OGI Magazine Summer 2023

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Summer 2023

CEO Matthew Patten

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A NOTE FROM THE EDITOR

The Emerging Hydrogen Market, a Finance Perspective

Asthe world shifts towards a low-carbon economy, hydrogen has emerged as a promising alternative energy source. With its potential to decarbonize various sectors, including transportation, power generation, and industrial processes, hydrogen is capturing the attention of investors looking to align their portfolios with sustainable and clean energy solutions. This article explores the investment opportunities presented by hydrogen stocks on the stock market and highlights the factors that investors should consider when venturing into this burgeoning sector.

Hydrogen is a versatile energy carrier that can be produced through various methods, such as electrolysis and natural gas reforming. It offers advantages such as high energy density, zero greenhouse gas emissions when produced from renewable sources, and the ability to be stored and transported. These attributes position hydrogen as a viable solution for achieving carbon neutrality and reducing dependence on fossil fuels.

The hydrogen market is witnessing rapid growth and is projected to expand significantly in the coming years. According to a report by the International Energy Agency, hydrogen’s share in the global energy mix could reach around 20% by 2050. This growth trajectory presents an attractive investment opportunity for those interested in capitalizing on the potential of hydrogen stocks.

As with any investment, thorough research and due diligence are crucial. Investors should assess the fundamentals of the companies involved in the hydrogen sector, including their financial health, technological capabilities, and market positioning. Additionally, understanding government policies, industry partnerships, and regulatory developments can provide valuable insights into the growth prospects of hydrogen companies.

Investing in hydrogen stocks requires a long-term perspective, as the sector is still in its nascent stages and may experience volatility. Patience and a focus on the underlying growth potential can yield favorable returns over time.

While the hydrogen sector presents exciting opportunities, it is not without risks. Some challenges include high production costs, infrastructure development requirements, and competition from other clean energy technologies. Investors should be aware of these risks and factor them into their investment decisions.

Investing in hydrogen offers a unique opportunity to participate in the growth of the clean energy revolution. With the potential to revolutionize multiple sectors and contribute to a more sustainable future, hydrogen presents an attractive proposition for forward-thinking investors. However, careful research, diversification, a long-term perspective, and a keen focus on ESG factors are essential when venturing into this evolving sector. By staying informed, investors can make informed decisions and position themselves to benefit from the ongoing hydrogen revolution. •

A Major Milestone

Norway-based well integrity specialist company HydraWell announced that it had reached a major milestone in the company’s evolution when it revealed the completion of its 500th plug installation using revolutionary technology.

Driving the Sustainable Transition of the FPSO Market

OGI sits down with regular contributor, Yinson, who has made major strides in their sustainability efforts when it comes to their projects and operations. Echoing their commitment towards a more sustainable future

Well Control Planning and Training

The return of the hurricane season to the U.S. Gulf of Mexico is a timely reminder for operators around the world to ensure they have an effective well control emergency response plan in place and an associated exercise program.

Keeping an Eye on Flares

Maintaining proper control of flare stacks not only helps oil and gas companies comply with legal requirements related to environmental monitoring,

World-Class Maritime Services

VMS Group repairs diesel engines worldwide, and sell engines, new and reconditioned spare parts, develop state-of-the-art propulsion solutions and provides project management and engineering services.

The Benefits of Water Jet Cutting

Innovation Critical to Driving Progress in the

Tank Cleaning Sector

The oil and gas sector is faced with complex challenges, including stringent safety and environmental regulations and the need to optimise operational efficiency.

Ultra High Pressure Solutions

The oil and gas industry operates in some of the most challenging environments, where maintenance, cleaning, and repair tasks often require advanced equipment to ensure efficiency and safety.

Enhanced Sand/ Erosion Management

Potentially causing serious erosion, sand is a major challenge in oil and gas production. Sand erosion implies risk to both assets and personnel, and often leads to increased operating costs.

PROCESSING

Going Greener

Oil and gas producers keen to decarbonise under corporate ESG strategies will naturally want their suppliers to share the same sense of sustainability and green values.

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HydraWell Technology Paves the Way Towards Bright, Diversified Future

In 2022, Norway-based well integrity specialist company HydraWell announced that it had reached a major milestone in the company’s evolution when it revealed the completion of its 500th plug installation using revolutionary technology.

Nowa year on, the company’s continuing drive to grow by innovating and diversifying is reaping further rewards as HydraWell expands its corporate horizons by geography and sector using lessons learned from its traditional markets to embrace change.

The uplevelling is being fulfilled thanks to a remodelled approach which involves the coming together of HydraWell, READ and ANSA, not only to fashion a leading well integrity specialist with ambitions to play a prominent role in late life oilfield activities but also streamline the customer experience by offering an expanded portfolio in one place.

Drawing strength from the long-established history which each component of the new business has in delivering expert well integrity services and solutions for clients, is combined with a single vision towards correctly satisfying growing demand for permanent plugging and abandonment of aging assets.

READ’s excellence in cement evaluation and tubing/casing integrity successfully mixes with ANSA’s well integrity and abandonment data analysis, fast turnaround and data analysis training. Add HydraWell´s Plug and Abandonment expertise, inclusive of annular remediation for slot recovery, tubing and casing integrity and zonal isolation, and the result is an integrated service which facilitates “cross pollination” within the portfolio. For the

customer, cross discipline involvement on wells reaps many rewards in terms of time and budget.

At the heart of the success and spearheaded by HydraWell’s ethos of rethinking existing well integrity operations, is the revolutionary Perf, Wash & Cement (PWC®) technology which provides a nimble and flexible method much in demand across a range of applications from permanent P&A and slot recovery to restoring annular integrity and casing shoe repair.

Originally developed for the energy sector, the patented system is now being deployed across a growing number of diversification opportunities, including the successful abandonment of geothermal wells and completion of CCS work in the Netherlands. One recent project took place in a salt mine where, although hydrocarbons are absent, hot water is required to dissolve salt so that it can be circulated out for processing – and, just like the energy sector,

P&A is required when a well reaches the end of its life. In the recent salt mine project, HydraWell’s innovative solution was deployed on a P&A scope of work which was completed in a 4700m underground well with flawless execution and in a single run.

The versatile system has also been successfully put to work on behalf of a leading tomato producer which uses geothermal energy to heat its facility. HydraWell was approached by its client whose affiliate had experienced reliability issues due to corrosion, leading to the decision to schedule the geothermal well for permanent P&A. In less than two days, the HydraHemera™, the HydraHemera™TM PWC® system was applied to perforate the 810m deep well before washing behind the casing and then setting the cement plug in the well.

In further development of capability, the recent addition of HydraCT™ – specifically designed for rigless coil tubing applications –has the potential to cut CO₂ emissions by 80% and reduce costs by up to 60%.

Late last year, the benefits were felt during the annular isolation of an existing well bore in a project in Alaska which needed a more cost-effective method for use in a remote area where rig availability is extremely limited. In a single run, HydraCT™™ eliminated

the need to mobilise a rig to site and cut the need to run drill pipe to remediate the annuli without compromising barrier quality or barrier verification using established field proven PWC© techniques.

The successful completion of these projects, and others, also represents an important advancement in HydraWell’s diversification plans, and further underlines the company’s enviable reputation for smart, superior, sustainable operations which exceed the customer´s expectations. It also shines a light on the team’s 98% plugging success rate, meaning that customers know they are in safe hands which can achieve optimum results.

More recently, a focus on the development of specialist Computational Fluid Dynamics (CFD) has allowed greater understanding and tangible evidence of what is happening downhole. CFD uses numerical computing analysis to examine fluid flow-related issues, allowing better understanding of the fluid displacement through a perforated casing. The result is better and, ultimately, safer P&A outcomes and CFD will be instrumental in opening up further opportunities in areas including food and drink, aerospace, automotive and chemical manufacturing as well as energy sectors.

However, the courage to try new things is arguably strongest when it comes from a sound core of values. At its heart is quality assurance driven by HydraWell’s commitment to the installation of high-quality, longlasting, hydraulic isolation barriers to prevent hydrocarbon contamination of the environment.

One common challenge is the verification of installed barriers and barrier elements but there are many different methods of installing barriers, each with advantages depending on well characteristics, including:

Direct Measurement

Good, direct measurement comes with drawbacks. It’s not always straightforward; it can be complicated to pressure test an annular barrier, and care needs to be taken about what is being tested. It’s a more sensitive approach, but it’s important to ensure it meets verification needs. There’s plenty of evidence that barriers

tested successfully with liquids are permeable to gases but, if the barrier is designed to contain gas, should it be tested with a gas with similar properties? What is an allowable leak rate? Guidelines say that only zero is acceptable, but the sensitivity of techniques and the use of cement has an inherent permeability, albeit quite low.

Indirect Measurement

Indirect measurements, such as Cement Bond Logs (CBLs), have more flexibility but risk only indicating barrier quality. CBLs also carry risk in interpretation but lower costs often make them the preferred option due to ease of execution, difficulty with achieving direct measurement, or a query on the measurement truly analysing barrier quality. Tried and tested methods often seem like the obvious “go-to” for quality – but success must also be assured.

Computer Simulation

To translate techniques, it’s vital to understand how changing operational parameters during barrier installation impact effectiveness and efficiencies. When using Perf, Wash and Cement (PWC©) to install an annular barrier, increases in fluid density increase circulation rates required for effective annular cleaning and cementation. Here, computer simulation and modelling can be useful. Replicating downhole conditions physically at surface is notoriously difficult, but computer modelling can predict results efficiently and confirm the impact of incremental changes, if inputs reflect reality, and the underlying algorithms are accurate. Then, modelling can provide valuable data to support the design of barrier installation procedures and optimise procedures to reduce durations and cost.

Looking ahead to the next 500 installations, much research on working without rigs is

forecast and HydraWell will be at the forefront of guiding how the sector can address the challenge of rig availability. This will involve executing abandonment work which moves away from the need for a rig to pull pipe towards rigless, coiled tubing innovations and HydraCT™ will lie at the heart of the next chapter. •

If you would like to know more about the topics discussed in this article, or would like to know more about HydraWell’s solutions please contact them at:

HydraWell

T: +47 51 69 76 00

W: www.hydrawell.com

E: sales@hydrawell.com

Above: The experienced HydraWell team are leaders in the field of developing technologies to transform global energy industry operations.

Driving the Sustainable Transition of the FPSO Market

OGI sits down with energy infrastructure and technology company, Yinson, who has made major strides in their sustainability efforts when it comes to their projects and operations. Echoing their commitment towards a more sustainable future, the organisation has launched its “30 by 30” initiative, whereby Yinson Group strives to achieve their 30 most impactful ESG targets by 2030. During the interview, we also discussed other global projects, technology solutions and more, below.

OGI: What is “sustainable development” and Yinson’s role in it?

YINSON: At Yinson Group, we recognised the importance of operationalising sustainability in driving positive change. Yinson has strategically channelled our corporate efforts to key sustainability focus areas guided by our Sustainability Framework. We aim to enhance long-term stakeholder value through environmental conservation & protection, championing human rights & human capital development and embracing good corporate governance.

We understand that modern energy is directly linked to the wellbeing, prosperity and development of every economy. To ensure an inclusive energy transition, it is crucial to consider the balance of energy reliability, affordability and sustainability. To support the energy transition journey, we aspire to be part of the solution towards creating a low-carbon, climate-resilient environment by developing innovative energy solutions such as the Zero Emissions FPSO Concept.

Recently, we have launched ‘30 by 30’, reaffirming our commitment towards sustainable development through 30 specific, measurable, timely and material targets to be achieved by 2030.

OGI: Could you share more about Yinson’s 30 by 30?

YINSON: Since setting sustainability at the core of our decision-making and business strategy in 2018, Yinson has endeavoured to progressively improve on the identification, monitoring and reporting of our ESG impacts, even as the understanding of sustainability itself matures against a rapidly evolving business and economic landscape.

‘30 by 30’ marks a significant milestone in Yinson’s ongoing sustainability journey, culminating all our learnings, commitments and aspirations into a single declarative set of our most material targets that we are committed to measuring and reporting against.

OGI: Could you share about Yinson’s plans for the future in regard to climate action as a key industry player within the energy landscape?

YINSON: Yinson has recently performed a TCFD Climate Risk Assessment involving transition risk exposures such as policy, market, reputation and technology. Following the assessment, we have decided to develop an Internal Carbon Pricing Framework with a revised incremental carbon price, which we will pilot for carbon-intensive business units. When the framework is in place, we intend to establish a Sustainable Investment Fund to invest in low-carbon projects that support and accelerate the energy transition. This is one

of the initiatives we are working on to manage climate-related transition risks and accelerate the implementation of solutions that contribute to the decarbonisation agenda.

Furthermore, Yinson is formalising a commitment to have at least 30% of equity in non-oil-based FPSO activities by 2030, solidly demonstrating our commitment to purposefully directing capital to support the energy transition agenda.

OGI: What are some key projects Yinson Production is currently working on around the world?

YINSON: Yinson Production is excited to establish operations in Angola and partner with Azule Energy for the development of FPSO Agogo. We are privileged to be given the opportunity to design, construct and operate, what will be, our most complex FPSO. Our highly experienced team is designing FPSO Agogo to incorporate our Zero Emissions FPSO Concept, as far as possible, optimising operations, while minimising carbon emissions and achieving the highest safety standards. This is a fast-track development where we are fully committed in supporting our client Azule Energy and the Angolan energy sector going forward.

OGI: Could you explain further about the work Yinson Production is doing in Brazil?

YINSON: In May 2023, we achieved first oil on FPSO Anna Nery operating at Petrobras’ Marlim field, in the Campos Basin. FPSO Anna Nery marks Yinson’s first FPSO operating in Brazil, with a charter duration of 25 years. We also have two other FPSOs under construction bound for Brazil; including FPSO Maria Quitéria for Petrobras’ Jubarte field, in the Campos Basin and FPSO Atlanta for Enauta’s Atlanta field.

To support successful operations, we have established our Rio de Janeiro office with a highly experienced team. We believe that the FPSO market in Brazil has huge potential and thus we would like to support the development

of offshore energy infrastructure with our emission-lowering technologies and contribute towards the country’s socioeconomic development.

OGI: Finally, digitalisation seems to be a key development area in the industry. Could you please enlighten our readers on your plans for digitalisation?

YINSON: Digitalisation is a crucial factor in Yinson Production, where digital tools and data are enablers for our human capital to reduce human risk exposure, increase efficiency and enhance sustainability in terms of the environment and economy.

Investments in areas like 3D printing, drones, and cloud-based platforms have advanced our FPSO business and these culminate in Project Polaris, an initiative aiming to develop leading-edge, fully autonomous, and sustainable FPSO solutions.

Project Polaris, centered around FPSO Helang, offers scalable enterprise system integration, predictive maintenance, and a unified operations center for datadriven decision-making. The contextualisation and automation of data will enhance the integration of existing engineering tools, enabling efficient decisionmaking throughout the asset lifecycle and develop sustainable solutions for the business, our stakeholders and the industry.

Yinson Holdings Berhad E: info@yinson.com W: https://www.yinson.com

Schlumberger and Subsea 7 Renew Global

Subsea Integration Alliance

Seven-year agreement to continue development of subsea solutions for deepwater developments

Schlumberger and Subsea 7 announced today that they have signed an agreement to renew Subsea Integration Alliance for a further seven years.

Subsea Integration Alliance is a worldwide non-incorporated alliance between Subsea 7 and Schlumberger’s OneSubsea® subsea technologies, production and processing systems business, to jointly design, develop and deliver integrated subsea development solutions through the combination of subsurface expertise, subsea production systems (SPS), subsea processing systems, subsea umbilicals risers and flowlines systems (SURF), and life-of-field services.

“The success of Subsea Integration Alliance is a result of the drive and commitment of both Subsea 7 and OneSubsea to deliver an enhanced experience and outcome for our clients,” said John Evans, Subsea 7 Chief Executive Officer. “Driven by the demonstrable benefits to clients of this mode of collaborating, integrated projects are expected to remain a significant component of the subsea market. We look forward to extending our relationship with OneSubsea as we address the opportunities of the offshore energy market.”

Over the past seven years, the alliance has successfully combined the complementary capabilities and market-leading technologies of OneSubsea and Subsea 7, and worked collaboratively with clients to design, develop and deliver integrated SPS and SURF solutions proven to optimize the cost and efficiency of deepwater developments.

The alliance continues to build momentum and, in recent years, has been awarded major greenfield projects in Australia, Brazil, Africa and Turkey, as well as significant tie-back work in the Gulf of Mexico and Norway. Since January 2020, Subsea Integration Alliance has won the majority[1] of integrated SPS and SURF projects worldwide.

“Subsea Integration Alliance has proven to be a tremendous success,” said Abdellah Merad, EVP, Core Services and Equipment, Schlumberger. “Having been awarded 12 integrated projects and more than 130 early engineering studies around the world, it has helped—and will continue to help—customers achieve maximum value from their subsea developments through industry-leading innovation and expertise.” •

Shell plc First Quarter 2023 Dividend Payments

TheBoard of Shell plc today announced the pounds sterling and euro equivalent dividend payments in respect of the first quarter 2023 interim dividend, which was announced on May 4, 2023 at US $0.2875 per ordinary share.

Shareholders have been able to elect to receive their dividends in US dollars, euros or pounds sterling. Holders of ordinary shares who have validly submitted US dollars, euros or pounds sterling currency elections by June 5, 2023 will be entitled to a dividend of US$0.2875, €0.2678 or 22.99p per ordinary share, respectively.

Absent any valid election to the contrary, persons holding their ordinary shares through Euroclear Nederland will receive their dividends in euros at the euro rate per ordinary share shown above. Absent any valid election to the contrary, shareholders (both holding in certificated and uncertificated form (CREST members)) and persons holding their shares through the Shell Corporate Nominee will receive their dividends in pounds sterling, at the pound sterling rate per ordinary share shown above.

Euro and pounds sterling dividends payable in cash have been converted from US dollars based on an average of market exchange rates over the three dealing days from June 7 to June 9, 2023. This dividend will be payable on June 26, 2023 to those members whose names were on the Register of Members on May 19, 2023. •

Eni and Vår Energi to Acquire Neptune

Eni

S.p.A. (“Eni”) is pleased to announce that along with Vår Energi ASA (“Vår”) it has reached an agreement to acquire Neptune Energy Group Limited (“Neptune”).

Neptune is a leading independent exploration and production company with a world-class portfolio of gas-oriented assets and operations in Western Europe, North Africa, Indonesia and Australia. The portfolio is competitive in terms of cost and low in operational emissions. Neptune was founded in 2015 by Sam Laidlaw and is currently owned by China Investment Corporation, funds advised by Carlyle Group and CVC Capital Partners, and certain management owners.

Eni will acquire assets comprising Neptune’s entire portfolio other than its operations in Germany and Norway (the “Neptune Global Business”) (the ‘’Eni transaction’’). The German operations will be carved out prior to the Eni transaction and the Norwegian operations (the Neptune Norway Business’’), will be acquired by Vår directly from Neptune under a separate share purchase agreement (the “Vår transaction”) (the Eni transaction and the Var transaction together comprising the “transaction”).

The Vår transaction will close immediately prior to the Eni transaction with the proceeds from the Norway sale remaining with the Neptune Global Business purchased by Eni. Vår is a company listed on the Oslo Stock Exchange and is 63% owned by Eni.

Under the agreed terms, the Neptune Global Business will have an Enterprise Value of c.$2.6bn, while the Neptune Norway Business will have an Enterprise Value of c.$2.3bn. As of 31 December 2022, net debt of the Neptune Global Business, pro forma for the sale of the Neptune Norway Business, was c.$0.5bn. The final net consideration for both transactions will be subject to customary closing adjustments and will be paid in cash at completion. The Eni transaction will be funded through available liquidity.

The transaction represents an exceptional fit for Eni. It complements Eni’s key areas of geographic focus and supports its objective of increasing the share of natural gas production to 60%, and reaching net zero emissions (Scope 1+2) from the Upstream business by 2030. The transaction aligns with Eni’s strategy of providing affordable, secure and low carbon energy to society, for which natural gas remains an important source. The transaction is also consistent with Eni’s operating and financial framework, as well as the targets set out in Eni’s 2023-2026 Plan, delivering earnings and cashflow accretion, additional shareholder value and remuneration upside.

Specifically, the transaction has the following benefits:

• As of 31 December 2022, reported 2P reserves of c.484 million boe of which c.386 million boe are net to Eni’s portfolio[1], and of which c. 80% is natural gas. The transaction equates to a 2P acquisition cost of $10.1/boe. In addition, there is significant additional contingent resource

upside.

• For the year ended 31 December 2022, Neptune reported revenues of c.$1.22bn and EBITDAX of c.$0.95bn for the Neptune Global Business.

• The transaction will add around 130 kboed[2] to the Eni and Var portfolios. From this, Eni estimates the transaction will add more than 100 kboed of low emission production1 over 2024-2026, of which more than 70% will be natural gas (compared to 53% for Eni in 2022), with almost all of that amount capable of supplying OECD markets via pipeline or LNG.

• Eni expects to generate G&A and industrial synergies to a value of over $0.5bn, with additional cost synergies, exploration and development including more CCS, financial and midstream value upside potential.

• The transaction is expected to be immediately accretive to earnings and CFFO per share, as well as free cashflow positive. It is also consistent with the 2023-2026 Plan presented in February 2023, in particular the guidance of:

- €1bn net positive contribution from portfolio activities over the period

- €37bn of organic capex over the period

- Leverage within a 10% to 20% range

- Achieving 2023-26 production CAGR of 3-4% predominantly through organic investment plus the net impact of inorganic high-grading activities. This will see Eni integrate new assets that deliver additional value, while divesting others as it restructures and simplifies its portfolio.

Commenting on the transaction, Eni’s CEO, Claudio Descalzi, said ‘’This transaction delivers to Eni a high-quality and low carbon intensity portfolio with exceptional strategic and operational complementarity. Eni sees gas as a critical bridge energy source in the global energy transition and is focused on increasing the share of its natural gas production to 60% by 2030. Neptune will contribute predominantly gas resources to Eni’s portfolio. Moreover, the geographic and operational overlap is striking, adding scale to Eni’s majority-owned Vår Energi; bringing more gas production and CCUS opportunities to the remaining North Sea footprint; building on Eni’s leading position in Algeria – a key supplier to European gas markets; and deepening Eni’s presence in offshore Indonesia, supplying the Bontang LNG plant and domestic markets. We also expect the added supply to provide further optimisation opportunities for Eni’s GGP operations. Indeed, we see the transaction adding around 4 Bcm of gas supply for European consumers. A critical element of the transaction is also the low-cost supply and accretive cashflow it provides to Eni. It therefore supports our commitment to an attractive and resilient dividend and adds to the potential for share buybacks that make up the balance of the 25-30% of CFFO we have committed to distribute. The nature and challenges of the energy transition require a focused response and in particular this transaction highlights two important aspects of Eni’s financial strategy – the flexibility and optionality that our strong liquidity and low balance sheet leverage offer; and our innovative satellite model which helps to align and access dedicated capital”. •

Decarbonizing Industry in France: TotalEnergies to Supply Certified Sustainable Biomethane to Saint-Gobain

TotalEnergies has signed a 100 GWh biomethane purchase agreement with Saint-Gobain France for a three-year period starting in 2024.

The biomethane will be produced by TotalEnergies at its BioBéarn biomethane plant, which came on stream at the beginning of the year and whose production is certified sustainable by ISCC1 under the highest sustainability criteria of the European Union REDII Directive. TotalEnergies is one of the very first producers to obtain this certification in France.

By acquiring the Guarantees of Origin, and thanks to their sustainable certification, Saint-Gobain will be able to attest, within the framework of the EU Emissions Trading Scheme, to the decarbonization of its energy consumption in France. This contract is also an example of a purely commercial sale, i.e., nonsubsidized, of biomethane.

“With this contract, TotalEnergies is supporting Saint-Gobain in its efforts to reduce greenhouse gas emissions in France, in line with TotalEnergies’ ambition to help its customers decarbonize their activities. It is also a first step towards the emergence in Europe of a merchant biomethane market, allowing the development of production without public subsidies,” said Stéphane Michel, President Gas, Renewables & Power at TotalEnergies. “This contract is also in line with our ambition to actively participate in the development of biogas in France, and more widely in the world.”

