MB Energy, Daimler Truck AG, and Kawasaki Heavy Industries, Ltd. have entered into a Joint Development Agreement (JDA) aimed at creating a liquefied hydrogen supply chain to Europe through the Port of Hamburg. This agreement was formalised during the “Hamburg Port Anniversary,” one of the largest port festivals globally, highlighting Hamburg’s ambition to become a significant energy hub for Europe.

Through this collaboration, the three companies will leverage their expertise to conduct studies focused on developing a financially viable liquefied hydrogen supply chain to Hamburg. Their goal is to achieve a Commercial Operation Date (COD) for the supply of liquefied hydrogen and hydrogen by the early 2030s. Building upon the existing Memorandum of Understanding (MoU) for a Japan-Germany hydrogen supply chain, the partners aim to expand their hydrogen-related business internationally, contributing to global energy security and fostering a decarbonised society for a sustainable future.

Volker Ebeling, senior vice president of New Energy, Supply & Infrastructure at MB Energy, stated, “Hydrogen has the potential to be a key driver for Europe’s energy transition, with Hamburg ideally positioned as Germany’s main entry point. We are integrating MB Energy’s infrastructure, service station network, and trading expertise with Daimler Truck’s advancements in hydrogen trucks and Kawasaki’s innovative hydrogen storage and shipping technologies. Together, we are working to establish a scalable, international hydrogen import corridor for Europe.” He added that creating a reliable liquefied hydrogen supply chain enhances energy security and sustainability, and they aim to deliver this as a comprehensive end-to-end solution.

MB Energy is recognised for its extensive expertise in fuel sourcing, trading, and logistics, supported by its established supply chain and service station network, including the conversion of key logistics hubs for liquid hydrogen (LH2).

Daimler Truck is pursuing a dual strategy for decarbonizing transport through both battery-electric and hydrogen-powered solutions. The company plans to introduce 100 hydrogen-powered fuel cell trucks into customer operations by the end of 2026, with series production expected to begin in the early 2030s, coinciding with the anticipated availability of necessary infrastructure and competitively priced liquid hydrogen.

Manfred Schuckert, head of regulatory strategy at Daimler Truck, emphasised, “The scaling of hydrogen-powered trucks across Europe in the coming decade relies on a dependable and competitive supply of liquid hydrogen. This agreement is crucial as it unites key partners to collaboratively explore and develop a liquefied hydrogen supply chain for Europe, focusing on feasibility, scalability, and long-term impact. Liquid hydrogen provides the energy density and operational flexibility essential for long-haul transport, but its potential can only be realized through coordinated efforts across the entire value chain.”

Kei Nomura, executive officer and general manager of the Hydrogen Strategy Division at Kawasaki Heavy Industries, expressed support for this Hamburg-centred initiative, viewing it as a critical step in developing a hydrogen supply chain between Japan and Germany. “By introducing our liquefied hydrogen technologies to Europe, we aim to meet the demands of industrial and heavy-duty vehicles, establishing a scalable international hydrogen corridor that enhances competitiveness, resilience, and climate neutrality.”

Kawasaki Heavy Industries will contribute its expertise in designing and manufacturing key infrastructure, including hydrogen liquefiers, LH2 storage tanks, and LH2 carrier ships, which are essential for building international liquefied hydrogen supply chains. As the demand for hydrogen energy grows in the quest for a decarbonised society, this partnership seeks to establish efficient transport routes from potential hydrogen-producing countries to Germany, promoting hydrogen utilisation across European industries, starting with Daimler Truck’s Zero-Emission Vehicles (ZEVs).

For more information, visit www.mbenergy.com

AG&P LNG has announced plans to increase its stake to 100 percent in the Cai Mep LNG Terminal, marking a significant milestone in the company’s expansion strategy across Southeast Asia.

The acquisition reinforces AG&P LNG’s growing presence in Vietnam’s energy sector and strengthens its position as a leading player in the region’s LNG infrastructure and energy transition initiatives.

Operational since 2025, the Cai Mep LNG Terminal has become a vital component of South Vietnam’s energy supply chain, providing liquefied natural gas to power plants and industrial customers across the region. The terminal supports the country’s increasing demand for cleaner and more reliable energy solutions as Vietnam continues to diversify its energy mix.

Following the transaction, the terminal will become a wholly owned flagship asset within the Nebula Energy portfolio, further enhancing the group’s LNG capabilities and long-term growth ambitions in Asia.

The move highlights AG&P LNG’s commitment to supporting Vietnam’s energy transition through strategic infrastructure investments that improve energy security, expand access to LNG, and contribute to lower-carbon economic development.

With full ownership of the Cai Mep LNG Terminal, AG&P LNG is expected to play an increasingly important role in enabling sustainable energy growth in Vietnam and across the broader Southeast Asian market.

For more information visit www.agplng.com

Representatives of INA and MOL Group have concluded a series of constructive meetings with senior officials from the Syrian Petroleum Company (SPC), focusing on the potential reactivation of INA’s oil and gas operations in Syria.

The three-day visit centered on evaluating pathways for restarting operations on INA’s former Syrian concessions. Earlier this year, INA and SPC established a joint technical team tasked with assessing the feasibility of resuming activities in the country. The team is currently reviewing operational, technical, commercial and regulatory conditions required for a potential return.

Both parties described the discussions as productive and forward-looking, highlighting a shared commitment to identifying a viable framework for renewed cooperation.

The SPC delegation was led by Yousef Qiblawy, CEO of Syrian Petroleum Company, alongside Zuhair Sawwan, director of Development and Exploration, and Hisam Suleymanelsalih, vice president of Gas Development. During the visit, the delegation held meetings at MOL Group’s headquarters in Budapest and INA’s offices in Zagreb. Representatives also met with Croatian Minister of Economy Ante Šušnjar to discuss ongoing developments and regional energy cooperation.

As part of the official programme, the delegation visited the LNG terminal on Croatia’s Krk Island on May 5th. The visit underscored the growing importance of energy diversification, secure supply routes and modern infrastructure development within the Mediterranean energy sector.

A major milestone of the visit was the joint expert team meeting held on May 6th, where participants reviewed key findings from a comprehensive assessment of infrastructure and field conditions following the suspension of INA’s Syrian operations more than a decade ago. The team is expected to define the technical and safety requirements necessary for restarting operations and establish a strategic roadmap for future collaboration.

Zsuzsanna Ortutay said the discussions had progressed positively, although significant regulatory, legal, commercial and operational matters still need to be resolved before operations can resume.

Meanwhile, Zsombor Marton highlighted Syria’s historic importance within MOL Group and INA’s international portfolio. He noted that the companies had successfully discovered and developed hydrocarbon fields in the country, reaching production levels of 37,300 barrels of oil equivalent per day by 2011. Before operations were suspended in 2012, INA had invested approximately $1.1 billion in Syria, including the construction of a gas processing plant at the Hayan gas field.

For more information visit www.molgroup.info

The recent inauguration of the refinery unit expansion under the Balikpapan Refinery Development Master Plan (RDMP) project is more than just a celebration of physical infrastructure progress. For the national energy sector, this momentum marks a paradigm shift from being a raw material exporter to a nation with greater processing sovereignty. With the increase in Balikpapan’s refinery capacity from 260,000 barrels per day (bpd) to 360,000 bpd, Indonesia’s collective processing capacity has now surpassed the 1.1 million bpd milestone.

“This country will never advance without industrialisation and downstreaming. Otherwise, we will only be a nation suffering from the natural resource curse.” (Source: Statement by Minister of Energy and Mineral Resources Bahlil Lahadalia at various official forums, late 2025).

However, behind the roar of the growing scale of refinery operations, structural challenges emerge that require serious attention from all stakeholders. The central government’s energy downstreaming programme has noble goals: increasing economic value added, strengthening industrial resilience, and reducing the trade balance deficit by cutting fuel product imports. To strengthen this downstream ecosystem, synchronised integration is required to ensure national industrial competitiveness.

Data indicates a widening gap between downstream ambitions and upstream production realities. According to SKK Migas annual achievement reports, national crude oil lifting currently fluctuates between 580,000 and 600,000 bpd. Based on 2025 data from the Ministry of Energy and Mineral Resources and SKK Migas, domestic production only covers about 55 percent of the total national consumption, which has reached 1.5 million bpd.

If this disparity is not immediately mitigated through significant increases in upstream production, magnificent downstream facilities like the RDMP risk facing operational pressure. Instead of reducing foreign dependence, large refinery capacities without domestic supply support will force Indonesia to significantly increase crude oil imports just to maintain optimal refinery utilisation. Economically, this merely shifts the import burden from finished products (fuel) to raw materials, which remain vulnerable to global oil price fluctuations and the depreciation of the Rupiah.

