Hughes Safety Showers is a premier manufacturer of emergency safety showers and eye/face wash equipment designed to protect workers on hazardous industrial sites.
Our ANSI compliant solutions are engineered to provide a thorough decontamination in the event of an accidental chemical splash or spillage.
Is Hydrogen a Realistic Replacement for Oil and Gas in the Short and Medium Term?
Asthe world accelerates its transition towards cleaner energy sources, hydrogen has emerged as a potential game-changer. Long hailed for its clean-burning properties—its only byproduct being water—hydrogen seems like a perfect candidate to replace oil and gas. But is it realistic to expect hydrogen to significantly displace fossil fuels in the short and medium term?
Hydrogen is incredibly versatile. It can be used in fuel cells for transportation, as a feedstock in industrial processes, and even to store and transport energy. It holds particular promise in sectors that are harder to decarbonize, such as aviation, shipping, and heavy industry, where electrification may not be feasible. However, its potential hinges on the ability to scale production in an economical and environmentally friendly manner. Hydrogen is categorized into three main types:
• Grey hydrogen, produced from natural gas with significant carbon emissions;
• Blue hydrogen, also from natural gas but with carbon capture and storage (CCS) to reduce emissions; and
• Green hydrogen, produced through electrolysis using renewable energy, which is the cleanest but also the most expensive.
In the short term, hydrogen faces significant barriers that prevent it from replacing oil and gas on a large scale. The most pressing challenges include:
Production Costs: Currently, green hydrogen is expensive to produce—up to three times more costly than grey hydrogen. The technology to make green hydrogen needs to become more affordable and scalable before it can compete with oil and gas.
Infrastructure Limitations: Hydrogen distribution and storage infrastructure is still underdeveloped. Transporting hydrogen through existing gas pipelines requires costly modifications due to hydrogen’s smaller molecular size, which can lead to leaks. Building entirely new infrastructure is even more expensive.
Energy Efficiency: Hydrogen’s energy efficiency, particularly in transport, is lower compared to electric batteries. When hydrogen is produced, transported, and then converted into electricity, a significant amount of energy is lost in the process.
Given these hurdles, it’s unlikely that hydrogen will replace oil and gas across all sectors in the short term. Instead, it will likely be used in niche applications, such as hydrogen-powered heavy-duty trucks, where batteries might not offer the required range and performance.
In the medium term, say over the next 10 to 20 years, hydrogen’s role could grow considerably, especially if key advancements are made. Several factors could contribute to a more favorable environment for hydrogen.
Government Policies and Incentives: Nations worldwide are increasingly committing to net-zero targets, with many earmarking hydrogen as a vital part of their energy strategies. Significant funding and incentives are being directed at green hydrogen projects, which could bring down costs through economies of scale.
Technological Innovations: Improvements in electrolysis technology and energy storage could make green hydrogen more cost-competitive. Additionally, carbon capture and storage (CCS) technology could make blue hydrogen a viable interim solution, bridging the gap between fossil fuels and renewable hydrogen.
Decarbonization Pressure on Heavy Industries: Sectors like steel, cement, and chemicals, where emissions are hard to eliminate with current technologies, could benefit from hydrogen. Green hydrogen, in particular, could allow these industries to maintain production without carbon emissions.
Oil and gas are deeply embedded in the global economy, and despite the rapid push towards renewables, they will likely remain part of the energy mix in the short and medium term. Natural gas, in particular, is being used as a “bridge fuel” to help transition to lower-carbon energy sources. Additionally, oil and gas companies are increasingly investing in hydrogen projects, positioning themselves to be part of a diversified future energy landscape.
However, the economic and environmental pressure to decarbonize means that hydrogen could gradually take on a more significant role, particularly in sectors where oil and gas have traditionally dominated. The shift will depend on how quickly costs come down and how effectively infrastructure challenges are addressed.
COVER STORIES & SPECIALS
Meeting the Challenges of FPSO Design and Construction
In this Q&A, OGI sits down with the Senior Vice President of Business Development, Paal Gunnar Heistad, of Yinson Production.
OGT
Optimized Gas Treating, Inc. (OGT) has been at the forefront of innovation in the gas processing industry since its founding in 1992.
Health & Safety: Hazardous Areas
• Illuminating Safety in the Oil and Gas Industry
• Monitoring Noise in the Oil & Gas Industry
• Enhancing Operational Safety
Pioneering the Successful Installation of 500 JetBased Wellbore Barriers Globally
In the ever-evolving landscape of the oil and gas industry, innovation is the cornerstone of progress writes Eivind Knudsen - Chief Operations Officer at HydraWell Intervention AS.
Can Robots Replace Workers in the Oil and Gas Industry?
The oil and gas industry, like many others, is constantly evolving. As technologies advance and the skilled labor pool shrinks, companies are increasingly turning to automation and robotics to streamline operations.
CONTENTS
MIDSTREAM & PIPELINES
Will Pipe-laying Come to an End?
Human life is always demanding energy everywhere on the planet. We at Suxxesion have been participating in important pipe line projects from the gulf of Mexico to Malaysia and India, pipelines are the veins of the world.
PROCESSING
Sustainable Switch: How Renewable Polypropylene Makes Essential Filtration Greener
The right filtration choice from the outset of procurement helps oil and gas producers ensure smooth operations, reduce OPEX, boost commercial performance and, increasingly, be good to the planet.
HYDROGEN SPECIAL
Rigflex Gaskets: Intelligent Testing for Bolted Connections
Flexitallic has introduced its innovative RIGFLEX FP and RJ gaskets, offering a breakthrough in leak testing high-pressure applications in the oil & gas and petrochemical sectors. These innovative gaskets provide a more efficient and safer solution, reducing costs and improving operational uptime by eliminating the need to leak test entire systems.
Precision Temperature Control for a Sustainable Future Transforming Power Generation in the Oil & Gas Industry
We are LAUDA Technology – the world leader in precise temperature control. Our constant temperature equipment and systems are at the heart of important applications contributing to a better future. As a complete one-stop-supplier, we guarantee the optimum temperature in research, production, and quality control.
Transforming Power Generation in the Oil & Gas Industry
ADIPEC SPECIAL EVENTS
Meeting the Challenges of FPSO Design and Construction
In this Q&A, OGI sits down with the Senior Vice President of Business Development, Paal Gunnar Heistad, of Yinson Production. The company is committed to driving an inclusive energy transition, with a commitment to being carbon neutral by 2030, and net zero by 2050.
OGI: Can you explain the process of converting an existing oil tanker into an FPSO unit?
Heistad: In simple terms, the hull conversion entails the refurbishment and life extension of the existing oil tanker. The key steps include replacing the steel and refurbishing the marine systems that will be used for FPSO duty.
The tanker then needs to be modified to accommodate the FPSO mooring system (either turret or spread moored solution) and the incoming and outgoing well streams. Finally, the tanker deck and superstructure need to be structurally modified and prepared for the installation of marine utility systems, topside module support structures and the topside modules themselves.
OGI: How does Yinson Production ensure the reliability and safety of its FPSO and FSO units in harsh offshore environments?
Heistad: FPSO and FSO units often operate in harsh and unpredictable offshore environments, facing extreme weather conditions, wave and wind forces, and corrosive saltwater.
To remain reliable and safe, these floating facilities require extensive engineering and operational expertise. Our sophisticated
engineering designs, rigorous maintenance protocols, and effective risk management strategies are all necessary to assure the structural integrity and stability of floating units while mitigating risks.
Several international conventions, protocols, regulatory requirements, industry standards and codes are already in place to provide a structured framework.
At Yinson Production, we diligently adhere to these established norms to effectively address the inherent challenges that accompany offshore operations.
OGI: What are the main challenges faced during the design and construction of FPSO units?
Heistad: The main challenge commonly revolves around the integration of various complex components to achieve the
“We are at the forefront of integrating carbon reduction technologies into our FPSO fleet,” says Mr Heistad.
desired FPSO capacity and performance, as specified by the field operators. Additionally, finding the right shipyard, fabrication facility, and equipment suppliers is a challenge in a tightening market.
As a top-tier FPSO contractor, we are tasked with the engineering, procurement and construction (EPC) of the FPSO hull, topsides and integration of various systems to enable efficient and reliable operations. Besides that, our effective supply chain management and diligent project management, allow for on-time and on-budget delivery.
OGI: Can you elaborate on Yinson Production’s Zero Emissions FPSO Concept and its expected impact on carbon neutrality goals?
Heistad: Yinson is committed to driving an inclusive energy transition, with a commitment to being carbon neutral by 2030 and net zero by 2050. This ambition has driven the innovation in our FPSO designs, culminating in the Zero Emission FPSO concept.
This concept encompasses various emission-reduction and energy-efficiency technologies to improve overall efficiency. Implementing the concept is fundamental to achieving our climate goals. Since the introduction of the concept, we have made strides in integrating most
FPSO Atlanta in Brazil.
Paal Gunnar Heistad, Yinson Production
of the technologies on our projects. The ongoing Agogo FPSO project would be the leading benchmark on emission-reduction technologies and would be the most efficient in Yinson’s fleet.
OGI: Can you provide an example of a successful FPSO project and its key achievements?
Heistad: The ongoing Agogo FPSO development is on track to be a successful FPSO project. The project demonstrated design acumen and strong project development performance from the Yinson Production team, our client and contractors.
At this time of writing, Agogo FPSO is undergoing construction and the project is 75% complete after 21 months of project execution.
Agogo FPSO has implemented carbon emission reduction technologies that demonstrate an industry-leading position. These technologies include closed flare system and hydrocarbon gas blanketing of cargo tanks, combined cycle power generation, post-combustion carbon capture, electrification with variable speed drives and seawater turbine generator.
OGI: How does Yinson Production’s strategy align with global trends towards sustainable and low carbon energy solutions?
Heistad: We are at the forefront of integrating carbon reduction technologies into our FPSO fleet. It is evident from our ongoing projects such as the FPSO Maria Quiteria and the Agogo FPSO that we implement carbon reduction initiatives. We are also working on reducing flaring of hydrocarbons from our existing fleet. We are also working on the development of low-carbon energy solutions to deliver an end-to-end carbon capture, collection,
Agogo FPSO under construction.
transportation and storage solution. This strategic direction echoes our climate ambitions.
OGI: How does Yinson Production collaborate with client and partners to develop and implement its sustainability initiatives?
Heistad: Yinson Production believes in collective action to drive long-term and sustainable change. We are proactive in collaborating with our clients and partners in their sustainability journey while pursuing wider sustainability initiatives for inclusive energy transition.
As an example of a fruitful client engagement, we are installing the world’s first offshore post-combustion carbon
capture plant onboard Agogo FPSO estimated to be operational in 2025. This pilot-scale unit will capture CO2 from the gas turbine exhaust, serving as a demonstration unit in an offshore floating environment to assess technical readiness and gain operational experience.
Yinson Production’s expertise in converting oil tankers into FPSO units, coupled with its commitment to ensuring the reliability and safety of these floating production systems in harsh offshore environments, showcases the company’s engineering prowess and dedication to industry standards. By addressing the challenges of FPSO design and construction with effective project and supply chain management, Yinson Production consistently delivers highquality, efficient, and on-budget solutions. Their innovative Zero Emissions FPSO concept further aligns Yinson Production with global sustainability trends, reinforcing their leadership in driving the energy transition. The Agogo FPSO project exemplifies Yinson Production’s capability to integrate cutting-edge carbon reduction technologies, underscoring the company’s role in achieving both operational excellence and climate goals. Yinson’s strategy not only meets current industry demands but also positions the company as a key player in the move towards sustainable, low-carbon energy solutions.
Yinson Production Offshore Pte Ltd E: enquiries.sg@yinson.com W: www.yinson-production.com
Transforming Gas Treating with Advanced Simulation Tools
Optimized Gas Treating, Inc. (OGT) has been at the forefront of innovation in the gas processing industry since its founding in 1992. As pioneers of the mass transfer rate-based approach for simulating amine gas treating applications, OGT has led the industry with cutting-edge tools that enhance efficiency, accuracy, and safety in gas treating processes. Their software solutions, such as ProTreat® and SulphurPro®, are renowned for providing rigorous engineering calculations that deliver accurate plant performance insights. We learn more below.
OGI: Could you start by explaining Questions for Optimized Gas Treating, Inc. credentials and experience in terms of your products and services for the oil and gas sectors? Could you tell our readers the breadth of your experience, how long the company has been active, and its reach?
OGT: Optimized Gas Treating, Inc. (OGT) began in 1992 with the singular goal of providing the industry with the best, most powerful tools possible by pioneering the development of the mass transfer rate-based approach to simulating amine gas treating applications in a commercial environment. OGT has been a pioneer ever since and has expanded its area of application from amine gas treating into physical solvents, glycol dehydration, caustic treating for mercaptan removal, ammonia sour water stripping, and Claus type Sulfur recovery units (SRU) with a global user-base. OGT was the first to break ground in rate-based simulation for our industry and has stuck to that philosophy with each new offering leading to fully mass and heat transfer rate-based capability. Other organizations have gradually recognised the
power of the rate-based approach and have followed suit. The company began as, and is still, the technology leader for modelling gas treating processes and downstream sulfur recovery units for both gas plants and refineries.
OGI: What are some of the risks for plant operators when they do not accurately measure plant performance data?
OGT: Risks involve both safety and financial operability concerns and lead to higher operational expenses, increased facility maintenance, frequent equipment failures
and unscheduled downtime. Severe operation outside plant battery limits has the potential of leading to fatalities.
Some of the generic models provided by competitors require users to fit the simulation model to their plant data through various factors and adjustments, so inaccuracies in measured plant data could be further exacerbated by future simulation once a model is regressed to bad data and then extrapolated further. This error could even be compounded when older instrumentation – which the generic model was fit to – is recalibrated or replaced with newer instrumentation.
To contrast, OGT has built a simulator, ProTreat and SulphurPro, that allows our clients to demonstrate what their plant should be doing with rigorous engineering calculations. Engineers and operators can then take that information and use it to help validate their measurement devices, improve the performance of their plant to reduce operating costs and determine unit capacity limits. For designers, our methods and software removes a lot of approximations and guesswork which leads to oversizing and waste in design. Reliable predictive accuracy helps minimize capital expenses and lowers estimated project cost leading to more competitive design bids.
OGI: What is OGT|Suite?
OGT: OGT|Suite is our suite of software
products for simulating gas treating and sulphur recovery processes. This suite of software is fully interconnectable to model the entire process from the introduction of sour feeds through to waste discharge to atmosphere and can also connect to other third-party software utilizing COM and CAPE-OPEN to expand the modelling capabilities to the entire operating facility. In OGT|Suite, ProTreat® simulates gas treating accurately through a strict mass-transfer rate-based modelling approach and SulphurPro® simulates Sulfur recovery units utilizing a strict kinetic reaction and heat-transfer rate-based modelling approach. As mentioned, our COM and API tools can connect to Excel or other programs depending on client needs. In that way you can use and integrate OGT|Suite into your current software use cases with very little effort.
OGI: Can you talk about your ProTreat software and what it does?
OGT: ProTreat offers the best-in-class rate-based modelling publicly available for gas treating and post-combustion carbon capture. Rather than relying on simplified shortcut methods, ProTreat uses first principles engineering to calculate mass transfer, heat transfer and reaction rates, along
with industry accepted calculation methods to quickly deliver accurate results. For anyone out there with an amine treating unit, physical solvent unit, glycol dehydration unit, acid gas enrichment unit, caustic treating unit, tail gas treating unit, or sour water stripper unit, it can provide the insights engineers and operators need to make better decisions for design and operations. It also includes many proprietary formulated solvents (such as INEOS GAS/SPEC and DOW UCARSOL), so you can seamlessly work with your vendor on operational and design issues or changes. Simulation is super accurate, lightning fast, with assured convergence.
OGI: Could you talk about the benefits of SulphurPro®?
OGT: SulphurPro® is a standalone tool to model Claus type sulfur recovery units and was created with the same intention as ProTreat; to accurately model the SRU through first principles rate-based modeling for reaction rates and heat transfer rates. SulphurPro can provide vital insight into reaction furnaces to help gauge ammonia and hydrocarbon/BTEX destruction along with COS and CS2 formation, waste heat boiler
operations to monitor valuable high pressure steam production and sulfidation corrosion, tail gas incineration for environmental monitoring, as well as Sulfur converters and hydrogenation reactors to monitor catalyst life/behavior and poisoning. SulphurPro can be fully integrated with ProTreat to model the full process from upstream acid gas removal units to the downstream TGTU through to the stack from the plant.
OGI: What are the main benefits of simulating gas processing and sulphur recovery?
OGT: The main benefits come from the insights you get from simulation to help understand how the plant behaves given changes in process conditions. This makes plant decisions proactive rather than reactive. ProTreat, SulphurPro, and other software offerings from OGT provide measurable value, whether you are an EPC or capital projects engineer working on design and pricing, a process engineer working on process optimization, or troubleshooting issues at your plant to prevent a shutdown.
OGI: Can you talk about your tailored solutions as it is assumed many situations would require a consultative approach.
OGT: In addition to our suite of software solutions, OGT also provides highlevel consulting services to aid clients in troubleshooting, assessing plant performance and optimizing operations, validating designs, among several other offerings. In addition to this, OGT also offers the ability to build custom models for unique and novel equipment operations, proprietary solvents, and more. We have successfully completed several consulting projects and have implemented several custom models for our clients over the years.
OGI: Thank you for your time.
If you would like more information about the topics discussed in this article, please use the contact information below:
Optimized Gas Treating (OGT)
T: +1 512 312 9424
E: info@ogtrt.com
W: https://www.ogtrt.com
Easy
Compilation of Tender Documents for Energy Applications
KROHNE added the new sections “Energy” and the fourth purification stage at wastewater treatment plants to the “Planning Tool for generation of tender documents”. The online tool, which is aimed at planning engineers and operators, thus covers not only water and wastewater systems but also the application areas of district heating, district cooling and green HVAC.
The planners of plants and systems in these areas are faced with the complex task of balancing new planning requirements and regulations with new technological developments and the opportunities they present. When it comes to process instrumentation, the planner must not only be familiar with the most important measurement technologies, but also know the advantages and disadvantages of all the measurement methods that can be used at a particular measuring point.
This is where KROHNE offers support with the planning tool: in the new Energy section, the planner can first select a process or plant section, e.g. the heat transfer station, solar thermal heating plant, geothermal heating plant, heat recovery in data centers or combined heat and power plant in the district heating section. The Planning Tool shows all the measuring points that can be equipped in the process and recommends suitable instrumentation.
for the first half of the year. As at 30 June 2024, AF Gruppen had net interest-bearing liabilities of NOK 979 million (1,582 million). Earnings per share amounted to NOK -0.07 (NOK 1.72) during the second quarter, and NOK 1.23 (NOK 1.69) for the first half of the year.
AF imposes the same strict safety requirements on all its partners and suppliers as it does on its own employees. AF’s subcontractors are included in the injury statistics. The LTI rate for the second quarter was 0.4 (0.7). For the first six months of 2024 the LTI rate was 0.6 (1.1).
AF works in a systematic and targeted manner to avoid workrelated absence. Sick leave in the second quarter was 3.6% (3.9%), and for the first six months of 2024 was 4.1% (4.2%).
“In recent years, the construction industry has experienced a high level of uncertainty regarding market forces that affect activity and employment for most players in the industry. To stimulate increased activity and profitability, the whole industry must work together to strengthen interaction, innovation and productivity throughout the value chain,” says Tøftum.
AF
Gruppen with Low Profitability in the Second Quarter of 2024
AF Gruppen recorded second quarter revenues of NOK 7,651 million. Profit before tax was NOK 21 million in the second quarter, corresponding to a profit margin of 0.3%. The Group delivered good results in Civil Engineering and Energy and Environment, but downward adjustments made to the estimated results for one offshore project reduced the result for the Group.
Revenues for the second quarter totalled NOK 7,651 million (7,853 million) and amounted to NOK 14,838 million (15,246 million) for the first half of the year. Profit before tax was NOK 21 million (292 million) in the second quarter and NOK 207 million (305 million) for the first half of the year. This resulted in a profit margin of 0.3% (3.7%) for the second quarter and 1.4% (2.0%) for the first half of the year. AF Gruppen had an order intake of NOK 5,629 million (10,877 million) in the second quarter and an order backlog of NOK 38,253 million (44,693 million) at the end of the quarter.
“AF Gruppen maintained a high level of activity in the quarter, but the result is impacted by downward adjustments made to the estimated results for one of the Group’s offshore projects. The quarter includes several strong performances, especially in the areas of Civil Engineering and Energy and Environment. It is gratifying to see continued positive trends in safety performance and sick leave,” says Amund Tøftum, CEO of AF Gruppen.
Net operating cash flow was NOK 661 million (227 million) in the second quarter of 2024 and NOK 789 million (203 million)
Euronav Changes Name to CMB.TECH on 1 October
ANTWERP,
Belgium, Euronav NV is pleased to announce that the name change of Euronav NV to CMB.TECH NV, which was approved by shareholders at the Extraordinary General Meeting of Euronav NV on 2 July 2024, will be effective on 1 October 2024.
The company is changing its corporate name to reflect its new strategy focusing on fleet diversification and decarbonisation. CMB.TECH is a diversified and future-proof maritime group, leading the way in sustainability. The group owns and operates more than 160 seagoing vessels: crude oil tankers, dry bulk tankers, container transport, chemical tankers, offshore wind vessels, tugboats and ferries.
The Euronav brand will remain the brand name of the crude oil tanker and offshore oil activities.
CMB.TECH remains listed on Euronext Brussels and the NYSE under the ticker symbol CMBT.
Confined Space Inspection Drone System
The Scout 137 is an innovative confined-space inspection drone system, especially made for no-man entry.
It keeps people safe from working at heights or in hazardous environments, while also offering important efficiency benefits.
Unlimited flight-time and fully wired control removes stress and promotes safe job completion.
The Scout Portal, our cloud-based inspection data service, offers full inspection replay and live streaming.
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Visual data and UT measurements
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Scan QR-code to read Case Study Revolutionary, fully robotic FPSO inspection with No Human Entry and Class Sign-Off: Read about the SHELL “Turritella” Special Survey!
Designed and built in Norway | www.scoutdi.com | sales@scoutdi.com
Under Pressure – When Flow Measurement Accuracy Matters
Titan Enterprises’ high-pressure Oval Gear liquid flow meters address the need for precise flow measurement across extreme operating conditions and harsh industrial environments, such as those seen in hydraulic system applications and the oil and gas industry.
Measuring the flow of fluid under high pressure, such as in hydraulic fluid monitoring, chemical additive injection and other challenging fluid power systems, ensures optimum operational performance as well as minimising wastage.
Hydraulic systems perform significant work in a broad range of industrial applications, such as:
• Aerospace: in deploying and retracting landing gear on planes, flight control actuators, etc.
• Mining, Construction, Agriculture: in lifting heavy loads with earth-moving equipment or processing materials with rockcrushing machinery.
• Oil and Gas industry: in drilling wells in oil fields or chemical additive injection to improve oil recovery.
• Marine: in pushing and steering the ship through water using propellors and thrusters powered by hydraulic systems.
• Automotive: in Formula One cars incorporating sophisticated hydraulic systems to handle multiple applications, such as powerassisted braking, clutch, gearbox, and throttle actuation.
