ltd, said, “We are delighted to complete this transaction and to bring these assets under the stewardship Gulf Energy Ltd. This project will play an important role in advancing Kenya’s domestic energy sector, creating opportunities for growth and development in the Turkana region, as well as supporting the country’s long-term energy security. We thank Tullow for its years of investment and commitment, and we look forward to building on that foundation as we work with partners and stakeholders to take the project forward.”
The technology provides a lightweight offline intervention solution.
In a first divestment development for FrontRow Energy Technology Group, its subsidiary, WellSense, a rapid fibre-optic well diagnostics provider, has sold FiberLine Intervention licence to oilfield services company, Halliburton
The agreement terms secure a global licence for Halliburton to deploy WellSense FiberLine Intervention (Fli) technology for use in well stimulation monitoring.
A FrontRow Energy Technology Group company, WellSense, will continue to deploy the technology globally for all other oil and gas applications, including well plug and abandonment (P&A), well integrity and leak detection, as well as carbon capture, utilisation and storage (CCUS).
Annabel Green, CEO of WellSense, said, “The successful completion of this deal is a defining moment for WellSense and for our parent company, FrontRow Energy Technology Group. Not only is it a strong industry endorsement of our technology and the value it delivers, but also our business model of bringing new and innovative solutions to market.
“Our unique bare fibre dynamic despooling technology delivers superior data quality for a detailed subsurface understanding. Unlike other well monitoring techniques it provides a lightweight offline intervention solution with disposable probes for significant efficiency savings and reduced risk.
“Meeting the complex challenges of upstream oil and gas requires the adoption of technologies that fundamentally improve how the industry operates. This agreement is the result of a decade of focused innovation, collaboration and delivery and I would like to extend my sincere thanks to all our employees, past and present, whose dedication has built the strong foundation that made this success possible.”
Steve Kent, CEO of FrontRow, said,“This deal is a major milestone for FrontRow and is a clear example of how UK-born innovation can solve industry challenges and attract global attention.
“This is FrontRow’s first commercial licence sale and a landmark in our journey. It demonstrates that innovation, when nurtured with the right expertise and support, can deliver technical success as well as real commercial value.”
The new system support remote operations. (Image source: FET)
Forum Energy Technologies has launched its next generation remotely operated vehicle (ROV) control system – ICE Unity
The system, introduced in response to the growing demand for data and control access from outside the main control system, can be rolled out across FET’s range of ROVs, which support underwater industry applications globally. It is compatible with the latest sensors and tooling.
Key features of ICE Unity include:
• A modern user interface with physical and touchscreen controls;
• One common user interface across different ROVs, minimising operator training;
• Network connectively which allows for remote operations as well as live streaming of survey data, and system monitoring.
Network connectively also enables machine learning, predictive maintenance, and remote support and updates.
Kevin Taylor, FET’s vice president operations – Subsea, said, “ICE Unity brings together innovation with seamless collaboration. This a step change in ROV controlling, bringing immense time and cost-saving benefits by enabling remote operations from outside the core control system.
“One major benefit is the ability to monitor performance remotely and reduce downtime by allowing the replacement of components when needed rather than using fixed maintenance intervals.”
The agreement comes with a signature bonus of US$12mn. (Image source: NOCAL)
After TotalEnergies, Atlas/Oranto Petroleum has closed four production sharing contracts with the Government of the Republic of Liberia
The agreement comes with a signature bonus of US$12mn, with the international oil company securing exploratory rights over four offshore blocks: LB-15, LB-16, LB-22, and LB-24, each with an estimated investment value of US$200mn.
Atlas Petroleum International and Oranto Petroleum, sister companies established in 1991, are recognised for having one of Africa’s largest exploration portfolios, holding 22 licenses across more than 11 countries. With current production of approximately 18,000 barrels of oil per day from assets in Equatorial Guinea, Nigeria, and Venezuela, the group maintains a strategic balance between production and frontier exploration.
Their expansive portfolio encompasses deepwater, shallow water, and onshore acreage in key African markets, including Uganda, Zambia, and Senegal. Notably, in Equatorial Guinea, Atlas/Oranto has committed over US$350mn to the Alen Unit “backfill” gas monetisation project in partnership with global energy players such as Noble Energy, Glencore and Gunvor.