Therefore, downstreaming must not be viewed as an isolated sector. The downstream sector requires “supply” in the form of a stable, sustainable crude oil supply that is geographically close to processing facilities to minimize logistics costs. This alignment is crucial so that downstream capacity expansion receives optimal support from the upstream side, creating a synergy that ensures every step of our energy development has a solid supply foundation.

Exploration: The Heart of Oil and Gas Industry Sustainability

Indonesia’s upstream oil and gas industry is currently in a race against time. Most of Indonesia’s major oil and gas fields have entered the mature phase, with a natural decline rate averaging 10 percent to 15 percent per year. Efforts to optimise existing wells through infill drilling and Enhanced Oil Recovery (EOR) remain vital operational pillars, but they must now be coupled with massive acceleration in exploration to maintain long-term supply sustainability.

Discovering new reserves through exploration, especially in frontier areas and the deep waters of Eastern Indonesia is the only way to reach the production target of 1 million barrels per day by 2030. Exploration is not merely a technical activity of finding drilling points; it is a high-risk investment decision involving immense capital. For industry players, investment security guarantees and legal certainty are determining factors.

The government has signaled a positive shift through various regulatory improvements, but field challenges persist. The lead time from exploration to the commercial production stage takes years. If exploration activities are not aggressively accelerated today, the gap between downstream refinery capacity and upstream supply will widen even further in the coming decade. Exploration must be treated as a national priority equal to downstream infrastructure development, because without new reserve discoveries, the energy independence envisioned through downstreaming will lose its primary foundation.

The Indonesian Petroleum Association (IPA) consistently emphasizes that the upstream and downstream sectors are one integrated value chain. The success of downstreaming must be measured by how well the sector strengthens overall national industrial resilience, rather than just shifting the point of import. In line with the 2026 National Energy Vision, the IPA focuses collaboration on four strategic priority pillars: massive exploration acceleration, improvement of the investment and regulatory climate, operational digitalisation, and a planned energy transition.

Among these four pillars, massive exploration acceleration is the most urgent foundation. Without significant new reserve discoveries, the supply sustainability for modernised national refineries will continue to face structural challenges. Therefore, strengthening the upstream side is not just about increasing production; it is a strategic step to ensure that our downstream expansion has an independent and sustainable supply base in the long term.

Consequently, a synchronised roadmap between relevant ministries and agencies is needed to bridge the aspirations of industry players with government policies. This synchronisation includes several strategic points: The government’s step in inaugurating the Balikpapan RDMP and pushing for downstreaming deserves appreciation as a bold move toward economic transformation. However, this momentum must serve as an alarm for all of us to look back toward the upstream. We cannot allow the downstream sector to race ahead alone without being accompanied by strengthening in the upstream sector.

Downstreaming is the great ship carrying us toward energy sovereignty. However, the sustainability of that ship’s voyage depends on how hard our upstream engines work. By synergising downstream ambitions and upstream realities within a single policy framework, Indonesia will not only possess modern refineries but also sovereignty over its own energy resources. Maintaining the sustainability of the upstream sector is not just a matter of business. It is about sustaining the long-term independence of the nation.

For more information visit www.convex.ipa.or.id

Meghna PVC Limited, a key company within Meghna Group of Industries (MGI), has taken a decisive step to reinforce long-term steel integrity by adopting a structured, data-driven approach to proactively maintain their assets through a partnership with Jotun.

Operating under extremely aggressive conditions typical of chemical-processing facilities — where corrosion can accelerate rapidly and compromise critical structures — Meghna PVC Limited has demonstrated strong leadership by prioritising preventive action over reactive repairs, using Jotun’s AssetKeeper.

“Meghna PVC Limited partnered with Jotun to implement AssetKeeper, a comprehensive three steps services that designed to optimise maintenance planning and enhance corrosion protection, thus supporting asset owners to establish a long term maintenance strategy” said Sunny Gwee, managing director of Jotun Bangladesh ltd., one of the leading paint and coatings manufacturers worldwide.

Jotun have developed the solution to provide a systematic assessment and maintenance plan. This enables sites to identify risk areas sooner, justify maintenance budgets with confidence, and plan interventions before corrosion escalates into costly damage, unplanned downtime, or safety incidents. Through the solution, Meghna PVC Limited is setting a benchmark for responsible industrial risk management in Bangladesh’s manufacturing sector.

“AssetKeeper gave us a clear view of our asset condition and helped prioritise maintenance more effectively. Jotun’s insights will support better planning and long-term protection of our facilities,” said Mohammad Iqbal, deputy general manager, Meghna PVC Limited. “Our focus is on protecting people, operations, and the integrity of the facility — and this approach supports all three.”

The initiative includes a detailed condition assessment of existing coatings, a maintenance prioritisation report, and recommendations covering repair strategies and optimised coating systems. Critically, Meghna PVC Limited has also committed to ongoing, yearly assessments to monitor coating performance and support continuous improvement in asset management — an important signal of long-term intent and accountability.

“Meghna PVC Limited’s commitment to safety and steel integrity is exactly the kind of leadership that drives sustainable industrial performance,” said Ashibul Hussain, segment manager marine and protective in Jotun Bangladesh. “By investing in structured assessment and long-term planning, they’re actively reducing risk and raising the bar for responsible maintenance practices.”

The scope encompasses comprehensive maintenance of the entire factory infrastructure, including steel structures and pipe-holding systems.

MGI is among Bangladesh’s largest industrial conglomerates, operating more than 57 industrial units and employing tens of thousands of people nationwide. Meghna PVC Limited is the sole manufacturer of PVC and PET in Bangladesh.

“Corrosion is costing the global economy over USD 2.5 trillion annually, and by 2030 it is estimated that up to 9.1 percent of global CO₂ emissions will originate from steel production only to replace corroded steel. Being proactive and maintaining steel integrity is therefore of high importance for the global environment as well, and we are reliant on responsible stakeholders like MGI,” concludes Ekaterina Mezhentseva, global solution manager in Jotun.

For more information visit www.jotun.com

INEOS Energy and Shell plc, through its subsidiary Shell Offshore Inc., have agreed to jointly invest in exploration and development opportunities near the Appomattox platform in the Gulf of Mexico, strengthening cooperation between the companies and supporting long-term energy security initiatives.

As part of the agreement, INEOS Energy will acquire a 21 percent working interest for an undisclosed sum, aligning with its existing ownership stakes in Appomattox, Rydberg, the Nashville discovery and the Mattox pipeline infrastructure.

The partnership will initially focus on three exploration and production opportunities, including Shell’s pre-final investment decision (FID) Fort Sumter discovery, the drilling of the Sisco exploration well and an additional exploration well planned before the end of 2030.

The agreement forms part of INEOS Energy’s broader expansion strategy, which includes operations in the Gulf of Mexico, Eagle Ford in South Texas, offshore Denmark and the UK Continental Shelf. The company said the partnership with Shell would further strengthen efforts to pursue future growth opportunities while leveraging existing infrastructure.

INEOS Energy said the collaboration aims to unlock additional value from the Appomattox platform by integrating production assets from Appomattox and Rydberg with existing pipeline infrastructure to support efficient production and improve project economics.

David Bucknall, CEO of INEOS Energy, said the partnership reflects the company’s focus on infrastructure-led growth, targeting areas close to existing facilities where development can progress efficiently while controlling costs and sharing exploration risk.

The latest agreement marks another step in INEOS Energy’s strategy to expand its upstream portfolio globally while maintaining capital discipline and working alongside established industry operators.

For more information visit www.ineos.com

Emerson has introduced the new Rosemount 396A Anti-Coating pH Sensor, designed to measure pH and oxidation-reduction potential (ORP) in abrasive, dirty and high-solids industrial applications.

The sensor features an anti-coating reference design and Modbus digital output aimed at reducing maintenance requirements while maintaining stable pH and ORP measurements in environments where coating and fouling are common.

According to Emerson, the Rosemount 396A has been developed for use in challenging process conditions across industries including chemical manufacturing, oil and gas refining, water and wastewater treatment, and pulp and paper production, where sensor reliability can be affected by buildup and contamination.

Rachel Jang, global product manager for liquid analysis at Emerson, said the new sensor combines anti-coating technology with digital connectivity to simplify installation and accelerate sensor replacement in demanding operating environments.

The company said the digital Rosemount 396A is designed as a direct replacement for legacy Rosemount 396P and 396PVP anti-coating sensors, allowing users to upgrade to digital technology without modifying existing installations or accessories.