The oil and gas sector also drives a significant portion of the flow meter market, with conventional flowmeters, such as positive displacement (oval gear) devices, still having the advantage of being proven across a large installed base. These flow meters are crucial for applications like high-pressure additive injection and custody transfer, where accuracy and chemical resistance are vital.
Pressure Testing – ensuring operational readiness
Pressure is a key factor when selecting hydraulic components and pressure testing each component within a hydraulic system helps to verify its structural integrity and fitness for purpose. A device’s pressure rating indicates its maximum operating pressure.
Conducted during the manufacturing process, pressure testing helps identify defects (such as leaks) early, preventing potential failures and reducing costly downtime caused by faulty components. Additionally, it also ensures that the hydraulic system meets safety standards set by regulatory bodies, safeguarding compliance. By confirming that both components and the entire system can endure and function effectively under the required operating pressure, pressure testing plays a crucial role in validating the system’s overall performance and reliability.
Titan’s Onsite Pressure Test Facility
Due to the demand for their high-pressure oval gear flowmeters, Titan made a capital investment into an in-house pressure test rig. This not only enables rapid turnaround of both new and refurbished flowmeters, but from an R&D perspective, allows Titan to pressure test new materials in development.
The Hydratron pressure test rig is capable of testing to a pressure of 1400 bar allowing for testing over the whole range of Titan’s oval gear flowmeters, including the 950 bar high-pressure options. The rig has also proved invaluable when testing new products and simulating the effects of cavitation within a hydraulic system. Alongside a refinement of gear design and standardising the flowmeter designs to improve product interchangeability, Titan’s pressure test rig has proven the design modifications, allowing a potential increase to the maximum operating pressure of its standard oval gear flowmeter range by around 50%.
Key features and benefits of Titans’ Oval Gear flowmeters
1. High Accuracy and Chemical Resistance.
The Oval Gear flow meters improve in measurement accuracy as liquid viscosity increases, from about 1% to around 0.1%
Custody Transfer
When a fluid (or gas) is transferred from one party to another, as in custody transfer, accurate and repeatable flowmeters are critical components in a complete metering system. Metering accuracy is vital as even small measurement errors in custody transfer can be very costly.
Positive displacement flowmeters, such as Titan’s Oval Gear devices, are designed to accurately measure high-value products such as refined fuels and petrochemicals.
of reading at higher viscosities. They are designed to handle a broad range of physical and chemical properties, essential for petrochemical additive injections which vary in viscosity and density.
2. Robust Construction
Compact and rugged design ensuring long-term performance with minimal maintenance. Models offer pressure ratings from 10 bar to 950 bar and can operate at temperatures up to 150°C. Intrinsically safe options for potentially explosive atmospheres, such as ATEX compliant models, are available.
3. Reliable Performance
Proprietary oval gear design providing high performance and 0.1% repeatability. Suitable for high-pressure applications such as marine fuel flow measurement, grease supply monitoring in wind turbines, offshore oil drilling additive injection, and biodiesel production.
4. CustomSolutions
Titan Enterprises collaborates with OEM customers to develop bespoke flow meters that meet specific high-pressure, high viscosity and chemical compatibility requirements, enhancing their application in various industries including oil, petrochemical, and green energy sectors.
By ensuring reliable and accurate flow measurement, Titan’s Oval Gear flow meters contribute significantly to the efficiency and safety of oil and gas processes, from additive injection to fuel measurement; and hydraulic systems in diverse and demanding environments.
To discuss a bespoke flow measurement solution for your unique OEM application, contact Titan Enterprises on +44 (0)1935 812790 or sales@flowmeters.co.uk
Safetrack patented digitized PinBrazing system is an extremely efficient, low temperature arc brazing method used for attaching electrical connectors to steel structures within Cathodic Protection systems such as pipelines, vessels, reinforcement bars, wind power, grounding, etc, without the need for welding. No need for different carbon moulds for different wires. Safetrack application methods always use materials of the highest quality to ensure the best electrical conductivity, corrosion resistance and strength.
ECONECT PinBrazing Unit - Lightweight,
High capacity
60 connections per charge
Battery powered
Nano Li-Ion, long life
Automated Gun
Self adjusting (patent)
Protectus Panzar
Divisible subsea cable protection
Protect your cables and save our planet!
• Made from 100% recycled plastic
• Massive savings in oil
• Huge savings in CO2
• 80% lower environmental impact
Advantages
Digitized
Same perfect result everytime (patent) Lightweight
Only 9,8kg (21,6 lb)
• No special training needed
• No waste of consumables
• Automated Gun
• Low temperature
• Low noise
• Fast & safe
Protectus Panzar is developed in close cooperation with experienced installers and is suitable for use in in a wide area of conditions. Our own weights can be mounted in several ways and the construction makes it possible to fasten Panzar in rocks/mountains. Tool-less installations both in subsea applications as well as above water. The cables are 100% protected at all times.
Bridgestone, Grupo BB&G and Versalis Create Closed Loop Ecosystem that Recycles Tyres to Tyres Bridgestone
EMEA (Bridgestone), Grupo BB&G (BB&G) and Versalis (Eni) today announced the signing of an agreement aimed at establishing a closed-loop ecosystem to transform endof-life tyres into new tyres. The agreement will bring together the innovation, experience and technological skills of all three companies. The partnership aims to develop a model for the creation of a scalable and increasingly sustainable supply chain.
Around one billion tyres reach the end of their useful service life every year, according to the World Business Council for Sustainable Development (WBCSD)’s Tire Industry Project. Bridgestone, BB&G and Versalis are seeking a solution that provides innovative and more environmentally responsible ways to address increased sustainability in the synthetic rubber business, helping to maximise the complete lifecycle of a tyre. The partnership between the three companies will contribute to achieving their environmental goals.
End-of-life tyres (ELTs) will be transformed, through pyrolysis, into tyre pyrolysis oil (TPO) to create high-quality elastomers comparable to those obtained from traditional feedstock for the production of new tyres. The three companies’ collaboration aims to boost the development of pyrolysis technology and TPO, as well as market scaling the polymers as a valuable circular resource for new tyres. The partnership will leverage BB&G’s
thermomechanical process of pyrolysis to recycle end-of-life tyres on a commercial scale.
BB&G has built and operated two generations of pilot plants in the past 10 years and has also recently commissioned its first commercial scale tyre pyrolysis production to validate the feasibility and quality outputs of the process. BB&G’s TPO unit is located in Fatima, Portugal and has been successfully up and running since 15 July 2024. Over the next months, a first amount of BB&G oil will be fed into Versalis’ plants to manufacture the circular elastomers that Bridgestone will use to create a first batch of tyres in early 2025. The BB&G TPO commercial plant will help improve the circular tyre ecosystem and play a crucial role in facilitating global tyre circularity.
Versalis, Eni’s chemical company, has been developing circular technologies and processes through polymer recycling. This includes complementary mechanical and chemical recycling. The company is also engaged in the diversification of feedstock, with both renewable sources and secondary raw materials. Through this collaboration and based on its own technological expertise for recycled materials, Versalis will integrate BB&G’s pyrolysis oil into its own supply chain thus expanding the Balance® - ISCC PLUS certified - product range. Versalis’ elastomers are designed to ensure high performance. Bridgestone, a global leader in tyres and sustainable mobility solutions, can transform these elastomers into tyres with an enhanced percentage of rubber obtained from secondary raw material.
Sub Sea
engineering
EEMUA 194 Subsea Engineering Basics
Materials selection and corrosion control – with reality built in
Blended online learning for all involved in the design, specification, commissioning, operation, maintenance, repair, and refurbishing of ageing and new underwater energy production equipment – to optimise cost-effective and reliable long term operation.
The EEMUA 194 Subsea Engineering Basics course encompasses the distilled know how of industry captured in the practical, 'how to' guidance of EEMUA Publication 194.
Course Tutors incorporate all this industry know how with decades of their own expert materials corrosion experience – for
effective learning with reality built in.
• Blended online learning combines live classes, 1-1 tutorials, session recordings, e-learning and more.
• Real-time interaction with Tutors ensures each Learner's immediate and correct understanding.
• In-depth course in manageable sessions over a period of 3 weeks – to fit busy schedules.
• Enables valuable team members to be where they're needed – on-site using industry's collected experience of real-world subsea engineering.
• Certification to industry requirements by exam.
• Adapts to engineering needs of each Learner and company through Induction.
Registration open n ow for the next course Induction of 2 hours to fit diaries in October 2024. Learning starts 4 November 2024
Find out more at www.eemua.org by contacting online-learning@eemua.org or call the EEMUA team on +44 (0) 20 7488 0801
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Mechanical Integrity Training with reality built in…
Developed and verified ‘for industry, by industry’, EEMUA 231 Mechanical Integrity courses come with reality built in for industrial engineers at every career stage. For efficient hands-on work with primary containment – to prevent loss of hazardous substances.
Satisfy industry requirements at each competency level –Awareness, Basic application, Practitioner.
Certificated for up to 5 years.
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Siemens Mobility Starts Rolling Stock Manufacturing in the United Kingdom
• The opening of the Goole Rail Village in East Yorkshire marks a significant milestone for Siemens Mobility’s commitment to the United Kingdom
• The UK Transport Secretary and Mayor of London marked the occasion
• Siemens also announced a new up to €50 million investment in addition to the up to €230 million investment in the Goole Rail Village, creating up to 300 more jobs at the site
• The Rail Village will contribute to the employment of up to 1,000 people in total and the creation of up to 1,700 supply chain opportunities
Mechanical Integrity Practitioner Certificate (MIPC®) – blended, live online learning – on-site or on-call –1:1s and Mentor Support – workbook builds from day-1 for immediate use in on-site application of EEMUA 177, 231 and 232 guidance, and the PSSR ACOP
• 80% of London’s new Piccadilly line trains will be assembled in Goole
Following– certificated for 5 years via exam and portfolio assessment – in-depth learning for 27 weeks, flexible 4 hours per week – CPD of 110 hours. The MIPC course adapts to engineering needs of each Learner their company and site/s via a 2-hour induction (made to fit work schedules ahead of the course) –learning starts 3 March 2025.
EEMUA 231 Mechanical Integrity Basics –Blended, online learning – Basic application competency level – flexible 4 hours of learning per week for 3 weeks – 12 hours' CPD – certificated via exam – next course starts 3 February 2025.
EEMUA 231 Mechanical Integrity e-learning
– Awareness level – with 1 hour of CPD – immediately available – on-demand
EEMUA 231 Mechanical Integrity In-house
training – at the Awareness level – CPD – 1 day or 2 half-days – by arrangement – for your choice of time, location, and method of learning – certificated
Also...
EEMUA Conference 2025 Cheshire, UK 26-27 March 2025
an investment of up to €230 million, Siemens Mobility is opening its Train Manufacturing Facility as a key part of its new Goole Rail Village in the United Kingdom, on a site which spans 67 acres, the size of 35 football pitches. London Underground’s new Piccadilly line trains will be assembled at the factory in Goole before they start entering passenger service from 2025, helping Transport for London (TfL) transform rail travel across the UK’s capital. Overall, Siemens Mobility’s investment in the region will create up to 700 new jobs and an additional 1,700 supply chain opportunities by 2030. This investment will strengthen local production to serve global markets.
Alongside the opening, Siemens Mobility announced an additional investment of up to €50 million in a state-of-the-art new facility in Goole to assemble and overhaul bogies for trains. The new Bogie Assembly and Service Center will incorporate and expand Siemens Mobility’s current capabilities to overhaul bogies from UK trains, including the 3,224 strong fleet of vehicles (572 trains) it maintains in the UK, and will also include new production lines for assembling bogies for new trains, a first for Siemens in the UK. This new investment will secure around 100 existing jobs and create up to a further 200. It is due to be operational towards the end of 2026.
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Repsol and OMODA & JAECOO Reach a Unique Multi-Energy Agreement in Spain
Repsol and the car brands OMODA & JAECOO, which belong to the Chery International Group, have reached a framework collaboration agreement to promote the decarbonization of the automotive sector in Spain.
Under this alliance, Repsol will provide OMODA & JAECOO with its extensive multi-energy offer, which the automakers will adopt to their needs. These initiatives include Repsol’s comprehensive electric recharging solution, both for customers and employees of the brands, the possibility of electrifying dealerships or corporate headquarters, 100% renewable fuels, solar power generation, selfconsumption, energy efficiency projects, energy saving certificates, emissions offsetting, and the supply of 100% renewable electricity.
In addition, the framework agreement contemplates that Waylet, Repsol’s payment and loyalty application, which has more than 8 million registered users, will become a means of payment in the automaker’s dealership network. At the same time, Solred, Repsol’s means of payment for the professional sector, can be used to pay for electric recharges or fuel in Repsol’s extensive network of service stations throughout the country. In addition, the Spanish company will offer app users special offers on OMODA & JAECOO vehicles.
Another point included in this collaboration is to explore the possibility of using Repsol lubricants, the use of OMODA & JAECOO vehicles in Repsol’s corporate fleets, and exclusive offers for workers of the multi-energy company.
In just six months, OMODA & JAECOO have demonstrated an unprecedented reception in the Spanish market, with more than 4,000 units sold of a single model, the first to debut in our country and in Europe: the gasoline powered OMODA 5. In addition, the OMODA 5 EV, a zero-emission version, will be launched in the coming weeks. And on September 17, the new JAECOO 7 will be launched, both in its gasoline version and its PHEV variant, a compact SUV that will bring a vision of the future and innovation to the automotive world and redefine the classic values of off-road, under the slogan “From Classic, Beyond Classic”.
Susana Baños, Director of Repsol’s B2B Sales Force, said that “this framework agreement with OMODA & JAECOO, that belong to one of the world’s leading vehicle manufacturers, consolidates our multi-energy offer in Spain. The automotive sector needs all the energy solutions available to decarbonize and at Repsol we are prepared to supply them.”
For his part, OMODA & JAECOO’s Country Manager in Spain, Darren Tu, pointed out that “surrounding ourselves with the best partners in each sector continues to be one of our priorities and this is already having an impact on the commercial success of our products. Our goal at OMODA & JAECOO is to offer different sustainable multi-energy mobility solutions to suit all user tastes and needs. And that is why, in the midst of a phase of settlement and expansion in our market, we have relied on the enormous possibilities offered by working from now on with a leading company in this field such as Repsol”.
This agreement reinforces the role of both companies as relevant players in mobility in Spain and establishes a general framework of collaboration to advance towards the decarbonization of the transport sector.
bp and Iberdrola Announce Final Investment Decision for Largest Green Hydrogen Plant in Spain
Madrid, bp and Iberdrola have given the green light for construction of a 25 MW green hydrogen project at bp’s Castellón refinery which is expected to be operational in second half of 2026. This is the first hydrogen project jointly undertaken by bp and Iberdrola through Castellón Green Hydrogen S.L., a joint venture equally owned by both companies. The project was presented at an official event to publicly celebrate the signing in July 2024 of the final investment decision between bp and Iberdrola.
This initiative, which includes the participation of the Technology Institute of Energy (ITE), has been awarded funding of 15 million euros from the Innovative Value Chain and Renewable Hydrogen Knowledge call of the Spanish Recovery, Transformation, and Resilience Plan, with funding allocated by NextGenerationEU of the European Union.
Millán Garcia-Tola, Global Director of Hydrogen in Iberdrola said “this partnership with bp and our project is another step in Iberdrola’s firm and real commitment to promote green hydrogen as a key vector for industrial decarbonization. The plant will convert 200 GWh/yr of Iberdrola’s renewable energy into green hydrogen that will contribute to bp’s decarbonization strategy, in another example of close collaboration between both companies, reliable partners that share values as long term decarbonization commitment. Iberdrola will apply all the experience of its existing green hydrogen plants to optimize and accelerate the development of this project”.
“This project marks a milestone in our strategy and reflects the importance of collaboration, both with other companies that share our vision, such as Iberdrola, and in the public-private sphere. In this way, we not only advance the transformation of our infrastructure in Castellón, but also aim to strengthen the economic fabric and industrial capacity of the entire Valencia region,” said Olvido Moraleda, President of bp Energía España.
Mario Ruiz-Tagle, CEO of Iberdrola Spain, highlighted that this project is “another example of our strategic alliance with bp, uniting us to lead the future of renewable hydrogen in the Valencian region. Projects like Castellón show that, with the collaboration of all agents in the sector and the appropriate incentives, it is possible to develop a new industrial model based on the green hydrogen value chain. The green hydrogen economy is emissions free, electrified, attracts investment and creates quality jobs in the region. This is the true energy transition. We continue to work with committed partners to position Spain as a technological benchmark, boosting the creation of a green hydrogen industry in Europe.”
The 25 MW electrolyzer will be powered by renewable electricity through a power purchase agreement (PPA) signed with Iberdrola that will supply 200GWh/year coming from Iberdrola’s photovoltaic and wind projects. The electrolyzer will include 5 modules of 5 MW containerized proton exchange membrane (PEM) technology, which will be supplied by Plug Power, a leading manufacturer of green hydrogen solutions. The green hydrogen produced by the electrolysis of water powered by renewable electricity will comply with European requirements to
produce green hydrogen (Renewable Fuels of Non-Biological Origin, RFNBO) and will support the transition of bp’s Castellón refinery into an integrated energy hub. It’s expected around 2,800 annual tons of green hydrogen could substitute part of the grey hydrogen currently used by the refinery – currently produced from natural gas – and as such is expected to result in avoiding the emission of 23,000 tons of CO2 per year, equivalent to the emissions of 5,000 cars over the same period. This plant could create up to 500 new direct jobs during its construction.
In parallel to this initial 25 MW project, bp continues to assess opportunities to increase capacity in the coming years. In subsequent phases of the project, the green hydrogen produced could also be used in key hard-to-abate industries in the Valencia region, such as the ceramics sector replacing natural gas used in its processes, in chemical industries and in heavy transport.
The launch of this project has been announced just weeks after bp signed a letter of intent with the Valencian Government to reinforce the region’s position as a leader in the energy transition. The letter has materialized in the creation of a joint working committee that will serve as a platform for dialogue and collaboration between both parties and will oversee the transformation of bp’s refinery in Castellón into an integrated energy hub.
In recent months, Iberdrola has closed several long-term alliances to promote the decarbonisation of the economy. Further to the joint venture with bp to accelerate the electric mobility in Spain and Portugal, Iberdrola has entered into a number of longterm partnerships with Norges Bank Investment Management, Masdar, Mapfre and Energy Infrastructure Partners to further advance the development of renewable energy, and with GIC to expand transmission networks in Brazil.
Trant Engineering Ltd Receive their Silver Employer Recognition Scheme Award!
Our Trant Veteran Association members Chris Clarke and Steven Yendall proudly received the award on behalf of Trant Engineering Ltd in the grounds of Admiralty House at HM Naval Base Portsmouth hosted by South East Reserve Forces’ & Cadets’ Association
This honor reflects our commitment to supporting the defence and armed forces community, including ex-personnel as a forcesfriendly employer.
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Equinor Reports on Norwegian Development Projects
Equinor is the operator of 19 projects currently under development in Norway. In the proposed National Budget for 2025, the Ministry of Energy listed the status of 13 Equinoroperated projects currently under development or recently completed.
The projects in question have a total investment framework of 198 billion kroner, from commencement to commissioning.
“Equinor has a good portfolio of profitable projects being developed in Norway, which will contribute to long-term security of supply of oil and gas to Europe. In 2023, our developments contributed to high activity and 25 billion kroner to the Norwegian supplier industry. Together with our partners and the industry, we have completed six projects during the past year,” says Trond Bokn, head of project development in Equinor.
The reported projects have seen a cost increase of 6.5 billion 2024-NOK over the past year, which is about 3 per cent. The overall increase since the plans for development and operation (PDOs) is 32.9 billion 2024-NOK. Currency effects account for 12.4 billion of this. If the Johan Castberg project and currency effects are omitted, the cost increase for the reported projects is around 3 percent since PDOs.
Two of the projects, Johan Castberg and Oseberg gas compression and partial electrification, have experienced a post-PDO increase of more than 20 percent, and are therefore mentioned specifically in the proposed national budget.
Johan Castberg
The production ship is now anchored at the field and Johan Castberg is on track for start-up towards the end of the year.
The cost increase in the project is 2.2 billion 2024-NOK since last year. This is due to a longer stay than estimated at Aker Solutions at Stord, currency effects and a general cost increase. Of this, almost NOK 800 million is currency effects. Since the PDO, estimated costs have grown by 25.7 billion 2024-NOK. Currency effects account for 8.1 billion of this.
Oseberg gas phase 2 and power from shore (OGP) OGP is composed of partial electrification of the Oseberg Field Centre and Oseberg sør, as well as installation of a new compressor module at the field centre.
The cost increase over the past year is 1.2 billion 2024-NOK. Since the PDO, the cost increase is about NOK 2.5 billion in 2024NOK. Since the PDO, estimated costs have grown by around
2.5 billion 2024-NOK. This is a result of longer delivery times for new transformers that were destroyed in a fire at Hitachi’s factory in Vaasa in 2023, as well as delays related to increased complexity. Planned commissioning has been postponed from 2026 to late 2027.
Snøhvit Future
Snøhvit Future encompasses onshore compression and electrification of Hammerfest LNG on Melkøya. Since the PDO, the cost increase is 1.9 billion 2024-NOK. More than 500 million of this relates to currency effects.
One of the main reasons for the higher costs is the joint venture’s decision to change the design of an electric boiler as a result of safety considerations.
Neptune Energy Receives two Exploration Permits for Lithium in Saxony-Anhalt
Neptune Energy is permitted to search for lithium mineral resources in northern Saxony-Anhalt. The company received the relevant permits in mid-August from the responsible State Office for Geology and Mining (LAGB) in Saxony-Anhalt. In the “Milde AL” and “Milde CL” permit areas, which include parts of the Altmarkkreis Salzwedel, Stendal and Börde districts, Neptune Energy has the right to search for the unmined lithium mineral resources over the next five years. During this time, the experts will first evaluate data and create models of the subsoil before later - subject to the approval of further operating plans under mining law - an exploratory borehole is also to be sunk in order to be able to prove the suspected lithium deposit. The LAGB provides further information on this in the official announcement at: https://lagb.sachsen-anhalt.de/service/ bekanntmachungen.
Welcoming our 2024 Apprentices
OnThursday the 5th of September we welcomed our new 2024 apprentices to our Head Office in Southampton for their ‘Introduction to Trant Engineering Ltd’.
The day was filled with talks from our current apprentices and staff members along with three fun filled activities to partake in followed by a tour around the campus. A big thank you to our current apprentices who were all on hand to support and give guidance.
Our 2024 apprenticeships cover a wide range of construction and engineering disciplines including electrical engineering, quantity surveying, civil engineering, accounting, payroll, mechanical installation and electrical installation.
Amy Yates, Learning & Development Manager said “This is the largest intake of apprenticeships we have had since Covid, the apprenticeships on offer vary from level 3 through to level 7. We look forward to supporting our apprentices as they launch and progress their career with Trant Engineering!”