Beyond upstream operations, the group has demonstrated a strong commitment to local content and capacity building. In Uganda, Atlas/Oranto has invested in initiatives designed to empower local enterprises to participate in the oil and gas value chain.
The divestment is in line with Eni's strategy of upstream portfolio optimisation.
Eni has divested 30% of its stake in the Baleine project in Cote d’Ivoire to Vitol
The shares in this significant offshore development now stands at 47.25% for Eni, 30% for Vitol, and 22.75% for Petroci.
The divestment is in line with Eni's strategy of upstream portfolio optimisation by accelerating the monetization of exploration discoveries through the divestment of equity stakes, a model known as the "dual exploration model."
This transaction adds to OTCP and Block 4 in Ghana, projects in West Africa that have already established long-standing collaboration between Eni and Vitol.
Eni has been present in Cote d’Ivoire since 2015. Baleine is Eni’s first development in the country, and the first net-zero development in Africa. The giant Baleine field was discovered in 2021, two decades after the last commercial discovery in the country and it achieved production in record time, in 2023. Currently, Baleine produces over 62.000 barrels of oil and more than 75 million cubic feet of gas per day from Phases 1 and 2. With the launch of Phase 3, production is expected to rise to 150,000 barrels of oil and 200 million cubic feet of gas per day, positioning Baleine as a cornerstone in meeting the country's domestic energy needs.
Global energy and commodities company, Vitol, has enjoyed a well established presence in West Africa since several years.
Pharos will retain a 45% working interest in the Consolidated Concession.
Pharos Energy has received approval from the Executive Board of the Egyptian General Petroleum Corporation (EGPC) for the consolidation of the El Fayum and North Beni Suef Concession Agreements into a new consolidated concession agreement
Pharos will retain a 45% working interest in the Consolidated Concession, with IPR Lake Qarun Company continuing as operator with a 55% working interest. In addition to the 12 development leases of the EF and NBS concessions, the Consolidated Concession will include three new exploration areas.
Katherine Roe, chief executive officer, said, "The approval by EGPC's Executive Board of the new Consolidated Concession is a significant milestone for our Egyptian business. The improved fiscal terms have the potential to unlock long-term value for all stakeholders and drive organic growth opportunities across the concession areas. I would like to thank IPR's and Pharos's in-country teams for their tenacity and diligence in concluding negotiations, and the Egyptian authorities for their positive engagement throughout the process. We look forward to planning the start of our drilling campaign to increase production."
The Consolidated Concession will unlock significant value in the Western Desert by improving certain fiscal terms, extending the duration of the licenses, and committing the Contractor parties (Pharos Group and IPR) to additional work programmes to deliver production growth. Based on Pharos' Competent Person's Reports ("CPR") as at 31 December 2024, the Consolidated Concession could result in moving 3.1 MMstb from contingent resources to 2P reserves, or a 25% increase from year-end 2024, net to Pharos working interest.
The Consolidated Concession is subject to customary approvals and to Egyptian Parliamentary ratification, which is expected to take place in late 2025 or early 2026, but the new set of terms will start imminently.
The improved terms of the Consolidated Concession reset our investment into the assets in order to unlock further value.
Stryde’s technology offers true scalability for large-scale seismic acquisition. (Image source: Stryde)
Exploration services company, Argas, has purchased 30,000 Range+ STRYDE nodes and Stryde’s Nimble Seismic System, marking the first-ever deployment of nodal technology for onshore seismic acquisition in Egypt
The first deployment of the newly acquired Stryde system will be on a very large 2D seismic survey in Egypt. The technology will be used to acquire high-quality seismic data across highly prospective sedimentary basins, supporting oil and gas exploration efforts in one of Egypt’s most promising frontier regions.
Impressed by its cost-efficiency and operational agility, Argas made the strategic decision to integrate Stryde’s technology into its operations.
Stryde’s technology offers true scalability for large-scale seismic acquisition. Its ultra-lightweight Range+ nodes, coupled with a state-of-the-art, high-capacity charging, harvesting, and QC ecosystem, enable thousands of nodes to be rotated daily.