The sensor incorporates Modbus digital communication to support simplified setup with compatible Rosemount liquid analysis transmitters. Emerson added that calibration data can be stored directly within the sensor, enabling bench calibration and replacement without requiring recalibration in the field, which can help reduce commissioning time and maintenance effort.

The Rosemount 396A is rated IP67 and IP68 for resistance against water and dust ingress, including submerged and washdown conditions. It also features a through-wall reference junction with increased surface area intended to improve performance in fouling applications.

Emerson said the Rosemount 396A sensor is now commercially available.

For more information visit www.emerson.com

Royal Vopak has reached an agreement in principle to acquire a majority stake in Green Energy Storage, in a move aimed at accelerating the development of large-scale battery energy storage systems (BESS) in the Netherlands.

GES, a Dutch battery storage developer based in Breda, has established a strong presence in the Dutch energy market through the development of utility-scale storage projects. The company oversees the entire project lifecycle, including site identification, permitting, construction and operational management, while also supporting efforts to reduce grid congestion and improve flexibility within the energy system.

Under the proposed transaction, Vopak will acquire a majority equity interest in GES and support the continued expansion of the company’s project portfolio. This includes the large-scale battery storage project in Oosterhout, which is planned to deliver 200 MW / 800 MWh of storage capacity. The project is expected to play a significant role in balancing the Dutch electricity grid and alleviating congestion.

Maarten Smeets, executive vice president global business development at Vopak, said the acquisition represents a strategic step into energy transition infrastructure through battery storage and noted that the combined expertise and project pipelines of both companies position them to accelerate the deployment of large-scale storage solutions.

GES CEO Guus Bengsch said the partnership with Vopak would help speed up the realisation of the company’s pipeline, enabling it to scale operations more rapidly and contribute more effectively to easing grid congestion and supporting the energy transition in the Netherlands.

The transaction remains subject to a Final Investment Decision, as well as customary approvals and conditions. Vopak said details of the investment value will be disclosed following completion of the transaction and a positive FID.

For more information visit www.vopak.com

The Transnet National Ports Authority (TNPA) invites interested entities to submit proposals in response to the Request for Proposals (RFP) for the selection of a terminal operator. This operator will be responsible for financing, operating, maintaining, refurbishing, and/or constructing a Liquid Bulk Terminal, which includes bunkering and related services, at the Port of Cape Town over a 25-year concession period.

The project will take place on an existing brownfield site, which features a tank farm with eight storage tanks that together have a capacity of approximately 44,430 m³, as well as an adjacent storage warehouse and administrative building. The site facilitates connections with common-user berths at Tanker Basin 1 and Tanker Basin 2, catering to both local supply from the refinery and the importation of bunkering products.

This RFP aims to maintain and enhance a vital liquid bulk terminal at the Port of Cape Town, ensuring the continuation of essential services. It also promotes long-term financial viability and optimal use of infrastructure through private sector involvement.

The Port of Cape Town is ideally located to support various liquid bulk operations. This RFP encourages private sector engagement to boost liquid bulk cargo volumes while enhancing bunkering capabilities and revenue generation.

By attracting a competent terminal operator, we intend to ensure the site operates efficiently, contributing to regional fuel supply and broader economic development. The RFP is grounded in clear market demand, which will guide the selection of a new terminal operator to achieve operational efficiency, ensure service continuity, and modernise existing infrastructure,” stated Ophelia Shabane, acting port manager at the Port of Cape Town.

RFP documents are available on the Transnet website at www.transnet.net.

Why mobile degassing is gaining importance in the industrial sector

Handling harmful emissions is a core operational task in many industries. In refineries, tank farms, chemical and petrochemical plants as well as in intermodal transport, gaseous pollutants are regularly generated that can enter the atmosphere directly if not treated properly. For operators of industrial plants, this is not only about environmental concerns, but also about safety, regulatory compliance, and the reliable execution of operational and maintenance processes.

Comment by David Wendel, Managing Director at ETS Degassing

Gaseous emissions arise as unavoidable by-products in many industrial processes – for example during the handling of raw materials and intermediates, when loading and unloading tanks, in storage operations, and in chemical processes. The resulting hydrocarbons, volatile organic compounds (VOC), and hazardous air pollutants (HAP) are harmful to health and require controlled and safe handling.

It is therefore crucial to capture and effectively treat these emissions. Residual gases often remain in tanks, pipelines, ships, rail tank cars, or other components. Before maintenance, cleaning, product changeovers, shutdowns, and transport, these residual gases must be treated and removed. This is the only way to ensure that they do not enter the atmosphere untreated or trigger unwanted reactions when in contact with other substances. Equally important is the temporary replacement of stationary emission control systems: if a stationary vapor recovery or treatment system fails, processes often cannot continue without interruption. This can lead to delays, additional effort, or, in the worst case, shutdowns.

Mobile degassing: flexibility as a key advantage

Technologies for mobile emission control help to address these challenges. Mobile degassing offers a key structural advantage: emissions can be treated directly at their source. Mobile vapor combustion units can be deployed flexibly at various locations, from refineries and tank farms to ports and loading facilities for tank trucks or rail cars. This flexibility is a critical factor in complex process and logistics environments and also provides operational security. In the event of maintenance or unplanned outages, mobile units can temporarily take over the function of stationary systems. This allows processes to continue without violating emission regulations or having to shut down facilities prematurely.

Another advantage of mobile solutions is their rapid availability and ease of integration. They can be used both as standalone systems and as a supplement to existing infrastructure, with minimal impact on industrial workflows. This makes it possible to continue operations even in challenging situations with as few restrictions as possible.

Mobile vapor combustion units: technical functionality and applications

In the mobile degassing process, pollutants are extracted and guided via pipelines into a mobile combustion chamber. There, they are thermally treated and broken down – with an efficiency of over 99.99%, without an open flame and without odor or noise disturbance. These systems enable the treatment of gases, gas mixtures, and vapors in the hazard groups IIA, IIB, and IIC. This allows tanks, containers, pipelines, ships, and other components to be degassed, and stationary emission control systems to be temporarily replaced. Different combustion capacities ensure that the technologies are suitable for a wide range of applications – from short-term deployments to long-term projects lasting several months.

The thermal treatment of gases significantly reduces pollutant emissions. For an LNG fuel tank with a capacity of 1,280 m³, the Global Warming Potential (GWP) factor for LNG is, for example, 60.87 tonnes. When mobile emission control technology is applied, the GWP of the LNG is reduced to just 6.64 tonnes. This reduces emissions by 89%.

In combination with mobile nitrogen vaporizers, liquefied gases under pressure – such as LNG or ammonia – can also be treated. Through inerting and purging, a safe environment is created, allowing containers to be emptied. Applications include the maintenance of pipelines, tanks, ships, and large vessels, as well as the degassing of spheric al gas tanks, gas tankers, and gas containers. In LNG handling, mobile vaporizers can also be used for LNG cool-down processes.

Conclusion

Mobile degassing is a flexible and efficient solution for safely handling gaseous emissions in industrial process environments. It helps companies to align safety requirements, emission reduction, and regulatory compliance with the practical needs of operations. Especially in dynamic or disruption-prone situations, it can help to secure workflows, avoid shutdowns, and ensure reliable process continuity. As such, mobile degassing is an important component of modern industrial operating strategies.

Perpetual Next has selected JPB Logistics as its preferred partner for biomethanol storage and handling services at the company’s Delfzijl biomethanol facility in Farmsum.

Under the planned collaboration, JPB Logistics is expected to manage the storage, handling and logistics operations for biomethanol produced at the facility, including deliveries to third-party customers.

The Delfzijl project is being developed by DeltaNor B.V., a wholly owned subsidiary of Perpetual Next. The project involves the construction, financing, maintenance and operation of a biomethanol plant in Farmsum with an anticipated production capacity of 220,000 tonnes annually. The facility forms part of Perpetual Next’s broader strategy to advance circular and low-carbon industrial solutions by converting biogenic carbon streams into sustainable products such as biomethanol.

The companies have signed a memorandum of understanding (MoU) outlining plans to negotiate a definitive storage agreement for the project. Proposed storage capacity is expected to range between 21,000 and 35,000 gross cubic metres, depending on the final configuration. The planned logistics setup includes inbound pipeline transport and outbound barge movements through dedicated lines, with truck loading and unloading available as a contingency option.

Anthony Mayle, head of business development at Perpetual Next, said the selection of JPB Logistics marks an important milestone for the Delfzijl biomethanol facility, noting that dependable storage and outbound logistics are critical for establishing a robust and financeable value chain.

Patrick Trakzel, CEO of JPB Logistics B.V., said the company’s terminal and jetty infrastructure in Farmsum would help support the safe and efficient logistics required for a project of this scale.