“The signing of this contract opens up promising prospects for biomethane players to develop infrastructures on the French territory. This first for Saint-Gobain in France demonstrates the intention to diversify the sourcing of decarbonized energy, supporting the development and viability of new local energy networks. This decarbonized energy supply is also part of Saint-Gobain’s commitment to reduce its CO2 emissions by 33% (from scopes 1 and 2) by 2030 compared with 2017, and to reach carbon neutrality by 2050”, said Thierry Fournier, General Director of Saint-Gobain France. •

Intrinsic and Siemens Collaborate to Accelerate the Integration of AI-Based Robotics and Automation Technology

• Collaboration to make industrial robotics more accessible and usable for manufacturing SMEs

• Exploration of new solutions to advance interoperability and more efficient interfaces between automation and robotics systems to address existing hurdles and cost drivers

• Solutions to speed up the development process for flexible work cells and facilitate their operation

Intrinsic, an Alphabet company, and Siemens have teamed up to explore integrations and interfaces between Intrinsic’s robotics software, which is designed for easy use of AI-based capabilities, and Siemens Digital Industries with their open and interoperable portfolio for automating and operating industrial production.

Intrinsic has a world-class team of robotics and AI experts with a strong footprint in advanced perception, machine learning and reinforcement learning. Siemens’ automation engineers and software developers have industry-leading domain know-how in automation technology in the industrial space.

Currently, the development and runtime environments for AIbased robotics and automation components differ significantly in their development paradigms and make integration cumbersome. For example, deploying advanced robotic capabilities such as pose estimation, robot manipulation or automated path planning are complex processes that typically require teams of domain experts to operationalize. The two companies intend to investigate new methods to seamlessly bridge the gaps between robotics, automation engineering and IT development.

Bridging both worlds will speed up the development process of flexible, AI-enabled robot work cells and facilitate their seamless operation. This will make industrial robotics more accessible and usable for more businesses, entrepreneurs, and developers - particularly for new market segments like small and mediumsized companies.

“Intrinsic’s mission is to democratize access to robotics. However, robotics is rarely decoupled from the production environment, where the most value is created today,” says Wendy Tan White, CEO at Intrinsic. “That’s why working with Siemens Digital Industries, an industry leading automation expert, is an exciting opportunity to bring joint solutions to the market in the future, so many more businesses can benefit from the value that robotics and automation can offer.” “Siemens is dedicated to bringing IT and OT closer together – the key principle of our Industrial Operations X portfolio”, says Rainer Brehm, CEO of Factory Automation at Siemens. “We are impressed by Intrinsic’s open approach to industrial robotics and we are excited to explore with Intrinsic how coupling of AI-based robots and automation technology can be further accelerated.”

Both Siemens and Intrinsic will be exhibiting at automatica 2023, the leading trade fair for intelligent automation and robotics, in Munich, Germany, from 27 – 30 June. On Tuesday 27 June, 1 –2 PM CET, Intrinsic CEO Wendy Tan White and Rainer Brehm, CEO Factory Automation at Siemens, will join the munich_i CEO Round Table, “Software: revolution for automation and robotics?”

Storage Tank Inspection

Get started with the Scout 137 Drone System -

Drone Inspection With Live Streaming

A key advantage of the Scout 137 Drone System is that the inspection data is locationtagged. Algorithms for simultaneous localization and mapping based on data from the onboard Lidar are used to create a 3D map in the form of a point cloud of the asset. In addition, the position and heading of the drone is estimated at every point in time. This means that, at any time, you are able to see where the drone is and where it’s headed; live while flying or in post while reviewing the inspection data.

Case Study: Storage tank inspection for Equinor at Mongstad refinery (photo, bottom right).

The scope of the Mongstad mission was to deploy the Scout 137 Drone System and perform an inspection inside a large cylindrical storage tank. The inspection would demonstrate the current capabilities of the drone system itself, as well as the remote inspection capabilities enabled via the Scout Portal.

The Mongstad mission was a success, both in terms of on-site performance and the value for the remote audience. The drone was easily deployed to gather all the data with a minimum of preparation and on-site overhead.

New BM26A-8000 Completes Series of Magnetic Level Indicators

• KROHNE completes the market launch of the new BM26A series of Magnetic Level Indicators (MLI)

• With over 65 years of experience, the current generation aims to be the most versatile and competitive MLI series on the market

• Standard designs for high or low temperature/pressure applications, wide range of accessories and options

With the introduction of BM26A-8000, KROHNE completes the market launch of the new BM26A series of Magnetic Level Indicators (MLI) in 2023. Replacing the previous generation, the devices are designed according to specific industry needs.

Initially introduced in 1955, the BM26 series has been one of the longest running designs of level measurement instruments. With over 65 years of experience in manufacturing and application of this device type, KROHNE developed the current generation to be the most versatile and competitive MLI series on the market. While the rugged design has not changed, a wide range of options have been added, and former special designs are now available as standard.

BM26A is available for measuring ranges from 0.3 m / 1 ft up to 5.5 m / 18 ft (other dimensions on request). Accessories and options include e.g. valves, thermal insulation, various materials, limit switches, hazardous area approvals, interface measurement, or designs for extreme operating conditions. Depending on the application, communication options for BM26A reach from local indication without external power supply to optional reed switches or reed-chain level transmitters providing analogue or digital output signals.

The BM26A series in detail:

BM26A-1000 for basic liquid storage applications up to +200°C / +392°F and 40 barg / 580 psig. The cost-effective level indicator is particularly suitable for continuous level measurement in water storage tanks, condensate receiver tanks as well as wash and surge tanks for fuels, lubricates, additives or similar chemicals.

BM26A-3000 for corrosive liquids up to +100°C / +212°F and 6 barg/ 87 psig. Made from corrosion resistant PVC, PP or PVDF, the level gauge is the perfect fit for continuous and safe level measurement in plastic or lined storage tanks, reactors, fermentation vessels or containers with aggressive chemicals such as sulphuric acid.

BM26A-5000, the bypass chamber (no float) for TDR guided radar, FMCW Radar or Displacer level transmitters, ensures ideal conditions for reliable and accurate level measurement under extreme operating conditions e.g., agitated product surfaces, -196…+400°C / -320.8…+752°F, ≤ 400 barg / 5801 psig, in industries such as Chemical, Oil and Gas.

BM26A-6000 for liquefied gas and cryogenic applications. The level gauge aims at continuous level measurement in process or storage tanks containing low temperature media like liquefied ammonia (NH3), liquefied carbon dioxide (CO2) or liquefied

propane. The MLI comes with various thermal insulation options for use in process temperatures down to -196°C / -320.8°F.

KROHNE completes the market launch of the new BM26A series of Magnetic Level Indicators in 2023

BM26A-7000 for extreme operating conditions and liquid interface applications up to +400°C / +752°F and 400 barg / 5801 psig. It is particularly suitable for continuous level measurement of high-temperature or high-pressure liquids in chemical, petrochemical and refining processes or in boiler applications of various industries. It is equally suitable for interface measurement in oil/water separators or similar installations. For level monitoring of corrosive products in pressurised tanks up to 40 barg / 580 psig, the PTFE-lined version of the MLI is the instrument of choice.

The new BM26A-8000 for redundant level measurement in liquid applications is available in two versions: the BM26A8000-TWIN consists of a double measuring chamber with one chamber featuring a flapper indication, and the other one acting as a bypass chamber equipped with a TDR guided radar, FMCW radar or displacer level transmitter.

The BM26A-8000-BI version features a unique measuring chamber with two compartments, one for the OPTIFLEX 7200 TDR transmitter probe and one for the float moving next to it.

By adding a reed-chain transmitter to these assemblies, the operator can compare the measuring values of the assembled radar level transmitter to those of the reed chain transmitter directly in the control room. This allows for redundant measurement as both technologies operate independently and uninfluenced from each other, providing a high degree of process safety in critical applications.

The BM26A-8000 can thus be the ideal choice for steam cycle applications in power plants, storage tanks with dangerous chemicals, separators in the oil and gas industry as well as a wide range of other level and interface applications. Depending on the selected configuration, the magnetic level indicator can also be used in safety-related applications up to SIL 2/3. •

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Eni: European Commissioner for Transport

Visits the ‘Eni 2050 lab’ Technology Hub at the Gazometro in Roma Ostiense

Today Eni welcomed the European Commissioner for Transport, Adina-Ioana Valean, at the “Eni 2050 lab” technopole, located within the architectural context of the Gazometro in Roma Ostiense, an Eni-owned complex currently undergoing transformation with the aim of creating the first technological innovation district dedicated to new energy supply chains and open to applied industrial research in collaboration with academic and research institutions.

During the visit, Eni illustrated to the Commissioner its proprietary breakthroughs at the heart of the company’s decarbonisation strategy, highlighting how each new result obtained by Eni’s research contributes to achieving its Net Zero objective by 2050. The lab bases its approach on the principle of technological neutrality, according to which there is no single solution for achieving the energy transition, but rather a technological mix adaptable to different applications and needs.

Eni shared with the Commissioner the most significant results accomplished by its R&D in the fields of renewables and new energies, decarbonisation solutions, and circular and bio products. Particular emphasis was given to development projects on agro-energy, such as, the EcofiningTM technology used to obtain biofuels from waste and raw materials of biological origin that do not compete with food use. Additionally, the tour highlighted key scientific collaborations with the Massachusetts Institute of Technology (MIT), Commonwealth Fusion Systems (CFS), ENEA and CNR in fusion energy research. Some research results on new renewables and energy storage was also presented, as well as systems and products in the field of CO2 capture, storage and utilisation.

Finally, the Commissioner was presented with a number of start-ups from the acceleration programmes of Joule, Eni’s Business School, which aims to support the growth of sustainable companies and, the ROAD project, Rome Advanced District, a network of companies formed by Eni, Acea, Autostrade per l’Italia, Bridgestone, Cisco, Gruppo FS and NextChem (MAIRE), which aims to create supply chain collaborations in researchusing the Gazometro asset as a ‘living lab’ for the experimentation of emerging technologies to support the community - and to teach skills for the development of new professions. •

Subsea 7 extends frame agreement with Aker BP

Subsea 7 today announced an extension of its existing frame agreement with Aker BP for four years to the end of 2028. The agreement covers the provision of engineering, fabrication and installation activities for subsea umbilical, risers and flowlines (SURF) as part of Aker BP’s field developments on the Norwegian continental shelf.

The value of the work to be called off under the frame agreement will be recognised in Subsea 7’s backlog when each new project is sanctioned.

Monica Th. Bjørkmann, Senior Vice President for Subsea7 Norway said: “The continuation of the frame agreement is a testament to our collaboration with Aker BP. The strategic partnership enables Subsea 7 to engage early in the field development process, optimising design solutions and contributing to positive final investment decisions for future projects on the Norwegian continental shelf”. •

Energy Sectors Poised for Growth

Energy Industries Council’s report sees Qatar’s LNG investments solidifying its position as the world’s leading exporter of the commodity.

Qatar, the world’s top exporter of Liquified Natural Gas, is poised to ramp up its production of hydrocarbon, especially of LNG, as energy producers from around the world vie to make up for lost supplies resulting from Russia’s war on Ukraine, according to a report by the Energy Industries Council, one of the world’s largest energy trade associations.

Qatar aims to bolster its position as a key contributor to the energy transition, supported by its abundant reserves of natural gas, the report said. The Arab Gulf state currently has 18 projects under development across the oil and gas sectors, with an estimated capital expenditure (CAPEX) of $60.2 billion.

According to the report, Qatar aims to substantially increase its liquefied natural gas (LNG) production from 77 million metric tonnes per annum (mtpa) to 126 million mtpa by 2027. Multiple contracts worth billions of dollars have already been awarded by QatarEnergy, the state-owned energy company, for the construction and expansion of LNG facilities. Qatar’s ambitious LNG expansion plans reinforce its position as the world’s largest LNG exporter.

The downstream sector is also set to see significant growth through the Ras Laffan Petrochemical Project (RLPP). QatarEnergy, in partnership with Chevron Phillips, has made a final investment decision (FID) to advance this project.

Despite a decline in hydrocarbon revenues in 2020 due to the COVID-19 pandemic, Qatar’s oil and gas industry has remained highly active and is projected to play a crucial role in the country’s economy for the foreseeable future. Approximately 80% of Qatar’s LNG is directed towards Asian markets, catering to the region’s growing demand.

The report also touched on Qatar’s efforts to strengthen its presence in the renewable energy sector. The country aims, as part its Sustainability Strategy, to generate 5 gigawatts (GW) of solar power by 2035. To achieve this goal, QatarEnergy has awarded engineering, procurement, and construction (EPC) contracts for two solar projects in Ras Laffan and Mesaieed.

Qatar has set targets to reduce emissions across all sectors by 25% by 2030. QatarEnergy’s Sustainability Strategy further aims to decrease carbon intensity by 25% in upstream operations and 35% in LNG facilities by 2035. The company also plans to implement carbon capture and storage technology to capture over 11 million tonnes of CO2 annually by 2035. •

AF Gruppen Rehabilitates Office Building

Strøm Gundersen Vestfold, a subsidiary of AF Gruppen, has been chosen by Larre Eiendom AS as the contractor for the total rehabilitation and extension of Storgata 1 in Sandefjord. The contract is a turnkey contract in collaboration and has a value of NOK 126 million excl. VAT.

The contract consists of two construction stages. Construction stage 1 includes design, demolition of existing facades and furnishings, new extension, and addition of a new 6th floor as well as new facades. Building stage 2 includes new core areas and furnishings with associated outdoor works.

Construction stage 1 has begun, while construction stage 2 will start after the summer. The project is to be completed in Q2 2024.

“We greatly appreciate the trust from Larre Eiendom for the rehabilitation of Storgata 1 and look forward to further cooperate with a solid and competent partner”, says Yngvar S. Brekke, General manager of Strøm Gundersen Vestfold. •

Katie Protheroe, Has Been Named Young Employee of the Year

Katie

Protheroe, an engineer at North East business Osbit, has been named Young Employee of the Year, at a prestigious local awards ceremony in Hexham.

The award, organised by the Rotary Club of Hexham, is an opportunity for businesses across the North East to recognise exceptional employees under the age of 25. The winner must demonstrate a positive attitude to work and will have made an important contribution to their organisation and the local area.

Katie, who is aged 24, was nominated for the award for her outstanding efforts in leading the build of an innovative upending hinge system which will be used to help install offshore wind farm turbines across the world. The 1,400-tonne system, which stands at 15 metres high, was designed in the North East, by a team of Osbit’s engineers. As well as helping to design the system, Katie successfully led its build project out in Singapore, managing a team of 25 people and dealing directly with the client.

Osbit, which operates globally, is headquartered in Riding Mill and runs an assembly facility in Port of Blyth. The company specialises in designing and building tailored equipment to enable the construction of offshore wind farms.

Katie, who is from Whickham, joined the business in 2020 having completed her degree in Mechanical Engineering at Newcastle University. Since then, Katie has progressed rapidly, working across a range of highly technical projects, as well as overseeing the Osbit STEM programme and engaging with local education providers to promote engineering as a career to young people.

Upon receiving the award, Katie comments: “It was a privilege to lead the build and commissioning of one of Osbit’s largest and most technically complex systems to date in Singapore and Rotterdam. It is again a privilege to have that work recognised by winning this award. I had the time of my life running the job and the team around me were extraordinary. The experience taught me invaluable lessons within my industry, but also within my own personal development. I am looking forward to continuing my career completing huge, world-first engineering projects within exceptional teams of people.”

At the award ceremony, which took place on 5th June at The Beaumont with sponsors The Reece Foundation and Hexham Town Council, Katie was presented with the Jack Charlton Trophy and £500 towards her personal development.

Osbit Joint Managing Director Brendon Hayward, adds: “The Young Employee of the Year Award is a fantastic recognition of the hard work and dedication that Katie has not only demonstrated on this particular project, but throughout her time with Osbit, and we’re very proud of her.

Supporting talented young people to rapidly develop in the way that Katie is, is very important to us and from the beginning, we have structured Osbit in a way that enables this to happen.

Katie is one of the many incredibly talented young engineers growing with our company and her success is something which we want everyone at Osbit to have the opportunity to experience.

We’re always on the lookout to expand our team with capable individuals and we’re currently recruiting for a number of roles across the business.” •

Government Go-Ahead for Irpa, Verdande and Andvare

The plans for development and operation of the subsea fields Irpa and Verdande, and the production well Andvare in the Norwegian Sea have been approved by Norwegian authorities. The gas field Irpa will be tied back to Aasta Hansteen, whereas the oil field Verdande and the Andvare well will be tied back to Norne.

“We are experiencing a strong demand for oil and gas from the Norwegian continental shelf in the current geopolitical situation. By utilising the Aasta Hansteen and Norne infrastructures, these development projects will quickly bring new production to market with low development costs, while extending the activity on the host platforms,” says Trond Bokn, Equinor’s senior vice president for project development.

The Irpa gas volumes may supply just over 2.3 million UK households with gas for seven years. The gas discovery is located almost 80 kilometres from the Aasta Hansteen field, and the development will extend the field’s productive life by seven years, up to 2039. The discovery also supports the 350 person-years of employment (direct and indirect) associated with the operation of Aasta Hansteen during this period.

Irpa, the second subsea field tied back to Aasta Hansteen, will be the deepest field on the Norwegian continental shelf, at 1350 metres.

It was recently announced that Westcon Helgeland will deliver large parts of the Irpa subsea facility as a TechnipFMC subcontractor. Momek in Mo i Rana is a subcontractor of Aibel, responsible for modifying the platform for Irpa gas tie-in.

Verdande, an oil discovery with some associated gas, will be tied back to Norne. Here, too, the field’s productive life will be extended by several years, which helps support the 900 personyears of employment (direct and indirect) associated with the operation of the Norne field.

Equinor, on behalf of the partners, recently awarded a contract to Aibel where most of the work will be performed by Aibel’s M&M community in Harstad, which will also use other subcontractors in the north. Aibel will also make modifications to the FPSO related to Andvare, a well that will be drilled as a side-track from one of the existing subsea templates on the Norne field.

“For Equinor and our partners, it is important that our activity in the north also has ripple effects here, and the projects will also result in increased and prolonged activity at the logistics base in Sandnessjøen and the helicopter base in Brønnøysund,” says Bokn.

The Ministry of Petroleum and Energy today celebrated the approval of a number of new projects on the Norwegian continental shelf. In addition to being the operator of Irpa, Verdande and Andvare, Equinor is also a partner in Yggdrasil, Berling, Skarv Satellitter and Symra. •

ENGIE Announces the Commissioning in Australia of its Largest Battery Energy Storage System

ENGIE and its partners Eku Energy and Fluence have reached a new milestone in Australia with the commissioning of the Hazelwood Battery Energy Storage System (HBESS).

Located on the site of the former Hazelwood power plant, the Hazelwood Battery Energy Storage System (HBESS) is a utilityscale battery of 150 MW / 150 MWh, making it ENGIE’s largest Battery Energy Storage System (BESS) worldwide. The battery is made up of 342 Fluence modules, providing first-rate reliability and safety. The installed capacity will be able to store the equivalent of one hour’s electricity generated by the solar systems installed on the roofs of 30,000 homes in the state of Victoria and to inject this power into the grid in periods of peak demand. By improving the stability of the electrical grid, HBESS will thus allow development of new renewable energy production capacity in Victoria to be stepped up to meet market demand.

Commissioning of this facility is fully in line with ENGIE’s ambition to ramp up flexibility technologies and accelerate the development of battery storage. HBESS will contribute to the Group’s target of 10 GW of installed battery capacity by 2030, announced last February.

The commissioning of HBESS is part of the site remediation of the former coal-fired power station initiated by ENGIE in 2017, in line with the Group’s strategy to withdraw from coalfired power generation. This first reallocation of former thermal assets to renewable energy technologies in Australia is a concrete illustration of the country’s energy transition and ENGIE’s commitment to its decarbonisation pathway. •

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Well Control Planning and Training Will Help You Weather This Storm Season

By Brad Rosello - Senior Response Specialist, WellCONTAINED, Wild Well Control

The return of the hurricane season to the U.S. Gulf of Mexico is a timely reminder for operators around the world to ensure they have an effective well control emergency response plan in place and an associated exercise program.

This year, the National Oceanic and Atmospheric Administration (NOAA) is forecasting up to 17 named Atlantic storms through November 30. Of these, up to nine could become hurricanes, and up to four major hurricanes. That honestly feels a little lighter than previous years, but still makes me want to dust off the planning cobwebs.

Lestwe forget the lessons taught by Katrina, Rita, Gustav, and Ike in the U.S. Gulf of Mexico, all operators should have an effective and drilled emergency response plan (ERP) as a part of their operational readiness package. Well Control Emergency Response Plans (WCERPs) provide a strategic process for responding to and safely managing well control emergencies. Usually, they form an important subset of a company’s corporate-level allhazards emergency response plan, including those dealing with hurricane response.

As the world’s leading provider of onshore and offshore well control emergency response, pressure control, relief well planning, engineering, and training services, Wild Well Control responds to about 80% of the global well control response market. We have successfully capped hundreds of wells worldwide in various operational environments and know what a good WCERP looks like.

To ensure your emergency well control plan is as robust and ready as it can be, I have inquired with our senior operators, and these are some of the key factors to consider.

An effective plan

For any company involved in well activities, a comprehensive well control plan is essential. It is no exaggeration to say that a detailed plan

could ultimately be the difference between a localized, low-level incident and a catastrophic event such as a blowout. As a result, when considering a well control plan, it is important at the outset to engage with an established and industry-recognized well control company to ensure all processes and safety-critical aspects

of your plan are fully covered.

Before being able to develop your WCERP, you and your plan provider must understand all the assets and operations it will support and gather all relevant data on these assets. Multiple basins in different locations provide their own specific challenges. The characteristics of onshore, offshore, and subsea wells are obviously different from each other. The complexity of subsea wells and the need for specialized equipment to access them means they require their own dedicated and highly detailed Source Control Emergency Response Plan (SCERP). Only subsea wells have dedicated capping systems; for other wells, companies are advised to ensure they have quick access to wellhead components in the event of a blowout and a need to rehead the well. A good well control planning provider will invest time in exploring all their customer’s logistics, organization details, and operations to create the best tailored solution. Well control emergency response plans should be developed with essential personnel before the start of any drilling operations. A good plan will establish well control levels

based on a primary and secondary barrier system. It will also align with your overall incident level and risk tolerances. It will define well control incident levels so that all personnel from operators, drilling contractors, and other sub-contractors, understand your expectations regarding well control and well barrier philosophy.

Wild Well Control’s WCERPs are strategic in nature and are built upon three sections: an actionable section, emergency response organization, and the provision of supporting information.

Well Control Incident Levels

Wild Well Control uses three general risk response levels in planning for an emergency:

Level 1 – identification of a pending loss of a barrier or a complication in a well. These may be lower-risk situations with an established procedure, and companies may be able to handle the issue without calling in third-party support.

Level 2 – confirmed loss of a barrier. This will often require external support to develop a tailored plan of action and response to the issue.

Level 3 – loss of well control - hydrocarbons to the surface or subsurface – a blowout.

Sometimes, companies structure their incident levels differently, and Wild Well Control will adapt its three-level process to your requirements to ensure complete clarity and understanding of the process by everyone.

With well control incident levels established, the plan must also include the necessary initial notifications and responsibilities at the outset of a declared well control event. This may involve organization charts in line with your incident management philosophy. Completing this step creates a clear definition of how a well control emergency is to be declared, as well as who is responsible and what initial notifications must

The Checklist

The decisions and actions taken in the period immediately after a well control event has been declared can have a crucial bearing on the incident’s outcome. An easy-to-follow preagreed checklist for initial strategic response actions can provide the process structure you need at what is often a highly confusing time and is critical to a timely response. Following checklists will ensure the appropriate steps are taken to mobilize incident management teams and resources. The checklist will also help responders as they progress from a reactive to a proactive position during a well control emergency. Documenting all the actions taken will assist post-incident investigations.

Resources

A robust well control plan will identify resources necessary to respond to a well control event. This may include mutual aid support, multiple vendors for selected equipment, as well as a plentiful supply of water. Pre-identifying personnel and equipment that may support your team in a well control incident will reduce overall response times and ease the crush of logistics at the onset of the response.

Practice! Once the WCERP is published, we must share our response strategy and expectations with first responders and regulatory bodies. This is often accomplished during exercises and workshops where relationships are built before an incident occurs and broadens our scope of resources. Ultimately this should make our initial

notifications much easier and pave the way for a successful response.

Success! Having a robust WCERP that your team has exercised against and is familiar with is one of the key elements to having effective risk management and an emergency preparedness strategy. Exercises can be extremely valuable in highlighting any weak spots in the plan, allowing these to be rectified before it is too late.

Many companies carry out training on an annual basis, but this can vary depending on your regulatory environment. Training delivered by Wild Well Control is tailored and modified to your requirements. It can range from short sessions of a couple of hours or plan review in a half-day workshop, to a whole-day table-top event or the penultimate full-scale exercise that includes first responders and public stakeholders.

Trust the experts

Wild Well Control can help you with all aspects of your well control emergency response plan and training from the North Sea to Asia-Pacific theaters of operation. So, when the time comes to put your plan into action, you’re as ready as you can be.