This ensures faster acquisition cycles and rapid delivery of high-quality seismic data, giving Argas a competitive edge in Egypt’s rapidly evolving energy sector.
“After working with Stryde’s system on previous projects, it became clear that this technology brings a significant advantage to both us and our clients,” said Soufiane Azzi, Director of Commercials and Collaborations of Argas.
“The system has proven to drastically reduce deployment time, reduce headcount and vehicles count, simplifies logistics, improve recording time window, and delivers excellent seismic data. We are proud to be the first to bring node technology to Egypt.”
“This is a major milestone, not only for STRYDE and ARGAS, but for Egypt’s energy sector as a whole,” said Mehdi Tascher, sales director at Stryde.
“ARGAS’s purchase is spot on, and reflects the growing demand for scalable and efficient seismic acquisition systems that enable high-density data capture for superior subsurface imaging, empowering more confident and informed exploration decisions. This sale underscores the global trust in STRYDE’s technology and its proven ability to transform seismic operations through operational excellence and data quality.”
The divestment is in line with Eni's strategy of upstream portfolio optimisation.
Eni has divested 30% of its stake in the Baleine project in Cote d’Ivoire to Vitol
The shares in this significant offshore development now stands at 47.25% for Eni, 30% for Vitol, and 22.75% for Petroci.
The divestment is in line with Eni's strategy of upstream portfolio optimisation by accelerating the monetization of exploration discoveries through the divestment of equity stakes, a model known as the "dual exploration model."
This transaction adds to OTCP and Block 4 in Ghana, projects in West Africa that have already established long-standing collaboration between Eni and Vitol.
Eni has been present in Cote d’Ivoire since 2015. Baleine is Eni’s first development in the country, and the first net-zero development in Africa. The giant Baleine field was discovered in 2021, two decades after the last commercial discovery in the country and it achieved production in record time, in 2023. Currently, Baleine produces over 62.000 barrels of oil and more than 75 million cubic feet of gas per day from Phases 1 and 2. With the launch of Phase 3, production is expected to rise to 150,000 barrels of oil and 200 million cubic feet of gas per day, positioning Baleine as a cornerstone in meeting the country's domestic energy needs.
Global energy and commodities company, Vitol, has enjoyed a well established presence in West Africa since several years.
The sale of its Kenya subsidiary marks Tullow’s exit from the country after 14 years.
The agreement comes with a signature bonus of US$12mn. (Image source: NOCAL)
The partners will conduct a high-resolution gravity survey. (Image source: 88 Energy)
88 Energy Limited has secured license extension for 12 months from the Namibian Government, extending the PEL 93 First Renewal Exploration Period to 2 October 2026
During the extended period the company will aim datasets Integration to select drilling location, and complete an Environmental Impact Assessment (EIA) for drilling.
The PEL 93 is located in the Owambo Basin, onshore Namibia.
A farmout agreement with Monitor Exploration Limited for a joint venture gives 88 Energy Limited a 20% working interest in PEL 93. By way of an amendment on the agreement, the partners have introduced a new stage 1A work programme to target pre-drill de-risking.
The 2024 2D seismic data collected from an anticlinal structure -- Lead 9 -- spreading across 100 sq km has led to new insights to be unlocked from a gravity survey area. The partners have hence included on the programme a high-resolution gravity survey to focus on the southern area of PEL 93. The survey will be supplemented by radiometric data.
This anticipation has been strengthened by similar findings from the Kavango West 1X exploration well where ReconAfrica is now all set to start drilling this month.
Lead 9 is similar to Recon’s imminent Kavango West 1X well in that both show a very large and robust structural closure including the shallow clastic reservoirs, the deeper Otavi carbonate reservoir seen in Naingopo-1 and the deeper source rocks.
Monitor's statement read, “Our early results are pointing to something potentially significant in the southern area of PEL 93 in the Owambo Basin. With multiple datasets aligning and the prospect of even larger structures emerging, the Joint Venture is building momentum towards a drilling event and what could be a basin opening discovery with broad implications for all of Namibia given the significance in unlocking a major new hydrocarbon play.”