The proposed partnership remains subject to several conditions, including Perpetual Next reaching a final investment decision for the Delfzijl project, successful project execution and agreement on final commercial terms.

Perpetual Next develops renewable commodity solutions by converting organic waste into products such as biomethanol, which can serve as a lower-carbon alternative to fossil-based methanol for use in chemicals, plastics, coatings and transport fuels. The company is developing a network of large-scale facilities in the Netherlands, Estonia and the United States as part of its efforts to support the transition to a circular and climate-neutral economy.

For more information visit www.perpetualnext.com

Delfin Midstream Inc. and Gunvor Group have announced that Gunvor International B.V. Amsterdam, Geneva Branch has signed a long-term LNG Sale and Purchase Agreement with Delfin LNG LLC, a subsidiary of Delfin.

Under the agreement, Delfin LNG will supply 0.3 million tonnes of liquefied natural gas (LNG) annually to Gunvor over a 20-year period. The LNG will be delivered on a free-on-board (FOB) basis from the Delfin FLNG1 facility, situated approximately 40 nautical miles off the coast of Louisiana.

Kalpesh Patel, co-head of LNG trading and member of Gunvor’s management board, said the agreement strengthens Gunvor’s LNG portfolio and supports the company’s strategy of maintaining reliable global LNG supply capabilities through its fleet infrastructure.

Delfin CEO Dudley Poston said the deal builds on the companies’ longstanding partnership and supports the continued development of US energy infrastructure, while reinforcing Delfin’s position as a long-term supplier of scalable LNG solutions.

For more information visit www.gunvorgroup.com

International energy consultancy Penspen has been awarded a critical research project designed to look into how hydrogen can support the transition of the UK’s industrial clusters.

Hydrogen Transition Pathways for Industrial Clusters is a research and decision-support project for the Future Energy Networks (FEN), Energy Innovation Centre, Northern Gas Networks (NGN), and Xoserve. FEN’s current members include National Gas and the four Gas Distribution Networks: Cadent, NGN, SGN and WWU.

Experts from Penspen’s asset integrity and engineering teams in the UK will carry out a comprehensive study to help determine where, how and under what conditions hydrogen should support the transition of industrial clusters and surrounding communities, alongside credible alternative pathways. The assessment will align with major UK industrial clusters including Teesside, Humber, Merseyside, South Wales, North Wales, Grangemouth and Southampton.

“As industries seek to decarbonise at pace, hydrogen offers a compelling pathway. This study represents a significant opportunity to unlock hydrogen’s potential as a cornerstone of low-carbon industrial clusters,” said Chris Wood, Director – Asset Integrity (Europe) at Penspen.

“We’re proud to support this important project, bringing our deep expertise in energy transition and critical infrastructure systems. We understand both the technical complexities and the commercial realities of integrating hydrogen, enabling us to deliver strategic guidance and technical insights that accelerate decarbonisation.

“Working closely with the EIC, NGN, Xoserve and FEN, we are excited to contribute to a study that focuses on practical pathways for industrial integration. The outcomes of this project will support more consistent and strategic planning, clearer prioritisation of pathways and clusters, reduced risk of misaligned investment, and improved consideration of affordability, workforce and community impacts.”

Roadmap to 2050

Supported by members of Penspen’s Centre of Engineering Excellence, the study focuses on four key areas: potential hydrogen supply and demand across clusters, including conditions for domestic uptake; how hydrogen networks could coexist with biomethane and natural gas by 2050, and the implications for system configuration, cost, operations, and maintenance; the costs and practicalities of converting local networks to hydrogen, and the social and economic impacts of hydrogen deployment, including supporting a just transition.

Key outputs will include a multi-criteria decision framework, a comprehensive report, cluster-level conversion playbooks, and pathway roadmaps to 2050.

“This project is critical to providing clear, evidence-based insight on where hydrogen can play the greatest role in decarbonising industrial clusters, while avoiding misaligned investment and supporting an affordable, coordinated and just energy transition,” said Lewis Kirkwood – Innovation Manager at Northern Gas Networks.

Jack Hewitt, Gas & Innovation Portfolio Development Lead at the Energy Innovation Centre said: “We’re delighted to be working on this project alongside Penspen, Northern Gas Networks, Xoserve and Future Energy Networks. This important work will help build a clearer understanding of how hydrogen can support the decarbonisation of the UK’s industrial clusters.

“We look forward to working collaboratively with all partners to deliver practical insights that support informed decision-making and long-term energy transition planning.”

For more information visit www.penspen.com

GI Chemical Solutions, a subsidiary of CSG, has recently partnered with Exolum to commission an 11,500 caustic soda storage tank at the Port of Immingham, expanding the UK’s capacity and strengthening supply resilience for key manufacturing sectors.

The facility, managed in partnership with Exolum, a leading chemicals and energy logistics organisation, provides a dedicated distribution and storage hub for caustic soda on the East Terminal in Immingham, featuring a specialist tank and upgraded tanker-loading infrastructure. Operated by GI Chemical Solutions, it is the largest seaborne caustic soda tank in the region and is designed to support growing industry demand across the UK.

GI Chemical Solutions is rapidly expanding its presence in the UK caustic soda market, growing its investment in UK infrastructure to support operations. Since launching its caustic soda operations in the UK, the company has grown the amount of caustic soda it distributes from zero to several thousand tonnes per month and manages an average of more than 55 bulk loads per week. The new Immingham facility offers 24/7 loading, improving speed and flexibility for customers.

To address delivery challenges often reported by manufacturing customers, the company has developed advanced dilution times at its dedicated water dilution facility at Immingham. The facility offers a full suite of caustic dilutions and is able to pump water at 1200 litres per minute, improving the speed of bulk caustic soda supply and strengthening supply chain resilience.

Nick Pickering, sales manager at GI Chemical Solutions, says: “Expanding into the UK market has been a big milestone for us, and the response has been incredibly strong. Customers here already know us for being reliable and easy to work with, and the Immingham facility helps us maintain that standard – delivering quickly, with the industry‑leading dilution times that we’re known for.”

James Scarisbrick, commercial manager, Chemicals, at Exolum, says: “This investment at Immingham is about making UK supply more resilient and more responsive. By adding dedicated storage and loading capability, we’re giving customers faster access to the caustic soda they rely on, at the times when they need it, helping boost confidence in continuity of supply. As an independent operator, we’re focused on operational excellence and on building the infrastructure that keeps UK manufacturing moving today, while strengthening the foundations for long-term industrial resilience.”

The caustic soda tank at Immingham strengthens the UK’s long‑term chemical supply capability. Caustic soda is essential in sectors such as textiles, pharmaceuticals, food processing, water treatment, and metals processing, meaning reliable supply is critical for many industries. An additional facility at Immingham helps to support domestic resilience of caustic soda supply.

GI Chemical Solutions’ operation in Immingham supports the region’s chemical sector and contributes to skilled employment in storage, transport and operations.

For supply enquiries or further information, visit www.csg-corporate.com/gi-chemicals/ or contact info@csg‑corporate.com.

MySep has announced the launch of MySep Middle East LLC, headquartered in Doha, marking a strategic expansion of its global operations. The company also confirmed the appointment of Mohammad Yasser Ramzan as managing director of its Middle East business.

The new entity reinforces MySep’s long-term commitment to supporting oil and gas, LNG operators, EPC contractors, and engineering teams across the Middle East. From its Doha base, the company will focus on delivering local technical engagement, including process optimisation, separator performance assessment, and advanced modelling solutions for both existing assets and new developments.

The move comes despite challenging market conditions and reflects the company’s continued investment in regional growth and technical collaboration. The Middle East remains a critical hub for global energy supply, with increasing demand for data-driven separation technologies to support efficient and reliable operations across upstream, midstream, and LNG sectors.

Ongoing investment in LNG, gas processing, and production facilities across the region has heightened the need for accurate modelling of complex multiphase separation processes, which are essential for maintaining asset performance and operational reliability.

Michel Van Vorselen, Senior Director at MySep, described the opening of the Doha office as a significant milestone for the company. He noted that the region’s central role in global LNG and gas supply is driving demand for more sophisticated separation modelling to support design decisions, plant optimisation, and operational performance. He added that the expansion underscores MySep’s commitment to advancing digital and data-driven approaches, including more rigorous gas-liquid-liquid separation modelling and digital twin applications.

Alongside the office launch, Mohammad Yasser Ramzan will lead regional operations and customer engagement from Doha. He brings extensive experience in the energy sector, with a background in process engineering, operational support, and project execution.