In this video (QR code below), I offer more insights on what you need for a good well control emergency response plan. Let’s make sure you’re ready. Contact us:

Wild Well Control

T: +1 281.784.4700

W: https://www.wildwell.com

E: info@wildwell.com

Keeping an Eye on Flares: Thermal Imaging Techniques for Remote Flare Monitoring

By Lenny Shaver, Director of Strategic Marketing, Critical Sensing and

Control Products at Advanced Energy.

Maintaining proper control of flare stacks not only helps oil and gas companies comply with legal requirements related to environmental monitoring, it is also critical to ensure personnel safety and protection of facility assets. Non-compliance with the strict rules governing flare stack control can result in harmful gases being released into the environment, substantial fines for operators, the need for costly shutdowns and severe implications for the protection of employees working at the facility.

Flare systems are subject to strict controls and regulations such as those of the Environmental Protection Agency (EPA) that stipulate the need for continuous pilot flame monitoring and mandate that the pilot flame must always be present when regulated material is routed to the flare.

Maximum achievable control technology (MACT) regulations that came into effect in January 2019 demand flare management plans (FMPs), plans for Continuous Parameter Monitoring Systems (CPMS) and further requirements around visible emissions and flare tip velocities.

Effective control means that having real-time insight into pilot flame and flare conditions helps ensure that:

• Vented gases are ignited in a carefully supervised way and burn with optimum efficiency

• The possibility of uncontrolled ignition is eliminated

• Operators are immediately alerted to potential problems, including lost combustion

Should combustion be lost for any reason, the plant operator needs to know immediately to reignite the flame and avoid production stops. This demands a reliable method to continuously monitor flare stacks to make sure they are operating correctly.

The challenges of flare monitoring include inaccessibility, particularly with offshore platforms that are located far from land and can be difficult to access. In addition, while most stacks operate in very harsh environments, offshore platforms face additional challenges such as high winds, waves and storms that can impact the performance of monitoring equipment. Irrespective of location, there is the challenge of emissions variability –flares can vary in terms of their composition, temperature and flow rate.

Equipment for Monitoring

There are many international legislations that operators need to observe with respect to effective flare monitoring, including U.S. Environmental Protection Agency (EPA) regulation 63.987, which states: “Where a flare

is used, the following monitoring equipment is required: a device (including but not limited to a thermocouple, ultra-violet beam sensor or infrared sensor capable of continuously detecting that at least one pilot flame or the flare flame is present.” Further EPA regulations specify how monitoring and compliance records must be kept (63.988) and reported (63.999).

The conventional approach to pilot flame monitoring is to insert a thermocouple directly into or very close to the flame. This relatively crude but effective approach is known as “in process” monitoring. It indicates the presence of a flame and gives very limited information such as the temperature of the flame. While effective, in process monitoring is far from reliable as the thermocouple is regularly exposed to thermal shocks in a highly corrosive environment. Consequently, the working lifetime is highly unpredictable and is often measured in months. Once the thermocouple fails, the operator faces a very difficult choice – continue operating and risk releasing undesirable gas to the environment

or shut down operations for a very expensive repair.

In addition, the simplicity of the ‘pilot light presence/absence’ thermocouple solution means that it does not automatically address other conditions that should be monitored and managed, either to meet the latest legislative requirements or because they can give operators additional insight that helps optimize the production process. This includes flare composition, temperature and flow rate.

Because of these reasons, there is a growing move towards remote, imaging-based monitoring solutions. In addition to addressing the inherent challenges related to thermocouples, such systems can monitor both the pilot and the flare from more easily accessible, less hazardous areas.

Remote Flare Monitoring

The options for remote monitoring typically fall into two categories – conventional CCTVtype cameras and infrared imaging. Operating in the visual light spectrum means that standard CCTV cameras do not necessarily detect gases that can burn without color, making them an unreliable solution for detecting flare events. In addition, they do not cope well with ambient conditions such as moisture, heavy rain or fog. The need for an operator to continually monitor the flare also increases costs and introduces the possibility of human error.

As a result, more and more operators are choosing to install remote flare monitoring systems built around infrared thermal imaging techniques such as Advanced Energy’s FlareSpection™ infrared camera system. Designed for continuous and automatic pilot flame and flare stack monitoring, this system can be used to measure multiple stacks simultaneously while resolving each individual pilot flame and flare.

FlareSpection works by bringing together a high-resolution 640 x 480 pixel thermal imaging

camera and high magnification optics, which are housed in an explosion-proof, stainless steel enclosure that protects the system in harsh environments and hazardous areas.

As a non-contact solution, the system can be mounted in safe areas at distances of up to 300m from the target while still providing clear focus irrespective of weather conditions. Furthermore, while many visual inspection systems need to avoid the annual sun’s path, this is not as critical for IR-based systems that can precisely pinpoint a specific measuring spot on the pilot flame or the flare. The wavelength of an infrared detection system typically allows for installation with

a detection spot size within 6 degrees of the sun’s annual path without generating a false signal.

Additional Considerations

Today’s thermal image flare stack monitoring systems are more than just a camera. Equally important is software that records, analyzes and transforms the flare stack and pilot flame data into useful and actionable information for plant operators.

Integrating with a plant’s distributed control system (DCS) via protocols such as Modbus and OPC, Advanced Energy’s FlareSpection software offers intuitive image and data displays to provide better understanding of the thermal characteristics of the flaring process. In addition, it can also log performance, record video and provide alerts for measurements that may fall outside of preset limits. The ability to provide thermal snapshots, real-time camera feeds, captured sequences and temperature profiles over large areas or precise pinpoint locations further contributes to information that supports process characterization, control and safety goals. Finally, connection to I/O relay switches allows for integration with flare re-ignite systems. •

If you would like to know more about the topics discussed in this article, or would like to know more about Advanced Energy’s solutions please contact them at:

Advanced Energy

W: https://www.advancedenergy.com

E: info@aei.com

T: +44 800 032 1546

Sustainability and the New Circular Economy: Today’s and Tomorrow’s Solutions.

It is commonly acknowledged that a circular economy with novel ways is the key to a clean, green future as resilient sustainability emerges as the preferred method of development. The linear economic method has historically been effective for development, but it has also contributed to increased expenses, pollution, and wastage, as well as being unpredictable over time.

In contrast, the circular economy promotes a cyclical approach to resource use and operations, which is a tactic that is by nature sustainable. The 4Rs (reduce, reuse, recycle, and remove) are the foundation of the circular economy, which aims to reduce greenhouse gas emissions. Economic growth is no longer reliant on resource consumption thanks to circularity. By investigating and embracing the possibilities provided by conservation, recovery, reuse, and finally recycling, there by building a sustainable economic development.

Similar to other industries, the oil and gas sector can also benefit from the application of circular economic principles to address numerous difficulties with wastage and utilization. Economic models that are linear are typically used in such industries. Using waste by-products, new beneficial products are created, some of which include water, gas, and even hydrogen. According to the circular economic model, production and consumption are streamlined, if these 4 requirements are met:

• Reusing

• Repairing

• Refurbishing

• Recycling

Dr. Adam Sieminski, president of KAPSARC, a non-profit research think tank in Saudi Arabia, stated that “hydrocarbons can continue to play an important role during the transition

towards net-zero, as long as carbon capture utilization, storage, recycle, and reuse options are incentivized” during IP WEEK, the international event for the oil and gas industries. Based on these, the fundamental principles of a circular economic approach are as follows:

Shift in design thinking: Where waste and pollution are minimized or eliminated during the design process. In the case of building, at BRIDGES2000, the design strategy must likewise place a high priority on high-quality, tough, long-lasting materials and machinery.

Life Extension: Of materials and resources that can be maintained, repaired, or refurbished to extend their useful lives

Reassessing the need: Considering current resources while determining the true requirement before building or creating.

For BRIDGES2000, it is crucial to think about whether an addition to an existing asset will meet the need. Additionally, reporting against circular economy indicators is required by planning regulations and green building certifications for new environmentally friendly structural fabrications.

Multi-purposing: It can be used for everything and anything to prevent redundancy Being adaptable and flexible: Preventing trash from ending up in landfills, being burned, or being released into the environment, waste should be disassembled, decommissioned, or recycled both throughout the construction or creation process and at the end of its useful life.

Modular construction and prefabrication: By utilizing prefabrication and modularity solutions, many construction-related tasks may now be completed off-site, resulting in significant cost savings and improved efficiency. This helps to promote sustainability. Although prefabrication and modular construction are not a new idea, they have become the main method for creating highperforming, low-carbon buildings as a result of technological advancements and growing utilization.

Technology: A major game-changer for the building sector is advanced technology. It has facilitated before unthinkable efficiencies and facilitated the transition to sustainability. The procurement of materials, real-time integration of processes, resource management, scheduling, and a host of other tasks are increasingly being handled by eco-friendly, green building projects using

augmented reality, drones, data analytics, artificial intelligence, and cloud technologies.

Technology solutions like 5D Building Information Modeling (BIM) have greatly enhanced sustainability plans, particularly ones related to Net-zero emissions, by enhancing accuracy, timetables, budgets, and scenarios.

Using smart retrofits: From a sustainability perspective, the growth of new developments is concerning, but smart retrofitting offers a potential remedy. It not only updates older structures for more contemporary or expansive use, but also generates sustainable energy efficiency. Smart retrofitting focuses on extensive repairs or refurbishments that provide sustainable benefits over the long term, makes better use of resources, and employs cuttingedge technology like the Internet of Things (IoT) to upgrade the infrastructure.

Innovations: Green building components are no longer difficult to find. There are numerous options available. In addition to being energyefficient, aluminum foam, hydrogel, and breathe blocks are also comprised of recycled and recyclable materials. Other sustainable choices are becoming more popular, like superhydrophobic cement and bamboo-reinforced concrete. Graphene, LED, OLED, transparent wood, and plasma rocks are a few other leading environmentally friendly advancements in the building industry.

For a secure world, BRIDGES2000 builds bridges and ecosystems. The company offers excellence in project management, technical advisory for “fit-for-purpose” bridges, and on habitats best suited for humans. The company’s objective is to provide safe links and habitats. Established in the Netherlands in 1999 and

owned assets for more than 20 years without taking out any loans.

In a world where connections are crucial to achieving quality of life and employment and where safety is becoming more and more vital, BRIDGES2000 aims to be the top adaptable builder of all types of connections, including bridges, gangways, and other access products.

BRIDGES2000 has provided services to the event, civil, maritime, and offshore sectors on

In conclusion, to stay in business, you must make money. I would advise everyone to consider service and product quality. We will develop stronger relationships with our customers if the service becomes more and more crucial. Our focus should be on the purpose behind everything we do. That will appeal to our customers or clients. The company Apple is an apparent illustration of this. Once we start using Apple, we hardly ever want to switch again. We should examine everything we discard more closely in order to create a profitable product. We can now discover new niche business models for all the additional materials we cannot employ in our primary goods in many plants. These specialized business concepts might launch regionally focused enterprises. In my company, BRIDGES2000, we carry this out. Since aluminum is lighter, requires less maintenance, and is used frequently there, it is better for the environment. Furthermore, we do not discard any portion of the root material. We employ multiple uses. For this, BRIDGES2000 serves as a sustainable, New Circular Economy Company. •

This article was written by Hendrik van der Ham, who is a ESG thought leader, visionary and founder and head of operations of Bridges2000 b.v.

Since 1999, Bridges2000 is a leading flexible bridge builder that creates safe connection contributing to the quality of life and work providing safety by building and supplying reliable bridges and gangway.

Bridges2000

www.bridges2000.com

Phone: +31 (0)10 820 1770

Email: info@bridges2000.com

initially built and rented bridges before evolving into a project development firm.

Seaway7 Awarded Offshore Wind Contract in UK

Subsea 7 S.A. today confirmed the award to Seaway7, part of the Subsea7 Group, of a very large1 contract by ScottishPower Renewables for the transport and installation of the foundations and inner-array cables for the East Anglia THREE offshore farm. The award comes a year after the preferred bidder agreement was announced2.

East Anglia THREE – located in the Southern North Sea, 69 kilometres off the Suffolk coast – will be the world’s second largest windfarm when it begins operation in 2026. Its 95 14.7MW turbines will have a combined capacity of 1,400MW, generating enough green electricity to power the equivalent of more than 1.3 million homes.

Seaway7’s scope of work includes the transport, logistics and installation of 95 monopile foundations, associated seabed preparation and scour protection along with the engineering, supply and installation of the 95 inner-array cables. In addition to the heavy lifting and cable lay vessels, Seaway7 will also utilise its heavy transportation fleet to handle the significant transportation scope.

Execution of the scope will be led from Seaway7’s Aberdeen and Sutton offices in the UK. The project will progress from early engineering works throughout 2023 with offshore activities scheduled to commence in 2024.

Ross Ovens, ScottishPower Renewables’ Managing Director for the East Anglia Hub offshore windfarms, said: “It’s fantastic to confirm this major contract with Seaway7 for East Anglia THREE. We’ve been moving at pace to put all the building blocks in place to ensure East Anglia THREE can get to work as quickly as possible, producing more green electricity in the UK, for the UK. I’m very proud that there’s more of the same to come while driving that transition to a cleaner, greener net zero future alongside partners like Seaway7.”

Stuart Fitzgerald, CEO Seaway7, said: “This award builds upon our leading position in the UK market. The integrated nature of the award, combining the installation of both foundation and inner-array cables, as well as the utilisation of our heavy transportation vessels, is further testimony to the range of capabilities we have secured across the complete value chain. We look forward to building our relationship with ScottishPower Renewables as, together, we deliver one of the world’s largest offshore wind complexes, representing a significant contribution to the UK’s renewable target”. •

Seadrill Limited

(SDRL) Announces Potential Sale of Qatar Jack-Up Fleet

Seadrill Limited today announces that it is in active discussions to sell (i) the jack-up rigs known as the West Castor, West Telesto and West Tucana (the “Qatar Jack-Up Fleet”), which are bareboat chartered by Seadrill to Gulfdrill LLC (“Gulfdrill”), a 50:50 joint venture between Seadrill and Gulf Drilling International, and (ii) Seadrill’s 50% equity interest in Gulfdrill. Seadrill has not reached agreement yet on material terms, including price, with any potential purchaser. Any transaction remains subject to additional due diligence and the negotiation and execution of definitive agreements. There is no certainty at this stage that the process will continue or that a transaction will materialize.

This announcement is considered to contain inside information as defined in article 7 of the EU Market Abuse Regulation, is subject to disclosure requirements pursuant to section 5-12 of the Norwegian Securities Trading Act, and was made public by Simon Woods at Hawthorn Advisors on the date and time stated above. •

Marathon Petroleum Corp. to Report SecondQuarter Financial Results on August 1, 2023

Marathon Petroleum Corp. (NYSE: MPC) will host a conference call on Tuesday, August 1, 2023, at 11 a.m. EDT to discuss 2023 second-quarter financial results.

Interested parties may listen to the conference call by visiting MPC’s website at www.marathonpetroleum.com. A replay of the webcast will be available on MPC’s website for two weeks. Financial information, including the earnings release and other investor-related material, will also be available online prior to the conference call and webcast at www.marathonpetroleum.com. •

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Pathfinder® Foam Caliper Pig Overcomes Challenging Pipeline Conditions to Identify and Accurately Locate

Geometric Deformations in Onshore Gas

By David Cockfield, Chief Executive Officer Pipeline Innovations Ltd, UK & Peter Ward, Director and Owner Pipeline Innovations Ltd, UK.

The Pathfinder foam caliper pig is unique in smart pigging. It combines the flexibility of a foam cleaning pig with the capability of a conventional full specification metal bodied geometry measurement tool.

Pathfinder’s foam body has a high degree of compression allowing the tool to safely pass through significant restrictions making it the first choice for pipeline proving and piggability assurance in pipelines that have little or no history or present other challenges due to geometry, configuration and debris build up.

Thepatented design is a highly flexible bore measurement tool which is capable of passing through restrictions of up to 40% of the nominal pipeline bore depending on tool size with minimal risk of the pig getting stuck in the line.

A common use for Pathfinder is for the first stage assessment of operational pipelines prior to the use of metal-bodied pigs and the implementation of a pipeline pigging strategy.

Information from the tool is used to locate and measure variations in internal diameter and identify any other geometric anomalies in the line, allowing informed decisions to be made on pipeline cleaning and or ILI strategies.

Pipeline details

The 8” pipeline constructed in 2011 is located onshore in northwest China. The line is 64km long and traverses difficult terrain including river crossings and mountainous areas with rapid elevation changes. The product is natural gas with an operating pressure of 27bar to 42bar. The pipeline supply’s gas to urban users. Continuous operation was essential adding constraints to line pressure, pig speed and run time as consumer demand varied depending on time of day.

Pigging History

Since construction a total of 17 foam cleaning pigs and 1 mechanical cleaning pig had been run through the line. The foam pigs all sustained medium to heavy damage and the mechanical pig got stuck in a large geometric deformation and subsequently had to be cut out. Plans to run an ILI metal-loss survey were shelved until the status of the line could be confirmed by carrying out a baseline

Pipeline

Operation

Pathfinder operations were carried out with PIL’s regional partner BJDC based in Beijing. BJDC provided and deployed AGM (Above Ground Marker) systems for tracking the pig. Due to the concerns over pig damage observed on previous runs it was decided to run a Dummy Pathfinder to prove the line prior to running the measurement Pathfinder. The Dummy Pathfinder is the same size and construction as an operational Pathfinder but does not contain the embedded sensors or electronics.

Received in good condition, pipeline piggability was confirmed and it was considered acceptable to go ahead with the Pathfinder operational runs. Due to the challenging pipeline route and terrain, two Pathfinders were run through the line. The first run was for initial identification of anomalies and or areas of interest. The second run was used to provide repeatability of the findings and provided the opportunity to re-position the AGMs to more closely match the position of significant anomalies to provide higher location

accuracy.

Data Analysis

Onshore pipelines are often more complex than offshore lines due to geography and terrain. This line was no exception. Pathfinder identified a whopping 2327 forged/mitred bends in the 64km line. Four significant anomalous features >10% were identified.

The pathfinder doesn’t have odometers but determines location based on known features such as bends to provide a distance based on girthweld identification and spool lengths to the feature. Using this method, we were able to locate all 4 features for verification digs.

Anomaly 1

A single point intrusion approximately 21mm deep at the 10 O’clock. The position was approximately 190m from

caliper survey using the Pathfinder tool.

External coating was removed and the pipe deformation measured.

launch. The feature was 7m downstream of a right 20° bend. It was thought to be a sharp dent.

BJDC conducted dig verification based on the location reported by Pathfinder. Excavation revealed a pipe with damaged coating and apparent dent damage within 1.0m of the stated location.

Anomaly 2

Identified to be immediately before a 45° degree bend in the 6 O’clock position. When this bend and section of pipe was excavated there were no signs of external deformation.

The client agreed to carry out an x-ray survey of the section of pipe identified by the Pathfinder. The results confirmed there was something in the pipe and the decision was reached to cut it out.

A large hard mass was adhered to the inside wall of the pipe. The surface had signs of wear indicating it was there during the previous cleaning pigs runs.

Anomaly 3

Pathfinder identified what appeared to be a single point intrusion approximately 27mm deep at the 11 O’clock position identified as a sharp dent.

The anomaly was reported to be approximately 13187m from launch in a mountainous area with steep inclines. Due to the difficulty of digging in this area the location had to be precise and great effort was taken to line up the feature list of bends both before and after to narrow down the position. Using information from the two runs, the anomaly position was pinpointed to an area buried under the cast concrete outlined by the red circle in the photograph below. A specialised construction company had to be employed to gain access up the mountainside and carry out excavation –Accurate location was therefore essential!

On completion of the excavation works the anomaly was uncovered in the location reported by Pathfinder. The section of pipe containing the pipe deformation was cut out and detailed measurement of the pipe deformation were as follows:

The dent was measured externally as 378mm long x 28.4mm deep. This matched well with the Pathfinder reported measurements of 400mm long x 27mm deep.

Anomaly 4

Pathfinder reported a deformations of the pipe approximately 20mm deep at the 3 O’clock position. The anomaly was located approximately 55930m from launch, 60m downstream of a right 25° bend (Feature 2189) and 130m upstream of the 56km AGM point.

The anomaly was reported to be in the bend pictured below:

The client was sceptical of the Pathfinders results as again there were no signs of damage on the outside of the pipe. An x-ray survey of the bend was carried out.

The X-Ray survey identified what appeared to be a build up of deposits on the inside of the bend.

The section was cut out of the line and an area of hard concrete type of deposit was confirmed on the inside of the bend

validating the reported result.

Summary

• Working closely with our local partner BJDC and in cooperation with the operator a project methodology was developed to provide a low risk, accurate bore measurement survey solution in a challenging pipeline application and environment.

• Pathfinder proved pipeline piggability and identified several significant restrictions from 13% to 26% of nominal OD that without remediation would impact pipeline integrity and prevent future ILI.

• All 4 reported anomalies have confirmed reporting location and sizing accuracy by infield dig verification with ≤ 3.0m positioning

• Anomaly 3 was accurately located with pinpoint accuracy in an extreme location, that required significant infield engineering and cost.

• AGMs had been successfully deployed to further enhance feature and anomaly location accuracy in the absence of an odometer measurement system.

Please visit out website for more information:

www.pipeline-innovations.com

If you have any specific applications for Pathfinder or would like to view the detailed case study from this project then please contact David Cockfield and Peter Ward via email:

dc@pipeinn.com

pw@pipeinn.com

VMS Group is World-Class Maritime Services. Worldwide.

VMS Group was founded in 2001 by Morten Vestergaard under the name Vestergaard Marine Services, with himself as the only employee. Vestergaard Marine Service repaired diesel engines. Twenty-two years later, VMS Group continues to repair diesel engines worldwide - and sell engines, new and reconditioned spare parts, develop state-of-the-art propulsion solutions and provides project management and engineering services.

The vision of VMS Group is very clear.

We want to deliver world-class maritime services to our customers. Worldwide. As sustainable as possible.

To be world-class and worldwide require competent and skilled people, not just at our HQ in Frederikshavn, Denmark, but also abroad. That is why we established VMS do Brazil in 2015 and VMS Namibia in 2019, with plans of further global expansion to e.g., the Middle East. Our global presence allows us to offer both workshop and onboard repair- & maintenance services to our global customers as well as local customers – applying our core values Care, Knowledge, Agility and Trust. Based on the feedback from our customers, we deliver worldclass service.

Over the years we have added additional offerings to our portfolio to improve our position as a total solution provider, strengthen our company and to realize our futures strategic vision to become a 360o partner to our core customers.

The additional offerings include:

• Partnerships with Bergen Engines, Kongsberg Maritime and Masson

• Distribution of YANMAR and Wabtec engines

• Fast supply of new and reconditioned spare parts

• Independent genset and engine test facility

• Project management and engineering services

In this way, we combine our maritime passion with years of experience in repair and maintenance of engines, gears, propellers

and turbochargers, sourcing and sales of spare parts, engineering, and sales of complete propulsion package solutions.

Global partnerships

As a total solution provider within the maritime industry, VMS Group collaborates with the world’s most recognized brands characterized by their high quality and innovative products. This includes distribution of Yanmar and Wabtec engines. The Wabtec engine meets US EPA Tier 4 and IMO Tier III emission standards with advanced exhaust gas recirculation (EGR), without the use of SCR systems and no urea injection.

We are also service partners for e.g., Bergen Engines and Kongsberg Maritime, which is testimony to the quality of our services.

Independent test facility

At our test facility in Frederikshavn, Denmark we can conduct and offer independent tests of gensets and engines. Right now, we are performing tests of four Wabtec engine gensets for a German cruise ship to be delivered later this year.

The Fredrikshavn workshop, VMS headquarters.

Project management and engineering

VMS Group’s Engineering department is a competent partner, regardless of whether it is a complete Turnkey project or technical sparring. Based on the customer’s goals, we work with the entire palette of maritime technical solutions with the clear focus of adding value to the project solution.

Fitting the pieces to build more sustainable solutions.

VMS Group is one of those companies whose business is getting their hands dirty producing and repairing e.g., engines and other vital parts of our production systems and infrastructure. Engines running on diesel and parts using oil. But we don’t decide the fuel, we just provide the best repair and care.

We wear our oil stains with pride, but today with the focus rightly is on climate issues and sustainability, we feel a need to explain the green side of our business. The sustainable side.

The green side of the label

An obvious green side of the label is that without the afore mentioned production system and infrastructure, the sustainability transformation wouldn’t be possible. No diesel engines running, no wind turbines erected. That is the basic logic of reality. That’s common sense.

We also reuse as many parts of the diesel engines as possible instead of replacing them with new parts. That saves a lot of energy and transport. It’s also good business.

There is also the aspect of engine maintenance. A well-maintained engine uses less fuel and pollutes much less than a poorly maintained engine. That is again a green result of what we do as core part of our business.