Stryde’s technology offers true scalability for large-scale seismic acquisition. (Image source: Stryde)
A single well location can now be pinpointed at Oryx prospect. (Image source: Pancontinental Energy)
Sercel's offerings come with value-added support. (Image source: Sercel)
A North African geophysical contractor has targeted large-scale 3D surveys in complex terrain with 75,000 of Sercel's DSU1-508 digital sensors
This was topped by 24 more Nomad 90 Neo broadband vibrators for an additional land seismic crew.
The contractor enjoyed an optimised survey performance with Sercel's set of value-added support services for Nomad with the Nomad Connect Asset Optimisation service, providing real-time insights into fleet performance and a complete overview of vibrator configurations. The Vibrator Auto-Guidance functionality enhanced operational accuracy and productivity in the field.
Jerome Denigot, CEO of Sercel, said, “We are pleased to continue building on our long-standing collaboration with this major North African customer. From project planning to delivery and field support, our team remains committed to providing the most advanced geophysical technology and services available. This latest milestone confirms Sercel’s position as the preferred technology partner for complex, large-scale seismic acquisition projects and highlights the growing demand for field-proven solutions that meet the evolving challenges of onshore exploration in North Africa and beyond.”
The technology provides a lightweight offline intervention solution.
The new system support remote operations. (Image source: FET)
Initial results from drilling and logging the Begonia-2 appraisal well are successful.
As energy demand continues to grow, Middle East-based natural gas company, Dana Gas PJSC, has confirmed commercial gas presence onshore Nile Delta in Egypt, in line with its US$100mn investment programme to support gas production
Initial results from drilling and logging the Begonia-2 appraisal well, which is the first of the 11 appraisal and exploration wells under the Begonia development area, have suggested the presence of 9 bn cu/ft of gas estimates that is likely to increase further. Drilling continues with the EDC-54 rig, and the next well is set to spud in August.
Profits from the Begonia development will significantly contribute to the company's million dollar gas programme, adding approximately 80 bn cu/ft in recoverable gas reserves over the course of the two-year plan.
Located in the New El-Manzala concession and operated by the joint venture, El-Wastani Patrolmen Company (Wasco), the Begonia-2 well generates an additional 5 mn cu/ft gas per day from enhanced recovery practices.
Egypt's Ministry of Petroleum and Mineral Resources is especially enthusiastic of the project, anticipating its domestic natural gas production potential. The government is also banking on the project's contribution towards solidifying the national energy system and driving economic development.
To boost and maintain production count, the company is focusing on well recompletions in other geological layers too. The Egyptco rig which was in plug and abandonment mode has been redeployed by the company for recompletion activities in the Balsam-3 well. Output enhancement besides, the recompletion eliminated the risks that accompany drilling exploration wells. It generated a total 4 bn cu/ft of gas while ensuring an additional yield of 3 mn cu/ft of gas per day.
Richard Hall, CEO, Dana Gas, said, “The successful drilling of the appraisal well 'Begonia-2' and the recompletion of the ‘Balsam-3’ well marks a significant strategic milestone. It signals the first steps in our ambitious US$100mn investment programme in Egypt, which includes drilling 11 new wells. We have been developing and producing gas in Egypt for over a decade, and the signing of the concession area consolidation agreement with the Egyptian Natural Gas Holding Company (EGAS) late last year has allowed us to acquire additional areas under improved financial terms, enabling us to launch this new phase.
"The success of drilling this well opens vast prospects for gas production in the 'Begonia' area and presents promising future opportunities for expansion and growth. It will also extend the operational life of our assets in Egypt. We are fully committed to making every effort to ensure the success of the programme and its efficient and timely execution. Dana Gas reaffirms its strong
commitment to reinvesting the payments it receives from the Egyptian government into executing this ambitious programme and supporting future development projects in the country. Regular and timely payments from our partners are crucial to sustaining these investments.”
This project underscores GTT’s central role in enabling major floating LNG developments in new markets.
The Agogo project involves the development of Agogo and Ndungu fields.
The new 750-meter quay will double the terminal’s capacity. (Image source: Adobe Stock)
As part of production optimisation strategy, the Republic of Congo is advancing investments on infrastructure development
With aims to expand the container terminal at the Port of Pointe Noire, a €230mn in financing has been generated to onboard freight forwarding service Africa Global Logistics (AGL) for the project.