Ramzan highlighted the unique characteristics of the Middle East market, including large-scale LNG facilities, complex operating environments, and long asset lifecycles. He noted that accurate separation modelling is becoming increasingly important for performance optimisation, debottlenecking, and ensuring operational reliability, adding that a local presence will enable closer collaboration with regional customers.

The establishment of MySep Middle East LLC strengthens the company’s global footprint, which includes its headquarters in Singapore and offices in the Netherlands, alongside a network of technical specialists across Europe and North America. The expanded presence is expected to enhance MySep’s ability to deliver consistent technical support while maintaining strong regional engagement.

For more information visit www.mysep.com

Metso has expanded its global Bulk Material Handling network with the inauguration of a new regional hub in Cape Town on April 15th, 2026. The facility is designed to enhance engineering capabilities and provide access to advanced automation technologies for bulk material handling and port customers across the African region. The development marks a further step in the company’s strategy to strengthen its presence in key markets.

The Cape Town hub is expected to reinforce Metso’s position in Southern Africa by deepening customer relationships and supporting a growing installed base of equipment. Operating within the same time zone as its regional clients, the centre is positioned to deliver faster technical support, improved responsiveness, and closer alignment with operational requirements.

Metso has maintained a long-standing relationship with Transnet, South Africa’s state-owned logistics infrastructure operator responsible for the country’s ports, rail and pipeline networks. According to Transnet Port Terminals Chief Executive Jabu Mdaki, the move to localise technical support represents a practical step toward improving operational reliability and performance, while strengthening collaboration in a more structured and sustainable manner.

The company highlighted the rapid growth of the African market as a key driver behind the investment. Ian Barnard, President of Metso’s Africa Market Area, noted that the company’s strong reputation and established partnerships in the region underpin its continued expansion efforts.

The hub employs approximately 60 people and provides a full range of services to customers across Africa, including lifecycle support, equipment modernisation, and technical assistance. In addition to direct employment, the operation is expected to contribute to the local economy through engagement with regional suppliers, contractors, and consultants.

Metso indicated that the facility will also support the development of local industrial capabilities, with a particular focus on skills development among young professionals and the broader workforce. The investment is expected to strengthen the operating environment for port solutions in South Africa and across the continent.

With more than a century of experience and over 8,000 bulk material handling installations globally, Metso continues to expand its footprint in the sector. The Cape Town hub builds on recent strategic developments, including the acquisition of MRA Automation to enhance capabilities in advanced automation and digitalisation. These technologies are expected to be deployed in Africa to support improved reliability and performance through digital tools.

Metso’s bulk material handling portfolio includes a wide range of equipment such as railcar dumpers, apron feeders, conveyors, stackers, reclaimers, and ship loading systems, alongside smart automation solutions. The company is recognised for delivering integrated, lifecycle-focused solutions tailored to evolving customer needs across the industry.

For more information visit www.metso.com

WPU, the plastics recycling business of Vitol, is planning to develop a new chemical recycling facility for end-of-life plastics at the Port of Rotterdam, adjacent to the company’s Rotterdam refinery (VPR). The proposed plant will have the capacity to process 80,000 tonnes of post-consumer plastic annually, increasing WPU’s total recycling capacity to 100,000 tonnes per year.

The Rotterdam site is expected to become one of Europe’s largest chemical recycling facilities for end-of-life plastics. It will utilise WPU’s proprietary batch pyrolysis technology to convert plastic waste into pyrolysis oil, which can be used as a circular feedstock in the production of chemicals, intermediates and new plastics. This approach is intended to deliver a lower carbon alternative to traditional fossil-based naphtha, as demand rises for circular feedstocks and regulatory frameworks across Europe continue to support increased recycled content and the decarbonisation of petrochemical value chains.

According to Jeffrey van Geloof, CEO of WPU and managing director of VPR, the project represents a significant step in the company’s growth strategy. He noted that building on operational experience in Denmark, the facility would substantially expand recycling capacity and support the scaling of WPU’s technology across the European market.

WPU has already deployed its pyrolysis technology at its facility in Farevejle, Denmark, which has an annual capacity of 20,000 tonnes and is currently operating near full utilisation. The company is considered an early mover in the commercial-scale application of plastics pyrolysis for end-of-life materials.

Tom Baker, Vitol’s global head of naphtha and head of the Middle East, said the project marks meaningful progress toward establishing a scalable circular economy in the plastics sector. He added that initiatives of this nature could help address plastic waste challenges, broaden access to alternative petrochemical feedstocks, and reduce the overall carbon intensity of plastic production. He also highlighted the strategic advantage of locating the facility alongside existing refinery infrastructure in Rotterdam, enabling efficient integration with industrial systems and end markets.

The plant will incorporate advanced furnace technology aimed at reducing emissions and improving energy efficiency. Similar systems implemented at Vitol’s Rotterdam refinery have already achieved significant reductions in emissions and energy consumption, positioning the site among the more energy-efficient refineries in Europe.

The project remains subject to regulatory approvals, with a comprehensive stakeholder consultation process expected to form part of the development.

For more information visit www.vitol.com

Hamburg’s Authority for Environment, Climate, Energy and Agriculture (BUKEA) has granted MB Energy approval to construct and operate a new ammonia import terminal, marking a significant milestone in the development of Germany’s emerging hydrogen and alternative fuels infrastructure. Subject to a final investment decision, the facility is planned for development at the site of the Blumensand tank terminal within the Port of Hamburg and is set to become the country’s first large-scale ammonia import hub.

The project is expected to play a pivotal role in supporting future energy security and advancing the ongoing transformation of the industrial and energy sectors. The terminal will be designed for the import and distribution of ammonia, which serves not only as a hydrogen carrier but also as an industrial feedstock and potential alternative fuel, particularly for the shipping sector. By enabling the import of these molecules, the facility aims to strengthen the domestic ammonia market and establish a foundation for scaling the hydrogen economy. In the longer term, it is also anticipated to contribute to the decarbonisation of maritime transport. From a technological perspective, ammonia may additionally be utilised in gas-fired power generation. The terminal will be capable of handling lower-carbon and renewable ammonia, subject to technical feasibility, market availability, and regulatory requirements.

Development will take place at the Blumensand tank terminal, the largest storage facility in the Port of Hamburg, which is owned by MB Energy’s storage subsidiary, enport by MB Energy. The terminal forms part of the wider New Energy Gate project, which also includes planned methanol handling capabilities at the same site. Project plans include the construction of a new storage tank for temporary ammonia storage, upgrades to existing berth infrastructure for inland and seagoing vessels, and the development of rail loading facilities. Future integration options are also being considered, including a potential feed-in connection to a yet-to-be-developed cracker plant where ammonia could be converted into hydrogen for injection into a future hydrogen grid network. The planned annual throughput is expected to reach approximately 600,000 metric tonnes of ammonia.

Volker Ebeling, senior vice president New Energy, Supply & Infrastructure at MB Energy, noted that the granting of the permit represents a key project milestone following a constructive permitting process. He highlighted the significance of the ammonia terminal in advancing Hamburg’s energy transition, describing it as a strong signal for a future-oriented and reliable supply of energy and raw materials, and expressed appreciation for the collaborative and solution-focused engagement of all parties involved throughout the process.

For more information visit www.mbenergy.com

The launch of a new Open Season for CO₂ storage capacity in Wilhelmshaven and Rotterdam marks a significant milestone in advancing Europe’s decarbonisation efforts. The initiative offers industrial emitters a timely opportunity to secure long-term access to reliable carbon storage infrastructure, a critical component in achieving net-zero targets.

By opening this process, companies are invited to formally express interest, reserve future capacity and actively participate in the development of scalable carbon management solutions. The Open Season is designed to support the growing demand for carbon capture and storage (CCS), particularly within major port-industrial clusters where emissions are concentrated and infrastructure integration is key.

Strategically located, Wilhelmshaven and Rotterdam are positioned to play a pivotal role in the evolving carbon storage landscape. Their established industrial ecosystems and connectivity make them ideal hubs for enabling efficient CO₂ transport and storage, supporting both regional and cross-border decarbonisation efforts.

The initiative also reflects a broader commitment, in collaboration with key partners, to accelerate the energy transition and provide practical, large-scale solutions for hard-to-abate sectors. By facilitating early engagement and capacity planning, the Open Season aims to ensure that infrastructure development aligns with industry needs, reducing uncertainty and enabling informed investment decisions.

With the deadline for expressions of interest set for 24th April, companies have a limited window to participate in this important phase. Early involvement will not only secure potential storage capacity but also contribute to shaping a robust and scalable pathway toward industrial decarbonisation.