We work with some of the leading and most innovative companies in the maritime industry, e.g., Bergen, Kongsberg, Yanmar and Wabtec.

As Channel partner for the Wabtec engine, we are capable to deliver VMS designed, produced, and fully classified generator sets, propulsion engines / systems. The Wabtec engine is the only medium speed Diesel engine on the market that meets IMO III and EPA Tier 4 without the use of any aftertreatment system, (SCR) or any need for Urea injection. This unique engine technology is built on engine and reduces the total system weight and space requirements significantly which equals to reduced emissions and better OPEC for the vessel operators.

That enables us to deliver some of the greenest propulsion systems on the market not only measured in NOx regulated by IMO but also

the particulate matter (PM / soot) regulated by EPA, clean and improved air quality.

Another important green area of focus for VMS Group is to increase the use of reconditioned parts when we repair marine diesel engines and other parts of a ship’s propulsion system.

We locate and buy parts from used or even scrapped engines to be reconditioned and stocked for future use.

Our reconditioned parts meet the same standard as equivalent new parts. They are however cheaper for the customer and better for the environment as recycling is better than new production.

The social side of the label

We are an equal opportunity company when it comes to gender, religion, and color. Our business might not be for everyone, but we are for everyone with the right skillsets.

Seventeen percent of our employees are apprentices, and we take in young people from our local community in need of a structure or a firm push in life. To us that’s just common sense and good business.

The future looks busy

VMS Group has high ambitions for the future. We aim to grow our global presence and expand our workshop capabilities at our different service sites.

We have recently extended our workshop capacities in Niteroi, Brazil, by 700 sqm and will add 2,900 sqm to our workshop in Frederikshavn, Denmark, later this year to keep up with the growing demands we face. Additionally, we are planning to set up a shop in Dubai later this year to be closer to our global customers in the Middle East. •

VMS Group A/S

T: +45 9622 1100

E: vms@vms.dk

W: https://www.vms.dk

The Benefits of Water Jet Cutting

OGI sits down with ANT Applied New Technologies AG to learn more about water jet cutting solutions as they apply to the oil and gas industries. We talk about ANT’s waterjet cutting technology and WAS (Water Abrasive Suspension) to find out about how these systems are quite distinct than traditional waterjet systems. There are multiple advantages of using WAS cutting technology, and we explore these in detail below. We also discuss one of ANT’s exciting products, the wellANT. wellANT is a tool which can ensure high efficiency in rigless plug and abandonment operations, while saving you time and money. More below.

OGI: Could you start by introducing ANT Applied New Technologies AG and its strategy? Please explain credentials and experience in terms of your products and services for the oil and gas sector.

ANT: ANT AG was founded in July 1999 and has since then been successfully active in the core areas of water abrasive suspension (WAS) cutting technology and special machine construction. By now, ANT has become the worldwide technology leader for mobile waterjet cutting.

ANT provides sophisticated abrasive cutting and eroding technology and integrated solutions, which enable you to manage challenging tasks in a safe, efficient and environmentally-friendly way. Particularly for offshore structures in the oil and gas industry, but the wind power industry as well, special requirements are needed at various stages of lifecycle management. Over the past 20 years, we have worked with global oil and gas companies and major service providers

OGI: What are the advantages of ANT waterjet technology, especially for the oil and gas sector?

ANT: Since the abrasive particles in WAS (Water Abrasive Suspension) systems are directly bound in the water, the ANT suspension jet is significantly more stable, precise and powerful than conventional waterjets, as well as free of air. ANT WAS systems do not require high pressure and save resources. There are no limits in terms of cutting material. The cutting process is contactless, without heat generation and without deformation. This special type of waterjet cutting is used both in the air and under water, as well as in potentially explosive and sensitive areas. Depending on the area of application, WAS enables safe and remote cutting of material thicknesses up to

1,000 mm from a distance of up to 1,000 m; under water up to 250 m. Besides the general advantages of the WAS cutting technology, ANT has developed specific offshore solutions to further improve performance of the Downhole Cutting Heads (DCHs) in great depth and challenging conditions of internal cuts. Even concentric multistring dual bore wells can be completely cut in a single pass. Specific manipulation systems for external cutting of piles and other offshore structures can either complement an offshore cutting spread for internal cutting or be part of an individually tailored WAS cutting system for a wide range of cutting challenges offshore and onshore.

OGI: Can you talk about the work ANT does in the offshore industry? How does ANT AG’s decades of experience help to better assist their clients?

ANT: ANT provides sophisticated abrasive cutting and eroding technology and integrated

within the industry. With our products, we have successfully supported various projects worldwide.

WellANT in Action.

solutions, which enable you to manage challenging tasks in a safe, efficient and environmentally-friendly way. The products are mainly suitable for sustainable repair, demanding production enhancements, challenging Plug & Abandonment operations and efficient decommissioning. Cutting of Multistring conductors, piles and structures 5 m below mudline works with our unique cutting technology and spreads. Everything deeper than that is a task for wellANT, our erosion tool.

We know the challenges our customers face and support them in finding the optimal solution for their business operations. These solutions are suitable for ATEX Zones, easy to set up, have a small footprint, and are safely monitored and controlled by real time cut verification. Commissioning, a test run of the waterjet cutting system as well as intensive instruction and training are a matter of course for us. True to the motto “Safety first”, our specialised teams prepare customers in the best way possible for the ideal use of their new waterjet cutting system. To offer a wide range of maintenance services for machines, our own service team ensures reliable troubleshooting in the shortest time possible, also via augmented reality. We don’t avoid challenging projects – that’s why we have our own research and development team, which is characterised by many years of experience, a solid foundation of technological know-how and innovative ideas. ANT also cooperates with universities and institutes for research purposes.

OGI: What is wellANT?

ANT: The wellANT is an exciting erosion tool that ensures high efficiency in rigless P&A as well as production enhancement. ANT AG’s decades of experience in downhole solutions enabled the

development of the tool, which comprises: stroker module, drive unit, rotation module, and nozzle head. First of all, the wellANT is deployed downhole on coiled tubing (drill pipe as well). Collapsed and restricted wells typically present problems, as plugging has to be done under the deformation zone. Traditional pipe conveyed mechanical mills can suffer from unintended side tracking due to reactive torque from the deformation, and require expensive rig mobilisations. As the tool activates, continual flow carries micro cuttings and mud to the surface, where they are screened and analysed, providing insight into what is going on downhole. A customised jet orientation has been refined to ensure the wellANT only erodes within the diameter of the existing wellbore, with very low reactive torque. wellANT can also be used to complement traditional drilling assemblies in side-tracking. Utilising the consistency of water jet cutting, the tool can be deflected via cement plug, whipstock or open hole whipstock, to provide a clear pilot

hole through multiple materials.

OGI: What are the advantages of using wellANT?

ANT: Compared to the conventional approach, namely mechanical drilling, the slipping of the drill head is avoided. This saves time and nerves. Another advantage is the reduced space requirement, which allows the work to be carried out on much smaller work platforms. The most important aspects are the immense time savings and the reduced need for spare parts, which reduces the costs for service providers to one third. wellANT is also capable of 360-degree swarfless section eroding, which provides a fast and cost-effective alternative to section milling. Whether used independently or alongside traditional drilling assemblies, wellANT brings advantages in cost, time, and the quality of the end result. The versatility of wellANT means it can bring advantages throughout the whole well lifecycle, from production enhancement all the way through to plug and abandonment scopes.

OGI: Thank you for your time. •

If you would like to know more about how ANT Applied New Technologies AG can help your company and its operations, please contact them:

ANT Applied New Technologies AG

T.: +49 (0)451 5 83 80-0

E: decom@ant-ag.com

W: https://www.ant-ag.com

Members of Service Team, Offshore.

NPD and Innovation Critical to Driving Progress in the Tank Cleaning Sector

Aidan Doherty, Managing Director of Re-Gen Robotics discusses how innovation and new product development are playing a crucial role in the oil and gas sector’s tank cleaning and maintenance programs.

The oil and gas sector is faced with complex challenges, including stringent safety and environmental regulations and the need to optimise operational efficiency. Innovative solutions can lead to safer more effective and environmentally friendly cleaning processes and a reduction in waste materials.

New product development facilitates the introduction of advanced technologies and cutting-edge equipment that can minimise risk, reduce costs and downtime while protecting asset integrity. Recent innovations such as Zone 0 robotic cleaning systems, automated inspection tools, and drone-based monitoring devices have enhanced operational accuracy, streamlined maintenance procedures and most importantly, protect workers from entering hazardous, confined space situations where they are exposed to toxic materials.

Oil Terminal operators are also keen to recover any oil contained in the sludge residue as the revenue generated from the recovered oil could help to cover some the cost of the cleaning operation. Embracing new product development and innovation in tank cleaning and maintenance allows oil terminal operators to enhance their overall performance, sustainability, and competitiveness in their sector.

One area that has seen significant improvements in recent times is the cleaning of crude oil tanks. Traditionally, tank cleaning operations were hazardous, time-consuming and labour intensive, requiring men to physically enter tanks to remove oil sludge and toxic materials. However, with the advent of Re-Gen Robotics, Ex Zone 0 rated robots and tankers the safety, speed and efficiency of crude oil tank cleans have been dramatically enhanced by up to 4070% times faster.

Re-Gen Robotics was recognised with the Safety Technology Award at the 2020 Global Tank Storage Awards, for revolutionising safety in the tank terminal industry. We were commended for ‘adding an additional layer of safety to oil terminals and eliminating the risk of injury or death to employees in the surrounding area’.

In December 2021, our company was recognised with three awards at the Energy Industries Council Awards, including the Innovation Award, the Sustainability Award, and the prestigious Company of the Year Award.

We’re currently building on the successes of our robotic equipment with two notable NPD projects which focus on increasing the speed and efficiency of desludging heavy crude tanks and reclaiming as much valuable hydrocarbon material from the crude sludge as possible.

The team is working on new cleaning heads for our ATEX robots including a steam injection head and mixed injection systems which allow operators to use not just cutting agent and hot water in order to improve the pumpability of oily sludges, but also the injection of steam.

Mixed injection systems combine the use of cutting agents, hot water, and steam to break down and liquefy oil sludges, making them easier to pump out. When mixed with hot water and steam, they create a powerful combination that can penetrate the sludges, reducing their viscosity and improving pumpability. This enables the robot operators to remove the sludges more efficiently, reducing the overall cleaning time, allowing for faster turnover of tanks and increased productivity. This is particularly advantageous in situations where tanks need to be cleaned rapidly for maintenance, inspection, or repair purposes. The amount of waste generated during

tank cleaning is also significantly reduced. This helps in minimising the environmental impact associated with the disposal of large volumes of sludge.

The disposal of waste generated during oil tank cleaning operations has long been a challenge for the industry. However, Re-Gen Robotics is preparing to implement a vertical centrifuge system which will enable our tank cleaning crews to separate solids and liquids effectively. This approach not only reduces the waste volume for disposal but also enables the recovery of viable hydrocarbon materials that can be utilised by our clients.

The vertical centrifuge system is a highly efficient and automated solution designed specifically for the separation of solids and liquids in the tank cleaning process. It will bring several benefits to our oil tank cleaning operations by significantly reducing waste volume, allowing for the efficient removal of the bulk of the waste. This reduces the environmental impact associated with waste management and lowers disposal costs for terminal operators.

Recovering viable hydrocarbon materials is a key advantage of the vertical centrifuge system. It not only provides economic benefits but also contributes to the circular economy by reducing reliance on virgin hydrocarbon sources.

As the industry continues to focus on environmental sustainability and resource optimisation, the adoption of new innovations and advanced technologies will play a vital role in achieving these goals.

Our tank cleaning robotic solutions are transforming the oil and gas industry, minimizing risk, and reducing costs and downtime while protecting asset integrity and the environment.

For further information on safe, smart, efficient tank cleaning, visit: Re-Gen Robotics Ltd.

W: www.regenrobotics.com

T: +44 28 300 50 800

E: info@regenrobotics.com

Ultra High Pressure Solutions from Superjet

The oil and gas industry operates in some of the most challenging environments, where maintenance, cleaning, and repair tasks often require advanced equipment to ensure efficiency and safety. One such technology that has revolutionized industrial cleaning processes is the use of ultra high pressure water jetting machines. These extremely powerful machines offer a versatile and eco-friendly solution for various applications in the oil and gas sector, including surface preparation, pipe and heat exchange cleaning, tank maintenance, and more.

The Superjet Range of UHP

Jetting Machines

Superjet (Part of the Jetchem Systems Group) offer a range of UHP (Ultra High Pressure) jetting units aimed at providing working pressures up to 3500 bar, which have been designed to provide a solution to a range of jetting applications across various industries. Superjet not only provide the jetting machines, either built to customer specification or available for nationwide hire, but they also specialise in accessories, spares and PPE (personal protective equipment) together with safety training courses.

Applications in the Oil and Gas Industry

Surface Preparation: Ultra high pressure water jetting machines are widely used for surface preparation tasks such as paint removal, rust and corrosion removal, and cleaning of metal surfaces prior to inspections or maintenance. The high-pressure water jets effectively strip away coatings and contaminants without damaging the underlying material, providing a clean and prepared surface for further treatment.

Pipe and Tube Cleaning: In the oil and gas industry, pipelines and tubes can become

fouled with scale, sludge, or other deposits over time, affecting their efficiency and potentially causing blockages.

The Superjet range of UHP water jetting machines offer a non-destructive and highly effective method for cleaning the interior of these pipelines, restoring their flow capacity and extending their operational lifespan.

Tank Cleaning: Oil storage tanks, chemical tanks, and other containers used in the industry require periodic cleaning to remove accumulated sediments, sludge, and other residues. Ultra high pressure water jetting machines can efficiently clean the interior of these tanks, removing contaminants and ensuring compliance with safety and environmental standards.

Heat Exchanger Maintenance:

Heat exchangers play a crucial role in the oil and gas industry, transferring heat between fluids in various processes. Over time, heat exchangers can suffer from fouling due to deposits and scaling, reducing their efficiency. Ultra high pressure water jetting machines can effectively remove these deposits, improving heat transfer efficiency and reducing energy consumption.

Benefits of Ultra High Pressure Water Jetting

Utilising high pressure water provides many benefits to the oil and gas sector such as enhanced efficiency, offering a faster and more efficient cleaning solution compared to traditional methods. The high-pressure water jets can remove contaminants quickly and effectively, reducing downtime and increasing productivity.

Non-Destructive Cleaning: Unlike abrasive methods that can damage surfaces, water jetting is a non-destructive cleaning method. It does not generate sparks, heat, or dust, making it suitable for use in potentially

explosive environments. It also preserves the integrity of the underlying material, minimizing the need for repairs or replacements.

Environmental Friendliness: Ultra high pressure water jetting is an eco-friendly alternative to chemical cleaning agents, as it uses only water and does not introduce harmful substances into the environment. The technique also reduces water consumption compared to other cleaning methods, as the high pressure of the water stream maximizes cleaning efficiency.

Operator Safety: With proper training and safety protocols, ultra high pressure water jetting machines can significantly enhance worker safety. Operators can clean surfaces remotely, minimizing exposure to hazardous substances and reducing the need for confined space entry. Superjet provide a wide range of safety equipment and accessories to aid in providing a safe working environment.

Superjet were recently commissioned by a company in Swansea to provide a solution for heat exchanger tube cleaning. Following a site visit and assessment of the task required a Superjet ESM132FE electric driven ultra high pressure jetting skid unit was provided. Due to the nature of the site an electric model was chosen, producing a performance of 1500 bar with a flow rate of 40 lpm (litres per minute).

Superjet, which is part of the Jetchem Systems Group, operate six nationwide UK based depots, which provide services such as sales, hire, service and repair, spares and training. They also export products and bespoke build jetting machines worldwide.

For more information on how Superjet can assist with your water jetting and drainage applications please contact us directly (below) or contact your local depot.

Jetchem Systems Limited

T.: +44 (0) 333 320 1990

E: info@jetchem.comm

W: www.jetchem.com

Superjet Electric UHP Jetting

Enhanced Sand/ Erosion Management with Non-Intrusive Erosion Monitoring

Potentially causing serious erosion, sand is a major challenge in oil and gas production. Sand erosion implies risk to both assets and personnel, and often leads to increased operating costs. To combat this common challenge, there’s a trend towards an increased use of non-intrusive sand and erosion monitoring, for both subsea and land-based applications.

Non-intrusive ultrasonic pulse echo technology provides the fastest response to changes in wall thickness. The most reliable interpretation of metal loss distribution is achieved through an array of high-accuracy pulse echo sensors distributed across the pipe section of interest (often at a bend). This is the technology Sensorlink have successfully deployed in projects worldwide.

Aiding operators to make informed decisions, the Sensorlink’s UltraMonit® (subsea) and PipeMonit® SWARM (topside) systems offer excellent solutions for proactive management of subsea and land-based applications. Increased production rates

Sand production often excel with increased production rates, and with the age of an oil and gas reservoir. To reduce the risk for sand and erosion damage, conservative limits on production rates are often set. However, this solution limits operation profits.

With Sensorlink’s achieved sensitivity of distributed pulse echo measurements (down to +/- 2,5 micrometer repeatability), it is suggested that measurements can be used proactively for early warning and process tuning (not just to verify asset integrity and fitness for service) thus increasing production rates. Up to 250 sensors can be used for monitoring one bend, giving extensive coverage of sand erosion in the bend. Several systems similar or

Early warning and process tuning

With traditional sensitivity, the purpose of ultrasonic monitoring has been to verify the integrity of pipes and measure long-term erosion rates. The high accuracy of Sensorlink’s measurements provides operators with additional opportunities.

With increased accuracy and repeatability, non-intrusive data can also be used more proactively, to warn operators of sudden changes and help tune production rates.

Warning of sudden changes

Warnings can be given if sudden changes in erosion takes place, e.g., because of a reservoir sand burst. This can be done by accurately calculating erosion rates over short periods (e.g., 1 day), warning operators if measurements exceed the random measurement variations.

identical to this have been installed in recent years by Sensorlink with a positive market feedback.

Figure 1: Sensors are permanently installed in the external pipe wall (in this example, covering positions bottom and top of the pipe).

Figure 2: Illustration of a subsea bend, monitored by an Array of UltraMonit UT sensors hooked up to a retrievable data unit.

Figure 3: A “dry” application of non-intrusive UT sensors, showing non-intrusive PipeMonit SWARM UT sensors installed on a bend. Sensors are distributed for increased probability of detecting sand erosion in the bend.

Figure 4: Non-intrusive PipeMonit SWARM LT-sensors. The system communicates processed data wirelessly to a gateway and the control system.

Tune production rates

Experience has shown that production rates (and thus operational profits) can be significantly increased by tuning production to the highest “sand free” or “acceptable sand” production rates, rather than staying inside established conservative limits. This can be done by accurately calculating erosion rates over short periods of time (e.g., 10 days) and lowering the alarm limit accordingly.

Monitor integrity of pipes and pipeline

Erosion rates calculated over longer periods (1 – 2 months) provide accurate quantification of erosion rates and, accordingly, better information about pipe condition and life expectancy at given erosion rates. This information is used for maintenance planning and general integrity

Figure 5: Erosion and erosion rates visualized based on data from the distributed UT devices. The heat map shows anticipated distribution from a high number of nonintrusive UT devices.

management (e.g., general inspection planning), avoiding unplanned repairs, and contributing to reduced plant downtime.

Array of high-accuracy ultrasonic sensors

By implementing Sensorlink’s high-accuracy UT-sensors you are provided several benefits, including:

• High accuracy (down to +/- 2,5 micrometer repeatability) ensuring fast and reliable information about erosion rates, allowing proactive use of data for production optimization.

• Distributed wall-thickness and erosion maps that are easy to understand and relate to, helping operators make informed decisions.

• Data processing on location, with digital wall-thickness data transferred directly to the user.

• Access to and presentation of erosion data independent of 3rd party software tools.

• Access to the raw data, for further analysis with more sophisticated software. Ask us about erosion monitoring system for your pipes or pipeline! Contact us:

Jan-Tore Ervik

Chief Marketing Officer jan-tore.ervik@sensorlink.no

Kjell Wold

Business Development Director kjell.wold@sensorlink.no

The Crucial Role of Traceability in Optimizing Pipe-Shop Operations for Oil & Gas Businesses

The world of oil and gas operations is dynamic and complex. Therefore it is of utmost importance for any executive to establish and maintain high levels of efficiency, in order to ensure that every aspect of their business is operating seamlessly and profitably. One crucial aspect that often goes overlooked is the traceability of pipe-shop operations, as well as the materials used therein. While other, more prominent yard operations are given a lot of attention, pipeshops often still operate using methods and mindsets that have fallen behind the times.

This article aims to shed light on the significance of traceability in the context of oil and gas businesses, emphasizing its positive impact on operational efficiency, quality control, regulatory compliance, and overall profitability.

Operational Efficiency:

Traceability plays a vital role in enhancing the operational efficiency of pipe-shop operations within an oil and gas business. By implementing robust traceability systems, executives gain visibility into every stage of the fabrication process, from design and engineering, through the various fabrication processes, all the way to installation. Real-time monitoring of the flow of material, the work processes, and quality control operations, enables executives to identify and rectify bottlenecks, reducing operational delays and minimizing downtime. With enhanced efficiency, pipe-shop operations can meet production schedules, optimize resource allocation, and ultimately boost overall productivity.

Quality Control:

In the oil and gas industry, ensuring the highest quality standards is non-negotiable. Traceability systems, such as the software suite provided by 3R solutions, enable pipe-shop managers as well as executives to maintain strict control over every aspect of fabrication. By accurately tracking the origin, specifications, and fabrication history of each pipe spool, including complete weld books, executives can effectively identify any quality issues, such as defects or failures. In the same line the performance of machines and welders can be tracked and documented. This proactive approach helps prevent costly incidents, including leaks, ruptures, or equipment damage, which not only incur financial losses but also pose significant safety and environmental risks. By maintaining rigorous quality control through traceability, executives can protect their brand reputation and build trust among stakeholders.

Regulatory Compliance:

Compliance with industry regulations and standards is a fundamental requirement for any oil and gas business. 3R’s traceability systems provide an invaluable tool for any executive or pipe-shop manager to ensure compliance with both internal and external regulations. Using the software executives can readily provide auditors, regulatory bodies, and customers with comprehensive documentation and evidence of compliance. The ability to trace the origin, materials, and manufacturing processes of pipe spools helps demonstrate adherence to safety, environmental, and quality standards, safeguarding the business against penalties, legal liabilities, and damage of reputation.

Risk Mitigation:

Traceability software significantly contributes to risk mitigation in pipe-shop operations. In the event of faulty or non-compliant material being identified, traceability systems enable swift identification of affected batches, minimizing the impact and facilitating targeted recalls or replacements. By promptly addressing such issues, executives can reduce financial losses, minimize operational disruption, and maintain customer satisfaction. Moreover, traceability systems enable proactive risk management by identifying potential weak links in the supply chain, allowing executives to implement appropriate measures to mitigate risks and ensure business continuity.

Profitability and Competitive Advantage: Efficient pipe-shop operations supported by robust traceability systems ultimately lead to enhanced profitability and a competitive advantage in the oil and gas industry. By streamlining processes, reducing operational costs, and minimizing quality-related incidents, executives can optimize resource utilization and improve overall financial performance. Moreover, the ability to provide customers with accurate and reliable information about the materials used in their projects, as well as the workshop activities, can differentiate an oil and gas business from its competitors. Clients value transparency and traceability as it demonstrates a commitment to quality, safety, and compliance, thereby attracting more business opportunities and fostering long-term partnerships.

Conclusion:

In the complex and demanding landscape of the oil and gas industry, executives must recognize the pivotal role that traceability plays in pipe-shop operations. From operational efficiency to quality control, regulatory compliance to risk mitigation, and ultimately profitability and competitive advantage, traceability serves as a catalyst for success. By embracing traceability systems and integrating them into their operations, executives can enhance transparency, optimize processes, and build a strong foundation for their oil and gas business in a rapidly evolving industry. 3R solutions www.3r.de

Tubacex Contributes to Cogniplant Project, Revolutionizing Industrial Processes through Advanced Digitalization and Intelligent Management

Tubacex is part of a broad consortium of organizations involved in the Cogniplant project, which is being developed under the Horizon 2020 program, a European Commission initiative for research and innovation funding. With a budget exceeding 8.5 million euros, the Cogniplant project aims to create a cognitive platform to enhance the performance and sustainability of European industrial processes, through to advanced digitalization and intelligent management of industrial processes.

It aims to utilize innovative developments in advanced analytics and cognitive reasoning, along with a disruptive use of the concept of Digital Twins, to enhance the operational performance of production plants. Cogniplant will provide hierarchical monitoring and control of operations, offering comprehensive insights into production performance, energy consumption, and resource utilization.