World Economic Forum: Siemens Factory in Erlangen named Digital Lighthouse Factory
• World Economic Forum’s Global Lighthouse Network honors leading manufacturing sites
• AI, digital twins, and robotics have increased productivity at Erlangen factory by 69 percent and reduced energy consumption by 42 percent
• Successful launch of in-house semiconductor production for high-performance frequency converters
The World Economic Forum (WEF) has announced that the Siemens factory in Erlangen, Germany, will become a Digital Lighthouse Factory, part of its the Global Lighthouse Network. The award recognizes leading technology companies that are at the forefront of applying fourth industrial revolution technologies. By following the Green Lean Digital approach, which combines innovative technologies and sustainable practices, the plant has made significant progress, increasing productivity by 69 percent and reducing energy consumption by 42 percent in four years.
Siemens announced last year that it would invest €500 million in research and infrastructure in Erlangen, establishing the site as a global research and development hub and as a nucleus for global technology activities for the industrial metaverse.
The Siemens plant in Erlangen is already the third Siemens manufacturing site to be recognized by the WEF as one of the most modern factories in the world, following in the footsteps of Amberg, Germany, and Chengdu, China.
“All good things come in threes. Following recognitions for Amberg and Chengdu, this award highlights the inventiveness of our Erlangen team. By utilizing technologies like AI, digital twins, and robotics, we have increased productivity by 69 percent, cut energy consumption by 42 percent, and are creating a blueprint for the industrial metaverse,” said Cedrik Neike, Member of the Managing Board of Siemens AG and CEO of Digital Industries. “This acknowledgement motivates us to continue our own sustainability efforts and to help our customers become more resilient and sustainable.”
Innovative technologies and sustainable practices
By deploying AI across more than 100 use cases and using the power of digital twins, the plant has made significant advances in enhancing the efficiency of its production. In addition, the plant has implemented innovative approaches to waste reduction, making optimal use of resources and minimizing its environmental impact.
The Siemens factory in Erlangen aims to “become the leading supplier of power electronics for the energy transition,” says Site Manager Stephan Schlauss. “This award recognizes the commitment of all our employees in recent years. It’s also an incentive for us to never rest on our laurels, but to improve even more.”
The factory convinced the WEF’s jury with five specific use
cases of digital technologies in a manufacturing environment. A notable example is the in-house semiconductor production project. A clean-room production facility was built in just 11 months to produce semiconductors for the latest generation of the SINAMICS frequency converter. Thanks to its end-toend data analytics platform, space requirements were reduced by 50 percent and material consumption by 40 percent, while still maintaining a high performance and improving energy efficiency. A special energy management system reduced energy consumption by over 50 percent.
ENGIE’s Board of Directors Proposes
Catherine MacGregor’s Reappointment as Chief Executive Officer
ENGIE’s
Board of Directors has decided to propose the renewal of Catherine MacGregor’s mandate as a member of the Board to the next Annual General Meeting which will be held in April 2025, with the intention of reappointing her as Chief Executive Officer.
The Board thereby reaffirms its support and confidence in Catherine MacGregor to pursue the Group’s transformation strategy.
Since her arrival at the head of ENGIE in January 2021, Catherine MacGregor and the Executive Committee she has put in place have refocused the Group and profoundly transformed its organization and culture to make it a leader in the energy transition. Under her leadership, ENGIE has weathered the energy crisis and strengthened its fundamentals, and today the Group presents a solid balance sheet.
Jean-Pierre Clamadieu, Chairman of the Board of Directors, commented: “For nearly four years, under Catherine MacGregor’s leadership and thanks to the professionalism and commitment of its 97,000 employees, ENGIE has accelerated its transformation to become a recognized leader in the development of tomorrow’s low-carbon energy systems. With the support of the Board of Directors, Catherine has strengthened the Group’s coherence to make it a more industrial, efficient and financially solid company, ready to pursue its future growth trajectory with confidence.”
Aquaterra Energy Launches Legacy Well Re-Entry and Re-Abandonment Services to Enable Offshore CCS and Hydrogen Storage Projects
Newly released Recoverable Abandonment Frame technology could reduce abandonment costs by £20million per well and cut project timelines by 50%
Norwich, UK, 10th September 2024 – Aquaterra Energy, a leader in offshore engineering solutions, today announces the launch of its legacy well re-entry and re-abandonment services along with its new patent-pending Recoverable Abandonment Frame (RAF). The combined solution will address challenges in locating, re-entering and re-abandoning legacy wells that penetrate, or pass through, offshore oil and gas reservoirs or saline aquifers that have been earmarked to be repurposed for carbon dioxide (CO2) or hydrogen storage.
The significant economic and technical challenges of reabandoning problematic legacy wells that pose a leak risk beneath the seabed could derail many carbon capture and storage (CCS) and hydrogen storage projects, that intend to use previously penetrated oil and gas or saline aquifer formations. Technical challenges such as traditional relief well drilling could be infeasible in shallow intersects or where azimuth and depth are unknown. Excavation methods require enormous amounts of material to be removed and may also fail to isolate re-abandonment loading from the compromised legacy well, meaning both methods may fall short in addressing technical, environmental, safety, and regulatory issues effectively.
Aquaterra Energy’s solution overcomes these challenges by employing advanced seabed and subsurface surveying technologies, well imaging, marking, and tagging to precisely locate wells. This allows the RAF to adjust to an exact well position and install conduits below the seabed to re-engage the legacy well and then back to the surface to allow for successful re-abandonment via a vertical well re-entry tieback method. Crucially the RAF also protects the legacy well components from environmental, lateral and axial loading generated by wave action on the tieback conduits and the re-abandonment operation itself for example by directing them into the frame and surrounding seabed instead of the potentially corroded and fatigued damaged legacy well.
Reacting to the announcement George Morrison, CEO at Aquaterra Energy said, “The introduction of the RAF and our re-entry services illustrate our strategy of pivoting decades of offshore expertise to address the wider challenges of the energy transition. Our team is committed to innovating and taking on the tough issues, ensuring that carbon and hydrogen storage can be effectively delivered as part of our broader commitment to driving the energy transition forward.”
The technology is intended for repeated use across multiple wells or locations with flexibility built in for differing seabed conditions. Its modular design allows for shipping worldwide or road transport for quayside assembly. This could enable the effective abandonment or re-abandonment of wells that may not have been previously possible, while also significantly lowering costs, saving operators £18-20 million per abandoned well – an estimated 80% reduction in comparison to other
methods currently deployed. The approach could also lead to major reductions in project timelines, estimated to be up to 50% quicker per well.
“The RAF and our associated suite of services for legacy well re-entry represents a significant leap forward in abandonment technology,” said Ben Cannell, Innovation Director at Aquaterra Energy. “Well re-abandonment for CCS is a new challenge, and our solution has been developed to meet it head-on. By reducing project risk, costs and operational time, we’re not only making well abandonment more efficient, but also enabling the viability of carbon or hydrogen storage, as these projects would generally be far more costly or even impossible to deliver.”
Argentina: Production Start-up at Fenix Offshore Gas Field
Paris, TotalEnergies announces the start of production from the Fenix gas field, located 60 km off the coast of Tierra del Fuego in Southern Argentina.
The Fenix field is part of the Cuenca Marina Austral 1 (CMA1) concession, in which TotalEnergies holds a 37.5% operated interest, alongside its partners Harbour Energy (37.5%) and Pan American Energy (25%).
With a production capacity of 10 million cubic meters per day (70,000 boe/d), the Fenix development consists of a new unmanned platform, located in 70 meters water depth and connected to the existing CMA-1 facilities. Gas produced at Fenix is sent through a 35-kilometer subsea pipeline to the TotalEnergies-operated Véga Pléyade platform and is subsequently treated onshore at the Río Cullen and Cañadon Alfa facilities, which are also operated by the Company. Fenix is a low cost, low emissions development, with a carbon intensity of 9 kg CO2e/boe, leveraging on the existing infrastructure.
“The start-up of Fenix production safely and ahead of schedule, only two years after FID, demonstrates the capacity of our Company to deliver its projects. Fenix will contribute to maintaining our gas production plateau in Tierra del Fuego and ensure a reliable supply to the Argentinean gas market” said Javier Rielo, Senior Vice President Americas, Exploration & Production at TotalEnergies. “With its low break-even and low carbon intensity, Fenix perfectly matches the Company’s lowcost and low-emission strategy.”
Norway: Northern Lights Facilities Completed
Paris, TotalEnergies and its partners, Equinor and Shell, announce the completion of the CO2 receiving and storage facilities of Northern Lights Joint-Venture in Norway. The facilities consist in a terminal that will receive CO2 cargos, a 100 km subsea pipeline for CO2 transportation to the offshore storage location, and subsea injection facilities for safe and permanent CO2 storage in a reservoir 2,600 meters below the seabed.
Northern Lights is now ready to receive and permanently store CO2 from European industries, with first CO2 injection expected in 2025. Developing CO2 transportation and storage services is one of the necessary levers to reduce emissions and a realistic decarbonization solution for European industry.
Northern Lights is the world’s first commercial CO2 transportation and storage project. The first phase of the project was supported by the Norwegian government and has a capacity of 1.5 Mt CO2/year, which has been fully booked by customers in Norway and Continental Europe. Studies are under way for a capacity expansion to more than 5 Mt CO2/y in a second phase.
“Today’s ceremony marks a significant milestone - one that fills us with great pride and hope for the future. This is a proud moment not just for Northern Lights as a company, but for Norway and for the advancement of Carbon Capture and Storage (CCS) worldwide”, says Terje Aasland, Norwegian Minister of Energy.
“Today we achieved an important milestone on our journey to demonstrate CCS as a viable option to help achieve climate goals. The whole world is looking to Norway to learn about CCS. Since construction started, we have welcomed more than 10,000 visitors from more than 50 countries. Today we celebrated the completion of the facilities together with the people of our host municipality Øygarden, the Norwegian Ministry of Energy and key stakeholders, including policy makers and industry partners in the CCS chain. All are instrumental for the success of Northern Lights and the CCS business in Europe”, said Tim Heijn, Managing Director of Northern Lights JV.
“We are proud to celebrate today the commissioning of the Northern Lights facilities. It has been a long journey since our partnership with the Norwegian State, Equinor and Shell was established in 2017. This major milestone signals the readiness of the infrastructure to store CO2 and we look forward to receiving the first volumes from hard-to-abate emitters in 2025. This will bring a strong contribution to the decarbonization of European industry”, said Arnaud Le Foll, Senior Vice-President New Business - Carbon Neutrality at TotalEnergies.
“This is an exciting day for both Equinor, Northern Lights Joint Venture and our partners Shell and TotalEnergies. We are proud that Northern Lights, as part of the Longship value chain, has now been completed and is ready to receive CO2. It is an important milestone in the work of establishing a Carbon Capture and Storage value-chain in Europe”, says Grete Tveit, Senior Vice President Low Carbon Solutions at Equinor.
“Carbon capture and storage has a vital role to play in helping
society achieve the goals of the Paris Agreement. Alongside efforts to avoid and reduce emissions, CCS will be an essential tool in supporting our customers on their decarbonisation journeys, particularly in those industries that are harder to decarbonise. I am delighted that the Northern Lights facilities are now ready to receive CO2 from industrial sites across Europe, for Shell this is an important part of our integrated offer to our customers”, said Anna Mascolo, Executive Vice President, Shell Low Carbon Solutions.
PTTEP Wins Best CEO and Best IR Awards at the IAA Awards for Listed Companies 2024
Mr.
Montri Rawanchaikul (Middle), Chief Executive Officer, PTT Exploration and Production Public Company Limited (PTTEP) received Best CEO award in the Energy and Infrastructure sector at the IAA Awards for Listed Companies 2024. The awards were presented by Mr. Pichai Chunhavajira (Right), Deputy Prime Minister and Minister of Finance and Mr. Paiboon Nalinthrangkurn (Left), President, Investment Analysts Association (IAA). Additionally, PTTEP was honored with the Best IR award for the third consecutive year in the same category. This award ceremony was organized by Investment Analysts Association and Stock Exchange of Thailand.
The IAA Awards for Listed Companies are presented to executives and listed companies, based on good corporate governance, management excellence, and the proficiency of the investor relations team. These key factors will drive business success and assure sustainable growth, supporting both Thai capital market and economy.
Illuminating Safety in the Oil and Gas Industry
In this Q&A, we sit down with Jonathan Somerset, Rayec’s Technical Director, a specialist in LED lighting solutions, to explore their extensive experience in the oil and gas sector. Since their founding in 2005, Raytec has been at the forefront of LED technology, providing cutting-edge products designed to enhance safety and efficiency in hazardous environments. In this interview, we delve into the applications of LED lighting, the importance of proper equipment in hazardous zones and more.
OGI: Could you start by explaining Raytec’s credentials and experience in terms of your products and services for the oil and gas sector? Could you tell our readers the breadth of your experience, how long the company has been active, and its reach?
Somerset: Raytec are specialists in LED lighting. Founded in 2005, every Raytec product manufactured since then has been based on LED technology. Today, we manufacture specialist LED lighting products across four main divisions – Hazardous, Industrial, Transport and Security. Our products are designed to increase safety and security for any application in which they’re installed across the globe.
Raytec products are deployed globally across the oil and gas industry, from offshore platforms and FPSOs to onshore refineries, LNG plants, storage facilities, and tank farms.
OGI: Could you explain to our readers the use and applications of LED lighting in the oil and gas sectors?
Somerset: LED lighting plays a crucial role in the oil and gas industry, providing essential illumination for safe and efficient operations. From illuminating walkways and stairwells to powering control rooms and storage areas, LED technology ensures a well-lit work environment. Beyond standard applications,
LEDs serve specialised purposes such as escape lighting, signal lighting, clear sky lighting, and turtle-friendly lighting. These innovative solutions enhance safety, improve worker well-being, and minimise environmental impact.
OGI: What are the differences between hazardous zones 1 & 2?
Somerset: Fundamentally, for an explosion to take place, flammable or explosive gases, vapours, mists or dusts will be present. Then, the level of risk of an explosion is based on
the frequency and duration of the occurrence of an explosive atmosphere. This level of risk is represented by classifying the hazardous area as Zone 0, Zone 1 or Zone 2 (for gas, vapour and mist atmospheres) or Zone 21 or Zone 22 for dust atmospheres.
Zone 1 is an area in which an explosive atmosphere is likely to occur occasionally in normal operation. It may exist because of repair, maintenance operations, or leakage.
Zone 2 is a place in which an explosive atmosphere is not likely to occur in normal
Jonathan Somerset, Rayec’s Technical Director
operation but, if it does occur, will persist for a short period only. These areas only become hazardous in case of an accident or some unusual operating condition.
OGI: Is it very important for companies operating in hazardous areas to make sure they are using the correct LED lighting and why?
Somerset: Where there is potential for an explosive atmosphere, special precautions are needed to prevent fires and explosions. Electronic equipment, including lighting, needs to be purpose designed for use in hazardous areas to prevent a spark occurring and igniting any flammable substances.
Although every application is different, for the ease of monitoring and specification each hazardous area is classified as a particular level or “zone”. As a result, all hazardous area equipment must be designed with hazardous area zone classifications in mind, as the “zone” governs the level of protection and precaution required. It is essential to know which zone you are working in, so that you can specify the most appropriate equipment.
OGI: Do you offer tailormade services, like a lighting design plan so clients can visualise what they are getting? How does that process work?
Somerset: Yes, Raytec offers an award-winning, free-of-charge, lighting design service to all our customers – bringing your installation to life. Getting your hands on this service is easier than you would expect. Depending on the complexity of your installation, Raytec can offer you a range of designs varying from simple to highly detailed, with the shortest turnaround time being just 3 days!
The team is continuously expanding its resources by employing more skilled professionals and investing in machinery, such as our in-house Goniophotometer, which helps to provide a much quicker turnaround, with just as much accuracy, efficiency, and detail.
To get your free lighting design, fill in a request form from the page here or connect with the team at sales@raytecled.com for more information.
OGI: What kind of aftercare to you provide potential clients?
Somerset: Raytec customers have direct access
to a variety of technical support outlets for help with all product enquires and issues. If a Raytec product is found to be defective within its warranty period, it is entitled to an RMA (Return Material Authorisation) claim for repair or replacement (RMA procedure). You must first contact Raytec so we can verify that your product is approved for an RMA claim.
We offer a comprehensive five-year warranty that protects against defects in components or workmanship and includes the luminaire’s PSU. To explore a full summary of what is included in the Raytec warranty, read here:
https://www.raytecled.com/warranty/ OGI: Finally, could you enlighten our readers of a case study where you helped a client with your solutions?
Somerset: I) Drill rigs - SPARTAN hazardous area LED floodlights from Raytec have been installed on several drilling rigs in the United Arab Emirates. The SPARTAN Flood luminaires have increased safety
on-site, providing an effective emergency lighting solution for the lifeboat and life raft deployment systems, and will also provide significant maintenance savings during the course of their operating life. Read the full case study here:
II) Oil rig - SPARTAN Flood and Linear luminaires, including emergency variants, were installed across an oil rig in United Arab Emirates. This included illuminating the lifeboat areas (to support evacuation procedures in an emergency scenario), around the helideck, and general illumination throughout the rig. Read more here: https://www.linkedin.com/posts/ raytec_ledlighting-ledlightingsolutionsoilrig-activity-709571989854214144049Xt/?utm_source=share&utm_ medium=member_desktop
OGI: Thank you for your time.
Raytec has established itself as a trusted leader in LED lighting solutions for the oil and gas industry, delivering products that enhance safety and efficiency across global applications. Their experience, dating back to 2005, has equipped them with the expertise to address various challenges in hazardous environments. With a strong focus on tailored solutions, including lighting design services and comprehensive aftercare support, Raytec continues to provide innovative, reliable, and safe lighting systems.
If you would like more information about the topics discussed in this article, please use the contact information below:
Raytec Ltd
T: +44 1670 520055
E: sales@raytecled.com
W: https://www.raytecled.com
Monitoring Noise in the Oil & Gas Industry
The oil and gas industry is one of the most demanding and high-risk sectors globally. With operations ranging from exploration and extraction to refining and distribution, workers in this field are exposed to a variety of hazards. Among these risks, noise pollution is a significant concern that can have long-term health implications if not properly managed.
As a leader in the field of noise monitoring solutions, Cirrus Research has a long history of developing cutting-edge technology aimed at helping industries monitor and control noise levels. This article explores the importance of noise monitoring in the oil and gas industry, the challenges involved, and how Cirrus Research products can provide effective solutions to ensure compliance, improve safety, and protect worker health.
The Noise Problem in the Oil & Gas Sector
Noise pollution in the oil and gas sector is a significant occupational hazard. The sound generated by equipment such as compressors, pumps, turbines, and drilling rigs can exceed 100 decibels (dB) routinely, a level that, if unprotected, can lead to hearing damage after prolonged exposure. According to the World Health Organisation (WHO), regular exposure to noise levels about 85dB can cause irreversible hearing loss. In extreme cases, high noise levels can lead to health issues including stress, tinnitus, and even cardiovascular problems. Offshore platforms, refineries and extraction sites are some of the noisiest work environments. Workers who spend extended periods of time in these environments are at high risk of experiencing hearing damage/loss. Despite the use of personal protective equipment (PPE), long-term exposure can still result in hearing degradation. Other than noise just affecting workers directly, it can also disrupt communication, reduce the ability to hear warning signals, and increase the likelihood of accidents, putting both individuals and overall operations at risk.
Regulations and Compliance
To mitigate these risks, there are strict regulations in place regarding noise exposure in the workplace. Agencies like Occupational Safety and Health Administration (OSHA) in the United States and the HSE in the UK, set clear limits on permissible noise exposure levels and mandate the use of hearing conservation programmes for workers at risk. These regulations typically require ongoing noise monitoring, risk assessments and the implementation of control measures. For example, in the UK, under the Control of Noise at Work Regulations 2005, employers must assess and identify measures to mitigate noise exposure if it exceeds 85dB, providing hearing protection when necessary, and
regularly monitoring noise levels to ensure compliance.
Failure to comply with regulations can result in significant penalties, lawsuits, and long-term reputational damage. More importantly, neglecting noise control can lead to deterioration in the health of the workforce, higher absenteeism, and decreased operational efficiency. Regular noise monitoring in the cornerstone of compliance, allowing companies to identify problem areas, evaluate the effectiveness of PPE, and ensure that mitigation strategies are properly implemented.
Challenges of Monitoring Noise in Oil & Gas Operations
The oil and gas industry presents unique challenges for noise monitoring compared to other industrial sectors. Operations often span large, complex facilities, and monitoring needs to be comprehensive and continuous. Remote locations, difficult terrain, and offshore environments add logistical hurdles. Another consideration is that oil and gas operations are rather dynamic in nature. Noise levels can fluctuate due to changes in equipment usage, environmental factors, or operational phases. For example, drilling activities can generate high levels of noise during peak operations, while other processes
may be quieter. This variability means that noise exposure monitoring systems must be flexible, adaptable, and capable of providing real-time data to identify and address emerging risks.
On oil & gas sites, it’s important to think about individual contractors, engineers and technicians who may rotate between different roles and sites, each with different noise exposure levels. This requires a comprehensive approach to ensure that workers are monitored individually and that noise control measures are site-specific and worker specific.
Cirrus Research: Delivering Solutions for Noise Monitoring in Oil & Gas
Cirrus Research has a range of solutions specifically designed to address the noise monitoring needs of industries like oil and gas. Our products are engineered to withstand the challenges of harsh environments, delivering accurate and reliable data even under extreme conditions.
Real-Time Monitoring
The Cirrus Research Optimus+ range of Sound Level Meters are perfect for providing real-time measurements across various points of an industrial site. These meters can log, analyse, and report noise levels instantly, allowing for immediate intervention if sound levels exceed regulatory limits. The
Intrinsically Safe doseBadge is another essential tool for monitoring individual worker exposure, particularly useful in ensuring that contractors and employees working in high-risk areas are protected. This instrument is also certified for use in hazardous and explosive atmospheres. Both devices are portable and rugged, making them ideal for deployment in the oil and gas industry. They’re equipped with all the features you need to track noise exposure over time and assess the efficacy of noise control measures.
Long-Term Monitoring and Reporting
For oil and gas operations, long-term monitoring is key to demonstrating compliance and optimising noise control strategies. Cirrus Research’s Quantum Outdoor is specifically designed to provide robust, continuous noise environmental monitoring in a variety of environment.
This instrument offers an all-in-one solution for remote, unattended noise monitoring. It is ideal for long-term deployment in both onshore and offshore locations, where environmental conditions can be harsh. Built for durability, this instrument ensures that it continues to deliver reliable data, even in the most demanding conditions.
Paired with the Cirrus Research cloud platform, MyCirrus, the system allows noise data to be accessed remotely, meaning noise levels can be monitored and managed from any location, regardless of where the equipment is deployed. This remote accessibility is particularly valuable for oil and gas operations spread over large areas or in isolated locations, allowing for efficient oversight without the need for physical presence on site.
Advanced Reporting and Analytics
Understanding and managing noise in complex operations require sophisticated analysis tools. Cirrus Research offers advanced reporting and analytics tools that provide in-depth insights
into noise patterns. Our products come with software that simplifies compliance reporting, automatically generating the necessary documentation for audits or inspections. This ensures that oil and gas companies can maintain a complete and accurate noise exposure record, safeguarding both their workforce and their legal standing.
Customisation and Scalability
Every oil and gas site is different, and Cirrus Research understands the need for customisable noise monitoring solutions. Whether an operation requires extensive monitoring across multiple platforms or
focused monitoring for specific processes, our products are designed to be scalable and adaptable. We work closely with industry leaders to ensure that our solutions meet the unique requirements of their operations. Monitoring noise in the oil and gas industry is an essential aspect of workplace safety, compliance, and operational efficiency. Given the scale and complexity of these operations, comprehensive, real-time, and long-term monitoring solutions are necessary to protect workers from harmful noise exposure and ensure regulatory compliance.