As momentum builds around carbon capture and storage, initiatives such as this Open Season highlight the importance of collaboration, forward planning and infrastructure readiness in delivering a sustainable, low-carbon future.

For more information visit www.hesinternational.eu/en/new-energies

H2NorthEast, a leading carbon capture-enabled hydrogen production facility being developed in the heart of industrial Teesside, has signed a Memorandum of Understanding (MoU) with Northern Gas Networks (NGN), the gas distributor for the North of England, to pursue opportunities to provide low carbon hydrogen to industrial end users across North East England.

The agreement comes as H2NorthEast submits its application for Phase 1 of the project into the East Coast Cluster Teesside selection process. Launched by the Department for Energy Security and Net Zero (DESNZ) in February 2026, this is a process to identify projects that could connect to and utilise CO2 storage capacity in the planned Northern Endurance Partnership transportation and storage infrastructure by 2032, crucial to achieving net zero in Teesside, one of the UK’s most carbon intensive industrial regions.

CATS Terminal
Image: Dawn McNamara 09/04/26

H2NorthEast and NGN are both committed to reducing UK emissions, through the development of decarbonised power and industrial clusters enabled by carbon capture and storage (CCS), and low carbon hydrogen transportation networks.

The MoU creates an opportunity for low carbon hydrogen produced by H2NorthEast, to also be delivered beyond Teesside to a wider customer base, via the East Coast Hydrogen future hydrogen transportation network, in which NGN is a partner. It would help support large-scale industrial decarbonisation for the UK through the supply of affordable low carbon hydrogen to energy-intensive industries, and H2NorthEast can bring significant economic benefits to Teesside including investment, jobs, skills development and supply chain opportunities.

Nathan Morgan, CEO of Kellas Midstream, one of the H2NorthEast project partners, said: “We are pleased to sign this MoU with NGN which marks an important step in ensuring that the low carbon hydrogen produced by H2NorthEast can decarbonise critical industries. It represents further progress in the creation of a fully integrated UK hydrogen value chain from production through to end use.”

Mark Horsley, CEO of Northern Gas Networks, said: “We are proud to collaborate with Kellas and support the H2NorthEast application into the East Coast Cluster selection process. Decarbonising industry requires this type of strategic approach where hydrogen production and transportation can move forward together. Our agreement will be key to securing jobs and investment for the region, while accelerating the UK’s transition to a cleaner energy system.”

For more information visit www.northerngasnetworks.co.uk

Following the strong success of its 2026 edition, the Africa Energy Indaba has unveiled its 2027 theme: African Energy – Pathways to Prosperity Connectedness and Cooperation.

This theme signals a forward-looking and decisive vision for the continent’s energy trajectory – one focused on enhancing linkages between countries, markets and communities to unlock Africa’s extensive energy resources and drive sustainable economic development.

Building on key insights and outcomes from 2026, the 19th edition of the Africa Energy Indaba will place emphasis on integrated energy systems, regional partnerships and collaborative frameworks – all critical to shaping a more resilient and inclusive energy ecosystem. In the context of a rapidly shifting and often uncertain global landscape, the importance of alignment and cooperation continues to grow.

Central to the 2027 theme is the understanding that energy underpins Africa’s development ambitions. Expanding and strengthening infrastructure – including cross-border transmission systems, regional power pools and energy corridors – will support more efficient electricity distribution and enable the optimal use of the continent’s diverse energy mix.

In line with the objectives of the African Continental Free Trade Area (AfCFTA), the event will highlight energy connectivity as a key driver of industrial growth, trade expansion and regional competitiveness. More integrated energy markets are expected to unlock investment potential, stimulate economic activity and improve access to reliable and affordable power.

At the same time, the programme recognises that infrastructure development alone is insufficient. A strong emphasis will be placed on human collaboration – bringing together policymakers, utilities, investors, developers and communities to co-create scalable and practical solutions. This collaborative approach is expected to support the advancement of cross-border energy initiatives, strengthen energy trading markets and create an enabling environment for innovation and business growth.

The 2027 agenda will also reflect a pragmatic and balanced approach to the energy transition. Discussions will consider how Africa can effectively utilise its full energy portfolio – including renewables, gas, nuclear and existing baseload capacity – to ensure security of supply, affordability and long-term sustainability, while remaining aligned with climate objectives.

In addition, a key priority will be mobilising capital and accelerating the pipeline of bankable energy projects. By facilitating connections between developers, financiers and policymakers, the Africa Energy Indaba will continue to act as a catalyst for investment and a platform for converting dialogue into tangible outcomes.

Liz Hart, managing director of the Africa Energy Indaba, noted that connectedness and cooperation are fundamental to the continent’s energy future – highlighting that the 2027 event will play a pivotal role in fostering partnerships that drive meaningful progress.

The upcoming edition will once again convene senior government representatives – including African Energy Ministers – alongside executives from utilities, financial institutions, infrastructure developers and global energy companies. Through a comprehensive programme of plenary sessions, strategic discussions and high-level engagements, the event will support policy alignment, facilitate investment and encourage cross-sector collaboration.

As Africa advances toward greater energy security and economic transformation, the Africa Energy Indaba continues to stand as a leading platform for the sector – where strategic ideas evolve into action and partnerships help shape the continent’s future.

For more information visit www.africaenergyindaba.com

Energy major TotalEnergies has announced a new hydrocarbon discovery on the Moho license offshore the Republic of Congo, marking a strategic milestone for a country rapidly pursuing 500,000 barrels per day (bpd) in oil production. Led by TotalEnergies as operator (63.5 percent) alongside Société Nationale des Pétroles du Congo (SNPC) – which is led by Managing Director Raoul Ominga – and Trident Energy, the discovery targeted the Moho G structure at the broader Moho complex, reinforcing the country’s position as a leading mature producer with untapped upside.

The African Energy Chamber (AEC) commends TotalEnergies for this latest achievement, recognising the company’s long-term commitment to Congo’s upstream sector. The Chamber also acknowledges the vital role played by the SNPC and Minister of Hydrocarbons Bruno Richard Itoua in fostering a stable, investment-friendly environment that enables international operators to thrive. Their collaborative approach continues to position Congo as a competitive destination for exploration investment as well as a home for foreign operators.

Situated within the prolific Moho complex – which represents more than half of Congo’s total oil production – the Moho G structure encountered a hydrocarbon column of approximately 160 metres in good quality Albian reservoirs. The find complements the previous Moho F discovery, which combined feature estimated recoverable resources of 100 billion barrels. The new find is particularly significant given its proximity to existing production infrastructure, allowing for cost-effective tie-backs and accelerated commercialisation. This includes the Alima and Likouf FPSO facilities which have a combined current production capacity of 90,000 bpd.

For TotalEnergies, this latest discovery aligns closely with the company’s plans to expand production capacity across key licenses in the Congo. The company committed over $500 million in 2025 to expand the Moho Nord complex, with the latest find showcasing the viability of infrastructure-led exploration. By leveraging existing FPSO facilities, the Moho G discovery will unlock additional resources at Congo’s biggest oil producing block while enhancing overall project economics and long-term resilience.

“TotalEnergies’ latest discovery in Congo sends a strong message to the market – this is a country where infrastructure, policy and partnership come together to unlock real value. Congo is proving that exploration is not just about frontier basins, but about maximising what you already have and doing it smarter, faster and more efficiently,” states NJ Ayuk, executive chairman, AEC.

Beyond Moho Nord, Congo’s exploration landscape continues to evolve as operators pursue additional volumes across both offshore and onshore margins. Major campaigns include Perenco’s February 2026 launch of the Kombi 2 platform – a $200 million facility targeting additional reserves of 10 million barrels at the Kombi-Likalala-Libondo II field. The new-generation infrastructure will host a six-well drilling campaign starting in 2026, aimed at bolstering production and optimising field efficiency.

Congo’s energy ambitions transcend the oil sector, with the start of the Eni-led Nguya FLNG unit in December 2025 signaling the second phase of the Congo LNG project. The 2.4 million-ton-per-annum (mtpa) facility complements the operational 0.6 mtpa Tango vessel, bringing total project capacity to 3 mtpa. The integrated development processed gas from the Nené and Litchendjili fields at the Marine XII license, making the country Africa’s fifth biggest LNG exporter.

As Congo continues to align policy, infrastructure and investment, the country is entering a new era of exploration – one defined not only by scale, but by strategic execution. With global demand evolving and capital becoming more selective, Congo’s model offers a compelling blueprint for sustainable upstream growth.