The project consortium consists of various companies involved in Cogniplant, including Ibermatica SA, Ideko, S.Coop, Technische Universitaet Muenchen Ingeteam Power Technology SA, Hermes Schleifmittel Ges.M.B.H., Savvy Data Systems SL,

SMART PIPE-SHOP AUTOMATION

Software Competence Center Hagenberg gmbh Logpickr, Mr. Nec B.V., Stam srl, Fornaci Calce Grigolin SPA, Core Innovation and Technology OE, Aughinish Alumina Ltd, and Acería de Álava, S.A. (Tubacex Group).

The goal of the project is to advance towards true Industry 4.0. The envisioned solutions are expected to deliver significant improvements, including up to a 68% enhancement in real-time control of the production environment, a 65% improvement in quality control of final products, and a 70% reduction in response time to unforeseen or uncontrolled incidents.

In the initial phase, the concept will be implemented by four end users from different SPIRE industries (Sustainable Process Industry through Resource and Energy Efficiency): a chemical plant in Austria, an aluminum refinery in Ireland, a manufacturing industry in Italy, and a metallurgical industry in Spain, Tubacex.

As part of the Cogniplant project, Tubacex’s task is focused on two main areas. Firstly, the installation and development of digitization technologies tailored to the steel industry. Secondly, data extraction for analysis and monitoring activities. The factory is preparing for the implementation of data analysis, digital twin, and intelligent monitoring technologies. Its primary Key Performance Indicators (KPIs) in the Cogniplant project revolve around production performance in terms of quality, reduction in energy consumption, and reduction of CO2 emissions. •

GOING GREENER: Why Higher-Spec Process Filtration Boosts Sustainability

Oil and gas producers keen to decarbonise under corporate ESG strategies will naturally want their suppliers to share the same sense of sustainability and green values. When it comes to the complexities of making process filtration more sustainable, small changes can make a big difference.

Filtration

equipment manufacturer Amazon Filters continues to invest substantially in technical improvements to ensure its products optimise performance and last longer.

A key aspect of the 38-year-old UK firm’s drive to go greener for itself and customers is holding the independently verified ISO 14001: 2015 standard for environmental sustainability.

Investment strategy

“Our investment programme is designed to help us and our customers streamline processes to be more energy efficient,” explains Project Specialist Padrig O’Hara, a process engineering expert. “We’re walking the walk ourselves by improving the environmental impact of our operations. We’ve made a series of improvements to our manufacturing processes, materials and packaging. And we have ensured that across our product range, we can support the main process filtration and separation applications at the heart of oil and gas production. These include particulate removal from both liquid and gas streams, along with gas/liquid and liquid/liquid coalescers.

“We know the right filter assembly can dramatically reduce change-out frequency. It’s one of the big benefits of the consistency we provide through both standard and bespoke solutions. Customers report reduced CAPEX and OPEX, minimised downtime, improved product quality and higher confidence in operators’ health and safety.”

FPSO sees dramatic benefits

A prime example of the positive difference Amazon Filters makes can be seen in a recent bespoke solution delivered on an FPSO. Process engineers on the facility were concerned about the performance of membrane pre-filtration on

KilBac technology features high-performance antimicrobial and antialgal additives.

their sulphate reduction plant.

Filter cartridge change-outs were having to be done every two to three days and taking 24 hours each time. Aside from cost, the operational challenges of this activity were significant.

Further investigation revealed the housings were undersized for the task in hand, resulting in a very high flux rate for seawater service and therefore shorter filter life. In addition, the internal assembly did not adequately support the cartridges as it should have done. This was limiting the maximum differential pressure at which the cartridges could be operated. It was well below their intended dirty values, resulting in the full dirt holding capacity being under-utilised. Due to the poor design, some cartridges were inevitably rupturing which necessitated disassembly of the internals and manual cleaning out of the debris on each cartridge change-out.

Amazon Filters’ solution was to supply ‘boltin’ replacement internal assemblies. As well as supporting the cartridges properly, it was possible to increase the number of cartridges fitted by better arrangement, resulting in a 20% increase in filtration area. Delivered ahead of schedule, the replacement internals were fitted by the customer with no modifications to the filter vessels required.

The improvements were dramatic. Cartridge change-out frequency was reduced from twoto-three days to two weeks, with change-out time itself cut from 24 to five hours. Alongside the use of Amazon Filters’ cartridges at a cheaper unit price than the original fitted ones, the solution delivered a 90% reduction in spend on cartridges, paying back the CAPEX in under a month. At the same time, maintenance hours were reduced.

Product enhancements

Standard products from Amazon Filters that support sustainable credentials for oil and gas producers include SupaSep, SupaPleat, KilBac and Contour Gas. All have undergone recent enhancements and variations under the firm’s ongoing investment strategy.

• SupaSep is a retrofit solution designed to enhance efficiency and drainage performance in high-flow filtration and separation processes. It is ideal for the removal of entrained liquid droplets such as water, condensate, oil, glycols and amines from natural gas.

• Liquid particulate filter SupaPleat 1401 supports fluid process applications at refineries and petrochemical plants including the filtration of solvents, acids, iron fines and hydrocarbons.

• KilBac technology, supporting SupaGard and SupaSpun filters, features high-performance antimicrobial and antialgal additives. It harnesses micronsized particles containing active silver, zinc and copper which, combined with a base polymer, combat the growth of bacteria or algae, so extending cartridge life.

• Meltblown cartridge filter Contour Gas helps with the removal from gas transmission lines of black powder, a common source of contamination mainly composed of hard particles of iron oxide and iron sulfide in sizes from 100µm down to sub-micron level.

For more information on Amazon Filters’ products and solutions for the oil and gas industries, visit: www.amazonfilters.com/retrofit-filters.

SupaSpun SRP filters provide essential prefiltration for sulphate reduction membranes.

TWTG Insight How to connect 10,000 assets?

ch 2023, together with Actility and Tektelic, TWTG will host the first Insight Seminar under the theme of dam or want to lear n e?

What is Optical Gas Imaging and Quantification?

This is a short overview on what Optical Gas Imaging is.

Before we dive into the technical explanation, we need to understand why do we need to detect gas? There are a few reasons.

Thefirst one is health and safety -by detecting a leak early, we can prevent explosions and toxins.

The second is environmental responses. Greenhouse gasses reduction and regulation compliance.

Lastly is Operational efficiency: Product loss prevention and cost reduction.

Some of the advantages of using OGI compared to alternative methods is that it’s very simple, you either see the gas or you don’t. It’s very quick, you can scan a very wide are quickly. It’s safe, you can stand from a distance, and its very user friendly and easy to operate.

What is OGI? Optical Gas imaging is thermal cameras, also known as infrared cameras which can visualize gas leaks.

In the electromagnetic spectrum, infrared is divided into 3 regions. Short-wave, Midwave and long-wave. There are 2 types of OGI technologies, cooled & uncooled.

A cooled OGI camera is very sensitive compared to an uncooled camera. In the mid-wave spectrum, there is a very strong absorption response to compounds such as Methane, Hexane, Butane and over 400 VOC’s. This enables us to see these compounds using a cooled, very sensitive OGI camera.

In the longwave infrared spectrum, where we use the Uncooled OGI technology there

is a weaker absorption response for VOCs, so it’s more difficult to detect these VOC compounds except methane in much larger concentrations.

There are several variants of the OGI cameras from a manufacturers point of view. The best devices on the market can work in very demanding environments, are certified

ATEX, have interchangeable batteries with at least 4 hours between charge, do NOT require maintenance and can connect easily to quantification software. Detecting gases is a simple task for OGI cameras but the real requirement is to try and ensure collected data is reported to the client, end user or internal committee. This is a real goal for all types of company’s when trying to achieve net zero, reduce emissions, stop leaks and be safe. Below is an explanation of the top scoring OGI software at the recently published GERG trials.

Physics Outside the OGI Camera

Figure 1 (page over) illustrates the “outside of the camera” physical principles of gas plume detection using OGI technology. Using a simplified 2-layer (background (b), gas plume (g), and foreground air (a) as depicted in Figure 1) radiative transfer model to describe the thermal radiance transferred from the background to the OGI camera. 1, 2, 3 Each layer in Figure 1, as in all bodies in nature, irradiates a temperature-dependent thermal electromagnetic radiation according to the black body Plank’s function.

The following Camera Specific OGI Equation considers the specific transmission of the camera’s optics. The camera’s optics (primarily bandpass filter) is key for compound specific

response to different levels of integrated concentrations, CL. The contrast ΔI at each pixel in the OGI image between the thermal radiance with and without gas present in the line of sight is given:

Ino gas – integrated thermal radiance over the bandpass filter spectral range, on pixels with no gas.

Igas – integrated thermal radiance over the bandpass filter spectral range, on pixels with gas.

t(λ) – bandpass filter transmission as a function of wavelength.

I(T) – integrated Planck’s function over the bandpass filter spectral range.

τa – integrated foreground air transmission over the bandpass filter spectral range.

Figure 1: Illustration of simplified 2-layer radiative transfer model for detection of gas plumes using OGI technology.

CRS(λ,CL):

Figure 3 (below) demonstrates the good match between the methane specific response spectrum and the camera standard filter (SF), for a wide range of CL values.

Unlike other OGI quantification software that uses response factors (RF) relative to propane response, an algorithm for determining CLs, based on compound specific response (CSR) function, CS-R(CL) has been developed. Integrating Equation 2 over the bandwidth of the filter, the CL dependent CSR function is defined as:

2: The retrieved components from a series of OGI images for calculating MFLR.

OGI Quantification

Quantifying concentration and leak rate values, based on OGI technology, is a complex and challenging task, that requires innovation and problem-solving skills in every step of the process. Recently, Opgal has developed special proprietary algorithms for accurately determining path integrated concentrations (PIC), or concentration-length (CL) for a pixel in the OGI image and mass flow leak rate (MFLR) for a series of acquired OGI images. In this original process, a new language of terms and set of equations had to be formulated. CL values are calculated as an intermediate stage for determining the target leak event’s average MFLR (equivalent to mass emission rate). Figure 2 describes the components, retrieved from an acquired series of OGI images, needed for determining the MFLR of a leak event. To calculate the CL for a line of pixels downwind from a leak, it is first needed to determine CL for each pixel in that line of pixels. Then, define from the camera specific OGI equation (Eq. 1), the compound specific response spectrum,

The software includes a very precise theoretical integration information of CSR function for each compound. This predetermined library of functions is calculated using very highresolution absorption coefficient data from the Pacific Northeast National Laboratory (PNNL) infrared library, the EyeCGas2.0 Standard Filter transmission spectrum, and a proprietary theoretical calibration procedure. These functions’ behaviour with CL values is specific for the absorption coefficient spectrum and bandwidth filter transmission.

Figure 4 compares this behaviour for propane and methane. It is apparent that this OGI camera is more sensitive to detecting propane than methane, and that these functions are not linear and are different for various compounds (logarithmic scale for the CL axis). Also, these functions are independent of the environmental scene (ΔT – temperature difference between background and air) and therefore are pre-calculated in Opgal’s software to serve as reference data for determining the CL from the acquired relative contrast for each pixel and each frame. Once a series of images (hundreds of frames) are collected for a target detected leak event, temperature dependent

CSR values are acquired for each pixel in each frame. A prior knowledge of the leaking compound allows the algorithm, using the predetermined library of CSR functions, to calculate CL, typically in ppm m, for each pixel in each frame. It is important to note that this measured relative contrast is corrected by taking the ratio of the measured contrast and the foreground air transmission, τa , calculated for the specific atmospheric and dimension variables of the measurement scene.

The next step is the calculation of windspeed by examining movement of the plume between frames. The last step is to integrate the CL over a line of pixels to estimate the plane-integrated concentration (See Figure 2) and multiply it by the retrieved windspeed to get a MFLR in mass per time units for each frame in the collected series of images. Taking the mean and standard deviation of all calculated leak rates of the series provides the average leak rate of the target leak event and the uncertainty associated with it. •

OSS Enviro (Global) Limited

T: +44(0) 1782 956 265

E: info@ossenviro.com

W: https://www.ossenviro.com

Figure 3 (below): Compounds specific response spectrum for methane and the camera SF, for a wide range of CL values.

Figure

Figure 4: CSR function on SF for Propane and Methane.

LoRaWAN for Industry Applications - Five Factors

In this article, Jorrit Walgien, TWTG’s Technical Business Development Manager, covers the basic questions clients ask when first starting with LoRaWAN, exploring the five key areas engineers need to access when evaluating wireless technologies for their future roadmap. As well as considering the advantages of LoRAWAN, Jorrit discusses the benefits of combining technologies to achieve the most comprehensive and financially viable solution.

Foreword

With 15 years of experience in wireless monitoring solutions within the energy industry, I’ve witnessed some fascinating developments over the past two decades. In that time, technology has advanced startlingly, and as capability has constantly improved, prices have continually dropped.

Only a decade ago, financially, engineers could only realistically monitor their most valued assets, but now with costs reducing, it’s feasible for engineers to digitise most assets. Battery life is now incredibly long, and the restriction of power cables and networking is a thing of the past - meaning today, there is no location that cannot be digitised.

While these technological opportunities are unquestionably exciting for everyone involved, we appreciate that for many of us, it can still seem like a daunting subject. That’s why it’s always a good idea to revisit the fundamentals and ensure we understand them.

I want to look at five essential criteria when assessing how to best digitise an energy or industrial facility. In particular, we always advise customers to consider the following aspects: vendor lock-in, battery life, security, range, and competing and complementary technologies.

The Importance of No Vendor Lock-in

The advantage of having no vendor lock-in is often overlooked, but it can provide complete

autonomy over your system, sensors, and data. With no lock-in, you have the freedom to choose the devices that operate on your system, ensuring that your data-driven goals are not compromised. Moreover, you have the flexibility to work with any supplier you choose based on the best solution for your system.

LoRaWAN’s open ideology is another critical differentiator, allowing any LoRaWAN device to be incorporated into a network, regardless of the supplier, manufacturer, or purpose. This means that you are not restricted by the level of certification of the device, and communication with any LoRaWAN thirdparty device is possible. Further enhancing LoRaWAN’s no lock-in credentials, its wireless nature means no hard wiring and, crucially, no manufacturer-specific plugs for connectivity.

One thing to remember is that many protocols are described as “open,” meaning that they’re free for any manufacturer. However, most of these solutions were designed to work with only the manufacturer’s products. So, if you want to incorporate third-party assets and functionality into your setup, it can be challenging and often come with limitations or restrictions.

LoRaWAN’s lack of vendor lock-in is a huge benefit, providing endless expansion possibilities. With just one LoRaWAN

network, your IoT strategy can be supported for years to come, with tens of thousands of sensors monitoring all possible variables in your plant infrastructure.

Device Life Batteries

LoRaWAN technology is an excellent solution for most industrial IoT applications due to its long battery life, easy installation, and low maintenance costs.

Long battery life means that LoRaWAN can be installed without any network or power cables, making them ideal for retrofitting to existing equipment. This also gives engineers the freedom to quickly relocate devices after initial installation if they need to fine-tune the location or re-assign the device to another asset. Additionally, the lack of power or network cables means that LoRaWAN devices can easily be fitted to devices in hard-to-reach places or installed up to a couple of kilometres from the nearest LoRaWAN gateway.

However, to keep battery usage at a minimum, LoRaWAN utilises star topology and unidirectional communication, which for 24/7 monitoring, has some severe implications - mainly devices and gateways are not permanently in contact and accordingly cannot receive instructions.

LoRAWAN works this way because otherwise, the device would waste much energy in standby mode. Still, reassuringly, because it is the sensor that

Jorrit Walgien

initiates communication, there are no delays when it comes to alerts or trigger messages. The battery life of LoRaWAN devices hinges on the frequency of messages. Accordingly, that frequency depends on the specific application’s need - maybe an irregular alert when something is on or off, a pump that communicates every 15 minutes with regular usage parameters or a steam trap that sends a signal once a week about its status.

Solutions that need remote actuation are inappropriate for LoRaWAN applications; in this case, we suggest employing an alternative monitoring solution such as WirelessHART. However, and this is the rub, this type of monitoring is costly and would not be financially viable for the remaining 99% of non-critical assets. These, however, can be monitored via LoRaWAN, and the resulting data from both solutions can be combined into a single DCS to achieve a complete data overview. The key is carefully considering the strengths and weaknesses of both solutions and ensuring that you match the most appropriate and viable technology to the application’s specific needs.

Keeping Devices Secure

LoRaWAN is a highly secure network that takes extensive measures to protect against cyber attacks. It employs device authentication, network and session keys, frame counters, and payload encryption and decryption to ensure data security. The LoRaWAN specification includes built-in security features such as session keys, frame counters, and MIC codes, which guarantee the authenticity, confidentiality, and integrity of communication.

While LoRAWAN security is robust, we always advocate best practices, such as secure device provisioning, strong passwords, and regular firmware updates, as these are essential to

enhance network and device security further.

So, with its solid security framework, LoRaWAN ensures the confidentiality and integrity of sensitive data transmitted over its networks. Furthermore, users of LoRaWAN can enjoy peace of mind knowing the LoRa Alliance is dedicated to continually updating the LoRaWAN specification to improve security and address any known vulnerabilities.

LoRa Literally Means Long-Range.

Very long, actually. In 2019, LoRaWAN set a world record for successful data transmission by covering an incredible 766 kilometres between gateways.

Practically, industrial LoRaWAN sensors must comply with regulations and certifications limiting their output power, resulting in a shorter range than regular LoRaWAN sensors. But these regulations still enable certified LoRaWAN to operate at exceptional distances, especially compared to competing solutions. Even within the most controlled environment, communication between gateways and devices can be up to several kilometres.

LoRaWAN achieves its longrange capability by utilising LPWA technology allowing devices to communicate over a greater distance while consuming less power. It operates in the sub-gigahertz frequency band, which has better propagation characteristics than higher frequency bands. LoRaWAN combines this advantage with a proprietary modulation technology called Chirp Spread Spectrum (CSS), which extends its range and makes it less susceptible to interference and radio noise. Furthermore, by using directional antennas and adjusting transmission power, interference can be mitigated and signal quality

can be consistent.

Another LoRaWAN capability, Spreading Factor (SF), is a parameter that affects both range and data rate. LoRaWAN optimises the trade-off between long-range and battery life by automatically adjusting the spreading factor.

So when helping plan a LoRaWAN rollout, we always advise engineers to consider the number of sensors, the spreading factor, and the proximity of gateways to ensure adequate coverage and connectivity. This way, LoRaWAN can be optimally used to achieve the desired results.

Weighing Up Technologies.

WirelessHART is a technology that, along with LoRaWAN, has proven adaptable and robust enough to meet the rigorous demands of the oil and gas environment.

But, while WirelessHART has been around for far longer than LoRaWAN and offers more advanced security features, LoRaWAN was designed to be scalable, easily deployable, and manageable. LoRaWAN was created explicitly for long-range communication with low data and low-power consumption. It requires a far simpler infrastructure than WirelessHART and is more cost-effective due to its lower device cost and much longer range.

Yet, as discussed, WirelessHART or a specialist solution may be the best choice for particular specific industrial application requirements.

The reality is that each of these proven technologies has its own pros and cons. Still, interestingly, the crossover in use cases is minimal, meaning that these two competing technologies complement each other very well. So, combining LoRaWAN and a second technology, such as WirelessHART, can actually help create the perfect digital solution, providing a facility with the ultimate breadth of insight and maximum integrity, but for an acceptable price. •

Contact

LoRaWAN

Combining Ultrasound & Thermography for Rig PMs – Condition Monitoring on a Different Wavelength

Tony Dale, MD at Geo Therm Ltd discusses combining two condition monitoring methods ultrasound and thermography to address rig uptime without service disruption.

The purpose of a survey is to verify rig equipment condition through comprehensive inspection needs, and is primarily focused on safety, in this article, the use of a third-party condition monitoring service is focused on surveying electrical distribution equipment using ultrasound and thermography, to address asset reliability to prevent operational breakdowns and costly downtime.

Rig survey arrangements are based on a preventive maintenance approach with a planned maintenance system containing predetermined maintenance tasks and acceptance criteria in accordance with standards of maintenance, legislative requirements, Classification, Client Specific Requirements, and the Original Equipment Manufacturers (OEM) specifications.

Two condition monitoring techniques that we regularly combine are 1. First pass Ultrasonic emission detection and 2. Infrared hot-spot thermography for annual electrical maintenance checks. When combined, the techniques become a ‘tour de force’ mutually benefiting the client bottom line while enhancing the early detection of electrical system failure.

The survey detection methods use different wavelengths, with failure potentials recognized early within the predictive domain along the Point of Failure (PF) curve, (before functional failure and possibility of collateral damage).

Ultrasonics detects Partial Discharge (PD) emissions above the human hearing range and as its name suggests, is an electrical discharge that occurs across a portion of the insulation between two conducting electrodes, without completely bridging the gap.

The value of ultrasonic PD tests has been recognized since the 1950’s and successfully used in many industrial sectors to determine electrical insulation integrity and equipment condition in high voltage HV systems.

PD analysis is a predictive test and indicates insulation degradation in advance of the failure. Survey testing does not affect the equipment under load, rather the occurrence of partial discharge can be identified within normal operating parameters, detecting cable insulation deterioration and other electrical problems in motors and generators, breaker switch gear systems, transformers, splices & cable terminations.

It is a proven fact that many HV equipment failures happen

because of PD. Partial discharges represent partial failures of the insulation, creating tracking, arcing or invisible corona across the surface or inside of the conductor insulation, each generating distinct harmonics above the frequency of human hearing while creating visible surface markings.

The effects of partial discharge are synonymous where voids, cracks, or other flaws where electrical stresses exceed the insulation capacity, even when there is no heat present. Once present, partial discharge remains within the electrical system.

Arcing, tracking, and corona have additional deleterious effects within an aged electrical system, the effects ionize the electrical cabinet air molecules creating ozone and nitrogen by-products, such as nitric acid when the humidity increases, (a reason why all modern rig switchgear rooms are air-conditioned).

The effects are visually evident, tracking causes dark dendritic tree-like branching patterns, while corona creates residual white smokey blooms on surfaces - often noticed around insulation tape wrapped around conductors and at fiberboard partitions, while acrid conditions cause a green patina on exposed copper.

Furthermore, the distinct harmonics and

Geo Therm Ltd technician using an UltraTev probe to access transient earth issues, and ultrasonic partial discharge.

Ultraprobe being used to scan around closed MCC cubicles to probe for partial discharge before the thermographic survey on the same cubicle.

observed spectra support diagnosis. The use of a magnetic ultrasonic contact probe placed upon the switchboard cabinet surface makes the inaudible audible, with discharges such as cracking and popping sounds begin heard, indicative of partial discharge occurring. While spectra data showing amplitude and frequency information can be reviewed if a UE System 15000 Ultra-probe unit is utilized to its full extent, and all surveyed while the electrical switchboard remains closed and operational.

Partial discharges can also occur in new equipment where poor design or workmanship is present (this is often evident in cable joints and terminations that are made on site). Once a partial discharge survey has been undertaken a thermal inspection can be carried out more safely, since equipment is deemed safe for opening.

• Ultrasound and Thermography are noninvasive diagnostic tools.

• Thermography reveals high-resistance hot spots, while airborne ultrasound reveal partial discharges associated with equipment flaws.

• Tests are performed when equipment is operational, without service disruption.

• A faulty electrical connection will produce detectable ultrasound before it generates enough heat to be detected by thermography.

• Ultrasounds are detectable even in high noise environments.

• Thermography passively detects thermal anomalies safely and quickly.

• Combined surveys are tailored to the client’s requirements, to suit operational conditions at that time.

• When used together, Ultrasound and Thermography will help reduce costly breakdowns, since faults are found early before outages and other consequential losses.

Due to safety considerations, it is advisable

to perform the HV non-invasive ultrasonic test before a thermographic hot-spot survey since equipment is deemed safe for opening. Thermography is a technique of detecting the infrared radiation emitted by a body to produce a thermal map or image of its surface.

Handheld or fixed mounted thermal cameras are used to display temperature variations, indicated in different colours or in shades of grey. The image produced is called a thermogram.

Thermogram interpretation supports the condition monitoring of both electrical and mechanical equipment, to identify high resistance, extreme hot spots once an unimpeded line of sight is gained and plastic dead front screens removed, (since plastic is nontransmissible to infrared energy).

Thermal imagers read the surface temperature of objects, however not all surfaces emit thermal energy equally well. Emissivity is the material property that describes the efficiency with which an object radiates heat, hence thermal camera adjustment is necessary to eliminate false positives.

Identifying thermal variations from a baseline image provides real-time feedback, helping to support trend analysis (with consistent loading) furthermore, immediately warns the user of equipment failure or electrical fire potential. Measured temperatures deviating from the norm indicate poor electrical connections such as loose, corroded, or oxidized connections, including phase imbalances and cable overloads.