Cirrus Research offers a range of state-of-theart products designed to meet the specific noise monitoring needs of the oil and gas industry, helping companies mitigate risks and promote a safer working environment. By investing in reliable noise monitoring solutions, oil and gas operators can protect their workforce, maintain compliance, and enhance the overall productivity of their operations.
Cirrus Research, here to help you
At Cirrus Research, our range of noise measurement products, including the Intrinsically Safe Noise Dosimeter, Optimus Green Sound Level Meter and Quantum Outdoor Environmental Monitor, are designed to meet the specific needs of the oil and gas industry, providing accurate and reliable noise measurement data in even the most challenging of environments.
You can contact our expert team to learn more about monitoring workplace and environmental noise in the oil and gas industry by contacting us:
Cirrus Research PLC
T: +44 (0)1723 891655
E: sales@cirrusresearch.com
W: www.cirrusresearch.com
ENHANCING OPERATIONAL EFFICIENCY IN THE OIL AND GAS INDUSTRY
In the dynamic and demanding world of the Oil and Gas industry, operational efficiency is not just a goal but a necessity. The industry operates under stringent safety and environmental regulations, coupled with the complexity of extracting, refining, and transporting resources that power economies worldwide. Within this framework, the role of continuous inspections emerges as a critical component to ensure smooth operations, mitigate risks, and maintain industry standards.
Understanding Continuous In-
spections
Continuous inspections in the Oil and Gas industry encompass a wide array of activities aimed at monitoring, evaluating, and optimizing various aspects of operations. These inspections are conducted at different
stages of the oil and gas lifecycle—from exploration and drilling to production, transportation, and refining. The overarching goal is to uphold safety, regulatory compliance, operational reliability, and environmental stewardship.
The Importance of Inspections
Inspections serve multiple crucial purposes within the Oil and Gas sector.
1. Safety Assurance:
Safety is paramount in the Oil and Gas industry due to the hazardous nature of operations. Inspections help identify potential risks, hazards, and safety breaches, allowing for timely interventions to prevent accidents and protect personnel, assets, and the environment spections help identify potential risks, hazards, and safety breaches, allowing for timely interventions
spections help identify potential risks, hazards, and safety breaches, allowing for timely interventions to prevent accidents and protect personnel, assets, and the environment.
2. Regulatory Compliance:
The industry is heavily regulated by local, national, and international bodies to ensure operational practices adhere to strict standards. Inspections verify compliance with these regulations, certifications, permits, and operational licenses, thereby avoiding legal repercussions and maintaining business continuity.
3. Asset Integrity Management:
Assets in the Oil and Gas industry, including infrastructure such as pipelines, platforms, and refineries, are capital-intensive and critical for operations. Inspections assess the condition, reliability, and performance of these assets to prevent failures, extend operational life, and optimize maintenance schedules.
4. Environmental Protection:
Environmental considerations are increasingly important in Oil and Gas operations. Inspections monitor emissions, waste management practices, and adherence to environmental regulations to minimize ecological impact and promote sustainable practices.
5. Quality Control:
Throughout the production and refining processes, inspections ensure the quality of extracted resources, refined products, and materials used. This includes monitoring chemical compositions, purity levels, and adherence to industry standards to meet customer expectations and regulatory requirements.
Type of Inspections
nspections in the Oil and Gas industry are diverse and tailored to specific operational needs and regulatory requirements. Here are key types of inspections conducted:
1. Asset Inspections:
Asset inspections focus on the physical condition and
operational performance of infrastructure such as pipelines, offshore platforms, storage tanks, and refineries. These inspections use various techniques, including visual assessments, non-destructive testing (NDT), and remote sensing technologies to detect defects, corrosion, structural weaknesses, and operational anomalies.
2. Operational Inspections:
Operational inspections involve monitoring dayto-day activities related to drilling, well operations, production processes, and transportation logistics. These inspections ensure that operational protocols are followed, equipment is functioning correctly, and production targets are met safely and efficiently.
3. Safety Inspections:
Safety inspections prioritize the identification and mitigation of safety hazards, risks, and non-compliance with safety protocols. These inspections cover personal protective equipment (PPE), emergency response preparedness, hazard communication, and adherence to safety regulations to protect workers and facilities from accidents and incidents.
4. Environmental Inspections:
Environmental inspections focus on monitoring and managing the environmental impact of operations. They include assessments of air emissions, water discharg-
es, waste management practices, spill prevention measures, and compliance with environmental permits and regulations. Environmental inspections aim to minimize ecological footprints and ensure sustainable operations.
5. Regulatory Inspections:
Regulatory inspections are conducted by governmental agencies or regulatory bodies to verify compliance with laws, regulations, permits, and operational licenses. These inspections are critical for maintaining legal standing, avoiding fines or penalties, and upholding industry standards.
Implementing Efficient Inspection Practices
Efficient inspection practices are essential for maximizing operational efficiency and minimizing disruptions in the Oil and Gas industry. Here are strategies to enhance the effectiveness of inspections:
1. Utilization of Technology:
Advancements in technology, such as drones, sensors, data analytics, and predictive maintenance tools, revolutionize inspection capabilities. These technologies enable remote monitoring, real-time data collection, predictive insights, and condition-based maintenance, enhancing efficiency, accuracy, and safety.
2. Integration of Data
Management Systems: Centralized data management systems facilitate the storage, analysis, and accessibility of inspection data. Integrated platforms allow for seamless communication, collaboration among inspection teams, and decision-making based on comprehensive insights
3. Training and Competency Development:
Investing in training programs ensures that inspection personnel are equipped with the necessary skills, knowledge of regulatory requirements, and proficiency in using inspection tools and technologies. Continuous education promotes adherence to best practices and enhances inspection quality.
4. Risk-Based Inspection Strategies: Implementing risk-based inspection (RBI) strategies prioritizes inspections based on the criticality and risk profile of assets and operations. RBI methodologies optimize resource allocation, focus on highrisk areas, and improve decision-making regarding maintenance and asset management.
5. Collaboration and Communication: Effective communication
and collaboration among inspection teams, operational staff, regulatory bodies, and stakeholders are crucial. Transparent communication fosters a culture of safety, compliance, and continuous improvement, ensuring that inspection findings are promptly addressed and corrective actions are implemented.
One innovative tool that enhances inspection efficiency in the Oil and Gas industry is SurveyCams. SurveyCams operates via mobile smartphones or tablets, allowing inspectors to conduct inspections seamlessly on-site. The app enables inspectors to capture photos, scan numeric references like barcodes and equipment tags, and input inspection data directly into the system in real-time.
SurveyCams stores all inspection reports on its encrypted servers, ensuring data security and integrity. Reports generated through SurveyCams are “tamper-free,” meaning that once an inspection is completed and recorded, the results cannot be altered or manipulated. This feature
EEMUA Publishes New Guidance on Written Schemes of Examination
TÜV Rheinland Industrial Services in the UK is the newest member of EEMUA’s Associate Company Scheme.
The Associate Scheme is open to organisations worldwide that provide goods and professional services to owners and operators of industrial assets. TÜV Rheinland Industrial Services provides technical services to the process industries, aiding them in achieving operational excellence through safe, reliable, efficient and sustainable operations.
On joining EEMUA, the company commented: “TÜV Rheinland Industrial Services has become an Associate of EEMUA, strengthening our commitment to assisting customers in the process industries in achieving safe and reliable operations. We are eager to contribute to EEMUA technical committees, actively participate in forums, and support the development of industry standards”.
Deovonne Ferreira, EEMUA Head of Membership, said: “We are delighted to welcome TÜV Rheinland Industrial Services as an Associate and look forward to their participation in EEMUA’s activities, supporting our aim of helping improve the safety, environmental and operating performance of industrial assets worldwide”.
Prosafe SE: Safe Boreas Contract Signed
Reference is made to press release dated 30 May 2024 where Prosafe announced the award of a Conditional Letter of Intent by an undisclosed client for the provision to provide gangway connected operations to support a project off the coast of Western Australia for a firm period of 15 months with up to six months of options.
Prosafe now advises that the contract has been signed. The Safe Boreas will mobilise from the North Sea within Q2 2025 and will undergo its five-yearly special periodic survey and other maintenance works prior to commencement of the contract.
The value of the contract remains at approximately USD 75 million to USD 100 million depending on options.
Terje Askvig, CEO of Prosafe says: “Formalising this contract has been a result of close and positive collaboration. Prosafe is confident that the Safe Boreas industry leading operational and safety performance will be delivered once again.”
Extinguishing Technology in Action: Fighting Wildfires
Thanksto preventive fire protection, typical residential fires are declining, while at the same time, climate change is exacerbating prolonged droughts in the natural environment. As a result, the danger of forest and vegetation fires increases more and more. These types of fires have always existed, of course, and in certain regions of the world, annual “fire seasons” are nothing unusual. However, it can be observed that the forest fire season is getting longer from year to year and the fires are getting more and more intensive.
The global impact of these wildfires is substantial. Beyond the destruction of forests, air quality deteriorates significantly, and large quantities of carbon emissions are released, further exacerbating climate change. This phenomenon, known as the “fire-climate feedback loop”, intensifies the cycle of climate change. (For more information, visit: WRI)
Halogens: a New Guide for an Environmentally Conscious Market
Halogens
offer various benefits and are widely used in electronics and other sectors, but their use has long been under scrutiny. There is an ever-growing spotlight on the need for tighter regulations on halogen substances. The halogenated compound per- and polyfluoroalkyl substances (PFAS), which can be found anywhere from water and fish to the soil and even in the air we breathe, has been attracting a lot of attention worldwide lately.
Since 2009, perfluoro-octane sulfonic acid and its derivatives (PFOS) have been listed under the international Stockholm Convention, aiming to eliminate their use. Over the past few years, Europe has restricted the use of halogenated flame retardants in electronics, and many countries have banned halogen bulbs in favour of more energy-efficient LEDs.
Even then, halogen use remains common. As more manufacturers grapple with how to produce environmentally responsible products and safely comply with regulations, a new IEC Guide emerges as a crucial resource.
HydraWell: Pioneering the Successful Installation of 500 Jet-Based Wellbore Barriers Globally
In the ever-evolving landscape of the oil and gas industry, innovation is the cornerstone of progress writes Eivind Knudsen - Chief Operations Officer at HydraWell Intervention AS. Companies that thrive continually push the boundaries of what is possible, integrating innovative technology with deep industry expertise. HydraWell, a leader in well integrity and wellbore barrier solutions, exemplifies this approach and, with the successful installation of 500 jet-based wellbore barriers globally, the company has solidified its reputation as an innovator and trusted partner in engineered wellbore barrier placement.
HydraWell: A Global Innovator
At the heart of HydraWell’s success is its unwavering commitment to innovation. Since its inception, the company has positioned itself at the forefront of well integrity solutions, consistently delivering advanced technologies that meet the evolving needs of the industry. HydraWell’s global experience is unparalleled, with operations spanning multiple continents and diverse geological environments. This has allowed the company to refine techniques and develop solutions that are not only technically superior but also adaptable to various operational challenges.
HydraWell’s global presence has been instrumental in driving success. With projects completed in regions such as the North Sea, the Middle East, Asia, Australia and the Americas, the company has demonstrated its ability to operate in a wide range of conditions. Whether dealing with the harsh environments of offshore well abandonment operations or the complex geology of onshore fields, HydraWell’s expertise ensures that each wellbore barrier is installed with precision and reliability.
A Milestone in Wellbore Barrier Technology
HydraWell’s achievement of successfully installing 500 successful jet-based wellbore barriers marks a significant milestone in the industry and is testament to the company’s technical capabilities and relentless pursuit
of innovation. Each installation represents a critical step in ensuring the safety and longevity of well integrity management and removal operations, protecting both the environment and the investments of energy companies worldwide.
The use of jet-based technology in the installation of remedial wellbore barriers is a prime example of how HydraWell has redefined traditional methods of wellbore barrier placement. Unlike time-consuming and less reliable conventional operations, HydraWell’s jet-based barrier placement approach offers a more efficient and effective solution when re-establishing wellbore integrity or closing wellbore hydraulic access in-perpetuity. This ensures a uniform barrier is placed in the wellbore ensuring optimal sealing and long-term integrity.
The Power of Computational Fluid Dynamics
A key differentiator that sets HydraWell apart in the marketplace is its use of Computational Fluid Dynamics (CFD) in the design and installation of wellbore barriers. CFD is a sophisticated tool that allows engineers to simulate and analyse fluid flow within the wellbore, providing invaluable insights into the behaviour of barrier materials under various conditions. By leveraging CFD, HydraWell can design barrier placement that
is not only more effective but also tailored to the specific requirements of each well.
The application of CFD in wellbore barrier design has been a game-changer. Traditional methods often rely on empirical data and experience which, while valuable, can be limited in their ability to predict the operational performance and verification of barrier placement in complex environments. CFD, on the other hand, allows detailed analysis of fluid dynamics, factoring in the likes of perforation size, fluid rheology and viscosity, and wellbore geometry. This level of detail enables HydraWell to optimise the design of each barrier, ensuring that the operation is performed as intended in realworld conditions.
Moreover, the use of CFD reduces trial and error in the field – by simulating the installation process in a virtual environment, HydraWell can identify potential issues before they arise, minimizing the risk of failure and, crucially, reducing operational costs. This proactive approach enhances the reliability of the barriers and improves overall project efficiency.
A Commitment to Environmental Stewardship
In addition to its technical innovations, HydraWell is also deeply committed to environmental stewardship. The company recognizes that well integrity is not just about protecting assets but also about safeguarding the environment. Efficient placement of effective wellbore barriers plays a crucial role in
Eivind Knudsen, Chief Operations Officer.
preventing the uncontrolled release of hydrocarbons, which can have devastating effects on marine and terrestrial ecosystems.
HydraWell’s jet-based system for wellbore barrier placement is designed with ‘verification by design’ in mind. The precision and effectiveness of the barrier placement ensure that wells are securely sealed, preventing leaks and reducing the environmental impact of well decommissioning operations. Furthermore, the efficiency of the installation process means that less time is spent on-site, reducing the overall carbon footprint of the operation.
The company’s commitment to the environment is also reflected in its approach to research and development. HydraWell continuously invests in new technologies and methodologies to improve the sustainability of its operations. This forwardthinking approach ensures that the company remains at the forefront of well integrity solutions, providing its clients with the tools they need to meet increasingly stringent environmental regulations.
Case Studies: Demonstrating Success Across the Globe
An enviable track record of success is best illustrated through the numerous case studies that highlight the effectiveness of its jet-based wellbore barriers. In the North Sea, for example, HydraWell successfully installed barriers in some of the most challenging offshore environments. The region’s harsh weather conditions and complex geology posed significant challenges for well abandonment, but HydraWell’s expertise and innovative technology assured ‘right first
In Asia, HydraWell’s solutions have been instrumental in managing the unique challenges of minimal footprint, low impact operations. The variable operating conditions experienced in the region require barriers that are both robust and simple to deploy. HydraWell’s use of CFD in the design process allowed the company to tailor solutions to the specific needs of each well, resulting in successful installations that have set new standards for well integrity in the region. Australia and the Americas have also benefited from HydraWell’s wellbore barrier expertise in a variety of environments, from deepwater offshore fields to remote onshore locations. Each project presented its own set of challenges, but the team’s global experience and innovative approach ensured successful outcomes every time.
Looking Ahead: The Future of Wellbore
Barriers
As the energy industry continues to evolve, the need for reliable and effective wellbore barriers will continue to grow. HydraWell is well-positioned to lead the way, thanks to its proven track record. The company’s success in installing 500 jet-based wellbore barriers globally is just the beginning. With ongoing investments in research and development, and a focus on expanding its global footprint, HydraWell is poised to continue setting new standards in well integrity solutions. In the future, HydraWell will further refine its technologies, incorporating the latest advancements in CFD and other cutting-edge tools to stay ahead of the curve. The company’s ability to adapt to changing market conditions and regulatory requirements will be key to its continued success and, as the industry places greater emphasis on sustainability, HydraWell’s commitment to environmental stewardship will become increasingly important.
HydraWell’s achievement of 500 successful jetbased wellbore barrier installations is a testament to the company’s pillars of innovation, expertise, and global reach. Using advanced technologies like Computational Fluid Dynamics, the company has redefined the standards for wellbore barrier design and installation, offering solutions that are both efficient and effective. Ongoing commitment to pushing boundaries will ensure that HydraWell continues to be a leader in well integrity solutions for years to come.
To find out more, visit: www.hydrawell.no
time - simple solution’ barriers were installed efficiently and securely.
HydraWell’s jet-based system for wellbore barrier placement is designed with ‘verification by design’ in mind.
Hydra Well Intervention AS
SEEPEX Pumps in the Oil and Gas Industry
The oil and gas industry, whether onshore or offshore, requires robust, reliable, and efficient equipment to manage complex processes. From extracting crude oil to managing wastewater, drilling cuttings, and chemical treatments, every stage of oil production demands specialized solutions to enhance productivity, reduce downtime, and meet stringent environmental and safety regulations. SEEPEX progressive cavity pumps have emerged as a superior choice in this arena, offering distinct advantages for both oilfield operators and refinery professionals.
SEEPEX Pumps Enhance Oil and Gas Operation Processes
SEEPEX is renowned for its progressive cavity pumps, a type of positive displacement pump designed to handle a wide range of fluids. These pumps offer smooth, consistent flow with minimal shear, making them ideal for a variety of tasks in oil and gas exploration and production. Unlike traditional pump systems such as beam pumps, SEEPEX’s technology excels in challenging environments, from deep underground onshore oil fields to the rough and often unpredictable offshore platforms.
Key areas where SEEPEX pumps excel include drilling waste management, produced water treatment, crude oil transfer, and more specialized applications like polymer flooding and fracking. With their capability to handle varying viscosities and solid-laden fluids, SEEPEX pumps offer the versatility, durability, and precision necessary for today’s demanding oil and gas operations.
Superior Performance in Drilling and Waste Management
One of the most critical challenges in both onshore and offshore oil production is managing the waste generated during drilling operations. SEEPEX pumps excel in drilling waste management, providing efficient and reliable solutions for handling waste, transferring cuttings, and maintaining clean mud pits. Their
performance ensures streamlined operations and minimizes downtime, making them a valuable asset for oil and gas companies. For instance, the SEEPEX pumps used in drilling waste management can transfer heavy cuttings and other waste products with minimal pulsation and shear, thus reducing wear on the pump and ensuring a steady flow of materials to centrifuges and dryers. This is crucial in both land-based and offshore platforms where space is limited, and equipment downtime can result in significant financial losses.
SEEPEX’s produced water treatment solutions are another significant advantage for oil and gas operators. In oil production, the mixture of oil and water must be separated efficiently to comply with environmental regulations and ensure smooth operations. SEEPEX pumps handle these mixtures without damaging the integrity of the oil droplets, making them ideal for use in systems like induced gas flotation units and de-oiling hydrocyclones.
High Performance in Harsh Offshore Environments
Offshore oil extraction poses unique challenges due to harsh environmental conditions, limited space, and remote locations. SEEPEX pumps have proven their reliability in these tough conditions. Offshore platforms, such as jack-up rigs, semi-submersible rigs, and FPSOs (Floating Production Storage and Offloading units), require equipment that can handle the unpredictable pressures of deepwater drilling, variable flow rates, and the management of high-viscosity fluids like crude oil and drilling mud.
SEEPEX pumps are designed to operate efficiently in these conditions. Their ability to manage high solids content and variable inlet pressures, while still delivering consistent flow, makes them indispensable for offshore drilling
operations. Additionally, SEEPEX pumps are often used in FPSO systems, which face challenges related to low NPSHa (Net Positive Suction Head Available) and varying gas content in liquids. Their versatility and ability to function under such conditions ensure smooth and efficient crude oil transfer.
Another standout application is MEG reclamation: MEG (Monoethylene Glycol) is essential in offshore drilling to prevent ice formation in pipelines in cold, deepwater environments. SEEPEX pumps are highly efficient in purifying MEG and ensuring the safe removal of impurities, ensuring smooth pipeline operations and reducing the risk of costly shutdowns.
SEEPEX Pumps in Refining and Petrochemical Applications
SEEPEX’s pumps are not limited to exploration and drilling; they also play a critical role in the refining and petrochemical sectors. Refinery operations involve the processing of crude oil into refined products like gasoline and diesel, a process that requires pumps capable of handling high pressures, extreme temperatures, and corrosive substances. SEEPEX refinery pumps are specifically designed for these demanding conditions, ensuring reliable, efficient fluid transfer even under harsh conditions.
to viscous drilling mud and produced water mixtures. This versatility makes them suitable for various tasks, from polymer flooding and water injection to drilling waste management and produced water treatment.
Durability and Reliability
In petrochemical plants, SEEPEX pumps support various processes, including catalyst slurry injection and the accurate dosing of chemicals like corrosion inhibitors and flocculants. Their low shear and minimal pulsation design ensure that even shear-sensitive fluids are handled without degradation, making them an ideal solution for chemical mixing and dosing applications.
Advantages of SEEPEX Pumps for Oil and Gas Operators
SEEPEX pumps bring several advantages to the oil and gas industry. Here are some of the key benefits customers can expect when purchasing these pumps:
Versatility
SEEPEX pumps handle a wide range of fluid types, from crude oil with high solids content
In the demanding environments of oil and gas operations, equipment failure can lead to costly downtime. SEEPEX pumps are designed for long-term durability, with low wear rates even when handling abrasive or corrosive fluids. Their low pulsation and shear characteristics reduce the risk of mechanical failure and help maintain the integrity of the fluids being processed.
Energy Efficiency
SEEPEX progressive cavity pumps are known for their energy efficiency. Their design ensures a steady flow of materials with minimal energy loss, reducing overall operational costs. This is especially important in offshore platforms and remote oil fields where energy resources may be limited.
Precision and Control
SEEPEX pumps offer precise flow control, essential for applications like chemical dosing and custody transfer. Their ability to deliver consistent flow rates, even in variable pressure environments, ensures accurate measurement and efficient processing of materials.
Reduced Maintenance Costs
Progressive cavity pumps like those from SEEPEX have fewer moving parts than traditional pump designs, leading to lower maintenance requirements. This feature reduces operational costs and minimizes downtime, a critical factor in both onshore and offshore oil production.
SEEPEX pumps have become an integral part of the oil and gas industry, from onshore production fields to the most challenging offshore environments. Their superior performance, reliability, and energy efficiency make them a preferred choice for oilfield operators, offshore platform managers, and refinery engineers. By investing in SEEPEX pumps, oil and gas companies can enhance operational efficiency, reduce maintenance costs, and ensure compliance with environmental regulations, all while maintaining the highest standards of safety and productivity.
In a rapidly evolving industry where efficiency and reliability are paramount, SEEPEX pumps provide a competitive edge, enabling operators to meet today’s challenges and prepare for the demands of tomorrow.
If there is anything SEEPEX can do for you, please let us know. •
SEEPEX GmbH
T: +49 2041 996-0
E: info@seepex.com
W: www.seepex.com
Robots and Cobots – Can they Replace Workers in the Oil and Gas Industry?