The new 750-meter quay – scheduled for completion by 2027 – will double the terminal’s capacity to 2.3 million containers annually and support the country’s growing oil and LNG exports.
The Pointe Noire project is being executed by AGL’s subsidiary Congo Terminal in collaboration with engineering firm China Road and Bridge Corporation. Backed by both international and Congolese banks, the €400mn platform will include 26 hectares of quayside, a dredged 17-meter-deep basin, and the installation of 16 gantries. It forms a key part of Congo’s strategy to boost hydrocarbon production to 500,000 barrels of oil per day and LNG output to 3 million tons per annum within five years.
In Angola, AGL also launched operations at its Lobito Terminal in March last year. The terminal – Angola’s second-largest port hub – handles over one million tons of bulk cargo and more than 100,000 20-ft equivalent unit containers annually, with 730 employees operating deepwater berths and modern equipment. The project comes at a pivotal time for Angola, which is preparing to bring several major energy developments online between 2025 and 2028. These include the Cabinda Oil Refinery in 2025, the Agogo Integrated West Hub development in late-2025, the Quiluma and Maboqueiro gas fields in 2026 and the Kaminho Deepwater Development in 2028.
Meanwhile, in Ivory Coast, AGL is playing a vital role in Phase 2 of the Baleine offshore development - West Africa’s first net-zero emissions project. In partnership with engineering firm Saipem, AGL began manufacturing critical subsea structures for the Baleine field in April 2024 at its Carena shipyard in Abidjan. The works include anchoring systems and underwater fixtures totaling over 200 tons, to be deployed in ultra-deep waters. AGL has mobilized 100 skilled local workers – including certified welders, painters and crane operators – reinforcing its commitment to local content, capacity building and sustainable energy infrastructure in Ivory Coast’s rapidly growing oil and gas sector.
AGL’s recent activities in Africa align with its broader vision to support the continent’s energy infrastructure. In addition to the Republic of Congo, Angola and Ivory Coast, the company is currently modernising the Walvis Bay terminal in Namibia while playing a key role in major energy logistics across Mauritania, Senegal and Mozambique.
Major refinery projects are underway in Africa. (Image source: Adobe Stock)
The refinery will have a capacity of 240,000bopd.
AOW:Energy 2025 will serve as a platform to spotlight Ghana’s strategic assets. (Image source: Adobe Stock)
Ghana is set to host the 31st edition of AOW:Energy, the flagship event for Africa’s oil, gas, and energy sector, from 15th to 18th September 2025 in Accra, under the auspices of the Ministry of Energy and Green Transition and the Petroleum Commission
It is the first time in over three decades that the event will be held outside Cape Town, South Africa. As regulator of Ghana’s upstream petroleum industry, with a strategic vision of positioning Ghana as a competitive upstream petroleum hub, the Commission views the AOW: Investing in African Energy as a notable opportunity to further raise awareness of the country’s hydrocarbon potential on the global stage.
“We have an opportunity to present a dedicated national showcase, where His Excellency President H.E John Dramani Mahama will outline his vision for positioning the country as one of the most attractive upstream destinations with good geological prospects, through a progressive fiscal regime, regulations, investor-friendly incentives, and forward-thinking energy policies,” noted Emeafa Hardcastle, Ag. CEO of the Petroleum Commission. “AOW:Energy 2025 will serve as a platform to spotlight Ghana’s strategic assets, engage with global investors, build critical partnerships and offer regulators across the continent an opportunity to present emerging regulatory reforms that will shape the continent’s energy future.”
Paul Sinclair, CEO of AOW:Energy, expressed enthusiasm for the momentum building around the event, noting a record level of government and private sector participation. “We are excited about the strong support from the Ghana government in welcoming ministers, national oil companies, regulators and global investors to AOW:Energy 2025. Africa is quickly becoming a top destination for energy investment, and 2025 will be a year for the continent’s upstream sector. Ghana, I believe is ready to take the spotlight when AOW:Energy comes to Accra,” he said.
As AOW:Energy evolves, it continues to consolidate its founding mission of bringing together a powerful network of governments, national oil companies, regulators, energy agencies, and private sector players.