Abnormal heating associated with high resistance or excessive current flow is the main cause of many problems in electrical systems. The checking of electrical devices should be

undertaken when they are fully warmed, and at steady state conditions with at least 40% of the typical load.

Infrared thermography and ultrasound detection should only be performed in a diagnostic function by trained, certified and experienced personnel. Both survey techniques are relatively quick, surveying the same piece of equipment in a non-intrusive manner, requiring only one surveyor to scan the exterior cabinet then the interior.

Retro-fitting ultrasound ports integrated into thermal windows further improves safety duality, as systems no longer need opening to gain internal access.

Both Thermographic and Ultra-sound systems have their merits. When used together they are mutually beneficial, able to tackle more asset compliant needs from a different wavelength perspective. To help identify and diagnose the rootcause more efficiently. Furthermore, reduce maintenance overheads, while improving integrity and uptime of the critical electrical systems, and all without service disruption. •

Geo Therm LTD (Head Office)

T: +44 (0)1502 723241

E: tonydale@geothermltd.co.uk

W: https://www.geothermltd.co.uk

Geo Therm Ltd surveyor wearing an arc-flash suit while scanning an open transformer with a thermal camera to locate high resistance at busbar and winding tap terminations.

Above: Geo Therm Ltd surveyor using a thermal imaging camera to safely look through an infrared window of connections in a generator terminal box.

It’s Back. Offshore Europe 2023: Charting a Path to Sustainable Energy Solutions

As the world continues to grapple with the challenges posed by climate change and the urgent need to transition to more sustainable energy sources, the spotlight is set to shine on Offshore Europe 2023. This eagerly anticipated event will bring together industry leaders, experts, and innovators to discuss and showcase the latest advancements in offshore energy exploration and production. Scheduled to take place from 5-8th of September, Offshore Europe 2023 promises to be a pivotal moment for the offshore energy sector and a platform to propel the industry towards a greener and more sustainable future.

Offshore Europe has long been recognized as a premier event for the offshore energy industry, providing a valuable forum for networking, knowledge exchange, and collaboration. With an impressive lineup of keynote speakers, panel discussions, technical sessions, and an extensive exhibition, the event offers a unique opportunity for participants to connect with like-minded professionals, share insights, and forge strategic partnerships.

One of the key themes at Offshore Europe 2023 will be the exploration and promotion of sustainable energy solutions. As the global demand for energy continues to rise, the offshore sector has a crucial role to play in meeting this demand while minimizing the environmental impact. Participants at the event will have the chance to delve into topics such as renewable energy integration, carbon capture and storage, offshore wind power, and advancements in energy storage technologies. The conference sessions will explore the latest research and innovations driving the industry towards a more sustainable future.

Offshore Europe 2023 will also showcase the cutting-edge technologies and best practices transforming the offshore energy landscape. From advancements in exploration and production techniques to digitalization and automation, participants will gain valuable insights into how technology can enhance operational efficiency, reduce costs, and

mitigate environmental risks. Exhibitors will have the opportunity to present their latest solutions, ranging from robotics and drones to remote monitoring systems and predictive maintenance tools.

As countries worldwide commit to ambitious net-zero targets, the offshore energy sector must navigate the transition towards decarbonization. Offshore Europe 2023 will facilitate discussions on the strategies, policies, and investments required to accelerate this transition. Key stakeholders, including

government representatives, industry leaders, and environmental experts, will explore the challenges and opportunities associated with decarbonization, highlighting the importance of collaboration and innovation in achieving sustainability goals.

In addition to the technical and environmental aspects, Offshore Europe 2023 will also focus on the financial aspects of the offshore energy industry. The event will feature sessions dedicated to investment trends, financing models, and the role of public-private partnerships in driving sustainable energy projects. Investors, financial institutions, and project developers will engage in discussions on risk mitigation, return on investment, and the future of funding renewable energy initiatives.

Offshore Europe 2023 holds immense significance as the offshore energy sector seeks to navigate the path towards a sustainable future. The event’s emphasis on collaboration, technological innovation, and decarbonization underscores the industry’s commitment to addressing the challenges posed by climate change. With a platform that brings together leading experts and stakeholders from around the world, Offshore Europe 2023 is poised to drive transformative change and shape the offshore energy landscape for years to come.

Submersible Motor Design Considerations and Advancements Through the Years?

A submersible motor is a specially designed motor that has fluid inside the motor. Special design considerations are required for this type of motor to ensure safety and reliability whilst it operates submerged in fluid.

Theworld’s first submersible motor was developed by Hayward Tyler in 1908 for a marine salvage application. Since its first invention, submersible motors have undergone gradual changes to meet the demand of various industries with international standards setting a precedent on design considerations. Conventional air-cooled submersible motors appeared on the market as a form of marinised resin encapsulated ‘dry’ motors. Fluid filled, primarily oil-filled, submersible motors are also used as an alternative to the conventional air-cooled machines. However, the biggest draw-back of these designs are they are not tolerant against moisture and seawater ingress. The insulation used in the electrical windings and electrical joints are made of hygroscopic materials i.e. they tend to absorb moisture from the surroundings. This is obviously not desirable for an electrical motors as it could cause a short to ground. To satisfy the requirements of safety critical applications such as firewater pumps and to ensure trouble-free operation when installed in harsh environments, water-glycol submersible motors are the preferred choice for applications in the offshore oil and gas, desalination, renewables, mining, and defence industries.

Winding Insulation

The stator windings of a submersible motor need to be water resistant and operate under constant hydrostatic pressure at the design voltage for at least 20 years. Hayward Tyler whom has pioneered submersible motor design, initially used PVC insulated windings between the 1960s to 1990s. PVC even though water resistant has a comparatively(?) low dielectric breakdown strength and a lower temperature class rating compared to other water-resistant wires that were available at that time, which limited the lifespan of the windings. With ever increasingly challenging markets, to increase the lifetime of the stator windings, the wire insulation was then upgraded to Sioplas. However, Sioplas being chemically crosslinked, had its own disadvantages associated with storage conditions and splice manufacturing. Sioplas was eventually superseded by polyethylene crosslinked (XLPE) via irradiation in the 1990s. Irradiated XLPE creates an increased uniform and controlled insulation crosslinking, which has resulted in higher dielectric breakdown strength (70kV/mm), higher insulation thermal class rating (maximum 90oC continuous rating) and a significant improvement to the mechanical

properties of the wire. Hayward Tyler only uses irradiated XLPE on submersible motors up to 13.8kV, for direct on-line and inverter duty application. Even though irradiated XLPE winding wires are more expensive than PVC and Sioplas, the benefits of using this technology results in longer wire life and a significant reduction in meantime-between-failure (MTBF). Longer life and reduction in MTBF is especially important in applications when lifting the motor out of the fluid (i.e. off shore) is very expensive and impacts the operability of the system.

Winding Wire

As well as the insulation system, equal emphasis should also be given to the overall winding wire design . The copper conductor of the winding wire that Hayward Tyler uses are manufactured from high conductivity copper to increase the motor efficiency by reducing stator copper loss. For high voltage applications, it is important to use a semiconducting layer as the conductor screen. This semiconducting layer helps to smooth out surface irregularities and reduce electrical stresses, which is important to eliminate partial discharge activity within the wire. The insulation thickness of the wire varies depending on the operating voltage of the motor and the quality of supply voltage. Motor manufacturers need to ensure that inverter driven submersible motors are provided with adequate insulation thickness to withstand the voltage stresses at the output of the inverter. The winding wire outer sheath is covered by a film of polyamide to protect the winding wire against mechanical damage that can occur throughout the manufacturing process and during operation. These factors are important to prevent the formation of water-treeing within the winding insulation of a submersible motor. Finally, to ensure consistent quality, Hayward Tyler only uses approved cable manufacturers, which have undergone quality audits and stringent product testing in accordance with ISO 9001, ISO 14001, OHSAS 18001, IEC/EN 60811, IEC/EN 60034 standards.

To increase the reliability of a submersible motor, Hayward Tyler ensures that an adequate level of cleanliness is maintained, not only during the cable manufacturing process but also during the electrical

joint manufacturing. Hayward Tyler’s manufacturing facility is divided into several zones of cleanliness level, and the cleanliness level of the stator winding manufacturing is compliant with ISO Cleanroom standard 9. By adhering to a stringent cleanliness level, foreign object debris, which are known to initiate partial discharge activity within the electrical insulation, can be practically eliminated to ensure a highly reliable product.

Electrical Joints

The reliability of the electrical insulation system of a submersible motor lies in the integrity of the electrical joints. Submersible motors are 3 phase induction motors. Each phase can comprise of either a single length of cable or multiple bundles. To connect the individual cable lengths together electrical joints are needed. Additional joints are needed to connect the stator windings to the motor power cables. However, joints are inherently the weakest part of the motor insulation system therefore Hayward Tyler has undertaken extensive development work to maximise the reliability of our joints. Earlier generations of submersible motors used off-the-shelf insulating tapes that were hand wrapped for the electrical connections within the stator. The effectiveness of these joints decreased with increasing pressure. Material compatibility between the insulating tapes and various types of water glycol was also an issue. As the demand for submersible motors to be installed in deeper waters grew, so did the need for more effective jointing methods that could withstand the increased pressure and voltage requirements. Initially handtaped XLPE joints were developed by Hayward Tyler in the 1990s that consisted of a homogenous electrical insulation system,

offering a complete XLPE-insulated windings and joints. The nature of the XLPE is that upon proper manufacturing treatment the materials bond into one homogenous pieces with no boundary layers separating them. These XLPE handtaped joints, however, had its own disadvantages. Being a manual process, the technique is highly dependent on the skills of the operator especially in maintaining a uniform joint thickness. . In 2010s, Hayward Tyler developed a novel moulded joint using a custom designed injection moulding machine. Hayward Tyler had developed a technique to create a solid XLPE-only insulation system that is void-free, water resistant and the ability to operate up to 400 bar up to 13.8kV that can operate for at least 20 years. Injection moulded joints not only retained all the benefits of the handtaped joints described above, but the process is automated and simple resulting in a more consistent joint. Having a complete XLPE homogeneity insulation system also ensures compatibility with a wide range of glycols used in various installations around the world.

As part of the design and manufacturing process of cable and joint assemblies, Hayward Tyler employs the use of Finite Element Analysis (FEA) and physical product testing. The design of the cable-joint assemblies is verified using FEA to simulate the operating conditions. The cable-joint assemblies then undergo a series of qualification testing to the Subsea Electrical Power Stadardisation standard EPS SP-1001. Testing to other standards can also be carried out where required by customers or local requirements.. Examples of tests include high voltage tests insulation tests, partial discharge tests, pressure and temperature cycling tests, mechanical tests, and material tests. All of the tests are completed in the Hayward Tyler factory in Luton, UK. The results of the FEA and tests allows improvement to the design and qualify the product for use in the market. Thermal analysis is also performed on the whole motors to ensure the stator windings will operate within the thermal insulation class.

Cooling Circuit

The cooling circuit of a submersible motor consists of an internal auxiliary impeller that provides forced circulation through the motor internals. Cooling channels located along the thin-skinned motor case allows the heat generated by the motor to be transferred externally to the seawater. A header tank or diaphragm is required to maintain a positive differential pressure, to lubricate the mechanical seal and eliminate sea-water ingress. Hayward Tyler uses an environmentally friendly glycol fluid as the motor coolant. This cooling system ensures the internal temperature of the motor is maintained below the maximum rated temperature of the winding cable, ensuring a long life service for the motor under all operable conditions.

Condition Monitoring

As Hayward Tyler continues to strive for product improvements, a condition-based monitoring system was developed with the aim to help our customers plan for maintenance work, to reduce their production downtime

with the aim of driving down the equipment cost of ownership.

Hayward Tyler’s condition monitoring system is intended to be used where the equipment is located in a remote or inaccessible area and in hazardous or extreme environments where sensors cannot be fitted to the equipment.

Hayward Tyler continues to invest in advancements to our submersible motor designs to offer customer best in class reliability. Our focus on continuous improvement of the design and materials has allowed to minimise the risks to our customers whilst maximise the motor run time. Our proprietary jointing technique is widely recognised as the most reliable in the industry and sets our motors apart from our competitors.

The calculations below provide a guide to estimate the volt drop of a cable.

Cable selection for submersible motors in borehole application

Hayward Tyler’s submersible motors will operate satisfactorily with a 3.5% volt drop at the motor terminals when connected to a three-phase power supply. Certain standards and the wiring regulations require the cable selection to be limited to volt drop of 2.5%. While there are benefits in selecting a cable which result in lower voltage drop such as lower running cost due to lower copper loss, the initial cost would be higher because of the use of a larger and more expensive cable.

Where there are stipulations to use 3.5% volt drop for a deep borehole application, then the following steps should be used. •

This article was written by: Tim Angs of Hayward Tyler Ltd.

If you would like to know more about the topics discussed in this article, or would like to know more about Hayward Tyler Ltd.’s solutions please contact them at: Hayward Tyler Ltd.

T: +44 (0) 1582 731144

W: https://www.haywardtyler.com

Calculations:

Vd=(Mv.I.C)/1000

Vd = Volt drop

Mv = Multivolt drop per amp per meter (Obtained from cable manufacturer datasheet)

I = Full load current of the motor

C = Cable length (meter)

To find the volt drop using 100m of 25mm2 cable with a motor full load current of 100A, Vd=(1.6 x 100 x 100)/1000 = 16 Volts for 460 volts supply, Vd = 3.5% Therefore, 100m of 25mm2 cable would be suitable as a borehole cable if the supply is 460V but not if it is 415V.

If a specific standard or regulation must be adhered to limit the volt drop to 2.5%, or where lower running cost is preferred, then 35mm2 cable should be considered.

Vd=(1.1 x 100 x 100)/1000 = 11 Volts on 440 volts supply, Vd = 2.5%; for 460 volts supply, Vd = 2.4%

The power lost in the cable can be calculated and used to determine the overall efficiency of the installation.

Power lost = √3 x Vd x I = √3 x 11 x 100 = 1.9kW

Note that the current rating of the cable must not be exceeded and should be used as a starting point for borehole cable selection. For shallow boreholes, this will be the only factor to be considered.

Energy Efficient Temperature Control

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 longestablished 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: process-

orientated, 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 second-tonone 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 Europe-funded research project RHeaDHY.

The project aims to develop innovative, high-performance 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 high-pressure refuelling that generates significant heat.

LAUDA, as a part of a consortium of European partners, will develop a high-performance 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 forecase 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.

LAUDA Technology Making Waves

Offshore Europe boasts a ’50-year story of continuous innovation that mirrors the evolution of North Sea energy’, and so does ours. Established in 1956, LAUDA have since continuously been at the helm of cuttingedge innovation. Involvement in projects like RHeaDY prove we are committed to continuing this legacy and building a more sustainable future.

Our experts will be on stand 1A30 from 5th – 8th September, 2023 at the Offshore Europe Exhibition in Aberdeen, welcoming the chance to discuss your heating and cooling solutions, provide further information on LAUDA’s commitment to hydrogen innovation, and of course meeting you face-to-face!

We know that the transition to a sustainable energy future depends on our industry. SPE Offshore Europe provides a platform for collaboration, progress, and high-quality results designed by us in the industry, for the industry. •

LAUDA. Empowering Excellence. For a better future.

If you can’t make the show, we are always contactable in other ways:

Email: info@lauda-technology.co.uk

Phone : +44 (0)1780 243 118

Web: lauda-technology.co.uk

Front Line Maintenance (FLM)

Front Line Maintenance (FLM) is the preservation of tools and assets in a company in order to allow operations to continually run smooth transactions and avoidance of major hindrances. FLM is more convoluted than other forms of maintenance since it requires maintenance crews to fix issues whilst the assets are in use (Brightside, 2021).

General Overview

An example of FLM in application is when trains in metro stations are delayed due to maintenance issues. In order to increase profitability and availability of services with steady operations, workers have to adhere to strict guidelines and training courses for the best FLM practices. For the purposes of this article, Front Line Maintenance (FLM) will be mostly associated to the Oil and Gas industry unless stated otherwise.

Performance Improvement

Narayanan, Wardhaugh and Das (2021) stipulate that the improvement of performance in the realms of maintenance works hangs in the balance between both efficiency and execution. In other words, teams have to plan accordingly under strict timelines and scheduling along with constructive resource administration and allocation. Findings on performance benchmarking of refinery or plant operators conclude that their time is being mismanaged, and around 25% of it should be appointed to maintenance efforts. Workers should be able to find and fix issues like corrosion in equipment as early as possible to increase productivity.

Safety

Safety is usually a top priority for FLM in the Oil and Gas industry – especially in marine and offshore worksites. Frontline workers have to be “responsible for managing process safety and other risks in their hazardous workplaces,” (Lilburne, Lant & Hassall, 2021) with the use of either their own knowledge or others’ in order

to manage critical situations. Aging assets tend to pose as a threat to safety because of the “cumulative degradation” due to corroded machinery that may cause erosion and fatigue in the mechanisms – this eventually causes normalisation of deviance (complying to degraded asset conditions) (Khan, Mad, Osman & Aziz, 2019).

Other safety barriers on assets include structural, mechanical, process and marine integrity, fire and explosions, pipelines, corrosion, human factors and others (Khan, Mad, Osman & Aziz, 2019).

Asset Life

The Oil and Gas (OG) industry requires recurring maintenance of all parts, structures

and engines to ensure optimal performance of assets. Should the performance of assets be reduced, it results in downtimes, high costs and endangerment of labourers. According to Márquez and Papaelias (2020), the three types of maintenance that are undertaken for assets are “corrective”, “preventative” and “predictive” maintenance respectfully. Corrective maintenance is conducted when a failure occurs; Preventative maintenance decreases the likelihood of failure when performed at specific periods according to strict criteria determined through a timeschedule or through system sensors, testing or analytics.

Predictive Maintenance is carried out according to the expected asset condition to avert failures.

Khan, Mad, Osman and Aziz (2019) claim that asset degradation factors include namely corrosion, erosion, fatigue, asset obsolescence and normalizing of substandard conditions/ operations. These issues are exacerbated when there are a large amount of aging assets to maintain. The NOROG (2017) mention that manipulations of fluid composition influence occurrence of corrosion in specific systems. Hydrocarbon Release

Hydrocarbons comprise of various compounds that naturally occur in crude oils like petroleum and natural gas (Clark, 2018). Hydro-carbon releases (HCRs) causes major casualties in off-shore facilities and even though accidents have reduced since 1992,

Front Line Maintenance

there are over 140 accidents occurring in a year just in the UK itself (Gilroy, Dumolo & Porter, 2012). HCRs tend to be performance indicators of asset integrity management of offshore installations as they potentially herald severe accidents. (Adejugba, 2013). According to the Hydrocarbon Release Reduction Toolkit, HCR’s do not occur mainly through involuntary lapses in equipment operations, but basic human error instead; in terms of designing, maintaining and operating (Step Change in Safety, 2010). HCR’s are also caused due to corrosion in pipelines or other storage tanks and facilities mainly in the Marine and offshore institutions. In order to keep these HCRs from occurring frequently, rapid action must be taken on-site to mitigate corrosion and strengthen asset integrity.

Addressing Corrosion

Issues

Rahuma & M (2014) specify the following; the “economic loss” in the OG industry is “extremely high” and some products used to combat it are corrosion inhibitors since they are very economical (Miksic, Furman & Kharshan, 2009) and are categorized according to their chemical, cathodic, anodic or mixed nature. Inhibitors that are made in the form of coatings extend the life of an asset as they produce a protective thin film that prevents the substrate underneath from corroding. Potential of the substrate is increased when the metal “enters the passivation region” where an oxide film is created and the inhibitor reacts with the corrosive elements and removes them (Popoola, Grema, Latinwo, Gutti & Balogun, 2013).

Compatibility with the environment, economical constraints, providing corrosion protection with minimal side-effects should be the top priority of OG companies that choose to use the coating to mitigate corrosion. In order to save on costs, the selected coating being used must be able to be applied and be used within a short period of time to revive the asset and allow for flawless operations. Application of this

coating should ideally be without the use of large equipment, excessive manpower and tools or equipment and should be applied onsite as opposed to a third-party site.

In order to articulate the entire process of using such a coating (ZINGA) to address and fix corrosion issues on-site, a flowchart has been provided and can be used as a checklist when applying ZINGA onto surfaces that need corrosion protection as a corrective, preventative or predictive maintenance application.

ZINGA has become a staple in the OG Industry for both upstream and downstream in Malaysia and Singapore. It has been tried, tested and proven to meet the stringent requirements to protect and preserve aging assets since 2015. Various trial tests have

been conducted to validate the corrosion protection performance of ZINGA that are now implemented across the board.

Corrosion Protection of ZINGA

ZINGA is a one component zinc rich coating or Film Galvanising System containing 96% zinc (dust) in its dry film. It is a metallic coating and not a paint. The purity of the zinc used, is so high that dry ZINGA does not contain any toxic elements. ZINGA provides active and passive protection and therefore can be applied as a paint. Active protection refers to the Zinc (anode) sacrificing itself in favour of the steel substrate (cathode); where the electron flow in the circuit prevents corrosion from occurring.

As for Passive protection, paints and cladding create a barrier between the steel substrate and the elements that are eventually breached –that allow for corrosion to compromise the substrate beneath the coating. As for ZINGA, the zinc oxide layer and organic binders create an additional impervious barrier by blocking the zinc’s natural porosity with oxide particles. Once the barrier is breached however, the zinc will re-oxidise and will once again to provide anti-corrosive protection.

ZINGA is known to be a standalone system as its protection standard is comparable to that of galvanization without the need for topcoats. ZINGA can be re-applied on itself with minimal surface preparation without compromising its anti-corrosive integrity.

Characteristics of ZINGA

ZINGA is known to have record drying times compared to other coatings in the industry. It is touch dry in around 10 minutes at 20°C (40 µm DFT). It can be recoated

with a new layer of ZINGA an hour after being touch dried (other paints 6 to 24 hours after touch dry). Faster system applications allows for shorter application times, less man hours and shorter close down time of assets and structures. Since the cost of equipment, personnel and cost through economical loss due to non-functioning of the structure is the highest of a coating project, this means ZINGA is immensely cost-effective.

ZINGA can be recharged without major surface preparation – only the accumulated zinc salts need to be removed. Depending on the age of the layer of inga, salt removal can be performed through a water wash or steam cleaning at 150 bar at 80°C or by sweep blasting.

Each new layer of ZINGA makes the former layer liquid, ensuring that the layer is homogenous. In the case of drilling or welding surfaces, the first layer of ZINGA acts as a primer and can intercept severe damages. Another ZINGA layer can be reapplies and local damages can be repaired but welding seams need to be cleaned beforehand. If the entire surface need not be coated with ZINGA, it can instead be applied on damaged spots for corrosion protection to maintain structural integrity.

ZINGA happens to be fire retardant as well –which bodes well since most resources in the oil and gas industry are prone to combustion. It does not spread flames or produce toxic flames and his been tested by independent laboratories. A fire test at SGS Yarsley Technical Service (UK) found that ZINGA has a class 0 surface (best ranking) in flame spread ranking.

A reaction to fire test was performed at Efectis (Netherlands) in 2013. ZINGA showed to propagation of the fire, no toxic smoke or droplets.

Conclusion

OG industry organisations are forced to continue operations despite having aging assets and having to deal with the high costs and safety risks that come with it in such a competitive and highly regulated environment.

ZINGA meets these criteria for corrosion protection, safety, and productivity. It is easy

to use, reduces downtime and contains non-toxic elements within the formula that allow for harmless application. This increases its economic value and provides OG companies with a viable and effective solution that can be carried out at flexible time-periods. •

Written by: Aneesha Kaur Sachdev, Zingametall, Singapore. Director of Business.

ZINGAMETALL BV

Phone: +32(0)9/385.68.81

Email: info@zinga.eu

Web: https://www.zinga.eu

References

Adejugba, O. (2013). How has industry achieved a significant reduction in Hydrocarbon Releases? (Masters). University of Aberdeen. Brightside. (2021). What is maintenance?. Retrieved 14 October 2021, from https://www. brightknowledge.org/engineering/what-ismaintenance

Lilburne, C., Lant, P., & Hassall, M. (2021). Exploring oil and gas industry workers’ knowledge and information needs. Journal Of Loss Prevention In The Process Industries, 72, 104514. doi: 10.1016/j. jlp.2021.104514

Clark, C. (2018). What are hydrocarbons? - Gulf Coast Environmental Systems. Retrieved 16 October 2021, from http://www.gcesystems.com/what-arehydrocarbons/

Gilroy, J., Dumolo, D., & Porter, D. (2012). IDENTIFYING THE CAUSES OF HYDROCARBON RELEASES ON OFFSHORE PLATFORMS (1st ed., pp. 33-38).

Rugby, Warwickshire: Institution of Chemical Engineers.