The oil and gas industry, like many others, is constantly evolving. As technologies advance and the skilled labor pool shrinks, companies are increasingly turning to automation and robotics to streamline operations.
But can these machines truly replace human workers in such a complex and varied field? This article explores the viability of robots and cobots in oil and gas, with a focus on pipe-spool fabrication. It draws on more than 40 years of experience that 3R solutions from Germany has in the field of pipe-shop automation, with projects all over the world for some leading companies in the oil and gas industry.
While this discussion focuses on pipespool fabrication—3R Solutions’ core expertise—the same principles can be extended to other areas of oil and gas operations.
Reasons to automate
The current situation in the industry, is that there are more and more projects, but fewer and fewer skilled welders. This is a global problem, across many industries, meaning that the oil and gas industry is in direct competition for workers with other industries, such as ship-building, civil works and the nuclear industry.
Due to this increasing scarcity of skilled workers, in particular welders, the idea to automate, in order to reduce the number of workers required is quite tempting. In addition to reduced reliance on a shrinking labor pool, there are a number of additional advantages.
1) Reduced operating costs
While the initial investment can be quite significant, the expected savings over time will make up for this capital expense. Because reductions in the work force on the shop floor also mean savings in positions such as insurance,
sanitation, parking and transportation, and other aspects which may not be immediately
apparent.
2) Repeat accuracy
A machine or robot will not get sick, will not get tired, and will not have fluctuations in performance. Once the parameters or programming have been set, the machine or robot will process the tenth or twentieth joint with the same accuracy as the first joint – provided the material falls within the tolerances, and the edge preparation is accurate.
3) Traceability
With the right software it is possible to monitor all parameters and give real time feedback of each process to a central database. This makes the documentation for each joint’s weld history significantly easier.
Potential challenges
However, there are a number of drawbacks or potential problems with automation. While some of these affect mechanized process as well, they are particularly problematic for robotic welding:
Unlike a robot, a cobot allows an operator to enter the work area without emergency shutdown.
1) Spool geometries
Unlike the automotive industry, where a robot will produce hundreds of thousands of identical units, the oil and gas industry has different requirements. Within a single project there will be hundreds, if not thousands of individual geometries, each of which will be fabricated only a few times, in many cases only once.
Because of this the programming for the robots becomes more and more complex, especially if the geometries themselves become more complex. So while the robot may replace one or even more welders, there now is the issue of needing a skilled programmer to operate it.
2) Accessibility
In order to weld a joint, a welding robot has to be able to get into the correct position. If the pipe can be rotated, this is easy, as the robot only needs to move into a stationary position to weld the joint. However, in this case the robot becomes little more than a very expensive torch holder. For 2D or 3D welds, however, the robot needs to be able to move entirely around the pipe. This is usually not the case, so the robot has to stop welding, reposition, and start again, which can lead to problems with the welding process. In addition the program the robot follows has to correctly identify the position of the joint, making the programming yet more complex.
3) Tolerances and repeat accuracy
The complexity of the programming is a major issue, as the robot will normally follow the program without deviation. That means that unlike a human it cannot easily adapt to changes in its work process. A welding robot using simple point to point programming will strictly follow the programmed welding route, even if the actual joint is a little offset due to tolerances. It will not check whether the pipe that has been loaded is the correct dimension or even material either.
There are two ways to overcome this difficulty. One is to buy calibrated materials with no tolerances in dimensions, wall thickness, etc. But any tolerances in for example cutting length will still accumulate, so that by the time the pipe comes to the welding robot, the welding accuracy still cannot be guaranteed.
The other option is to use sensors and adaptive programming, which allows the robot to compensate for issues like offsets or ovality. However, this makes the robot significantly more expensive, while at the same time making the programming yet more complex.
4) Safety requirements
The robot’s work area has to be fenced off, with no risk of a human entering it. This is not a big problem when the work area only has a relatively small foot-print, but can become an issue if large areas of the workshop have to be segregated from normal operations, because of the robot. This becomes less of a problem with the use of collaborative robots (cobots), who are designed to work in an environment where humans work as well. However, cobots are more expensive, as they require additional sensors and safety measures. And cobots still require programming, which becomes more and
more complex as the number of geometries increase.
Conclusion
While full automation may not yet be a viable solution for complex fabrication processes in oil and gas, a balanced approach—combining human expertise with automation—can lead to significant productivity gains. As cobot technology evolves and programming becomes more intuitive, we may see greater adoption across the industry. But for now, the key lies in optimizing workflows, as demonstrated by 3R Solutions’ integrated systems.
In fact, the end goal of any project to
process should make it faster, safer, cheaper, or more accurate. If automating a process does not achieve at least some of these four goals, it is not viable.
The balanced approach of 3R solutions, which is to analyze the current fabrication processes, and identify the biggest actual causes of timeloss, as well as the actual requirements of the shop.
By streamlining the workflow, combining the most suitable machines with automated handling systems, as well as using a dedicated software for the preparation of optimized work packages, it is possible to significantly increase productivity, while retaining the advantages of human experience and adaptability.
How ANT AG is Shaping the Future of Waterjet Technology
In the fast-evolving oil and gas industry, precision and innovation are essential. ANT Applied New Technologies AG stands out as a global leader in mobile waterjet cutting systems, leveraging over 25 years of experience. Known for delivering tailored solutions that emphasize safety, efficiency, and sustainability, ANT has solidified its role in the sector. In this interview with OGI, we explore ANT’s expertise, including the strategic launch of its UK subsidiary, which enhances local customer support. From advanced Water Abrasive Suspension (WAS) systems to key contributions in offshore decommissioning, ANT AG demonstrates a steadfast commitment to innovation and operational excellence. Learn more below.
OGI: Thank you for joining us today. Could you start by sharing ANT’s experience and capabilities in serving the oil and gas sector? How long has the company been operating, and what is the scope of its work?
ANT AG: We’re proud to have over 25 years of experience in the technology and manufacturing of mobile waterjet cutting systems. Over that time, we’ve partnered with more than 100 clients globally, and our ongoing focus on research and development has led to over 100 patents worldwide. In the oil and gas sector, we provide tailored solutions and hands-on training, assisting our clients throughout their projects. Recently, we launched ANT UK to improve customer support in the region, further enhancing our reach. At ANT, we specialize in advanced abrasive cutting and eroding technology, which is essential for offshore structures across oil, gas, and wind power industries. Our systems offer safe, efficient, and environmentally friendly solutions for even the most complex tasks. With decades of expertise, we’ve built strong relationships with major global oil and gas companies, playing a key role in projects worldwide.
OGI: Your Water Abrasive Suspension (WAS) cutting systems seem to be quite advanced. Could you explain their key advantages?
ANT AG: Absolutely. Our Water Abrasive Suspension (WAS) system is at the heart of what we do. In WAS, abrasive particles are suspended directly in water, creating
a stable, precise, and powerful jet that surpasses conventional waterjet technologies. Unlike typical systems that rely on air, ours operates without it, meaning there’s no need for extremely high pressure, which saves resources.
The system is incredibly versatile, cutting a wide range of materials without generating heat or causing deformation. It’s also contactless, which makes it ideal for sensitive or potentially explosive environments. Depending on the project, WAS can cut materials up to 1,000 mm thick and even operate 250 meters underwater. It’s effective in a variety of applications, whether in air, underwater, or in challenging conditions.
OGI: ANT UK is a relatively new addition. What are your goals for this subsidiary in the UK market?
ANT AG: Our main goal is to enhance customer service by being physically closer to our clients. The North Sea, which is right on our doorstep, presents
Internal pile cutting up to 118’’ with DCH 4.
Liam Toovey, ANT Applied New Technologies AG
numerous decommissioning opportunities, and we’re uniquely positioned to support those efforts. Having a local presence allows us to respond more quickly and efficiently to the needs of the UK market.
Many of the service providers here are already our clients, so it was a natural step to establish a stronger base in the region.
OGI: Decommissioning is a significant challenge in the oil and gas sector. Can you tell us more about how ANT contributes to decommissioning projects?
ANT AG: Decommissioning is a key area where our technology excels. Our solutions are designed to tackle the most challenging tasks safely, efficiently, and sustainably. This is particularly crucial for operations like Plug & Abandonment (P&A) and decommissioning of offshore structures. For instance, our technology enables the cutting of multistring conductors, piles, and other structures up to 5 meters below the mudline. We’ve also developed cutting systems that can handle concentric multistring wells in a single pass, which is a unique capability. Our external pile-cutting systems complement offshore spreads and can be integrated with our WAS systems for customized solutions. We offer additional tools like the ANT Cutting Calculator, which helps our clients plan their projects down to the smallest detail—determining the most efficient cuts, tools, and timelines. Our goal is always to make decommissioning processes more efficient, while ensuring maximum safety and environmental responsibility.
extendable cutting head. This makes it highly effective for cutting a wide range of pipe diameters.
It’s an extremely versatile tool that’s ideal for cutting large piles offshore. We’ve seen great success in its application for piles with diameters ranging from 70 inches to 118 inches, which is a significant range.
OGI: Many of your products are certified for use in ATEX zones. Can you give us more details on that?
OGI: Could you tell us about the DCH 4 and its applications in the industry?
ANT AG: The DCH 4, or Downhole Cutting Head 4, is a highly specialized tool that was developed in response to increasing demands from offshore decommissioning projects. Its standout feature is the continuous clamping mechanism combined with a stepless,
ANT AG: Yes, all of our waterjet systems are certified for use in ATEX zones, which are areas with potentially explosive atmospheres. This includes our range of Downhole Cutting Heads, Manipulation Tools, and other equipment like the Packer and Pump systems, which can operate in waters up to 250 meters deep. The Abrasive Mixing Unit (AMU), which is at the core of our systems, is fully approved for ATEX Zone II 3G IIB T3 environments.
Our commitment to safety is paramount, so we ensure that every component meets the highest standards for operating in such hazardous zones.
OGI: Thank you for sharing your insights with us today.
In conclusion, ANT Applied New Technologies AG is a global leader in cuttingedge waterjet solutions, bringing decades of expertise to the oil and gas sector. With a deep commitment to safety, efficiency, and environmental responsibility, ANT’s advanced technologies, such as the Water Abrasive Suspension (WAS) system and specialized tools like the DCH 4, offer innovative solutions for decommissioning and offshore projects. The company’s expansion into the UK market through ANT UK underscores their dedication to providing localized support and service excellence, particularly in tackling the challenges of the North Sea. As the industry continues to evolve, ANT’s focus on research, development, and customer-driven innovation positions them at the forefront of sustainable decommissioning and cutting technology solutions.
If you’d like to learn more about ANT Applied New Technologies AG and their services, please reach out to them at: ANT Applied New Technologies AG
T: +44 7904 244738
E: decom@ant-ag.com
W: ant-ag.com
Plug Removal & Rigless Sidetracking with wellANT.
Chevron to Boost Oil and Natural Gas Recovery at Two Facilities in U.S. Gulf of Mexico
Houston, TX, Chevron Corporation** Today announced that it started water injection operations at two projects to boost oil and natural gas recovery at the company’s existing Jack/St. Malo and Tahiti facilities in the deepwater U.S. Gulf of Mexico, where Chevron operations produce some of the world’s lowest carbon intensity oil and gas.
“Delivery of these two projects maximizes returns from our existing resource base and contributes toward growing our production to 300,000 net barrels of oil equivalent per day in the U.S. Gulf of Mexico by 2026,” said Bruce Niemeyer, president, Chevron Americas Exploration & Production. “These achievements follow the recent production startup at our highpressure Anchor field, reinforcing Chevron’s position as a leader in technological delivery and project execution in the Gulf.”
At the Jack/St. Malo facility, Chevron achieved first water injection at the St. Malo field, the company’s first waterflood project in the deepwater Wilcox trend. The project was delivered under budget, with the addition of water injection facilities, two new production wells, and two new injection wells. It is expected to add approximately 175 million barrels of oil equivalent to the St. Malo field’s gross ultimate recovery.
The St. Malo field and Jack/St. Malo facility are approximately 280 miles (450 km) south of New Orleans, La., in approximately 7,000 feet (2,134 m) of water. Since the fields started production in 2014, Jack and St. Malo together have cumulatively produced almost 400 million gross barrels of oil equivalent.
At the Tahiti facility, located approximately 190 miles (306 km) south of New Orleans in around 4,100 feet (1,250 m) of water, Chevron started injecting water into its first deepwater Gulf producer-to-injector conversion wells. The project included installation of a new water injection manifold and 20,000 feet of flexible water injection flowline.
Bolstered by multiple development projects since the start of operations in 2009, the Tahiti facility recently surpassed 500 million gross barrels of oil-equivalent cumulative production. The company continues to study advanced drilling, completion, and production technologies that could be employed in future development phases at Tahiti and Jack/St. Malo with the potential to further increase recovery from these fields.
Chevron, through its subsidiary Union Oil Company of California, is operator of the St. Malo field and, together with its subsidiary Chevron U.S.A. Inc., holds a 51 percent working interest. Co-owners MP Gulf of Mexico, LLC owns a 25 percent interest; Equinor Gulf of Mexico LLC, 21.5 percent; Exxon Mobil Corporation, 1.25 percent; and Eni Petroleum US LLC, 1.25 percent.
Chevron U.S.A Inc. is operator of the Tahiti facility with a 58 percent working interest. Co-owners Equinor Gulf of Mexico LLC and TotalEnergies E&P USA, Inc. hold 25 percent and 17 percent stakes, respectively.
Liberia Launches Direct Negotiation Licensing Round with Support from TGS, Offering Enhanced Seismic Data for Offshore Exploration
OSLO,
Norway - The Government of Liberia, through the Liberia Petroleum Regulatory Authority (LPRA), has initiated a Direct Negotiation Licensing Round featuring 29 offshore blocks in the Liberia and Harper Basins. This licensing round, structured under the 2019 amendments to the Exploration & Production (E&P) law, underscores Liberia’s commitment to transparency and competitiveness, aiming to attract significant investment in its offshore exploration and production sector.
TGS is pleased to support this initiative by offering an extensive portfolio of multi-client subsurface data for the available blocks. This dataset includes over 24,000 kilometers of 2D seismic data and more than 26,000 square kilometers of 3D seismic data. This data set includes 5,100 square kilometers of newly reprocessed 3D seismic data and 12,000 kilometers of 2D seismic data, both enhanced using advanced Pre-Stack Depth Migration (PSDM) technology. This reprocessing method delivers enhanced imaging of key targets in the Cretaceous reservoirs, providing the latest insights into the region’s potential.
As a trusted partner to Libera, TGS acknowledges the significant offshore hydrocarbon opportunities in the region. The highquality seismic data provided will be crucial for companies participating in this Direct Negotiation Round, allowing them to evaluate the potential within an under-explored yet proven petroleum system.
The Liberian offshore sector presents diverse geological plays, ranging from the syn-rift Lower Cretaceous to the deepwater Upper Cretaceous, with multiple source rock intervals throughout the stratigraphy. The comprehensive multi-client data offering, including 2D and 3D seismic, gravity, magnetic data, and well data—delivers a robust understanding of these plays, with numerous prospects and identifiable leads.
President Joseph Nyuma Bokai Sr. emphasized the country’s commitment to creating a stable and favorable investment environment that adheres to the highest standards of ethics and governance. He invited top-tier companies to join Liberia in realizing its hydrocarbon potential, ensuring both prosperity and sustainability.
PETRONAS and Partners to Advance Methane Emissions Reduction Efforts in Southeast Asia Region
PETRONAS, in collaboration with key players from the Association of Southeast Asian Nations (ASEAN) energy sector, government agencies, and international organisations, today launched the ASEAN Energy Sector Methane Leadership Programme 2.0 (MLP 2.0).
Themed “Turning Capacity into Action”, MLP 2.0 builds on the inaugural Methane Leadership Programme (MLP) that ran from June 2023 to October 2024. It also marks the beginning of a collaboration between PETRONAS and Japan Organization for Metals and Energy Security (JOGMEC) to establish the Southeast Asia Methane Emissions Technology Evaluation Centre (METEC).
MLP 2.0 aims to strengthen emissions reduction targets and enhance coordination between businesses and governments, also supporting the Global Methane Pledge signed by over 150 countries, including Malaysia. Reducing methane emissions from the oil and gas sector is important as it is one of the most impactful actions that can be taken to achieve climate goals. The ASEAN Ministers during the 42nd ASEAN Ministers on Energy Meeting welcomed methane emissions reduction initiatives in the region.
In the first edition of the MLP, oil and gas producing companies in Southeast Asia have been equipped with essential knowledge and resources through workshops and masterclasses covering methane emissions measurement, monitoring, reporting, verification technologies and reduction strategies. The number of MLP members has grown from 13 to 18 since its inception.
MLP 2.0 is also expected to expedite regional collaboration on methane emissions management technology, facilitating demonstrations from partners within and beyond the region. Contributing partners include ASCOPE, ASEAN Centre for Energy (ACE), Asia Natural Gas & Energy Association (ANGEA), , Environmental Defense Fund (EDF), JOGMEC, Methane Guiding Principles (MGP), Ministry of Economy, Trade and Industry (METI) Japan, PetroVietnam Exploration Production Corporation Limited (PVEP), PT Pertamina (Persero), PTT Exploration and Production Public Company Limited (PTTEP), The World Bank, International Methane Emissions Observatory (UNEP IMEO), United States Agency for International Development (USAID), United States Department of Commerce – Commercial Law Development Program (CLDP), United States Department of Energy, United States Trade and Development Agency (USTDA) and Woodside Energy.
This initiative is a critical component of PETRONAS’ Net Zero Carbon Emissions by 2050 Pathway, aligning with its commitments to the United Nations Environment Programme Oil & Gas Methane Partnership 2.0 (OGMP 2.0) and the Oil and Gas Decarbonization Charter. Recently, PETRONAS achieved the OGMP 2.0 Gold Standard Pathway for the 2023 reporting year.
Southeast Asia Methane Emissions Technology Evaluation Centre
Under MLP 2.0, PETRONAS will be collaborating with JOGMEC to establish the Southeast Asia Methane Emissions Technology Evaluation Centre (METEC). The first of its kind in Southeast Asia, the centre will play a significant role in improving regional methane emissions management efforts by supporting experts to oversee measurement, monitoring, reporting and verification processes, as well as research and development initiatives.
METEC aims to be established at two locations in MalaysiaInstitut Teknologi Petroleum PETRONAS (INSTEP) in Bukit Rakit, Terengganu and Universiti Teknologi PETRONAS (UTP) in Tronoh, Perak.
ONGC Videsh, OIL & KABIL sign MoU with IRH, UAE for Global cooperation in Critical Mineral Supply Chain
ONGC
Videsh, a Schedule “A” Navaratna Central Public Sector Enterprise along with Oil India Ltd. (OIL), and Khanij Bidesh India Ltd. (KABIL) signed a Memorandum of Understanding (MOU) with International Resources Holding RSC Ltd. (IRH), UAE, to collaborate globally on the Critical Mineral supply chain. The primary goals of this MOU are to identify, acquire, and develop Critical Mineral projects worldwide, including India.
The parties aim to leverage their expertise, resources, and networks to pursue mutually beneficial opportunities, achieve operational excellence, and secure a stable supply of critical energy minerals. The MOU outlines a cooperative and coordinated approach, focusing on project identification, joint due diligence, risk management, and developing a long-term offtake strategy.
ONGC Videsh Ltd., a wholly owned subsidiary of ONGC, the flagship NOC of India, is engaged in overseas E&P operations and is India’s largest international Oil and Gas E&P company having 32 Assets in 15 countries. ONGC Videsh’s production of Oil and Oil Equivalent Gas (O+OEG) during FY’24 was 10.518 MMtoe and is currently producing about 200,000 barrels of O+OEG per day. ONGC Videsh has total O&G reserves (2P) of about 476 MMtoe whereas its parent, ONGC has 2P reserves of 704 MMtoe as on 1 April 2024.
Mubadala Invests in Leading Global Hyperscale Data Center Developer Yondr Group
Mubadala Investment Company (“Mubadala”), the Abu Dhabi sovereign investor, today announced its investment in Yondr Group, a leading global hyperscale data center developer, alongside Apollo via an existing investment from Apollo-managed funds.
Mubadala Investment Company (“Mubadala”), the Abu Dhabi sovereign investor, today announced its investment in Yondr Group, a leading global hyperscale data center developer, alongside Apollo via an existing investment from Apollomanaged funds.
Yondr, headquartered in London, is a global developer, owner, and operator of hyperscale data centers. The company provides scalable data center infrastructure for major blue chip technology players and has a contracted and reserved capacity of 878MW, with 58MW currently operational.
Mubadala’s investment will support Yondr’s ambitious growth strategy, which has been developed in line with the rapid demand growth for hyperscale data centers. Global cumulative data center demand is expected to grow at an 11% Compound Annual Growth Rate (CAGR) by 2032, driven by advancements in artificial intelligence (AI), 5G technology and the internet of things (IoT).
The investment builds on Mubadala’s rapidly growing portfolio of leading global data center assets under its digital infrastructure portfolio. In 2023, Mubadala invested in Aligned Data Centers, a leading pan-Americas data center company headquartered in the US that provides both Scale Data Centers (colocation) and Build-to-Suit solutions to support global hyperscale and enterprise customers.
Additionally, in 2022, Mubadala invested in Princeton Digital Group, a leading pan-Asian data center company focused on expanding world-class data center services to meet increasing demand across Asia. Mubadala is also investing in major global fiber network providers such as the UK’s CityFibre and GlobalConnect, a fiber-based data communication and data center service provider to enterprises across Northern Europe.
Mounir Barakat, Senior Executive Director of Digital Infrastructure at Mubadala Investment Company, said: “This investment marks an exciting addition to Mubadala’s rapidly expanding digital infrastructure portfolio. We are witnessing a strong growth in demand for hyperscale data centers in response to the rising data demands from AI adoption, 5G and IoT, and Yondr will play a key part in providing solutions for some of
the world’s fastest growing corporations. We look forward to working closely with Yondr and our investment partners to develop world-class solutions that create long-term value for their customers and stakeholders.”
Chester Reid, Chief Financial Officer at Yondr, added: “We are pleased to welcome Mubadala as a key financial partner. With their additional support we are well-positioned to accelerate our growth and continue delivering sustainable data center solutions to our clients worldwide, meeting the increasing demand for capacity.”
West Coast Gas Outlook 2024 – Calm before the Storm?
EnergyQuest’s
West Coast Gas Outlook 2024 brings together the most comprehensive data, forecasts, and analysis available on the Western Australia domestic gas market. The new report released by independent energy consultancy EnergyQuest, West Coast Gas Outlook 2024 – Calm before the storm?, shows that WA’s domestic gas market is likely to see significant supply shortfalls from 2029.
• The West Coast Gas Outlook 2024 shows the WA Government didn’t need to make major changes to its Domestic Gas Policy to ensure sufficient domestic gas supply over the next four years, but we are in the calm before the storm and changes to the Policy are on the cards from 2029.
• Gas supply into the 2030s will be important as WA’s large gas users are unlikely to reduce gas use over the next decade. Gas is the only option for many users, and while low emissions alternatives are under development they are unlikely to be available or implemented in the next decade. The WA Government’s policy to close coal fired power generation is also likely to add significantly to demand as domestic gas supply peaks and starts to decline.