Brenntag, the global market leader in chemicals and ingredients distribution, today announced a partnership with BASF for the distribution of Keropur fuel performance additives packages in Europe and some countries beyond. Keropur branded fuel performance packages are for Gasoline as well as Diesel and are aimed at fuel retailers and fuel marketers e.g. terminals as well as wholesale fuel suppliers.

Keropur is a highly effective multifunctional fuel additive which provides smoother running and increases performance by deposit control, conductivity and cetane number improvement, anti-foam, and anti-corrosion performance. Additives are used to upgrade base fuels beyond legal specifications and industry standards and are key to enabling better drivability, increased power and potentially lower maintenance costs, contribute to sustainability by reducing fuel consumption and exhaust emissions. Keropur also offers options for branded and differentiated fuels.

Brenntag has deep expertise in refinery additives, brings exceptional market reach and a strong supply chain network. Together, Brenntag and BASF are creating new opportunities to deliver high-performance solutions like Keropur to a broader range of customers across the fuel industry.

Jeroen Bakker, president focused industries and services Brenntag essentials EMEA, states: “This partnership represents an important step in expanding the reach of our innovative fuel additive portfolio. Brenntag’s capabilities and customer focus make us the right collaboration partner for BASF to expand the availability of fuel additive solutions across Europe. We very much look forward to serving our and the BASF customers to our very best.”

Roland Merten, head of sales management EMEA, Fuel Additives, BASF: “This partnership represents a meaningful step in expanding the reach of our innovative fuel additive portfolio. Brenntag’s capabilities and customer focus make them an outstanding partner as we expand the availability of our fuel additive solutions worldwide.”

For more information visit www.corporate.brenntag.com

The African Energy Chamber (AEC) has welcomed bp’s acquisition of a 60 percent operating interest in three offshore exploration blocks in Namibia, describing the move as a strong endorsement of Africa’s frontier basins and the continent’s expanding role in global energy supply.

The transaction grants bp operatorship of blocks PEL97, PEL99 and PEL100 in the Walvis Basin, representing a significant expansion of the company’s upstream footprint in Africa. The assets were acquired from Eco Atlantic Oil & Gas, positioning bp closer to Namibia’s fast-developing deepwater exploration corridor near the Orange Basin.

Industry stakeholders view the deal as further evidence of a shift in Africa’s exploration narrative, from perceived frontier risk to a more competitive global opportunity, supported by strong geological potential, improving partnerships and growing investor confidence.

NJ Ayuk, executive chairman of the AEC, emphasised the importance of both bp’s investment and the early exploration efforts led by Gil Holzman and Eco Atlantic. He noted that such collaboration between international majors and Africa-focused companies is key to unlocking value, building technical expertise and accelerating development across the continent.

Namibia has emerged as one of the world’s most closely watched frontier exploration regions following a series of offshore discoveries in the Orange Basin by companies including Shell, TotalEnergies and Galp. These discoveries have repositioned the country as a potential multi-billion-barrel deepwater oil province, attracting significant international interest.

While the Walvis Basin remains comparatively underexplored, it is increasingly regarded as a geological extension of the same petroleum system. Early indications suggest similar reservoir characteristics, positioning it as a potential next frontier for exploration-driven investment. Although development timelines remain long-term, Namibia is targeting first offshore production by the end of the decade, subject to continued exploration success and infrastructure development.

bp’s entry reflects a broader rebalancing of global upstream portfolios, with international oil companies prioritising high-impact exploration opportunities capable of delivering long-term reserves growth. As mature basins face declining output and rising costs, frontier regions such as Namibia are gaining prominence due to their scale, geological upside and relatively open acreage.

Under the terms of the agreement, Eco Atlantic will retain a minority stake alongside NAMCOR, ensuring local participation in the development of the blocks. This structure is seen as critical for translating exploration success into domestic economic value, skills development and long-term production capacity.

Although Namibia remains in the exploration phase, the pace of activity suggests a rapidly evolving basin. bp’s involvement is expected to bring both technical expertise and financial resources that could accelerate appraisal drilling and future development planning.

The transaction also reinforces Africa’s upstream sector as an increasingly important component of global energy security, particularly as supply diversification becomes a strategic priority. bp’s investment, alongside the early groundwork established by Eco Atlantic, highlights a collaborative model that positions Namibia as a key player in Africa’s deepwater future.

For more information visit www.energychamber.org

The Commercial UAV Expo 2026, widely regarded as the world’s leading commercial drone trade show and conference, has announced its Opening Keynote for the upcoming edition. Titled “The View From the Field: What Operators, Pilots, and Fleet Managers Are Saying About the Commercial Drone Industry,” the keynote will take place on September 1st, kicking off the event scheduled for September 1st–3rd at Caesars Forum in Las Vegas.

The session will highlight findings from a forthcoming industry-wide survey conducted by Commercial UAV News in collaboration with Pilot Institute. The State of the Industry Survey 2026 aims to capture insights from drone pilots, fleet managers, operations leaders, and regulatory compliance professionals actively working in commercial UAS operations.

The keynote will present a detailed and unfiltered view of the industry, focusing on current trends, operational challenges, and emerging opportunities. Matt Collins will introduce key findings from the research, followed by a discussion with Greg Reverdiau on the broader implications for the sector. Topics are expected to include regulatory developments, hardware procurement issues, workforce challenges, and the future trajectory of commercial drone operations.

According to Reverdiau, the session is designed to center the perspectives of UAV operators, emphasising the importance of real-world input as the industry navigates evolving regulations, supply chain shifts, and advancing technologies. Collins noted that the survey seeks to replace speculation with data-driven insights, helping stakeholders better understand both opportunities and barriers within the sector.

The survey, set to launch in the coming weeks, will address critical issues such as the FAA’s proposed Part 108 BVLOS framework, the impact of the FCC Covered List on procurement decisions, adoption of autonomous and AI-assisted systems, airspace access, workforce development, data security, and overall business outlook.

As part of the event, Pilot Institute will serve as an official partner and host “The Pilot Hub” on the show floor, featuring expert-led sessions, networking opportunities, and guidance on certifications, waivers, and career pathways in the drone industry.

Registration for the event is now open, with additional details on the keynote and survey expected to be released ahead of the expo.

To learn more about the Opening Keynote, visit www.expouav.com/keynotes

Registration is now open; visit www.expouav.com to learn more and register.

The Association for Materials Protection and Performance (AMPP), a leading global authority in materials protection and performance, is inviting certified professionals and industry stakeholders to participate in a complimentary 60-minute webcast scheduled for 2 p.m. EDT on Wednesday, April 15. The session, titled “Certifications in Action: New Tools, Recognition & What’s Next,” will highlight recent developments and future directions within AMPP’s certification programs.

The webcast will provide an overview of key updates, including enhancements to exam delivery systems, the introduction of recognition merit badges, and new tools aimed at helping professionals more effectively manage and advance their credentials.

Participants will gain insights into several important areas, including the delivery of the new virtual Senior Certified Coatings Inspector (CIP 3) certification exam, the role of recognition merit badges in showcasing professional experience and commitment, and the use of credentialing checklist guides to plan and maintain certifications. The session will also cover recent updates to the My Certification Portal.

Featured speakers from AMPP include Silvia Palmieri, certification community development specialist, and Karyn Waller-Finkelstein, CPA, CAE, senior manager of certification development and product strategy.

According to Palmieri, AMPP certifications are designed to reflect real-world competence while supporting professionals throughout their careers. She noted that the webinar introduces new tools and recognition opportunities that simplify tracking progress, demonstrating expertise, and aligning with evolving industry expectations.

AMPP certifications are globally recognised for establishing a baseline of knowledge, skills, and competency across the materials protection and performance industry. Continued enhancements to certification delivery and professional recognition aim to ensure credential holders remain well-prepared to meet industry demands.

The webcast will take place on Wednesday, April 15, 2026, at 2:00 p.m. EDT and will run for approximately 60 minutes. Professionals interested in maximising the value of their AMPP certifications and staying informed about upcoming changes are encouraged to attend. Further information about certification programs is available through AMPP’s Education and Certification resources.

For more information visit www.ampp.org/education

From renewable diesel to sustainable aviation fuel, biofuels are at the centre of the global shift towards more sustainable transport. And with the demand growing all the time, refiners are racing to ensure their facilities and infrastructure are able to serve this burgeoning sector.

One area in need of attention is fuel tank linings. For decades, organisations have used specialised coatings to protect the interior of crude storage tanks from corrosion.

Yet unlike conventional fossil fuels, biofuel feedstocks contain aggressive new compounds. Traditional long-term testing methods have identified that these compounds pose significant challenges to traditional tank linings, however, these tests fail to reflect the real-world reality of the biofuels business model.