Khan, R., Mad, A., Osman, K., & Aziz, M. (2019). Maintenance Management of Aging Oil and Gas Facilities. Maintenance Management. doi: 10.5772/ intechopen.82841

Miksic, B., Furman, A., & Kharshan, M. (2009). EFFECTIVENESS OF THE CORROSION INHIBITORS FOR THE PETROLEUM INDUSTRY UNDER VARIOUS FLOW CONDITIONS (pp. 1-2). NACE International, Corrosion Conference and Expo. Retrieved from https://www.cortecvci.com/Publications/Papers/ Nacereviewed/09573.pdf

Márquez, F., & Papaelias, M. (2020). Introductory Chapter: An Overview to Maintenance Management. Maintenance Management. doi: 10.5772/intechopen.86892

Narayan, V., Wardhaugh, J., & Das, M. (2008). 100 Years of Maintenance & Reliability: Practical Lessons from Three Lifetimes at Process Plants (1st ed.). New York: Industrial Press.

NOROG. (2017). 122–Norwegian Oil and Gas Recommended Guidelines for the Management of Life Extension (2nd ed., pp. 9-12). Stavange: Norwegian Oil and Gas Association. Popoola, L., Grema, A., Latinwo, G., Gutti, B., & Balogun, A. (2013). Corrosion problems during oil and gas production and its mitigation. International Journal Of Industrial Chemistry, 4(1), 35. doi: 10.1186/2228-5547-4-35

Rahuma, M., & M, B. (2014). Corrosion in Oil and Gas Industry: A Perspective on Corrosion Inhibitors. Journal Of Material Science & Engineering, 03(03). doi: 10.4172/2169- 0022.1000e110

Reliabilityweb. (2021). Operators as a Maintenance Resource - Reliabilityweb. Retrieved 16 October 2021, from https://reliabilityweb.com/articles/entry/ operators_as_a_maintenance_resource

Step Change in Safety. (2010). Hydrocarbon Release Reduction TOOLKIT (1st ed., p. 4).

Aberdeen, UK: Step Change in Safety.

Aquaterra Energy Secures Multi-Million UAE Decommissioning Contract

Aquaterra Energy, a leader in global offshore engineering solutions, today announces a multi-million-pound contract with a major Abu Dhabi based operator, working in partnership with TPMC, to provide offshore riser equipment and services for the decommissioning of eight wells, in 80m water depth offshore Abu Dhabi by 2028.

Aquaterra Energy secured the tender through its leading offshore engineering expertise, regional knowledge, and status as a fully independent riser connector OEM. The offshore specialists will provide a completion and workover riser system complete with AQC-CW connectors, as well as an additional subsea riser system, tieback engineering and rig modifications. Throughout the contract Aquaterra will deliver a complete end-to-end managed service, providing engineering services, expertise and personnel.

The completion and workover riser system, complete with AQC-CW connectors, is certified to BS EN ISO 13628-7 2006 and can operate in water depths of up to 1,500m. The system has been designed to withstand repeat make and breaks, whilst offering a gas tight metal-to-metal seal.

Aquaterra Energy will work closely alongside in-country partners to manufacture and transport the project equipment. This will provide thousands of hours of local employment for the region, as well as opportunities for upskilling and knowledge sharing. Local in-country inspectors will be deployed to ensure the high quality of work throughout the project. By working with local partners, Aquaterra will ensure significant carbon savings through minimising transportation and travel costs.

James Larnder, Managing Director, Aquaterra Energy comments: ‘We are delighted to have secured this work in the Middle East and to expand on our decommissioning and riser expertise. This is an important region for us as a business and we’ve seen significant growth here over the last few years. We plan to continue this momentum and are on course to increase both our presence and revenue in the region by the end of the year. This project represents a step forward in this journey as we spearhead our global expansion.”

Andrew McDowell, Operations Director at Aquaterra Energy said: “Winning this tender further demonstrates our team’s global riser system expertise, understanding of operational requirements in the Middle East, and the significant advantages of our independent connector OEM status. We’re looking forward to utilising our

experience and working closely alongside engineers in the UAE, sharing our knowledge, and building on existing local capabilities to deliver a top-class end-to-end service.” Aquaterra Energy has identified the Middle East as a key geography to support its global growth plan. This contract marks another significant step forward in the region for the business, building on its regional footprint, having delivered intelligent engineering solutions to over 35 projects in the Middle East to date. •

Germany: TotalEnergies and VNG Join Forces on Green Hydrogen to Decarbonize the Leuna Refinery

TotalEnergies and VNG, a German natural gas distribution company, have signed an agreement to initiate the future supply of green hydrogen to the Leuna refinery operated by TotalEnergies. Under the agreement, green hydrogen will be produced from renewable electricity with a 30 MW electrolyzer in Bad Lauchstädt, built and operated by VNG with its partner Uniper.

This agreement contributes to the decarbonization of the Leuna refinery and will reduce the site’s annual CO2 emissions by up to 80,000 tons by 2030.

Furthermore, the pipeline connection to the Bad Lauchstädt Energy Park will give the Leuna refinery access to the future European hydrogen infrastructure and the international markets for green hydrogen.

“This project is fully in line with TotalEnergies’ ambition to decarbonize all hydrogen used in its European refineries by 2030. Our ambition is to replace the gray hydrogen with low carbon hydrogen, representing a reduction of 3 million tons of CO2 per year by 2030,”said Jean-Marc Durand, Senior Vice President, TotalEnergies Refining Base Chemicals Europe.

About TotalEnergies and the decarbonization of its European refineries

TotalEnergies focuses on decarbonizing the hydrogen used in its European refineries, a move that should reduce CO2 emissions by 3 Mt per year by 2030. In addition to our partnership, launched in 2021 at the Normandy refinery, TotalEnergies and Air Liquide signed a partnership agreement in November 2022 to build an innovative, circular system at the Grandpuits biorefinery to produce and harness renewable hydrogen. At La Mède, the Masshylia project to produce hydrogen in partnership with Engie is moving forward. •

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The Multiple uses of Hydrogen in the Medical Field

The potential of hydrogen use in healthcare is huge. Safety, however, remains an issue that IEC conformity assessment can address.

Today hydrogen is most commonly used for industrial purposes in chemical processes and petroleum refining. In the future, it could also play a major role in transportation, energy storage, as well as electricity and heat generation. Could it also be used in the medical field? The answer is yes: hydrogen - and especially green hydrogen - has the potential to generate important changes in hospitals and healthcare settings.

New ways of using hydrogen-based applications in hospitals are currently under scrutiny but further research and development into safety considerations, infrastructure requirements and regulatory aspects are still needed before the full potential of these technologies can be harnessed. There are many examples of how hydrogen could be used in hospitals, some of which are listed below.

Power generation

Hydrogen fuel cells could become a clean and efficient power source for hospitals. Fuel cells generate electricity and heat by combining hydrogen and oxygen, producing only water vapour as a byproduct. The technology may offer a sustainable and reliable energy solution, thus reducing hospitals’ reliance on traditional energy sources. Additionally it could also reduce the long terms costs of energy.

Investments in the technology to produce green hydrogen are expected to be initially significant but in the longer term, the technology could be beneficial due to lower maintenance costs.

Research and lab applications

Hydrogen could be utilized in various research and laboratory applications, such as gas chromatography, as a carrier gas or a fuel for flame detectors. It could also be used in certain chemical reactions and experiments.

• Sterilization

Hydrogen could become an alternative to traditional sterilization methods. Hydrogen peroxide gas plasma sterilization systems are already in use, particularly for delicate and sensitive medical equipment. Hydrogen gas can kill microorganisms and sterilize equipment without leaving residue or toxic byproducts.

Scientists are also exploring hydrogen’s potential therapeutic use in a variety of medical applications, including:

• Antioxidant and anti-inflammatory effects

Hydrogen is believed to have antioxidant properties, meaning it may help reduce oxidative stress in the body, and thus may protect cells from damage. Hydrogen has also shown antiinflammatory effects.

• Neuroprotection

According to research, hydrogen gas may have neuroprotective effects, which could help with neurological conditions such as strokes, traumatic brain injuries and neurodegenerative diseases like Parkinson’s and Alzheimer’s. It may help reduce brain inflammation and neuronal damage.

• Cardiovascular health

Studies suggest that hydrogen may help improve outcomes in various cardiovascular diseases, including heart attacks, heart failure and cardiac arrests. It may reduce inflammation and cell death in the heart tissue.

Metabolic and diabetes-related conditions

Hydrogen may help improve insulin sensitivity, reduce oxidative stress associated with diabetes and alleviate complications related to these conditions.

• Radiation therapy

Researchers have also explored the potential of hydrogen in mitigating the side effects of radiation therapy, protecting healthy tissues from radiation-induced damage. In brief, it may enhance the effectiveness of radiotherapy while reducing adverse effects.

• Inhalation therapy

The potential therapeutic benefits of hydrogen gas inhalation are being studied. Since it may have antioxidant and antiinflammatory effects, inhalation therapy using hydrogen gas is currently being explored in clinical trials for conditions like acute respiratory distress syndrome (ARDS), lung injury and other respiratory disorders. Again, the research results so far seem promising but hydrogenbased therapies are still in the early stages of development and further studies, including clinical trials, are needed to establish its effectiveness and safety in specific medical applications.

Additional challenges

While research in the potential use of hydrogen in hospitals and healthcare concentrate on applications in infrastructure and therapy, the safety and reliability aspects, both for medical staff and the patients, must be taken into consideration.

Detection of hydrogen leaks is difficult because the gas tends to disperse upwards. Hydrogen burns more easily than petrol and a single spark of static electricity can generate a fire, which may not be immediately noticeable because hydrogen flames are also invisible, resulting in an explosion that can result in human casualties and structural damages nearby. Handled by skilled professionals in industrial facilities with restricted public access and the appropriate equipment, the risks are limited. The new hydrogen economy envisages much wider applications for hydrogen, meaning many more people, not all versed in the operating of hazardous areas and much greater risks of accidents.

ADNOC, John Cockerill Hydrogen, and Strata Manufacturing to Boost UAE’s Hydrogen Economy

Agreement supported by Ministry of Industry and Advanced Technology brings the production of electrolysers to the UAE for the first time, strengthening decarbonization and domestic manufacturing

Abu Dhabi, United Arab Emirates - June 1, 2023 – The Ministry of Industry and Advanced Technology (MoIAT) announced today at the “Make it in the Emirates” Forum in Abu Dhabi that is has supported a strategic collaboration agreement between ADNOC, John Cockerill Hydrogen and Strata Manufacturing, aiming to manufacture electrolysers in the UAE for local use and for export.

Electrolysers produce green hydrogen, an energy source made from renewables that does not emit carbon dioxide at the point of use. The arrangements intended to be put in place as contemplated by the agreement enhances the development of the UAE’s green hydrogen economy through the in-country manufacturing of electrolysers and supports the UAE’s “Make it in the Emirates” initiative to promote local industry and create a favorable environment for investors.

The agreement was signed at a ceremony witnessed by His Excellency Dr. Sultan Ahmed Al Jaber, Minister of Industry and Advanced Technology and Managing Director and Group CEO of ADNOC, Her Excellency Sara Al Amiri, Minister of State for Public Education and Advanced Technology, His Excellency Ahmed Jasim Al Zaabi, Chairman of Abu Dhabi Department of Economic Development (ADDED), His Excellency Antoine Delcourt, Ambassador of Belgium in the UAE and Jean-Luc Maurange, Executive Member of the Board, John Cockerill Group. It was signed by Hanan Balalaa, Senior Vice President, New Energies and Carbon Capture, Utilization and Storage, ADNOC, Ismail Ali Abdulla, Managing Director & CEO of Strata Manufacturing and Raphael Tilot, CEO of John Cockerill Hydrogen.

His Excellency Omar Al Suwaidi, Undersecretary of the Ministry of Industry and Advanced Technology, said: “Accelerating the development of future industries is one of the main objectives of the National Strategy for Industry and Advanced Technology. Therefore, the ministry is committed to ensuring the national industrial sector benefits from innovative solutions and advanced technologies that support the expansion of future industries. Stimulating cooperation between leading national

companies and international and local manufacturers is key to these efforts, which reinforces the industrial sector’s contribution to decarbonization in line with the UAE’s net zero and COP28 targets. “Led by ADNOC, this strategic cooperation agreement strengthens our industrial sector and provides the necessary capabilities for future industries to thrive. The agreement will be particularly beneficial to the field of hydrogen, which represents one of the most important future industries and underpins a greener economy.”

Balalaa said: “We are very pleased to partner with John Cockerill Hydrogen and Strata Manufacturing in this landmark initiative that could enable electrolysers to be manufactured in the UAE for the first time. Hydrogen is a critical fuel in the energy transition and this agreement underscores how the energy sector can work with the industrial and hard-to-abate sectors to decarbonize at scale, drive low-carbon economic growth and enhance energy security. ADNOC will continue to advance lower-carbon solutions and decarbonization technologies to strengthen our position as a responsible energy provider and support the UAE Net Zero by 2050 Strategic Initiative.”

Abdulla said: “We are excited to join forces with ADNOC and John Cockerill Hydrogen in this groundbreaking initiative. Strata’s expertise in advanced manufacturing will play a crucial role in establishing the UAE as a global hydrogen leader. This collaboration aligns with our strategic vision of driving innovation and economic growth in the UAE.”

Tilot said: “As a leader in large scale green hydrogen production and distribution solutions, we are delighted to collaborate with ADNOC and Strata Manufacturing to explore opportunities to develop electrolyser manufacturing capabilities in the UAE. This partnership will strengthen the UAE’s position in the global hydrogen market and will enable the country to achieve its ambitious decarbonization objectives.”

ADNOC is an early mover in the production of clean hydrogen and is a key enabler of the UAE’s ambition to become a key supplier to global hydrogen markets. The company is also a shareholder in Abu Dhabi Future Energy Company (Masdar) which has around 20 GW of clean power capacity and targets at least 100GW renewable energy and up to 1 million tons of green hydrogen by 2030.

The second edition of the Make it in the Emirates Forum has attracted extensive participation from decision makers, government and private sector officials, experts, entrepreneurs, financing entities, investors, startups, and SMEs. Its primary goal is to showcase investment opportunities within the local industrial sector, emphasizing the potential for investment, product development, product localization, and redirecting procurement towards the national economy.

In addition to showcasing the UAE as a global hub for manufacturing and innovation, the forum seeks to promote sustainability and reduce and eliminate carbon emissions within the industrial sector in line with objectives of the ‘Year of Sustainability’, the UAE’s Net Zero by 2050 strategic initiative, and its preparations to host COP28. •

Creating Connections Safe

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Princeton Digital Group and Tata Power Renewables Join Forces Through 25-Year Renewable Energy Agreemen

Mubadala Investment Company (“Mubadala”), the Abu Dhabi sovereign investor, today announced a landmark partnership between its investee companies, Princeton Digital Group (“PDG”) and Tata Power Renewable Energy Limited (“Tata Power Renewables”) for the supply of clean electricity to one of PDG’s flagship data centers in India.

Under the terms of the agreement, PDG, a leading Pan-Asia data center operator, and Tata Power Renewables, one of India’s largest integrated power companies, have co-invested in a captive power plant that will supply electricity to PDG’s MU1 data center in Airoli, Mumbai, under a 25-year renewable Power Consumption Agreement (PCA).

First power from the solar plant, located in the Nanded district in the Indian state of Maharashtra, will be generated in June 2023, with additional capacity to come online following the completion of future phases of the solar plant. The solar plant will help PDG’s MU1 with its target to be powered by up to 50 per cent by renewable energy.

Khaled Abdulla Al Qubaisi, Chief Executive Officer, Real Estate and Infrastructure Investments (“RE&II”) at Mubadala, said: “Mubadala is delighted about the partnership between two of our investee companies, PDG and Tata Power Renewables. Both companies align with our focus on value creation and delivering positive outcomes for society, and our view that digitalization is vital to socioeconomic progress and development. By bringing our partners together, we are further supporting the build of sustainable solutions in India, a key strategic partner and market for Mubadala.”

Vipin Shirsat, General Manager, India, PDG, added: “Cloud and digital adoption continue to surge in India leading to unprecedented growth in digital infrastructure. This gives us an opportunity to make long term decisions that not only fosters growth and innovation but also solves sustainability. Our agreement with Tata Power enables us to offer world class sustainable data center services to our customers by substituting a substantial part of conventional energy with renewable energy. This partnership is testament to PDG’s commitment to work towards achieving Net Zero for our Scope 1 and Scope 2 emissions by 2030.”

Ashish Khanna, CEO, Tata Power Renewable Energy Ltd, said: “Our collaboration with Princeton Digital Group will enable their data center to source fixed-priced clean and renewable

energy on long term basis which is the most cost-effective way. Data centres are factories of the future and we are committed to supply them with green energy. Tata Power Renewable Energy Ltd. offers a comprehensive portfolio of renewable energy solutions and, through our expertise in the domain, we shall continue to contribute towards India’s Net-Zero target.”

In 2022, Mubadala invested $350 million in PDG, which has a portfolio of 21 data centers with a capacity of more than 700MW spanning six countries. In the same year, together with BlackRock Real Assets, Mubadala invested $525 million in Tata Power Renewables, which is at the forefront of India’s energy transition and aims to contribute 30GW by 2030, a significant step towards achieving the nation’s sustainable energy goals. •

Australian LNG Monthly Report

Thecold weather approaches, and with it the second decision from Minister King on whether to activate the Australian Domestic Gas Security Mechanism (ADGSM) due at the end of June.

The ACCC’s March 2023 interim gas inquiry report indicated a shortfall of 11 PJ in the third quarter of 2023 and a surplus of 18 PJ in the fourth quarter. This isn’t a large deficit overall and shouldn’t present a problem, but the issues in winter 2022 stemmed from greatly increased peak demand rather than overall demand/supply balance.

The long-range forecast for the east coast energy market isn’t good. Demand isn’t decreasing, no new projects have been sanctioned in six months, and supply is forecast to decline in coming years. On the brighter side, the weather outlook has improved. The Bureau of Meteorology’s outlook has recently shifted to an El Nino alert, which brings dry and warm conditions for most of Australia this winter – a positive for a stressed east coast energy market.

Downward pressure on LNG prices in the short term Mild weather in the northern hemisphere and burgeoning gas storage inventories are putting downward pressure on European Union (EU) and Asian spot prices.

Overall, Japan’s LNG imports in May 2023 were the lowest in over 20 years and about 30% lower than May 2022. Japan has so much LNG stored that its importers were offering shipments for sale in May.

Some of the statistical highlights in this report are:

• Australian LNG projects shipped 6.822 Mt in May (99 cargoes), up on 6.7 Mt (97 cargoes) in April.

• Australian LNG export revenue in May was $6.3 billion, higher than the $6.0 billion in April, and down by 3% on May 2022.

• Queensland exported gas to the other states in May, with daily net flows to southern states throughout the month.

• Queensland had the lowest average spot gas prices in May at $17.06/GJ, with southern states at $18.20 – $19.57/GJ: all well above the $12/GJ price cap, even allowing for transport costs.

PETRONAS, MOL, and SDARI Acquire Four AiPs for LCO2 Transportation

PETRONAS,

Mitsui O.S.K. Lines, Ltd. (MOL) and Shanghai Merchant Ship Design & Research Institute (SDARI) have attained four Approvals in Principle (AiPs) for their jointly developed liquefied carbon dioxide (LCO2) carriers and LCO2 floating storage and offloading unit (FSO).

The approvals were awarded by the classification societies Det Norsk Veritas AS (DNV) and American Bureau of Shipping (ABS). The AiPs indicate that the classification societies have reviewed and approved the basic design of the LCO2 carriers as well as the FSO, as they fulfill the technical requirements and safety criteria.

Datuk Adif Zulkifli, Executive Vice President and Chief Executive Officer of Upstream PETRONAS said, “LCO2 carriers for CO2 transportation play a key role in the Carbon Capture and Storage value chain. The attainment of the AiPs further strengthens PETRONAS’ commitment in providing decarbonisation solutions, aligned with our aspiration to establish Malaysia as a leading CCS hub in the region.”

Nobuo Shiotsu, Senior Managing Executive Officer of MOL said, “MOL is pleased with our achievement of the various designs of the LCO2 carrier and FSO in cooperation with PETRONAS and SDARI. Development on a large scale is an essential step for the CCS value chain within the Asia Pacific and Oceania region. Through the newly acquired AiP, MOL will further accelerate this initiative on the CO2 transport business as part of our effort to reduce society’s overall GHG emissions.”

Zhou Zhiyong, Vice President of SDARI said, “SDARI is delighted to join this innovative project with PETRONAS and MOL. The concepts will be essential to LCO2 transportation and operation, and will boost CCS development in the maritime industry.”

The two AiPs from DNV are for a short-haul LCO2 carrier with the capacity of 14,000 m3 and a long-haul LCO2 carrier with the capacity of 87,000 m3. The other two AiPs from ABS are for an 87,000 m3 LCO2 carrier with Dynamic Positioning System, and a 96,000 m3 LCO2 FSO for intermediate storage.

The 14,000 m3 LCO2 carrier is presently the world’s largest design with AiP for medium temperature and medium pressure conditions, while the 87,000 m3 LCO2 carrier and 96,000 m3 LCO2 FSO are presently the world’s largest designs with AiP

for low temperature and low temperature conditions. The large capacities enable a more competitive unit rate for LCO2 marine transportation.

For PETRONAS, collaboration with industry partners is part of its deliberate steps to accelerate the delivery of effective solutions with lower carbon footprints, in line with its aspiration to achieve Net Zero Carbon Emissions by 2050. •

CEO of PTTEP honored with the Thailand Top CEO of the Year 2023

Mr. Montri Rawanchaikul (right), Chief Executive Officer of PTT Exploration and Production Public Company Limited (PTTEP) received the Thailand Top CEO of the Year 2023 award in the Natural Resource Exploration and Production, and Utility category from BUSINESS+ magazine. In collaboration with the Faculty of Commerce and Accountancy, Thammasat University. H.E. Mr. Nurak Marpraneet (left), Privy Councillor presented this prestigious award, recently held at InterContinental hotel, Bangkok.

The award aims to honor top executives in various sectors who possess a vision and employ effective strategy in managing the organization for success.

The information, statements, forecasts and projections contained herein reflect the Company’s current views with respect to future events and financial performance. These views are based on assumptions subject to various risks. No assurance is given that these future events will occur, or that the Company’s future assumptions are correct. Actual results may differ materially from those projected. •

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ModuSpec has been awarded a contract to support the intake of a stranded new-build jack-up drilling rig. The jack-up was originally constructed in 2020 in Singapore and has remained stranded in the construction yard following the market crash and global pandemic.

As the upstream oil & gas market has recovered, the owners of the stranded rig have been awarded a multi-year contract in Latin America.

The ModuSpec team will support during the reactivation period of the jack-up – to be ready to commence a programme commencing Q4 2023 – including witnessing the reactivation and recommissioning of key equipment and systems.

Over the past 24 months, ModuSpec has helped several clients to bring stranded rigs back to life, requiring a unique approach working in collaboration with the rig owner and oil company.

Mark Watson, Operations Manager for ModuSpec, said: “We are delighted to be chosen for this contract. There are around 50 stranded new-build rigs located in the shipyard which could be reactivated and made available to the market.

“We have a proven history with new-build rig projects, providing the support required before they can leave the shipyard and commence operations. We have to take into account that this rig has been stranded for nearly three years and special attention is needed to ensure the equipment and systems can function safely, as intended and within compliance. We look forward to working with another client in Latin America, a market where we have been very successful.” •

Petrofac Extends Relationship with NEO Energy to Optimise Life of Field

Petrofac, a leading provider of services to the global energy industry, has been awarded an extension to its integrated services contract with NEO Energy.

The life of field extension, worth £250 million, will see Petrofac continue to deliver operations, maintenance, engineering and construction support for NEO Energy’s UKCS-based floating production storage offtake (FPSO) vessel, Global Producer III (GPIII).

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Current forecasts expect the asset to remain fully operational until at least 2026 when it is due for its next reclassification by DNV. In parallel, both NEO Energy and Petrofac are working hard to further extend field life beyond this date.

EEMUA's Mechanical Integrity portfolio includes: MIPC®, Mechanical Integrity Basics, E-learning, Classroom and In-house courses – to suit learning to all levels (Practitioner, Basic application, Awareness), sites and engineering needs ModuSpec Awarded Stranded Jack-Up Rig

“Our partnership with NEO Energy has seen us collectively overhaul production efficiency, maintenance execution and safe operations. Our proven approach to late life asset transformation, including a robust programme of continuous improvement and deployment of digital tools, has again played out to significantly extend asset life.” •

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PETRONAS, TEGAS Join Forces to Advance Digital Innovation and Talent Development in Sarawak

PETRONAS has signed a Memorandum of Understanding (MoU) with Tabung Ekonomi Gagasan Anak Sarawak (TEGAS) to collaborate on creating digital jobs and talent upskilling through the newly-established PETRONAS Regional Delivery Centre in Sarawak.