• New supply from the Scarborough project and Perth Basin will be important in coming years, but beyond those projects there aren’t many options for increasing domestic supply other than to rely even more on LNG exporters.
• Developing new supply is difficult as WA, and Australia more broadly, has low exploration levels, and there is a lack of undeveloped gas resources not linked to LNG projects. Reducing demand is difficult as doing so in the next decade would likely involve project closures due to a lack of alternatives. Developing new LNG resources with new domestic supply obligations could make a major difference but has become difficult and uncertain in Australia. The North West Shelf, which has for decades underpinned WA’s gas supply, is in decline.
The West Coast Gas Outlook 2024 includes updated supply and demand forecasts now extended to 2050. This longer-term view indicates the structural shortfall from 2029 could become substantial in coming decades. Aggressive assumptions are required to significantly reduce gas demand by 2050, and if carbon capture and storage is adopted by WA’s large gas users, demand will remain resilient.
Custom-formulated Jack-Up grease for optimal performance. Providing safe and smooth operation and targeted protection.
Seadrill Announces Second Quarter 2024 Results
HAMILTON,
Bermuda- Seadrill Limited reports its second quarter 2024 results.
Quarterly Highlights
• Delivered Operating Profit of $288 million and Adjusted EBITDA (1) of $133 million on $375 million of Total Operating Revenues for an Adjusted EBITDA Margin (1) of 35.5%
• Completed sale of three jack-up rigs and associated interest in the Gulfdrill joint venture, supporting fleet refinement and capital return program
• Repurchased total of $566 million of shares, or more than 15% of its issued share count, since initiating repurchase program in September 2023
“Seadrill delivered a strong second quarter and generated a combined $257 million in Adjusted EBITDA (1) during the first half of year. Strong supply-side fundamentals underpin our faith in a long and enduring upcycle. However, we continue to see volatility that can affect financial outcomes,” Johnson continued. “Now, as ever, through-cycle resiliency matters. As a company, we continue to benefit from a highly standardized fleet strategically positioned in advantaged geographies, a strong balance sheet, a disciplined management team, and a pursuit of operational excellence that allows us to deliver on our promise of safe, efficient operations for the benefit of all our stakeholders.”
Financial and Operational Results
Second quarter 2024 operating revenues totaled $375 million, a sequential increase of $8 million. Contract revenues were $267 million, a decrease of $8 million, primarily due to fewer operating days on the West Aurig a and the West Polaris and lower utilization , partially offset by increased days on the Sevan Louisiana . Management contract revenues were $65 million, a $7 million sequential improvement reflecting an increased management fee received on the three drillships Seadrill operates through Sonadrill, its 50:50 joint venture with Sonangol, applied retroactively to January 1. Leasing revenues were $26 million, compared to $11 million the prior quarter. The increase is attributable to a new bareboat charter rate, applied retroactively to January 1, for the West Gemini, which Seadrill charters to Sonadrill, as the joint venture partners began receiving additional income proportional to their rig contributions.
Second quarter 2024 operating expenses totaled $290 million, a sequential decrease of $13 million. Vessel and rig operating expenses were $165 million, a decrease of $15 million, primarily due to lower operating expenses on the West Auriga and West Polaris as the rigs underwent preparation for upcoming Brazil contracts for the duration of the quarter. Management contract expense was $41 million, a $3 million increase, reflecting the timing of repair and maintenance expenses on the Sonadrill rigs. Selling, general, and administrative expenses were $24 million and included $2 million of non-recurring costs associated with the consolidation of the Company’s corporate offices to Houston. Other operating items included a gain on sale of $203 million, associated with the Company’s sale of three jack-up rigs and associated interest in its Gulfdrill joint venture, which closed on
June 25, 2024, for cash proceeds of $338 million.
Adjusted EBITDA (1) was $133 million, compared to $124 million the prior quarter. Adjusted EBITDA Margin (1) was 35.5%.
Cash Flow and Balance Sheet
Cash flow from operations during the second quarter of 2024 was $79 million, including $60 million of long-term maintenance costs. Capital upgrades captured in investing cash flows were $43 million. Resulting Free Cash Flow (1) was $36 million.
In the second quarter of 2024, Seadrill made $125 million of share repurchases. On June 25, 2024, the Company initiated the first $200 million tranche of its second $500 million share repurchase authorization. Since initiating its repurchase program in September 2023, the Company has returned a total of of $566 million to shareholders and repurchased a total of 12.3 million shares, or 15% of issued share count.
At quarter-end, Seadrill had gross principal debt of $625 million and $862 million in cash and cash equivalents, including $27 million in restricted cash, for a net cash position of $237 million.
Operational and Commercial Activity
As of August 5, 2024, Seadrill’s Order Backlog (2) was approximately $2.5 billion. During the quarter, the Sevan Louisiana secured a one-well contract with an independent operator in the U.S. Gulf of Mexico, that began in direct continuation of its previous contract and secured the rig into August. The Company today provided an updated fleet status report on the Investor Relations section of its website, www.seadrill.com .
Outlook
Seadrill revised full year 2024 guidance based on the completion of the Gulfdrill sale; current expectations for contract start dates for the West Auriga and West Polaris that delay EBITDA recognition into future periods; and near-term outlook for uncommitted capacity on the Sevan Louisiana and the West Phoenix . After adjusting for the $30 million of bareboat charter income the Company expected the Gulfdrill assets to earn in the second half of the year, the mid-point outlook for the previouslydisclosed EBITDA range would be $395 million. The Company now expects full year 2024 revenues between $1,355 million and $1,405 million; Adjusted EBITDA of $315 million and $365 million; and capital expenditures and long-term maintenance between $400 million and $450 million. Guidance includes $75 million of reimbursable revenue and expenses.
“Though a combination of supply chain, weather, and scope have shifted West Auriga and West Polaris start dates, both rigs will soon set sail for Brazil and should begin their contracts by year-end, contributing meaningfully to Seadrill earnings and cash flow in 2025,” said Johnson. “Any additional work the Sevan Louisiana secures this year would represent upside opportunities to the mid-point of our guidance.”
The blueprint for sustainable storage
80% of exhibitors would recommend StocExpo
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We have been attending StocExpo as an exhibitor for years. We use this show as an outlook to connect with customers from international markets, including companies from Belgium, the Netherlands, and other European countries. This event provides a great opportunity for us to network with valuable customers.
Esma Gulten, Co-Founder & CEO, Gizil GmbH
stocexpo.com
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Stepan to Announce Third Quarter 2024 Results Soon
Supporting slides will be posted at approximately the same time on the Investors/Presentations page at www.stepan.com. The Company will hold a conference call to discuss and answer questions about its financial and operational performance on the same day at 9:00 a.m. ET (8:00 a.m. CT).
The call will be hosted by Scott R. Behrens, President and Chief Executive Officer, and Luis E. Rojo, Vice President and Chief Financial Officer.
The call can be accessed by phone and webcast. To access the call by phone, please click on this Registration Link, complete the form and you will be provided with dial in details and a PIN. To avoid delays, we encourage participants to dial into the conference call ten minutes ahead of the scheduled start time. The webcast can be accessed through the Investors/Conference Calls page at www.stepan.com. A webcast replay of the conference call will be available at the same location shortly after the call.
first responders in the impacted areas.
Earlier this month, Chevron announced a $250,000 donation to the same organizations to support Hurricane Helene recovery efforts in the Southeast.
Chevron will match qualifying donations employees and retirees make to hurricane relief efforts and will provide financial contributions to organizations where its employees volunteer. The aim of this collective financial assistance is to help communities in times of need.
BOEM Approves Construction and Operations Plan for Atlantic
Shores South Offshore Wind
Projects
Valero Energy Corporation to Announce Third Quarter 2024 Soon
SAN ANTONIO- Valero Energy Corporation announced today that it will host a conference call on October 24, 2024 at 10:00 a.m. ET to discuss third quarter 2024 earnings results, which will be released earlier that day, and provide an update on company operations.
Chevron Commits An Additional $250,000 to Hurricane Relief Efforts
San Ramon, Calif., Chevron today announced a donation of $250,000 to support relief and recovery efforts after Hurricane Milton devastated parts of Florida. The funds will provide support for emergency teams and volunteer efforts.
“Our thoughts are with the Florida residents as they recover from Hurricane Milton,” said Mike Vomund, vice president of Fuel Sales, Chevron. “We understand that reliable energy is essential to the recovery process, and we are working to help restore fuel supplies to the impacted area as quickly and safely as possible. We are proud to support organizations like Fuel Relief Fund, Team Rubicon, and Volunteer Florida as they assist Florida communities through the recovery process.”
• Fuel Relief Fund will receive $100,000 to support relief efforts throughout the impacted region
• Team Rubicon will receive $100,000 to aid emergency response teams
• Volunteer Florida will receive $50,000 to support volunteer mobilization and recovery efforts
Chevron has also donated 8,500 gallons of fuel in-kind direct from its Panama City Terminal. This fuel will be distributed to
The Bureau of Ocean Energy Management (BOEM) today announced its approval of the Atlantic Shores South project plan to construct and operate two wind energy facilities, furthering the Biden-Harris administration’s goal of deploying 30 gigawatts of offshore wind energy capacity by 2030. This is the final approval needed from BOEM following the Department of the Interior’s July 2024 Record of Decision.
“The Biden-Harris administration is dedicated to advancing responsible offshore wind energy projects like Atlantic Shores South Wind, which will create good-paying jobs and drive economic growth, while combatting the climate crisis and making our communities more resilient,” said BOEM Director Elizabeth Klein. “I am proud to announce BOEM’s final approval of Atlantic Shores South Offshore Wind Projects 1 and 2, which have the potential to generate up to 2,800 megawatts of clean, renewable energy—enough to power nearly one million homes.”
Subsequent to the Record of Decision, the original lease was divided into two separate leases, both approximately 8.7 miles offshore New Jersey at their closest points. The approved construction and operations plan includes up to 197 total locations for wind turbine generators, offshore substations, and a meteorological tower, with subsea transmission cables potentially making landfall in Atlantic City and Sea Girt, providing clean electricity to the New Jersey grid.
BOEM incorporated important feedback from Tribes, government agencies, ocean users, and other interested parties prior to making this approval decision. The feedback resulted in required measures to avoid, minimize, or mitigate any potential impacts from the project on marine life and other important ocean uses, such as fishing.
Under the Biden-Harris administration, the Department of the Interior has approved more than 15 gigawatts of clean energy from ten offshore wind projects, enough to power nearly 5.25 million homes. It has also held five offshore wind lease auctions, including a record-breaking sale offshore New York and New Jersey and the first-ever sales offshore the Pacific and Gulf of Mexico coasts. Earlier this year, Secretary Haaland announced a schedule of potential additional lease sales through 2028.
www.omnetics.com | sales@omnetics.com
Will Pipe Laying Come to an End?
Human life is always demanding energy everywhere on the planet. We at Suxxesion have been participating in important pipe line projects from the gulf of Mexico to Malaysia and India, pipelines are the veins of the world.
Our largest projects however, involved Nord Stream 1 & 2. All 440,000 pipes have been handled with our equipment at least 5 times per pipe before it was loaded into the supply boats to the pipe laying vessels. The pipe and sheet handling took place in Germany and Russia at the pipe producers and coaters.
Due to the political circumstances both pipe lines are not in use for the time being.
Based on lessons learned, Suxxesion is constantly improving their products for the benefit of our clients to improve life-cycle, reduce cost of ownership and thus reliability of the equipment, wherever in operation in the world. This means not only the handling and storage of pipes along the stretch, but also in the fore field at the pipe mills and coating yards. To upgrade the logistics CPW awarded orders for the supply of our Suxxesion multitool to handle pipes at the stock yard, but also in the factory to handle pipes going from one production line to another. We have equipped two material handlers and one reach truck to handle a maximum of four to five pipes at a time. With our equipment almost all tele-cranes became obsolete. By using Suxxesion multi–tools the loading time of trucks was reduced to a minimum. With a one man operation the work became safer and pipe damage due to handling, was almost zero.
As stipulated, pipelines are the veins of the world and have proven to be very reliable for transportation of large volumes of mainly hydrocarbons over long distances. If humankind will be able to make the energy transition pipelines for hydro carbons will be upgraded for hydrogen transport or sweet water. Sweet water is needed to irrigate land which becomes too dry due to the disappearance of the local habitat.
If we
CO2 emission
and help to limit global warming.
Therefore, pipeline projects will not stop and pipelines will contribute to bring prosperity to all living beings on the planet.
Suxxesion hopes to contribute to these future
To learn more please contact: Suxxesion BV
harry@suxxesion.com
+31 344 5713 90
+31 6 51 380 418
projects by building more sophisticated pipe handling equipment for mutual interest. •
Lack of water makes life very difficult for all living beings.
manage to bring water to restore nature,
can be reduced
Making and Maintaining the Right Connection
Destec Engineering has specialised in the manufacture of high pressure Flanges, Seals & Connectors for the Oil, Gas & Renewable Energy Industries for over 50 years.
PRODUCTS WE DELIVER:
— Destec Compact Flanges
— DESALIGN Misalignment Flange
— G-Range 4 Bolt Connectors
— Compatible Seals
— GSB Subsea Single Bolt Clamps
SERVICES WE OFFER:
— On-Site Machining
— Bolt Tensioning
— Special Purpose Machine Tools
— Laser Alignment Services
— NDT Services
— Regenerator & Vessel Head Removal
Prioritizing Safety and Sustainability in Offshore and Maritime Services: VMS Group’s Comprehensive Approach
In the maritime and offshore industry, safety and sustainability have become fundamental aspects of operational practices, driven by regulatory requirements and the need for environmental stewardship.
VMS Group is committed to these priorities by integrating stringent safety measures and sustainable practices across its wide range of services.
This article discusses how VMS Group’s holistic approach, combining extensive offshore expertise with energy optimization initiatives, is setting new standards for the industry.
Safety as a Cornerstone in Offshore
Operations
Safety is at the core of VMS Group’s approach, especially in the offshore drilling sector, where the operational environment is inherently challenging. The company’s teams are highly trained and equipped with the necessary offshore certifications, ensuring that all safety standards are met and often exceeded.
VMS Group’s proactive safety culture has earned praise from several of our customers, who recognize the company’s efficient reporting and thorough safety procedures during a 2023 audit. This culture encompasses detailed safety protocols, continuous monitoring, and adherence to rigorous Health, Safety, and Environment (HSE) standards.
Each project undertaken by VMS Group is managed by a dedicated project manager who oversees all safety-related aspects. This includes providing real-time updates, daily service reports, and ensuring all activities align with established safety procedures. Having a single point of contact ensures a streamlined process, allowing clients to have direct insight into ongoing safety measures and project developments.
To maintain high safety standards, VMS Group invests heavily in the training and development
of its personnel, ensuring that the teams stay up-to-date on the latest safety practices and regulatory changes. This is especially important in offshore environments where conditions can change rapidly, requiring a swift and well-prepared response to mitigate risks.
Commitment to Sustainability as a Core Principle
The global maritime industry is facing increasing pressure to reduce its environmental impact. VMS Group recognizes this challenge and has integrated sustainability into its service strategy. The company focuses on reducing emissions and optimizing energy use across its projects, helping clients comply with environmental regulations, including the International Maritime Organization’s (IMO) requirements for the Carbon Intensity Indicator (CII) and Energy Efficiency Existing Ship Index (EEXI), as well as regional initiatives like the EU Emissions Trading System (EU ETS).
One of the key elements of VMS Group’s sustainability strategy is its energy optimization services, which include energy screenings and audits. These services provide
clients with a thorough understanding of their vessels’ energy consumption patterns and emissions. By identifying areas for improvement, VMS Group offers tailored solutions that reduce the carbon footprint of operations, such as upgrading propulsion systems, retrofitting components, or adopting alternative fuels.
The company’s commitment to sustainability extends beyond compliance with regulations; it involves guiding clients towards long-term environmental goals. VMS Group supports the entire process, from developing and implementing energy-saving measures to monitoring their effectiveness over time. This comprehensive approach ensures that sustainability benefits are realized and maintained.
Pathways to Energy Optimization and a Greener Future
VMS Group is leading the transition towards decarbonization in the maritime industry by offering a comprehensive range of energy optimization services. These include energy profiling, baseline footprint verification, and operational energy mapping, which help clients understand their current energy usage and identify opportunities for improvement.
Examples of the impact of these services include an energy screening conducted on a chemical tanker, which showed a 12.5% reduction in carbon emissions and a return on investment within 3.5 years. Additionally, the energy profiling of a dredger led to
recommendations for upgrading to a dieselelectric propulsion system, which could reduce emissions by up to 14.5%. These cases demonstrate that strategic energy optimization can significantly decrease environmental impact while also delivering financial benefits.
Navigating Regulatory Challenges with Sustainable Solutions
The evolving regulatory landscape in the maritime industry has introduced stricter requirements for emissions reduction and energy efficiency. The IMO’s CII and EEXI regulations, coupled with regional policies such as the EU ETS, mandate significant changes to the way ships operate. VMS Group’s services are designed to help clients navigate these complexities by offering solutions that not only meet current standards but also prepare them for future requirements.
Moreover, VMS Group acknowledges the market’s increasing demand for sustainability. Customers and end-users are prioritizing companies that maintain a strong green profile, and adopting sustainable practices can enhance market competitiveness. By optimizing operations and adopting energy-efficient technologies, VMS Group ensures that its clients are not only compliant with regulations but also positioned as leaders in sustainability within the maritime sector.
Safety and Sustainability: An Integrated Approach in Offshore Operations
The integration of safety and sustainability defines VMS Group’s offshore operations. While adhering to strict safety protocols, the company also adopts sustainable practices to minimize the environmental impact of its activities. For instance, VMS Group prioritizes the reuse of parts during overhauls to reduce waste and decrease the demand for new materials, aligning with circular economy principles.
The company’s in-house machining capabilities further contribute to sustainability efforts by allowing for the repair and refurbishment of engine components, thus extending the lifespan of equipment. This approach ensures that high-
performance standards are maintained while also reducing the environmental impact associated with producing new components.
VMS Group also supports the implementation of green technologies in offshore settings, such as installing energy-efficient equipment and optimizing existing systems to minimize fuel consumption. This comprehensive view of sustainability encompasses both operational efficiency and environmental responsibility, enabling clients to meet their safety and sustainability goals simultaneously.
A Global Presence with Local Expertise
To provide clients with reliable support worldwide, VMS Group has strategically expanded its service hubs across Denmark, West Africa, South America, North America, and the Middle East. These hubs allow for rapid mobilization of teams and resources, which is crucial in the offshore industry where downtime must be minimized. Each hub is staffed with personnel who have extensive experience in both local and international maritime environments, enabling VMS to deliver services that are tailored to specific regional requirements while maintaining global standards.
For instance, in Namibia, VMS Group has reinforced its presence with the appointment of a new country manager who brings substantial offshore experience to the role. New service hubs in New Orleans (USA) and Dammam (Saudi Arabia) provide quick
response capabilities and localized expertise to support the growing demand.
Continuous Innovation and Sustainable Growth
VMS Group’s dedication to continuous innovation is evident in its ongoing expansions and the development of new capabilities. The company recently opened a new headquarters in Frederikshavn, launched an automation department, and formed partnerships with engine manufacturers such as Bergen Engines and Yanmar. These initiatives reflect VMS Group’s commitment to adopting cutting-edge technologies and enhancing service offerings to meet the evolving needs of the industry.
The company’s focus on energy optimization services is a natural extension of its maritime expertise, providing clients with practical solutions for improving operational efficiency and reducing emissions. By continually evolving its services and adopting new technologies, VMS Group remains at the forefront of the industry’s shift towards safety and sustainability.
Conclusion
For VMS Group, safety and sustainability are not merely compliance requirements but are central to its service philosophy. By focusing on stringent safety practices, energy optimization, and sustainable operations, the company is not only addressing the demands of today’s regulatory environment but also shaping a more responsible future for the maritime and offshore industry.
Through its integrated approach to safetyfocused offshore operations and tailored sustainability strategies, VMS Group is wellequipped to support clients in achieving their safety and environmental goals. As the maritime sector continues to evolve, VMS Group’s comprehensive solutions will play a vital role in driving a safer, greener, and more sustainable industry.
VMS Group A/S
T: +45 9622 1100
E: vms@vms.dk
W: www.vms.dk
Sustainable Switch: How Renewable Polypropylene Makes Essential Filtration Greener
The right filtration choice from the outset of procurement helps oil and gas producers ensure smooth operations, reduce OPEX, boost commercial performance and, increasingly, be good to the planet. These are the reasons customers rely on equipment and solutions from Amazon Filters for safe, reliable and efficient upstream, refinery and downstream processes.
And this year the process filter maker has become the first UK firm to use polypropylene from renewable resources in the production of meltblown filter media.
The move effectively lowers the carbon footprint of each filter in Amazon Filters’ flagship SupaSpun II, SupaGard, Contour and VisClear II ranges while ensuring the same, robust level of polymer quality as in fossil-based plastics.
These filters are widely used in critical liquid filtration processes across various industry sectors including oil and gas.
Offshore, SupaSpun II provides essential prefiltration for sulphate reduction membranes while Contour helps gas producers remove black powder, a form of contamination that accumulates in pipelines and other transmission lines, potentially affecting downstream equipment and instrumentation.
Mass-balance approach
Traditionally, monomers sourced from fossil fuels have been the base media feeding into the polymers involved in polypropylene manufacturing.
But now, under a ‘mass balance approach’ developed by Amazon Filters’ Vienna-based manufacturing partner Borealis, a proportion of the fossil-derived propane is replaced by an identical volume of sustainable monomers made from renewable feedstocks.
Rigorous tests show that replacing one tonne of conventional polypropylene with the sustainable material will stop 2.1 tonnes of carbon emissions. That means a reduction of 1 kg in emissions for every 30” meltblown filter.
Describing the process, Amazon Filters Managing Director Neil Pizzey said: “The bio-propane produced as the starter for the polypropylene production is exactly the same specification as the propane derived from conventional fossil-based feedstocks.
“Tests, including gas chromatography and differential scanning calorimetry, confirm the absence of any impurities in the sustainable material and so guarantee the equivalent standard.
This ensures that the end user receives products of identical quality to the purely fossil-derived material but with the assurance of a reduced carbon footprint compared to conventional
plastics.
The ‘mass balance’ approach is no different to using monomers sourced from fossil fuels that may originate in different locations, for example, oil from different countries that will have an inherent degree of variation.
Customers can enjoy complete confidence that the sustainable cartridges perform to exactly the same level as the previous version and so have zero effect on their production activities or quality assurance standards. They can be reassured of a seamless transition to the sustainable versions.
If you are responsible for critical liquid filtration processes, and if compliance with environmental standards is key to your work, you too can benefit from our reassurance of outstanding filter quality backed with enhanced sustainability.”
Independent certification
Manufacture of the polypropylene filters is independently certified under ISCC PLUS, the International Sustainability and Carbon Certification system for supply chains.
This confirms that the feedstock is sustainable, traceable to its point of origin and provides a credible reduction of carbon footprint.
A life cycle assessment study in accordance with the ISO 14040 and 14044:2006 standards has also been conducted to verify carbon reductions.
Going to market
Amazon Filters is highlighting its adoption
of renewable polypropylene at the Sasolburg Petrochemicals & Energy Roadshow in South Africa this autumn.