The 2025 edition is expected to open new doors to investment, innovation, and collaboration, providing direct access to emerging opportunities across Africa’s energy landscape.
The partnership aims to tackle mounting concerns in global energy markets.
The theme for ADIPEC 2025, "Energy. Intelligence. Impact." (Image source: dmg events)
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The Agogo project involves the development of Agogo and Ndungu fields.
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The well was spudded last November. (Image source: Adobe Stock)
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The two subsea tie-back projects will deliver additional production. (Image source: TotalEnergies)
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Initial results from drilling and logging the Begonia-2 appraisal well are successful.
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Both partners have entered into detailed commercial discussions.
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A single well location can now be pinpointed at Oryx prospect. (Image source: Pancontinental Energy)
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The Kavango West 1X well was spud on July.
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Capricorn forecasts the drilling of 10 development wells for H2 2025.
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The sale of its Gabon assets marks Tullow’s exit from its licences in Gabon after 21 years.
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Afentra eyeing operatorship in Angola block.
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The MoU will advance regional energy development in sub-Saharan Africa.
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The Banga Kayo, Holmoni and Cayo permits will see development.
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The MoU outlines the areas of common interest between partners. (Image source: SONATRACH)
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The MoU was signed during the visit of Karim Badawi, Minister of Petroleum and Mineral Resources, and others. (Image source: bp)
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Godwin Kudzo Tameklo, CEO of NPA. (Image source: African Energy Chamber)
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The rig will begin operations this month. (Image source: Northern Ocean)
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This project underscores GTT’s central role in enabling major floating LNG developments in new markets.
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The Cabinda Refinery aims to double capacity to 60,000 bpd. (Image source: Adobe Stock)
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The analysis will support safe and efficient well operations.
Latest News
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The sale of its Kenya subsidiary marks Tullow’s exit from the country after 14 years.
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The technology provides a lightweight offline intervention solution.
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The new system support remote operations. (Image source: FET)
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The agreement comes with a signature bonus of US$12mn. (Image source: NOCAL)
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The divestment is in line with Eni's strategy of upstream portfolio optimisation.
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Pharos will retain a 45% working interest in the Consolidated Concession.
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Stryde’s technology offers true scalability for large-scale seismic acquisition. (Image source: Stryde)
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The blocks cover an area of approximately 12,700 sq km. (Image source: TotalEnergies)
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Sercel's offerings come with value-added support. (Image source: Sercel)
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Vertiv’s digital infrastructure solutions are designed to assist with power supplies and distribution. (Image source: Vertiv)
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Oil & gas sector requires effective technology infrastructure. (Image source: Vertiv)
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Galp steps into Sao Tome and Principe.
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The MoU outlines the areas of common interest between partners. (Image source: SONATRACH)
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This project underscores GTT’s central role in enabling major floating LNG developments in new markets.
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The MoU was signed during the visit of Karim Badawi, Minister of Petroleum and Mineral Resources, and others. (Image source: bp)
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The Banga Kayo, Holmoni and Cayo permits will see development.
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Afentra eyeing operatorship in Angola block.
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Invictus' Cabora Bassa gets National Project Status.
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MODEC has extensive African experience.
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The new crewboats have been made to especially serve ultimate capacity for passenger transfer.
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The technology provides a lightweight offline intervention solution.
The new system support remote operations. (Image source: FET)
Sercel's offerings come with value-added support. (Image source: Sercel)
Vertiv’s digital infrastructure solutions are designed to assist with power supplies and distribution. (Image source: Vertiv)
Oil & gas sector requires effective technology infrastructure. (Image source: Vertiv)
MODEC has extensive African experience.
The new crewboats have been made to especially serve ultimate capacity for passenger transfer.
This solution is an expansion on the long-range CorrosionRADAR: LR solution. (Image source: CorrosionRADAR)
Winson has equipped the NGUYA FLNG with CHART’s IPSMR liquefaction technology and SPB tank. (Image source: Winson Energies)
Operators can rely on SK Well Pages.
The analysis will support safe and efficient well operations.
The project will involve the installation of compact twin-well configurations. (Image source: Adobe Stock)