Here, Joao Azevedo and Michael Harrison from Sherwin-Williams explain how biofuel adoption is driving changes in tank storage and refining practices, and how updated testing methods reflect real-world storage conditions.

Corrosion protection considerations

With the global shift towards more sustainable transport taking hold, biofuel demand is set to expand by 38 billion litres in the period 2023 to 2028. That’s a near 30 percent increase from the last two five-year periods.¹

This growing market is in the process of building the protocols and practices it needs to operate safely, effectively, and profitably. One important area is biofuel storage, and the appropriate methods needed to protect expensive infrastructure from corrosion.

For years, the fossil fuel production sector has used specialised coatings to perform this function, and the expectation is that biofuel operators will follow suit.

However, there are a number of sector-specific considerations. While finished biofuels are chemically identical to traditional fuels, bio-feedstocks, such as recycled cooking oil, are more aggressive in nature, presenting a risk of degradation.

These lipid-based bio-feedstocks are “living substances” that decompose into aggressive fatty acids during storage, particularly at high temperatures. With prolonged storage these fatty acids will increase in the bulk liquid, further compounding the corrosion risk and damage to internal linings.

In addition, operators face challenges during the vapour stage. Because exposing bio-feedstocks to air at high temperatures can lead to rancidification, or the formation of corrosive organic acids (including acetic and formic acid) and aldehydes.

Evolution of testing methods

Biofuel adoption, then, is driving a change in how refiners think about and assess, storage tank lining.

Traditional long-term testing methods for fossil fuel, for example, evaluate tank corrosion after six months of exposure. When this approach was utilised in the biofuel arena, it revealed significant damage to traditional tank linings.

But the method was not reflective of the real-world conditions of this emerging industry. Biofuel tanks are regularly replenished, with the turnaround of feedstocks in storage typically being less than three weeks.

A new method of cyclic testing, developed by Sherwin-Williams, incorporates regular inspections and the partial replacement of feedstocks on a monthly basis. Compared to traditional long-term storage tests, this provides a much better simulation of realistic storage and replenishment cycles and, therefore, more accurate and reliable data on coating durability and performance

This new method is currently being tested in a comparative study, with the first six monthly results demonstrating that uncoated panels show pitting corrosion during the vapour phase and at the bottom.

Such updated testing methods have enhanced accuracy in predicting real-world outcomes, which means refiners can now consider a broader range of lining materials. And test results are driving the development of next generation, high performance bio-feedstock tank linings.

The potential economic benefits are clear. By investing in infrastructure protection, facility owners can maximise the use of existing tanks, and embrace this new, rapidly expanding market. It all adds up to greater reliability and confidence for refiners and storage operators alike.

The view ahead

Biofuel adoption is gaining fast momentum, but their distinct chemical behaviour is challenging the traditional approach to tank lining corrosion protection.

Early assumptions about long-term degradation ignored the way biofuel feedstock tanks are used in practice, and ended up overstating the risks.

With cyclic testing, which mirrors real-world feedstock storage conditions, the industry can now better evaluate tank lining performance, confidently protect their biofuels infrastructure, and help support the wider adoption of biofuels as a sustainable energy source.

Reference:

1. IEA Bioenergy. (2024) IEA Renewables 2023 – Biofuel and Biogas Forecasts. Available at: www.ieabioenergy.com/blog/publications/iea-renewables-2023-biofuel-and-biogas-forecasts/ Last accessed: 3^rd February 2026.

OPW Retail Fueling, a global leader in fluid-handling solutions, will showcase its latest offerings in Booth 1001 during the upcoming M-PACT Fuel & Convenience Tradeshow, April 15-16, at the Indiana Convention Center in Indianapolis, IN.

OPW Retail Fueling will highlight a wide array of products during the show, with its 71SO Segmented Overfill Prevention Valve being a particular standout. The 71SO Segmented Overfill Prevention Valve, which significantly reduces storage, shipping, installation and testing complexities, recently earned California Air Resources Board (CARB) Enhanced Vapor Recovery (EVR) certification. This designation signifies that the 71SO Segmented Overfill Prevention Valve meets the industry’s highest safety, containment and emission standards.

The 71SO Segmented Overfill Prevention Valve:

• Retains the breakthrough two-stage positive shut-off mechanism of the original OPW 71SO
• Allows for more compact packaging and easier transport due to the drop tube’s four 5′-long interlocking sections
• Eliminates shipping damage and overlength shipping fees
• Is easily pieced together during on-site installation without the need for glue or epoxy

“The new 71SO Segmented Overfill Prevention Valve reflects the OPW Retail Fueling team’s commitment to addressing our customers’ fueling system equipment challenges regardless of when they occur in the lifecycle of a part — during installation, testing, routine operation or even during shipping,” said Ed Kammerer, vice president global product marketing, OPW Retail Fueling. “‘Fueled By Excellence,’ our mission is to provide dispensing, fuel containment and transfer products that rise above the industry standard to deliver superior performance. We look forward to showcasing that at M-PACT.”

In addition to hands-on product demonstrations with OPW Retail Fueling Product Managers and District Managers, OPW Retail Fueling will record episodes of its popular podcast, “The Fueling Station,” at the show.

For updates from the OPW booth during the show, follow along on LinkedIn and Facebook. To learn more about OPW Retail Fueling products and expertise, please visit opwglobal.com/opw-retail-fueling.

Golden Pass LNG, a joint venture between QatarEnergy and ExxonMobil, has reached a significant milestone on its path to full operations with the production of its first liquefied natural gas (LNG). The achievement marks the start-up of the first of three LNG trains that together will deliver a total production capacity of 18 million tonnes per annum.

The successful production of first LNG represents a critical step toward the commencement of export activities from the facility in Sabine Pass, Texas. It sets the foundation for sustained liquefaction operations and positions the project to meet its commercial and strategic objectives, with the first cargo expected in the second quarter of 2026.

Image source QatarEnergy

Saad Sherida Al-Kaabi described the milestone as particularly significant, noting that the project represents one of the largest single investment decisions in the history of the US LNG sector. He highlighted that the facility’s transition into operations and entry into the global market comes at a time when energy security remains a top priority worldwide.

The development forms part of QatarEnergy’s broader international investment strategy, which has been pursued over the past decade. It also aligns with previously announced plans to invest approximately $20 billion in the U.S. energy sector. The project is expected to play an important role in enhancing global energy security while supporting access to cleaner energy sources.

The Golden Pass LNG project is owned by QatarEnergy, which holds a 70 percent stake, and ExxonMobil, which holds the remaining 30 percent. The partners took a final investment decision exceeding $10 billion in February 2019 to advance the development of the export facility.

With first LNG now achieved, the project moves closer to full operational status, marking a major step forward in strengthening LNG supply capacity to global markets.

For more information visit www.qatarenergy.qa

A new contract has been successfully secured, marking an important milestone for the organisation as it continues to expand its portfolio within high-hazard industrial environments.

The agreement, which spans three years, has been awarded by a client operating a major COMAH (Control of Major Accident Hazards) facility. This partnership represents a significant opportunity to contribute to the safe and strategic development of a complex industrial site.

The initial phase of the project will focus on a comprehensive, site-wide assessment of existing buildings. This will form the foundation for a detailed strategic plan addressing both remediation requirements and future site development. The approach will take into account critical factors such as operational needs, major accident hazards, and the practicalities of phased implementation, while also ensuring alignment with both current demands and long-term functionality.

Through this engagement, the organisation will apply its specialist expertise to support improvements in safety, resilience, and overall performance. The project is expected to play a key role in strengthening the long-term sustainability and operational effectiveness of the facility.

Work is set to commence shortly, with the team looking forward to delivering meaningful value and establishing a strong collaborative relationship with the client.

For more information visit www.engenix-consulting.co.uk

PALA has announced the appointment of Richard Moran to the role of policy and procedure manager, marking a significant step in strengthening the organisation’s operational framework.

Moran has consistently demonstrated a strong commitment to doing things the right way, bringing structure, clarity, and accountability to the company’s operations. His approach has contributed to more effective and disciplined processes, making him well-suited for this critical role.

In his new position, Moran will focus on enhancing policies and procedures across the organisation. His work will play a key role in driving consistency, reinforcing operational standards, and ensuring the company continues to deliver safe, high-quality, and predictable outcomes, hallmarks of PALA’s reputation.

The appointment comes at an important time for the organization, as it continues to grow and scale. Strong systems and well-defined procedures are essential to maintaining performance at a high level, and this role will be central to supporting that objective.

With his leadership, attention to detail, and commitment to continuous improvement, Moran is expected to make a lasting impact, helping to further strengthen the foundation for PALA’s ongoing success.

For more information visit www.palagroup.com