African distributor partner National Separations (Pty) Ltd will demonstrate the products’ technical features and efficiency and sustainability benefits.
Companies attending the roadshow represent the petrochemicals and oil and gas industries and their engineering, procurement and construction supply chains.
One of this year’s key event themes is the ‘enterprise and supplier governance’ aspect of successful procurement.
Simon Hughes, Amazon Filters’ Sales Director, said partnering on the roadshow is an ideal opportunity to demonstrate how UK-manufactured filters and housings can aid critical filtration processes in the petrochemicals and energy sectors worldwide.
Simon said: “We have been partners with Natsep for more than 20 years. What began as a fledgling relationship has blossomed to the point where they have become one of our key distributors internationally and in South Africa specifically.”
For more information on polypropylene filters, call +44 (0) 1276 670600 or visit: www.amazonfilters.com/renewablepolypropylene-p.
For details of the Sasolburg roadshow, visit: https://africanpetrochemicals.co.za/ sasolburg-petrochemical-roadshow/.
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Hydrogen Instead of Nuclear Power?
The energy company RWE has received the nuclear licence from the Lower Saxony Ministry for the Environment, Energy and Climate Protection to decommission and dismantle the former Emsland nuclear power plant (KKE).
“We have waited a long time for this moment and will tackle our legal obligation to dismantle the plant safely and swiftly with an expert and highly motivated team made up of our own staff and partner companies”, said Steffen Kanitz, Chief Nuclear Energy Officer at RWE Power AG.
The first dismantling measures will be the removal of the core internals and steam generators.
The past few months have already been used for preparatory measures. For example, ‘full system decontamination’ has been carried out to thoroughly clean the systems that are active during power operation. According to RWE, this will significantly reduce radiation exposure for operating personnel during dismantling and downstream processing of dismantled plant components.
Air Products Completes $1.81
Billion Sale of Liquefied Natural Gas Process Technology and Equipment Business to Honeywell
Air Products announced it has completed the sale of its liquefied natural gas (LNG) process technology and equipment business to Honeywell for $1.81 billion in cash. First announced in July 2024, closing conditions for the transaction have been fully met and regulatory approvals received.
The divestiture of the LNG process technology and equipment business is strategic, reflecting Air Products’ firm focus on its two-pillar growth strategy to profitably grow its core industrial gases and related equipment businesses, and to deliver clean hydrogen at scale.
With the sale, related assets, manufacturing capability and personnel associated with the LNG process technology and equipment business have transferred successfully to Honeywell, including approximately 475 employees and the Port Manatee, Florida coilwound heat exchanger manufacturing facility.
Chairman, President and Chief Executive Officer Seifi Ghasemi said, “I want to thank our former LNG colleagues for their contributions, hard work and expertise, which have built a strong foundation that Honeywell can now take forward. Air Products remains laser focused on creating shareholder value by executing our
With the construction of a technology and logistics building on the site of the Emsland nuclear power plant, RWE has been creating the necessary logistics space for plant dismantling since mid-2023.
In future, low and medium-level radioactive waste from the Lingen nuclear power plants, i.e. the Lingen nuclear power plant (268 MW) and the Emsland nuclear power plant (1,400 MW), will be professionally packaged in final storage containers and made available here until it is handed over to the federal government for disposal.
Parallel to the dismantling of the nuclear power plants, the transformation of the Lingen site into a central hydrogen hub is already in full swing. Markus Krebber, CEO of RWE AG, at the inauguration of the pilot electrolysis plant at the beginning of August
growth strategy in industrial gases and clean hydrogen to drive the energy transition and decarbonize.”
Lazard, Inc. served as financial advisors to Air Products, while Skadden, Arps, Slate, Meagher & Flom LLP provided external legal counsel.
Air Products is a world-leading industrial gases company in operation for over 80 years focused on serving energy, environmental, and emerging markets. The Company has two growth pillars driven by sustainability. Air Products’ base business provides essential industrial gases, related equipment and applications expertise to customers in dozens of industries, including refining, chemicals, metals, electronics, manufacturing, and food. The Company also develops, engineers, builds, owns and operates some of the world’s largest clean hydrogen projects supporting the
2024: “Lingen is one of the most exciting places in the German energy transition. Right next to our flexible gas-fired power plant and our modern large-scale battery, we are now also producing green hydrogen. Over the next few years, we will continue to expand the production of green hydrogen here at the site in order to make green molecules available to industrial customers and thus support them in their decarbonisation efforts.”
transition to low- and zero-carbon energy in the heavy-duty transportation and industrial sectors. Additionally, Air Products provides turbomachinery, membrane systems and cryogenic containers globally.
The Company had fiscal 2023 sales of $12.6 billion from operations in approximately 50 countries and has a current market capitalization of approximately $60 billion. Approximately 23,000 passionate, talented and committed employees from diverse backgrounds are driven by Air Products’ higher purpose to create innovative solutions that benefit the environment, enhance sustainability and reimagine what’s possible to address the challenges facing customers, communities, and the world. For more information, visit airproducts.com or follow us on LinkedIn, X, Facebook or Instagram.
Flexitallic’s RIGFLEX Gaskets: Intelligent Testing for Bolted Connections
Flexitallic has introduced its innovative RIGFLEX FP and RJ gaskets, offering a breakthrough in leak testing highpressure applications in the oil & gas and petrochemical sectors. These innovative gaskets provide a more efficient and safer solution, reducing costs and improving operational uptime by eliminating the need to leak test entire systems.
Traditional leak testing methods involve identifying and fixing leaks in large volume pressure systems, which can be costly and timeconsuming, requiring significant amounts of test media, such as nitrogen gas, and a dedicated team to manage the process.
Flexitallic’s RIGFLEX gaskets, however, enable targeted testing of individual flanged connections, reducing downtime and exposure to high test pressures.
Designed for enhanced safety and operational efficiency, RIGFLEX gaskets allow a single operator to conduct tests using portable equipment. This capability not only lowers the risk of exposing aging piping systems to high pressure but also supports proactive maintenance strategies by enabling real-time monitoring of potential leaks after installation. Operators can quickly identify high-risk areas, such as frequently disassembled connections, and address them before they escalate into more significant problems.
The RIGFLEX FP gasket features a unique design tailored for high-pressure environments. Its construction includes a precision-machined, grooved, and serrated metal core with dual Kammprofile elements coated in Corriculite, a cutting-edge material developed by Flexitallic to resist flange face corrosion and enhance gasket performance under extreme conditions. The metal core, equipped with a high-pressure test pipe and a non-return quick release coupling, allows for controlled pressurisation and direct assessment of the connection’s integrity.
After testing, the gasket remains in place, allowing for ongoing monitoring or re-testing
without additional setup. This design not only ensures safety but also reduces operational costs by maintaining the integrity of the connection under challenging conditions.
Corriculite, which can withstand temperatures ranging from -196°C to +260°C, serves as a robust barrier against corrosive elements, extending the life of flanged connections and minimising the need for expensive maintenance or replacement. It is also fire-safe according to API 6FB standards, making it ideal for high-risk environments.
The RIGFLEX RJ gasket, constructed from a precision-machined octagonal Ring Type Joint (RTJ), also features a high-pressure test pipe and quick-release coupling. This design allows for direct monitoring of the connection’s integrity through external pressurisation. Both FP and RJ gaskets come with fire-safe, high-pressure blind plugs for post-test isolation, along with anti-crush/
rotation plates to protect the test port from damage due to excessive flange rotation. To further enhance durability, the test port is positioned within closed flanges to prevent external damage. The gaskets can be used with a hand-operated hydraulic pump or adapted to existing pressurisation setups, providing flexibility in application.
Available in sizes ranging from 1/2” to 24” NPS and rated for pressure classes from 150 to 2500, RIGFLEX gaskets are compatible with standard ASME B16.5 ring grooves and raised face flanged connections. Their versatility across multiple sectors and applications underscores their adaptability to various highpressure environments.
Flexitallic’s RIGFLEX gaskets are designed for both test and service use, enabling seamless transitions from testing to operational use without the need for gasket replacement. This reduces time and effort for maintenance activities and facilitates the swift identification of leaking connections, minimising unplanned downtime and consumption of test materials. Overall, the RIGFLEX range represents a significant advancement in sealing technology, delivering improved safety, costefficiency, and performance for the oil & gas and petrochemical industries. With their innovative design and functionality, these gaskets provide a more streamlined alternative to traditional leak testing methods, ensuring robust and reliable performance in the most demanding conditions.
Flexitallic
For more information visit: https://flexitallic.com/applications/reverseintegrity-testing/
The RIGFLEX RJ
Precision Temperature Control for a Sustainable Future
We are LAUDA Technology – the world leader in precise temperature control. Our constant temperature equipment and systems are at the heart of important applications contributing to a better future. As a complete one-stop-supplier, we guarantee the optimum temperature in research, production, and quality control. We are the reliable partner for electromobility, hydrogen, chemicals, pharmaceuticals/biotech, semiconductors and medical technology. We have been inspiring our customers for more than 65 years with our expert mentoring and innovative solutions – every day anew and all over the world.
Accurate Heating and Cooling in the range -150 to +550 °C
For applications requiring customised solutions tailored to your individual requirements, LAUDA Technology offer a made-to-measure design service using a long-established and highly-skilled team. Project engineering is a core competence of LAUDA and using the modular engineering approach, we can design and scale a system specifically for your application.
With the capability to provide accurate heating and cooling in the range of -150 to +550 °C using a variety of proven modules including heat transfer systems, process colling systems, secondary circuit systems, fired heaters and molten salt plants, we are able to prove unique, cost-effective solutions unparalleled by others.
Modular Engineering
In accordance with the principle of ‘modular engineering’, LAUDA process cooling systems, heat transfer systems and secondary circuit systems are planned and built precisely according to customer’s wishes: processorientated, customised and with precision control, meeting the strictest safety standards.
Project engineering is our specialist field. Working in close cooperation with you, we draw up your specific system during the design process. They keyword here is ‘modular engineering’. Tried and tested modules, combined for the application, provide you with tailor-made solutions. The matching of desired and actual values demands precise planning and exact project work at all interfaces. Each single LAUDA planning module has been proven many times and is continually developed further. This enables us to guarantee our high quality standard.
Advantages of our Heating and Cooling Systems
There are several LAUDA specific advantages of using our tailor-made heating and cooling systems as your solution.
First and foremost, through competent consultation, you can rest assured that the LAUDA solution will be the very best for your needs. Our experts have years of experience and a wealth of knowledge that’s secondto-none in bespoke heating and cooling systems. Further to this, modular engineering plays a part in our provision of unfaltering quality standard of solution. The inclusion of optimal interaction with the ‘LAUDA Plug & Play’, and our stringent test runs, mean that your solution is fit for purpose and running smoothly from the very beginning. Above all, LAUDA Technology provides a highly dependable service, we adhere to the motto ‘Always Available Anywhere’.
Advancements in Hydrogen Cooling Technology
LAUDA Technology are committed to playing a part in any and all advancements taking place in the heating and cooling technology sphere. An example of this is our current participation in the Horizon Europefunded research project RHeaDHY.
The project aims to develop innovative, highperformance solutions for faster hydrogen refuelling in heavy-duty applications. With the European Union contributing almost €4 million in funding, the project’s ultimate goal is to reduce carbon dioxide emissions from freight transport using hydrogen-powered vehicles. To achieve this, refuelling trucks and similar vehicles with 100kg of hydrogen
within ten minutes is targeted, requiring highpressure refuelling that generates significant heat. LAUDA, as a part of a consortium of European partners, will develop a highperformance cooling system to address this challenge. The project is expected to run until early 2027, with near-series technology available for installation at two locations in Germany and France.
LAUDA Technology have been a strong partner to hydrogen refuelling station producers and operators since 2015, delivering numerous systems to industry leaders. These include SUK 350 L process cooling units for hydrogen cooling during refuelling, and the Ultracool line circulation chillers for electrolyser cooling during hydrogen production, both of which are produced in large quantities. With a forecast of around 3,000 additional hydrogen refuelling stations by 2030 in Europe, LAUDA is preparing to significantly expand its production capacities to meet the growing demand. The Ultracool series has already been redeveloped to be more compact, powerful, and energy efficient, with several new models set to be launched later this year. The Ultracool product line, which is produced serially, can cover cooling capacities of up to 240 kW.
Through the RHeaDHY Project, LAUDA reaffirms its expertise in the field of hydrogen cooling, and its commitment to innovation and development towards a sustainable future. Our specialists work tirelessly to provide outstanding performance for a better future, and their willingness to break new ground and devote themselves to pioneering technologies is a cornerstone of what LAUDA stand for.
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Transforming Power Generation in the Oil & Gas Industry: Agile, Sustainable, and FutureReady Solutions
The oil and gas industry is navigating a complex and evolving landscape, marked by fluctuating market demands, growing environmental concerns, and a global shift towards sustainable energy sources. As the sector faces mounting pressure to reduce carbon emissions and meet stricter regulatory standards, the need for innovative power solutions has become critical. Advancements in technology, such as renewable energy integration, decarbonization, and energy efficiency measures, offer promising avenues for reducing the environmental impact while maintaining operational efficiency. According to recent McKinsey’s analysis, companies must diversify their energy portfolios, integrating renewable and decentralized technologies to enhance resilience, efficiency, and sustainability, especially in the scale of deployment needed to meet 2030 and 2050 targets.
This article explores the transformative potential of advanced, distributed gas turbine technology, focusing on four key areas: the conversion of flare gas into valuable energy, the economic advantages of fuel flexibility, the shift towards hydrogen-ready turbines, and the strategic mobility of power assets.
Converting Flare Gas into Power: Turning Waste into $2 Million in Annual Savings Gas flaring is one of the burning issues in the modern oil & gas industry. According to the latest World Bank’s Global Gas Flaring Tracker Report, global gas flaring increased to 148 billion cubic meter in 2023, which is equivalent to approximately 400 million tonnes of carbon dioxide emissions, resulting in the highest level of flare gas since 2019. This isn’t just bad news for the planet; it’s bad news for the industry too — as gas burns, so does money. How can a business stop flaring, or even benefit from it?
Advanced, distributed gas turbine technology offers a solution by converting flare gas into valuable electricity, straight at the well. Small
gas turbines use diverse fuels (including flare gas) as a source of power generation, handling fuels with high impurity levels and dynamic composition changes. This energy can be used for local upstream operations, fed into grids, or even sold, generating additional revenue while enhancing environmental sustainability. Experience (1) shows that customers who benefit from the power generation from converting flare gas can save significantly: $2.5 million savings annually on energy costs per flare gas site are well within reach. Power output and production capacity also increase, while harmful emissions drop. This result demonstrates the scalability of gas turbine technology, confirming that it can be effectively applied across hundreds of flare gas sites globally, offering significant environmental and economic benefits at a larger scale. The advanced combustion technologies used in gas turbines is one key solution for reducing harmful emissions, addressing both environmental concerns and
regulatory demands.
Transitioning from the challenges of gas flaring, the broader story of fuel flexibility in the oil and gas industry further underscores the value of resource optimization. As companies seek to reduce both environmental impact and operational costs, the ability of advanced gas turbines to handle a wide variety of fuels becomes a key advantage. Beyond just flare gas, gas turbines are capable of processing both gas and liquid, as well as both low and high-calorific fuels with high sulfur contents (up to 7%), without the need for expensive gas treatment installations.
However, flexibility goes beyond just fuel variety. Dual fuel options, allowing operators to switch between different fuels in real-time during operations are now part of proven gas turbine features. This helps optimize fuel usage based on availability and cost, while also reducing carbon emissions — a vital consideration in today’s energy landscape. Fuel flexibility also means that flare gas is not the only waste that can serve as fuel in the turbine, other waste products like syngas, biogas, pyrolysis oil or biomass (among others) can also serve as fuel.
While hydrogen presents an exciting opportunity to reduce carbon emissions, it is unlikely to fully replace traditional fossil fuels in the near term. However, hydrogen offers oil and gas companies a chance to diversify their energy portfolios and participate in the energy transition. By investing in hydrogenready technologies, companies can stay relevant as the world moves towards cleaner energy sources, which helps them align with regulatory pressures and market demand for lower carbon solutions. Oil and gas companies can use their existing infrastructure for hydrogen production and transportation, particularly with “blue hydrogen” derived from natural gas, where carbon capture technologies are applied. This allows them to remain key players in the energy landscape
while transitioning to cleaner energy.
The hydrogen market is growing rapidly, with projections suggesting it will grow to US$1.4 trillion by 2050, according to Deloitte. European governments have been proactive in advancing hydrogen technology. The Dutch hydrogen program within the Top Sector Energy, for example, aims to develop an ultra-low emission combustion system that can operate on fuel mixtures ranging from 100% natural gas to 100% hydrogen.
When utilizing gas turbines for power generation, oil and gas companies must adopt a forward-thinking approach by ensuring their capital investments are future proof. As the energy landscape evolves and the push for decarbonization intensifies, it becomes increasingly critical to select technologies that can adapt to these shifts. A logical step is to require gas turbines that are capable of handling hydrogen as part of their fuel mix. In the near term, this may involve using hydrogen as a small fraction within a blended fuel gas mixture, but the turbines should also be designed to transition to 100% hydrogen operation in the future as hydrogen infrastructure and supply chains expand.
This adaptability not only prepares companies for stricter emissions regulations but also aligns them with the broader global trend toward cleaner energy sources. By investing in hydrogen-compatible turbines today, oil and gas firms can safeguard their operations from obsolescence, reduce their carbon footprint, and ensure long-term profitability in a rapidly decarbonizing world. Future-proofing these assets is not just a matter of technological choice but also a strategic business decision to remain competitive in an energy market that increasingly favors sustainability and flexibility.
Maximize ROI: Preventing Stranded Assets Across Projects
As hydrogen-ready turbines position themselves at the forefront of clean energy innovation, the conversation naturally extends to the need for mobility and flexibility in power
generation assets. The oil and gas industry, with its dynamic nature and constantly shifting operations, requires solutions that can not only adapt to cleaner fuels like hydrogen but also be easily deployed and relocated across different geographic regions. Mobile and decentralized power generation assets offer the ability to maximize return on investment (ROI) while preventing stranded assets in projects that may change location or scale over time. This flexibility ensures that as the industry moves towards a more sustainable future, it can do so efficiently, without sacrificing the operational agility that is critical to its success.
The compact design of small gas turbines ensures them to be easily relocated from one site to another, adapting to shifting project requirements and operational needs. By leveraging this mobility, companies can maximize their operational efficiency and profitability, ensuring that their investments deliver continuous value and adapt to evolving project demands. Moreover, these turbines are designed with the future in mind, featuring upgradeable components and modular designs, extending their operational lifespan and avoiding early obsolescence.
Embracing Innovation for a Sustainable Future
Adopting advanced gas turbine technologies
isn’t just about keeping up with industry trends; it’s about leading the transformation of power generation. From converting flared gas to preparing for the hydrogen economy, and from fuel flexibility to mobile designs, these innovations provide substantial advantages in sustainability, efficiency, and profitability. Businesses that embrace these technologies can improve their environmental performance and position themselves for long-term success in a rapidly evolving industry.
Investing in advanced gas turbines allows companies to reduce emissions, enhance operational efficiency, and stay ahead of regulatory and market shifts. The era of innovation is already here, and those who embrace it will help shape a more flexible, sustainable, and future-ready oil and gas industry.
(1) Referring to a recent project carried out by Destinus Energy.
Destinus Energy develops, manufactures and services state of-the-art gas turbine systems, and is headquartered in Hengelo, The Netherlands. With over 30 years of market presence, the OP16 gas turbine is a flagship product renowned for its reliability, availability, fuel flexibility and minimal maintenance requirements. The OP16 offers cost-effective and robust solutions for global energy needs, particularly in the 1.8MW turbine segment. Its innovative combustion technology can efficiently turn dirty fuel gas that would otherwise be flared, vented, or simply wasted into green power and clean exhaust gas, setting new standards for sustainable energy generation. In-house testing of the OP16 proved that it can effectively utilize up to 100% hydrogen as a fuel source.
www.destinus.energy • Sales@destinus.energy Destinus-Energy B.V. Hengelo, The Netherlands. Learn more:
Linde Signs Long-Term Agreement to Supply Clean Hydrogen to Canada
Linde announced today it has signed a long-term agreement for the supply of clean hydrogen to Dow’s Fort Saskatchewan Path2Zero Project. The company will invest more than $2 billion to build, own and operate a world-scale integrated clean hydrogen and atmospheric gases facility in Alberta, Canada.
Linde’s new on-site complex will use autothermal reforming, combined with Linde’s proprietary HISORP® carbon capture technology, to produce clean hydrogen and will also recover hydrogen contained in offgases from Dow’s ethylene cracker. In the first phase, Linde will supply the clean hydrogen, nitrogen and other services to support Dow’s world-first net-zero emissions integrated ethylene cracker and derivatives site1. Linde’s new facility will also supply clean hydrogen to existing and new industrial customers seeking to decarbonize their operations. In total, Linde’s complex will capture carbon dioxide emissions for sequestration in excess of 2 million metric tons each year.
Upon completion in 2028, Linde’s new complex in Alberta will be the largest clean hydrogen production facility in Canada, and one of the largest globally. It will be Linde’s largest single investment and its second new world-scale clean hydrogen project, following the announcement of its project to supply clean hydrogen to a major blue ammonia project in the U.S. Gulf Coast.
“Linde is helping to build a more sustainable future,” said Sanjiv Lamba, Chief Executive Officer, Linde. “This landmark project aligns with our strategy of developing high-quality projects with secured off-take. Our technology, experience and execution are enabling the transition to a cleaner economy. We are proud to partner with Dow in its mission to decarbonize its Fort Saskatchewan site and are appreciative of the support of the Province of Alberta and the Federal Government.”
“Our business strategy to decarbonize our assets and drive growth while enabling higher shareholder returns is central to Dow’s longterm success,” said Jim Fitterling, Chair and Chief Executive Officer, Dow. “Having support from collaborators and partners across the value chain is essential. We’re glad to have Linde as a partner on this industry-leading project.”
As one of the world’s leading industrial gases and engineering companies, Linde is playing a key role in the clean energy transition. The company is actively helping its customers to decarbonize their operations with the latest hydrogen technologies through its world-class engineering organization, key alliances and ventures, and leveraging its extensive experience and infrastructure. Linde is developing
clean hydrogen projects across a range of applications and industries and growing its established hydrogen business along the entire value chain.1 with respect to scope 1 and 2 greenhouse gas emissions. •
Linde Supports RWE Project for Large-Scale Hydrogen Production in Lingen
The four megawatt (MW) electrolysis plant designed and built by Linde Engineering was integrated into RWE’s 14 MW pilot electrolysis facility. The pilot facility was commissioned in Lingen, Germany, in the presence of Federal Minister for Economic Affairs and Climate Action Robert Habeck.
Delivery of the electrolysis plant, which is based on proton exchange membrane (PEM) technology from ITM Power, marks the first milestone of a cooperation between Linde and RWE. Linde Engineering will also design and build two 100 MW PEM electrolysis plants as part of the GET H2 Nukleus project in Lingen. The first of the two 100 MW electrolysis units is due to go into operation
in 2025, the second one in 2026.
“Major projects like this are crucial for Germany to reach its net zero ambitions,” said Tilman Weide, Senior Vice President Global Execution at Linde Engineering. “We are honored that RWE has chosen us as a partner for this major project. Linde can draw on over 100 years of experience in the hydrogen business, and being part of the GET H2 Nukleus project is yet another demonstration of our expertise in developing hydrogen projects at scale to help accelerate the world’s energy transition.”
The GET H2 Nukleus project connects the production of green hydrogen in Lingen with industrial customers in Lower Saxony and North Rhine-Westphalia.
”With Linde Engineering as EPC contractor for our pilot plant and the first two units for GET H2 Nukleus, RWE is laying the foundation for the production of green hydrogen on an industrial scale in Lingen. In Linde, we have found a strong partner to drive forward our hydrogen ambitions,” said Sopna Sury, COO Hydrogen RWE Generation SE. •
Seplat Energy Rising to Nigeria’s Energy Challenge, Sustainability Commitments on Track
Seplat Energy Plc, Nigeria’s leading independent energy company, says it is rising to the challenge of energy deficit in Nigeria through its new critical projects, which are capable of taking the company’s gas processing capacity to 850 Million standard cubic feet per day (MMscfd) consolidating the company’s position as a leading gas supplier to the Nigerian market.
The Director New Energy, Seplat Energy, Mr. Okechukwu Mba, said this while delivering a keynote at the ongoing Society of Petroleum Engineers (SPE) Nigerian Council’s 47th Nigeria Annual International Conference & Exhibition (NAICE) in Lagos.
Mr. Mba, who represented the CEO of Seplat Energy, Mr. Roger Brown, spoke on the Conference theme: “Petroleum Industry Value Chain Optimization: The Inevitability of Midstream and Downstream Development”.
He said the company’ new $700m ANOH gas project in Imo State, with a capacity of 300MMscfd of gas in addition to Liquefied Petroleum Ga (LPG) will greatly boost domestic gas supply.
“Also completing a new 85MMscfd gas plant in Sapele Delta state expected to come on stream by Q4 this year. These new projects bring Seplat Energy’s gas processing capacity to 850MMscfd consolidating our position as a leading gas supplier to the domestic market,” Mba noted.
He said Seplat energy is also looking to invest in Compressed Natural gas (CNG) projects in support of the government’s CNG initiative, adding that: “When we receive approval for the MPNU transaction, we intend to promptly develop the significant gas resources in the asset to further enhance Nigeria’s energy security.” Currently, the country is experiencing insufficient supply of electricity from the national grid (about 4GW daily); very low electricity usage per-capita (with some Nigerians with no access to energy); insufficient supply of gas to some power plants; and with a bulk of electricity used in Nigeria generated off-grid at two or three times the cost of generation using gas turbines.
To this end, Mba said: “We need to develop our abundant gas resources and deliver sufficient gas to the power sector for energy security. Gas is an affordable and reliable source of energy. Incentives provided in the recent Executive Orders as well as
recent review of Domestic Gas Delivery Obligation (DGDO) gas prices are commendable.
“Current reforms in the power sector need to be sustained like tariff increase, bilateral power trading between power generation company (GenCos) and power distribution companies (DisCos). Key gas infrastructure like the Obiafu-Obrikom-Oben (OB3), The Ajaokuta-Kaduna-Kano (AKK) gas pipelines, and so on, should be delivered.”
The company also reiterated its resolve to addressing the dual challenges of ensuring energy security and meeting climate change mitigation targets.
Mr. Okechukwu Mba, gave the assurance during a panel session themed “Energy Security: Exploring the Interplay Between Technology, Market Dynamics and Organizational Capabilities”.
Mba, who represented Mr. Roger Brown, CEO Seplat Energy Plc, at the session, said every molecule of gas Seplat Energy produces is targeted at displacing utilizable diesel, and the company’s new gas plant developments now come with Liquefied Petroleum Gas (LPG) installations, which promote clean energy and discourages the use of biomass for cooking.
“We are committed to ending routine gas flaring by 2025, and all projects aimed at making this a reality are on track,” Mba assured. In a bid to end gas flaring as targeted, Seplat Energy has continued to progress efforts to secure evacuation options for unprocessed associated gas from the Sapele Flow Station. Alongside this, work has continued on the construction of the Sapele Integrated Gas Plant (SIGP), which is scheduled to be completed during H2 2024. Once operational, SIGP offtake has the potential to materially reduce Group Scope 1 emissions.
Other ongoing key flare-out projects, including the Western Asset Flares Out (installation of VRU compressors), Sapele LPG Storage & Offloading Facility, Oben LPG Project and Ohaji Flares Out Project, are on track for completion by their respective due dates.
The Seplat New Energy Director also referenced the company’s Tree4Life initiative, which recently saw the NEPL/Seplat Energy joint venture and the Edo State Government sign an agreement that allocates 6,000 hectares of land from Edo State protected forest reserves to enable a large-scale tree planting initiative by Seplat Energy Plc. This is in furtherance to increase forest cover and carbon sequestration efforts within the region and ensuring a sustainable environment for living.
The efforts by Seplat Energy and other operators to drive LPG penetration in Nigeria also received commendations from the 2024 SPE NAICE participants and organisers, as the moves are expected to boost supply of LPG in Nigeria and possibly bring down prices of the commodity, thus promoting accessibility and energy security.
Also speaking to Seplat Energy’s commitment to ensuring sustainable business partnerships, Mba said all efforts are being deployed to check any form of production deferment and downtime by ensuring strong partnerships with suppliers, who are continuously supported to succeed in delivering value to Seplat Energy and its other stakeholders.
Seplat Energy Emphasizes Alignment of Communication Goals with Sustainability at Lagos PR Conference
Seplat Energy Plc, a leading indigenous energy company in Nigeria, has once again reinforced its commitment to sustainability and climate action at the 11th edition of the Lagos Public Relations Stakeholders’ Conference (LaPRSC). The event, a key gathering of thought leaders and industry experts, centered on the theme ‘Stakeholders’ Conversations on Climate Change and Environment: Communication and The Sustainability Agenda.’
Chioma Afe, Director of External Affairs & Social Performance, Seplat Energy, served as a distinguished panelist at the conference, offering critical insights into the urgent need for action beyond dialogue. Afe emphasized that while discussions are essential, they must be complemented by tangible actions to address the escalating climate crisis. “For me, it’s about talking and doing. We’ve had the conversations, but what concrete steps are we taking? Engaging with the government and the private sector to share ideas is valuable, but the true challenge lies in execution,” Afe asserted.
While speaking to the issue of achieving the right communication goals for climate change by organisations, Afe outlined the critical role of embedding sustainability within the strategic priorities of businesses. “The first thing is situating it within the strategic priority of the business. To be able to establish communication goals, if the organization is not first rooted in the message of sustainability and sustainable business, then we cannot begin to think about communication goals,” she explained.
Afe cited Seplat Energy’s commitment to energy transition and sustainable business development as key examples of how corporate strategy must align with sustainability objectives. “When you narrow down to sustainable business and what it is that you do, you look at your portfolio of products and try to understand the impact of your business on the community and the environment around you,” Afe noted. She further emphasized the importance of educating both internal and external stakeholders once these goals are clearly established.
Afe added: “At Seplat Energy, our evaluation confirms our business’ resilience across all climate change scenarios. We remain committed to reducing our greenhouse gas (GHG) emissions by addressing scope 1 and 2 emissions across all assets by implementing planned GHG emission projects.
“Decarbonisation is integrated into our annual Capex prioritization processes. We have earmarked significant part of our resources towards decarbonising our operations, including ending routine flaring (by 2025) and implementing an afforestation programme.”
The 11th LaPRSC, organized by the Nigerian Institute of Public Relations (NIPR) Lagos State Chapter and held at the Muson Center in Onikan, Lagos, brought together participants across sectors—including government, corporate organizations, environmental experts, NGOs, and media professionals—to explore the critical intersection of climate change, environmental sustainability, and communication.
Representing the Lagos State Governor, Babajide Sanwolu, the Honourable Commissioner for the Environment and Water Resources, Mr Tokunbo Philip Wahab, charged all attendees present to take personal responsibility for sustainability in their respective spaces, while also reiterating the government’s commitment to collaborating with necessary stakeholders in combating the effects of climate change within the state.
Comfort Obot Nwankwo, Chairman of the Lagos State Chapter of NIPR in her address, highlighted the significance of this year’s theme, underscoring the need for collaborative efforts to advance the sustainability agenda in Nigeria and beyond.
Seplat Energy’s participation in the conference underscores its leadership role in driving conversations and actions that contribute to a more sustainable future. The company remains dedicated to delivering a just energy transition and fostering sustainable business practices that positively impact the environment and the communities it serves.
NNPC LTD/Chevron Sign Pia Conversion Terms for its JV Assets at NNPC Towers, Abuja.
L-R:
Mrs. Michelle Pflueger (Director, Deep Water & Production Sharing Contract, Chevron Nigeria Ltd.) and Mr. Mele Kyari (GCEO, NNPC Ltd.) signing tthe Contract Documents while Mr. Tolulope Ibikunle (Business Advisor, Upstream to the GCEO) observes, during the Signing Ceremony of NNPC Ltd/Chevron PIA Conversion Terms for its JV Assets at NNPC Towers, Abuja.
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NNPC Ltd/TotalEnergies’ $550m Ubeta Upstream Gas Project Takes Off
The $550 million upstream gas project between the NNPC Ltd and TotalEnergies on the development of the Ubeta field has taken off, the Presidency announced on Tuesday.
Special Adviser to the President on Energy, Olu Verheijen, disclosed this during an inaugural US-Nigeria Strategic Energy Dialogue, hosted by the U.S. State Department in Washington, DC.
The signing ceremony of the 550 million USD Final Investment Decision (FID) on the Ubeta Field Development Project took place in Abuja in June, this year. The Ubeta field, which was discovered in 1964, is located northwest of Port Harcourt, Rivers State.
Speaking at a luncheon organised as part of the inaugural USNigeria Strategic Energy Dialogue, Verheijen said the upstream gas project would deliver 350 million standard cubic feet of gas per day when operational.
Verheijen added that major energy reforms introduced by President Bola Ahmed Tinubu since June 2023 focused on improving energy security, attracting investments, and deepening collaboration with key partners, including the US government.
She said the key reforms had improved the viability of the gasto-power value chain of the country.
The reforms, according to her, included initiatives to improve cash flows in electricity distribution through smart metering and the payment of outstanding debts owed investors and to reduce
carbon emissions from gas production.
She added that the President issued five new executive orders to support the reform efforts, aimed at providing fiscal incentives for investment and reducing the cost and time of finalising and implementing contracts to develop and expand gas infrastructure.
The presidential aide said the directives are aimed to immediately unlock up to $2.5 billion in new oil and gas investments in the country. Responding, the U.S. Assistant Secretary of the State Department’s Bureau of Energy Resources, Geoffrey Pyatt, said the dialogue was apt and strategic.
“The inaugural U.S.-Nigeria Strategic Energy Dialogue has set the stage for strengthened energy collaboration between the United States and Nigeria. Together, we’re advancing shared energy security, decarbonisation, and economic growth goals,”
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Aramco Unveils New Initiatives to Drive Digital Development
• Collaborations aim to enable next-generation industrial capabilities
• Deployment of supercomputing infrastructure supports deployment of AI solutions
• Projects aim to advance in-Kingdom AI development
Aramco, one of the world’s leading integrated energy and chemicals companies, today unveiled new initiatives that aim to drive the development and deployment of advanced digital solutions across its operations. Details of these initiatives were disclosed during the Global AI Summit (GAIN), which commenced today at the King Abdulaziz International Conference Center in Riyadh.
Ahmad Al-Khowaiter, Aramco EVP of Technology & Innovation, said: “New digital technologies such as Generative AI and the Industrial Internet of Things are expected to transform not only how we work, but also our commercial environment. Aramco is pioneering the use of these technologies at an industrial scale to add significant value across our operations. Our history of innovation inspires us to continue harnessing emerging technologies and help realize the Kingdom’s ambitions to become a global AI leader.”
Advanced AI computing
During the Global AI Summit, Aramco signed Memoranda of Understanding (MoU) with Cerebras Systems and FuriosaAI to explore collaboration in the supercomputing and AI domains. Another MoU signed with Rebellions focuses on potential deployment of the latter’s Neural Processing Unit chips in Aramco’s data centers, with a view to enhancing digital infrastructure and driving advanced AI innovations.
Aramco also signed an MoU with SambaNova Systems to explore ways to accelerate AI capabilities, innovation, and Kingdom-wide adoption.
Aramco also announced the deployment of an AI supercomputer, one of the first systems of its kind in the region. Powered by some of the most powerful NVIDIA Graphical Processing Units (GPUs), it is designed to accelerate complex computing tasks like analyzing drilling plans and geological data to recommend low options for well placement.
AI on the edge
In addition, Aramco has collaborated with Qualcomm Technologies on initial deployment of industrial generative AI solutions on the edge, which aim to enhance Aramco’s facility monitoring, predictive maintenance, and use of autonomous drones.
Digital innovation
The new initiatives announced during GAIN are part of Aramco’s broader strategy to adopt cutting-edge digital solutions across its business, building on its launch of the Saudi Accelerated Innovation Lab (SAIL) — a national engine to transform cutting-edge ideas into fully functional products —
and its Global AI Corridor ecosystem. The approach has so far resulted in the creation of Aramco’s first large language model (LLM) serving industrial AI applications. It has also launched the Eye on AI Program intended to establish robust AI cybersecurity governance and systems, as well as equip users with necessary cybersecurity skills in a rapidly evolving landscape.
TUBACEX Stands out in Institutional Investor’s “Developed Europe Executive Team” Awards
Institutional Investor, a global leader in financial sector rankings, has announced the results of its prestigious annual “Developed Europe Executive Team” awards, in which TUBACEX has garnered significant recognition. These accolades are based on a Europe-wide survey of 1,765 professionals from 820 financial services companies, including analysts and fund managers.
In this year’s edition, Jesús Esmorís, CEO of TUBACEX, secured third place in the Best CEO category within the metals & mining sector. Additionally, Raquel Ruiz, Head of Investor Relations at TUBACEX, earned second place in the Best IR Professional category. The company’s investor relations team also achieved third place in the Best Investor Relations Team category for small & mid-cap companies.
These awards are based on several criteria, including credibility, leadership, and communication skills for CEOs. Meanwhile, the investor relations rankings evaluate aspects such as the productivity of conferences and roadshows, the quality of earnings presentations, business and market knowledge, responsiveness, and consistency in financial disclosures.
TUBACEX was also recognized as one of the Most Honored Companies, a title granted to firms that achieve high scores across the seven categories combined, based on votes from both buyside and sell-side professionals, reflecting outstanding overall performance. The awards ceremony will take place on September 19th at the Europe & Emerging EMEA Equities Awards Dinner & Ceremony in London.
This recognition underscores TUBACEX’s commitment to excellence in corporate management and investor relations, solidifying its position as a global leader in its sector.
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ADIPEC 2024 to Focus on AI to Accelerate Energy Transition
Held under the patronage of H.H. Sheikh Mohamed Bin Zayed Al Nahyan, President of the UAE, ADIPEC 2024 will take place in Abu Dhabi on 4-7 November
Landmark 40th edition will include the inaugural Energyai by ADNOC exhibition, Energyai Conference, and AI-focused Leadership Roundtables to explore critical relationship between energy and AI Three new conferences to feature new voices from finance, technology, youth and the Global South to help shape a more sustainable and inclusive energy future
ADIPEC, the world’s largest energy event, has announced that this year’s landmark 40th edition will bring the global energy industry together to explore the key role of artificial intelligence (AI) and finance in accelerating the global energy transition. It will also include three new conferences with new voices from finance, technology, youth and the Global South to help shape a more sustainable and inclusive energy future.
Held under the patronage of H.H. Sheikh Mohamed Bin Zayed Al Nahyan, President of the United Arab Emirates, and hosted by ADNOC, ADIPEC 2024 will take place in Abu Dhabi on 4-7 November 2024. Over 184,000plus attendees are expected, with more than 1,800 leading innovators, experts and visionaries from energy, AI and other technologies to speak at the expanded conference.
Tayba Al Hashemi, Chair of ADIPEC 2024 and CEO of ADNOC Offshore, said: “AI needs energy and energy needs AI. This AI-energy nexus will be a major focus of ADIPEC’s milestone 40th edition. Bringing global leaders and innovators together, we will discuss AI’s potential to transform economies and industries, particularly its role in accelerating a just, orderly and equitable energy transition.”
The ADIPEC Strategic Conference agenda convenes some of the world’s most influential voices to explore how technological innovation can fast-track the energy transition while highlighting the importance of cross-sector partnerships for decarbonisation.
Christopher Hudson, President of dmg events, said: “Marking 40 years since its inception, ADIPEC 2024 will be the most ambitious edition yet. The international community and global energy ecosystem will unite there around the need for decisive action to secure net zero. Featuring innovative technologies, valuable insights and influential voices, the event will deliver a renewed global commitment to creating a secure, equitable and sustainable energy future for all.”
Attendees at ADIPEC’s new Digitalisation and Technology Conference will learn how next-generation technologies, including AI, can unlock decarbonisation and efficiency opportunities presented by Industry 4.0.
The agenda will showcase progress in new materials, the Industrial Internet of Things (IIoT) and carbon capture, utilisation and storage (CCUS), while also addressing how technologies can be scaled up in a sustainable and equitable manner.
ADNOC will launch an inaugural exhibition called Energyai (Energy to the power of AI), which highlights the impact AI can have on the energy value chain, while also revealing AI’s impending demand on global energy systems. Within Energyai, an AI Conference will gather leaders from the energy, technology and government sectors to develop a strategic roadmap for integrating AI into the energy landscape.
The Finance and Investment Conference is another addition to ADIPEC 2024. This conference gives leaders from government, finance and energy a platform to discuss the disparity between capital flows and the investment necessary for a fair and equitable transition. The new Voices of Tomorrow Conference aims to connect the Global North and South, giving future leaders a voice in an inclusive future.
The ADIPEC Leadership Roundtables will also include a focus on AI. The exclusive, invitation-only closed-door discussions will explore the critical relationship between AI
and energy, focusing on how AI can accelerate the development of a future-ready energy system.
Complementing the 10 conferences at the event, the ADIPEC Exhibition will span 16 halls and bring more than 2,200 exhibitors from the full spectrum of the global energy ecosystem together to showcase the latest breakthroughs shaping the future of energy. This includes 54 NOCs, IOCs, NECs and IECs, 30 dedicated country pavilions and four specialised industry areas focused on decarbonisation, digitalisation, maritime and logistics and AI. •
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Overcoming the New Energy Trilemma Through Decarbonisation, Efficiency, and Collaboration
The energy trilemma of the past has evolved to reflect the challenges of our current moment. While before, global leaders were concerned with the supply of energy that was secure, affordable, and sustainable, today the challenge is to provide the world with energy that is secure, sustainable and equitable. Equitable encapsulates the previous trilemma definition’s energy affordability, as well as accessibility and the socioeconomic impacts of energy in a country. This is of particular importance, as the development levels and quality of living gaps between the Global South and North close.
While this new trilemma definition encompasses more needs, making it more complex to resolve, the broad solutions are still the same. The major action needs to come from the global energy industry, which must continue to lead efforts to decarbonise and drive efficiencies through artificial intelligence (AI) and technology.
Critical to overcoming the current energy trilemma is the introduction of more low- and zero-emission energy sources, like liquified natural gas, green hydrogen, solar, wind, and biofuels. These fuels can help provide an increasing number of the low-carbon energy molecules the world needs. Related to this is transitioning industries that previously ran on fossil fuels -- like the hard-to-abate sectors of transportation, cement and steel production, and shipping -- to running on low or zeroemission electricity. Supporting a shift from coal-powered electricity to clean energypowered electricity in Asia alone – which currently accounts for 82% of the world’s coal generation – could have vast benefits. Clean energy-powered industrial activity across Asia could advance the decarbonisation of many of the continent’s heavy industries while significantly reducing global carbon emissions. Achieving such large-scale changes requires supportive policy frameworks, financial incentives and tax breaks, clean energy finance and investment, and technology development. And while the end goal of the energy transition is an energy system that is effectively zero carbon, it will take time to develop, commercialise, scale, and implement the technologies and systems that can do that. In the interim, we will continue to use energy sources that produce carbon but must do so while reducing their emissions impact. That is why the global energy industry needs to continue its efforts to develop and incorporate carbon capture, sequestration and utilisation (CCUS) and direct air capture (DAC) technologies, which can help ensure that the hydrocarbons we use do not contribute to climate change. In parallel, government and industry should support the many startups that are working to turn captured carbon into useful
borrowed from the Global North.
Another key element to solving the energy trilemma is to increase the focus on energy efficiency. The International Energy Agency (IEA) estimates that around two-thirds of the total prime energy of the world goes to waste –primarily through energy leaks and ineffective energy use. This otherwise wasted energy can be considered an untapped energy source that the industry can harness through improved energy efficiency. This can be done through the integration of digitalisation technologies, like machine learning and AI.
The last critical component of the energy trilemma looks to address that third expanded need – energy equity. The pursuit of energy equity is about ensuring that no one is left behind in the global energy transitions. Achieving it is not as simple as developing new clean energy technologies or implementing mega projects in places like Europe and North America. In many parts of the Global South, any type of energy supply is lacking, let alone clean energy. The energy industry must prioritise fair access to clean energy, ensuring the benefits of secure clean energy access reach vulnerable communities. This can be achieved through collaborative efforts between the Global North and South to promote equitable distribution of resources and technologies. This collaboration needs to include technology transfer, access to finance and investment, and the development of customised solutions to create energy systems that are ideally suited for each unique market, instead of attempting to shoehorn solutions
Recognising the importance of bringing together the wider global energy industry to accelerate efforts to resolve these complex issues, the world’s largest energy event ADIPEC has made enabling the actions to overcome the new global energy trilemma a major focus of its 2024 edition. With our Strategic Conference gathering the world’s decision-makers and innovators, we will facilitate a meeting of minds across diverse sectors and geographies, forging the alliances and collaborations necessary to reengineer the global energy system. By platforming visionaries on critical topics, the conference will harvest insights on the latest thinking, trends and solutions around emissions, energy efficiencies and disruptive technology needed to advance global energy transitions. This mission is supported by the introduction of three new dedicated conferences –Digitalisation and Technology, Finance and Investment, and Voices of Tomorrow – that will spotlight industry progress and inspire collaborative and equitable action to fully unlock the opportunities presented by the integration and adoption of Fifth Industrial Revolution technologies.
Through ADIPEC’s timely agenda, the energy trilemma’s needs for decarbonisation, energy efficiency, and Global North-South collaboration will be advanced. ADIPEC’s gathering of the wider energy industry will facilitate the inclusive, meaningful and actionoriented dialogue needed to ensure that clean energy access reaches all corners of the world.
products like graphene, polymers, concrete, and even biofuels.
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China National Convention Center Chaoyang District, Beijing https://www.wgc2025.com/eng/home
XPONENTIAL 2025
19.05.2025 - 22.05.2025
George R. Brown Convention Center, Houston, TX, US https://www.auvsi.org/events/xponential-2025
Global Petroleum Show 2025
10.06.2025 - 12.06.2025
Calgary, Canada https://globalpetroleumshow.com/
Offshore Europe
02.09.2025 - 05.09.2025
Aberdeen, Scotland
Africa Oil Week 2025
06.10.2025 - 09.10.2025
Cape Town, SA
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