The new centre set up at the TEGAS Digital Innovation Hub in Kuching will generate digital jobs for local talent and serve as a launchpad for developing the region’s digital ecosystem.

The MoU was signed by PETRONAS Vice President of Group Technology and Commercialisation Aadrin Azly and TEGAS CEO Udin Bujang. The event was witnessed by PETRONAS Senior Vice President of Project Delivery and Technology (PD&T), Datuk Bacho Pilong and Deputy Minister of Urban Planning, Land Administration and Environment Datuk Len Talif Salleh, who is also TEGAS Chairman.

Datuk Bacho said, “PETRONAS is committed to the holistic development of the local community not just by creating more digital jobs but also through upskilling in areas such as software and data engineering.

“Our efforts will also include training unemployed and underserved job seekers in low code development skillsets so that they, too, can participate in the digital economy,” he added.

Commenting on the collaboration, Datuk Len Talif said, “We look forward to working with PETRONAS on developing an inclusive digital innovation and entrepreneurship ecosystem through the TEGAS Digital Village and Digital Innovation Hub, in line with the Sarawak Post COVID-19 Development Strategy 2030. We will further promote the partnership by leveraging our existing relationships with local startups, ecosystem partners and universities in Sarawak”.

The partnership will extend beyond job creation, as PETRONAS and TEGAS aim to continuously promote and advance digital innovation and entrepreneurship initiatives among the local community. The shared vision is to nurture a pool of knowledgeable and skilled talent ready to navigate the digital frontier. •

Mubadala and SailGP Make Waves Together, Embarking on an Exciting New Partnership

Trailblazing businesses join forces to create a more sustainable future through the platform of this exhilarating hightech sport, while acknowledging the rich maritime heritage of Mubadala’s home in the United Arab Emirates

LONDON / UNITED ARAB EMIRATES: SailGP, the world’s most exciting race on water, has announced a new partnership with Mubadala Investment Company, an Abu Dhabi-based international investor, as Global Series Partner. This collaboration brings together two leading-edge organizations, building on Mubadala’s successful two-year tenure as the SailGP Season Grand Final title partner in San Francisco.

The new partnership extends for the next three seasons until the end of 2026. It will focus on three key pillars: building a more sustainable future through collective efforts in sport and business, connecting responsible investment with cutting-edge technology and innovation to drive forward new ideas, and collectively promoting STEM education and sports at all levels to create pathways for talent to thrive.

Aligning with the third pillar, Mubadala will also become a Global Partner of SailGP Inspire, the global league’s genderbalanced youth and community engagement program that aims to build a more inclusive sport from the ground up while promoting diversity, inspiring change and accelerating inclusion. Through its three pathways – careers, learning and racing – the program has reached over 14,665 young people around the globe.

Homaid Al Shimmari, Deputy Group CEO and Chief Corporate & Human Capital Officer, at Mubadala Investment Company, said: “Mubadala is pleased to be working with SailGP in a partnership which brings together two trailblazing organizations. The United Arab Emirates has a long heritage of sailing, which began when wooden dhows set out from Abu Dhabi to trade with the world. Like SailGP Mubadala aims to make waves, by being a responsible investor and contributing to finding solutions to global challenges. We are also proud to be the global partner of SailGP’s Inspire program, promoting Science, Technology, Engineer and Mathematics for youth and providing opportunities for future leaders and athletes.”

Andy Thompson, managing director of SailGP said: “After a successful two years of working closely with Mubadala, we are excited to have them now join us on a global scale – making an impact that will take this partnership to the next level. By working together to drive climate positive solutions and empower change in communities where we race around the world through our ground-breaking Inspire Program, I am confident that we can accelerate our goals and jointly create a better sport and a better planet.”

Mubadala’s dedication to the championship also extends to becoming the title partner for the new-look New York Sail Grand Prix on June 22-23, 2024. One of the biggest events of the Season with a re-located racecourse off Governors Island, the Mubadala New York Sail Grand Prix is set to provide thrilling racing conditions for fans against the iconic backdrop of the Manhattan skyline and the Statue of Liberty. •

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Eni Sustainable Mobility’s Enjoy Sdds Electric Vehicles to its Car sharing Fleet in Rome

Enjoy’s Rome fleet becomes also electric. As of today, Eni Sustainable Mobility’s car sharing service will have 100 new zero-emission city cars on the road in the unmistakable lime green colour. The electric cars contribute to Enjoy’s fleet already available in the Italian capital, which consists of around 800 vehicles between cars and cargo and will expand to 200 over the next few months.

With the arrival of the new Enjoy city cars in Rome, the advantages of electric mobility are combined with the convenience of ‘free floating’ car sharing, which allows rentals to begin and end anywhere within the dedicated service area, without predefined pick-up or drop-off points. Enjoy will take care of recharging, allowing customers to move around freely, with the new city cars available with a battery charge no lower than 30%.

“Enjoy’s car sharing service has been available in Rome for nine years. During this time, it has become an established service that is complementary to local public transport, facilitating mobility for citizens and contributing to making urban mobility more sustainable”, said Stefano Ballista, CEO of Eni Sustainable Mobility. “Eni Sustainable Mobility is contributing to the Net Zero by 2050 target set by Eni. Car sharing, now also electric, is part of the many solutions that are already available to contribute to the decarbonization of transport, such as the development of HVO biofuels, biomethane, e-mobility and hydrogen.”

Since it began operations in Rome in 2014, Enjoy has rented out more than 9 million vehicles locally, making car sharing a popular alternative to traditional individual ownership, with benefits on traffic decongestion and quality of life for those who live and work in the city. Renting Enjoy vehicles in Rome provides advantages such as free parking in blue spaces and access to low emission zones. Enjoy also allows free use of the Enjoy Parking facilities at some Eni service stations and access to dedicated pay car parks, for example at Roma Termini station.

Enjoy has over 1.5 million customers in Italy and has recorded 30 million rentals since 2013. With a total fleet of around 3,000 vehicles, Enjoy is present in Milan, Turin, Bologna, Florence and Rome. With the addition of the new vehicles in Rome, Enjoy is completing the deployment of electric vehicles across its fleet in all cities where the service is available. •

Eni and Vår Energi to Acquire Neptune, a Leading Independent Exploration and Production Company with Low Emission, Gas-Oriented Operations in Western Europe, North Africa, Indonesia and Australia

Eni

S.p.A. (“Eni”) is pleased to announce that along with Vår Energi ASA (“Vår”) it has reached an agreement to acquire Neptune Energy Group Limited (“Neptune”).

Neptune is a leading independent exploration and production company with a world-class portfolio of gas-oriented assets and operations in Western Europe, North Africa, Indonesia and Australia. The portfolio is competitive in terms of cost and low in operational emissions. Neptune was founded in 2015 by Sam Laidlaw and is currently owned by China Investment Corporation, funds advised by Carlyle Group and CVC Capital Partners, and certain management owners.

Eni will acquire assets comprising Neptune’s entire portfolio other than its operations in Germany and Norway (the “Neptune Global Business”) (the ‘’Eni transaction’’). The German operations will be carved out prior to the Eni transaction and the Norwegian operations (the Neptune Norway Business’’), will be acquired by Vår directly from Neptune under a separate share purchase agreement (the “Vår transaction”) (the Eni transaction and the Var transaction together comprising the “transaction”).

The Vår transaction will close immediately prior to the Eni transaction with the proceeds from the Norway sale remaining with the Neptune Global Business purchased by Eni. Vår is a company listed on the Oslo Stock Exchange and is 63% owned by Eni.

Under the agreed terms, the Neptune Global Business will have an Enterprise Value of c.$2.6bn, while the Neptune Norway Business will have an Enterprise Value of c.$2.3bn. As of 31 December 2022, net debt of the Neptune Global Business, pro forma for the sale of the Neptune Norway Business, was c.$0.5bn. The final net consideration for both transactions will be subject to customary closing adjustments and will be paid in cash at completion. The Eni transaction will be funded through available liquidity. •

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Roundtable on Benefits of Natural Gas for Population and Economy Held in South Africa

The International Roundtable titled “The Benefits of Natural Gas for the Population and the Economy” was held today in Johannesburg (South Africa). The event took place under the auspices of the African Energy Chamber with support from Gazprom.

Taking part in the Roundtable were Ilya Rogachev, Ambassador Extraordinary and Plenipotentiary of the Russian Federation to the SAR and concurrently to the Kingdom of Lesotho, Dmitry Khandoga, Head of Department at Gazprom, NJ Ayuk, Chairman of the African Energy Chamber, as well as representatives of business communities, experts and journalists from nine African countries: Algeria, Angola, Egypt, Ghana, Kenya, Mozambique, Nigeria, South Africa, and Tanzania.

The participants discussed the role of natural gas in the sustainable development of Africa. It was noted that most countries on the African continent are still facing the problem of energy availability and their energy consumption is several times below the world average.

At the same time, according to expert estimates, Africa will generate over 60 per cent of the global population growth by 2050. Taking into account the current urbanization trend, the region is expected to experience a significant economic growth, which will be accompanied by a two-fold increase in energy consumption. In particular, the demand for natural gas will increase by 2.5 times.

It was highlighted at the event that an increase in natural gas production will help meet the growth in gas demand on the African continent. However, as of today, the bulk of gas produced in Africa is exported abroad. For instance, every third person in Nigeria, the largest African LNG exporter, has no access to energy. This is why it is the availability of energy for the industry and population that will be of primary importance for Africa’s dynamic development.

The participants of the Roundtable discussed the benefits of using natural gas as compared to other types of energy sources. It was noted that air pollution is a major concern for the continent. According to the statistics, polluted air is among the leading causes of premature deaths on the continent. This problem can only grow bigger over time. It was highlighted that all areas of activities making the biggest contribution to air pollution can be effectively addressed through the use of natural gas.

The potential role of gas in solving the food problem was also highlighted at the event. Besides the fact that the use of gas does not require large areas for electric power generation and does not lead to the reduction of cropped agricultural areas, gas is also a valuable raw material for the production of fertilizers which make it possible to significantly increase crop yields. Presentations were delivered at the Roundtable by the representatives of Gazprom and the Gazprom Group companies, namely, Gazprom Gazifikatsiya, Gazprom Energoholding and Gazprom Helium Service. Their presentations provided information about the activities of Gazprom and the extensive scope of the Company’s competencies along the entire value chain of the gas business. •

TenneT has Signed a EUR 8 Billion Credit Facility to Finance its Increasing Investments in the Energy Transition

Earlier this year, TenneT announced its intention to explore the possibility of a full sale of its German activities to the German government on acceptable terms. Such potential transaction would enable the creation of two strong national players, controlled and funded by their respective governments, and cooperating in driving the energy transition.

To support the financing of TenneT’s increasing Capex programme while having the exploratory discussions with the German government, TenneT Holding B.V. (ratings A3/A-, stable outlook) has signed a EUR 8 billion Credit Facility with a tenor of 2.5 years.

The facility is one of the largest single tier ticket credit facilities in Europe since 2020 and is provided by TenneT’s existing relationship banks, namely BNP Paribas (Bookrunner), ABN AMRO, BNG, Commerzbank, Deutsche Bank, ING, Rabobank, Santander, SMBC, and UniCredit as Mandated Lead Arranger.

TenneT Chief Financial Officer Arina Freitag: “TenneT is one of the largest investors in the energy transition in Germany and the Netherlands and we welcome the support from our relationship banks to execute our Capex programme with a EUR 8 billion credit facility”. •

In Kenya a Radio Commercial by Eni to Promote the Collection of Used Cooking Oils

Fry responsibly, dispose accordingly: on Kenya’s main radio stations, Eni is broadcasting a commercial to promote the collection of used cooking oils. This circular economy project has been launched in the country to help UCO (Used Cooking Oil) management and prevent its dispersal in the environment and improper reuse: once collected, the oil can have a second chance and be transformed into biofuels in Eni Sustainable Mobility’s biorefineries.

Eni Kenya’s project aims to consolidate a supply chain for UCO collection in cooperation with the HORECA industry (hotels, restaurants, catering), food processing companies and food delivery platforms: thanks to Eni, these players can correctly dispose their cooking oils and receive a financial contribution for the waste they make available for collection. Eni Kenya is among the operators licensed by the National Environmental Management Authority (NEMA) to collect UCO and also adheres to the ISCC-EU sustainability certification scheme to provide clear traceability of the collected product.

The collection of biomass such as used cooking oil is part of the activities put in place by Eni to supply feedstock for the production of HVO (Hydrotreated Vegetable Oil) biofuel in the Venice and Gela biorefineries, in Italy. The biorefineries’ feedstock is composed by waste and residues from the processing of vegetable oils, used cooking oil, animal fats, and vegetable oils from drought-resistant crops in degraded, semi-arid, or abandoned soils not in competition with the food chain. For this latest kind of feedstock, Eni is developing a network of agri-hubs in African countries including Kenya where, in Makueni County, Eni opened the first seed pressing and vegetable oil production center in July 2022. •

& P Limited/Seplat Energy operational communities in Edo and Delta states.

“A total of 96,411 patients have been screened; 45,074 reading glasses have been dispensed; and 4,218 surgeries performed. And the 2023 edition, which is being flagged off at the Oba’s Palace Benin today, will further boost these numbers. About 90 communities will be served using 13 centres across Edo and Delta states.

With this, we are able to impact communities and families. People that were hitherto blind can see now; and they can go out and do work to earn a living. This is one of the indirect impacts of the programme,” Afe added.

In his remarks, the Director, New Energy, Seplat Energy, Effiong Okon, expressed gratitude to NNPC E&P Limited and other stakeholders involved in making the initiative a success. “We extend our sincere appreciation to the Palace, the government of Edo and Delta states, and NNPC E&P Limited for their unwavering support. Their collaboration has been instrumental in ensuring the success of the ‘Eye Can See’ Initiative over the years,” Okon said.

Seplat JV Commences 2023 ‘Eye Can See’ Programme

The Seplat Energy JV held the opening ceremony of this year’s edition of its Eye Can See Corporate Social Responsibility (CSR) initiative at the Oba’s Palace in Benin City, Edo State. The company’s signature CSR health programme is designed to ensure the provision of eye care, visual aid and surgical treatment for Cataract, Glaucoma and other eye problems within NNPC E

He added that Seplat Energy and its partners will continue to work to boost the impacts of the programme leveraging relevant technologies and other resources whist appealing to the company’s host communities to always support its operations. “As you know, at Seplat Energy, we are purpose driven, we are here to serve and to give back to the society. And on that note, please we will like to continue to bank on your support going forward as you’ve always done. We anticipate that this intervention will continue and even outlive all of us.” •

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MOECO and Chevron To Explore Advanced Closed Loop Geothermal Pilot in Hokkaido Japan

Chevron New Energies Japan GK (Chevron New Energies Japan), a subsidiary of Chevron U.S.A. Inc., and Mitsui Oil Exploration Co., Ltd (MOECO) today announced execution of definitive agreements to proceed with the pilot testing of advanced geothermal technology. Pursuant to these agreements, Chevron and MOECO will conduct pilot tests of a developing novel geothermal technology, specifically advanced closed loop (ACL) technology.

In September 2022, Chevron New Energies International Pte, Ltd. signed a joint collaboration agreement (JCA) with MOECO to further explore the technical and commercial feasibility of advanced geothermal energy development and other new energies technology. The agreements to conduct pilot testing by Chevron New Energies Japan and MOECO is the first project contemplated by the JCA.

ACL technology involves sub surface heat exchange through conduction by circulating a working fluid from the surface through a loop of underground wells to generate electricity (through surface facilities) by utilizing sub surface geothermal heat (sub surface radiator). It does not require direct extraction of hot water (brine) or steam from underground reservoirs, as is the case with conventional geothermal technology. ACL is gaining momentum worldwide as a novel technology that has the potential to unlock geothermal energy globally in multiple locations, closer to load and customers, promoting geothermal development which can be a lower carbon energy solution and a reliable baseload.

The pilot test using this ACL technology is expected to be conducted in the Niseko region of Hokkaido, Japan, with the aim of derisking, scaling and commercializing geothermal power generation based on ACL technology with additional potential as a heat resource. MOECO and Chevron New Energies Japan will consider commercial applications based on learnings from this pilot both in Japan and globally and will leverage the long relationship between the two companies that has developed through a collaboration of more than 40 years in energy development in the Asia Pacific region.

“Chevron believes that the future of energy is lower carbon and aims to be a leader in providing affordable, reliable and ever cleaner energy. Chevron and MOECO believe that geothermal can be a significant enabler in Japan’s lower carbon and net zero journey,” said Barbara Harrison, Vice President of Offsets and Emerging, Chevron New Energies International Pte, Ltd. “Geothermal development needs to be carried out with the final customer in mind and with consideration of potential impacts to the environment and the local community. This milestone confirms the commitment of Chevron New Energies Japan and MOECO to testing out novel geothermal technologies that have the possibility to unlock Japan’s geothermal potential while reducing potential community impact.”

“We are pleased to launch this pilot test of ACL technology with Chevron New Energies. ACL technology has the potential to unlock geothermal development in Japan and around the world. We expect to open up a new geothermal business by collaborating

with Chevron New Energies, which has advanced technology and extensive experience to tackle this challenging project,” said Hirotaka Hamamoto, Chief Executive Officer of MOECO. “We, MOECO, a member of the Mitsui & CO’s group company, aim to contribute to the stable supply of energy, achieving improved standards of living, and sustainable development of society through the promotion of renewable energy projects such as geothermal power generation.” •

Stepan to Announce Second Quarter 2023 Results on July 26, 2023

Stepan

Company (NYSE: SCL) will issue its second quarter 2023 earnings results on Wednesday, July 26, 2023 at approximately 7:00 am ET (6:00 am CT). 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 am ET (8:00 am 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.

Corporate Profile

Stepan Company is a major manufacturer of specialty and intermediate chemicals used in a broad range of industries. Stepan is a leading merchant producer of surfactants, which are the key ingredients in consumer and industrial cleaning and disinfection products and in agricultural and oilfield solutions. The Company is also a leading supplier of polyurethane polyols used in the expanding thermal insulation market, and CASE (Coatings, Adhesives, Sealants, and Elastomers) industries. •

Valero Energy Corporation to Announce Second Quarter 2023 Earnings Results on July 27, 2023

SAN ANTONIO-- Valero Energy Corporation (NYSE: VLO) announced today that it will host a conference call on July 27, 2023 at 10:00 a.m. ET to discuss second quarter 2023 earnings results, which will be released earlier that day, and provide an update on company operations.

Persons interested in listening to the conference call may join the webcast on Valero’s Investor Relations website at investorvalero. com. •

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ADNOC and Nafis to Create an Additional 5,000 Private Sector Jobs for UAE National Talent by 2027

Strategic agreement between ADNOC and Nafis will unlock skilled jobs for UAE talent in ADNOC’s supply chain and equip them to succeed in their careers

Since the launch of ADNOC’s ICV program, 5,000 UAE Nationals have been employed in the private sector, in its supply chain and empowered through the Nafis program

ADNOC to continue empowering local talent as it decarbonizes and future-proofs its business

Abu Dhabi, UAE – June 1, 2023: ADNOC announced today at the Make it in the Emirates Forum in Abu Dhabi, a strategic agreement with the Emirati Talent Competitiveness Council (ETCC) through its Nafis program to create an additional 5,000 jobs for UAE Nationals in the private sector by 2027.

The agreement will unlock skilled jobs for UAE talent in the private sector, in ADNOC’s supply chain, and equip them to succeed in their careers through several programs and incentives that will enhance their skills and competitiveness.

ADNOC and Nafis are building on the achievements of ADNOC’s In-Country Value (ICV) program which has created 5,000 jobs for UAE Nationals in the private sector since it was launched in 2018.

His Excellency Dr. Sultan Ahmed Al Jaber, Minister of Industry and Advanced Technology and ADNOC Managing Director and Group CEO, said: “Nurturing and empowering talent is a top priority for ADNOC and we are very pleased to once again partner with Nafis to create an additional 5,000 skilled jobs for UAE Nationals in advanced sectors such as nanotechnology, manufacturing and machine learning. Today, thousands of UAE Nationals are playing key roles across ADNOC’s supply chain and helping to ensure we remain a reliable supplier of lowercarbon energy to the world. As we decarbonize and future-proof our business, ADNOC will continue to empower local talent to build successful careers and contribute to the UAE’s economic development and prosperity.”

ADNOC continues to collaborate with its suppliers and partners to promote initiatives to nurture local talent. The company has hosted six private sector career weeks in the past year to match local talent with employment opportunities in its registered partners and suppliersthe private setcor.

His Excellency Ghannam Butti Al Mazrouei, Secretary General of the Emirati Talent Competitiveness Council, said: “The agreement with ADNOC to create 5,000 jobs for Emirati talent by 2027 in the private sector companies operating with ADNOC through the In-Country Value Program is a continuation of the constructive partnership with ADNOC, which has quickly borne fruit since the signing of the first MoU last year, and the pace of job creation for Emiratis within ADNOC’s supply chain companies in the private sector has accelerated significantly, reaching 5,000 jobs, in a remarkable achievement. The agreement will also strengthen cooperation frameworks in order to achieve the strategic goals of increasing the rate of Emiratisation in the private sector and empowering our local talent in the labor market. Through the agreement, ADNOC will provide training opportunities for 1,000 graduates in private companies operating in ADNOC’s supply chain through Nafis’s Apprentice Program”. Al Mazrouei pointed out his confidence that such cooperation will provide Emiratis with a sustainable opportunity to achieve prosperity and excellence in their career path.

At the Make it in the Emirates forum, a panel session titled ‘Emirati Empowerment in the Private Sector’ was held to discuss how the UAE is empowering local talent and how they can capitalize on opportunities in the private sector.

The panel session featured His Excellency Omar Ahmed Suwaina Al Suwaidi, Undersecretary of the Ministry of Industry and Advanced Technology (MoIAT), H.E. Ghannam Al Mazrouei, Yaser Saeed Almazrouei, ADNOC Executive Director, People, Commercial & Corporate Support Directorate and Eng. Arafat Al Yafei - Executive Director of Industrial Development Bureau in Abu Dhabi Department of Economic Development It was attended by over 800 young UAE Nationals as well as representatives from ADNOC’s contractors and companies in the private sector.

The Make it in the Emirates Forum is hosted by the Ministry of Industry and Advanced Technology (MoIAT) in conjunction with the Abu Dhabi Department of Economic Development (ADDED) and ADNOC. The forum is bringing together some of the largest industrial companies to explore local manufacturing and investment opportunities in the UAE. •

ConocoPhillips to Hold Second-Quarter Earnings Conference Call on Thursday, Aug. 3

ConocoPhillips

(NYSE: COP) will host a conference call webcast on Thursday, Aug. 3, 2023, at 12:00 p.m. Eastern time to discuss second-quarter 2023 financial and operating results. The company’s financial and operating results will be released before the market opens on Aug. 3.

To access the webcast, visit ConocoPhillips; Investor Relations site, https://www.conocophillips.com/investor, and click on the “Register” link in the Investor Presentations section. You should register at least 15 minutes prior to the start of the webcast. The event will be archived and available for replay later the same day, with a transcript available the following day. •

Reliance and bp Commence Production from Third Deepwater Field in India’s KG D6 Block

Reliance Industries Limited (RIL) and bp p.l.c. today confirmed the commencement of production from the MJ field, following testing and commissioning activities. The MJ field represents the last of three major new deepwater developments the RIL-bp consortium have brought into production in block KG D6 off the east coast of India.

The start of gas and condensate production from the MJ field follows the start-up of the R-Cluster field in December 2020 and Satellite Cluster in April 2021. All three developments utilise the existing hub infrastructure for the block.

Together, the three fields are expected to produce around 30 million standard cubic metres of gas a day (1 billion cubic feet a day) when MJ field reaches peak production. This is expected to account for around one third of India’s current domestic gas production and meet approximately 15% of India’s demand.

Mukesh Ambani, chairman and managing director of Reliance Industries Limited said: “We continue to be proud of our partnership with bp that combines our expertise in commissioning complex projects under some of the most challenging environments in the last few years. Alongside the other KG D6 fields, the MJ development truly supports the ‘Make in India’ and ‘Energy vision’ laid out by the Government of India.”

bp chief executive Bernard Looney added: “By safely bringing these new developments onstream, RIL and bp are making an important contribution to meeting India’s demand for secure supplies of gas. Our close strategic partnership with RIL now stretches back over 15 years and we are proud of how it continues to deepen – in gas, retail, aviation fuels and sustainable mobility solutions. Together we are helping to meet India’s growing energy needs, bringing the best of each partner to create real value.”

Discovered in 2013 and sanctioned in 2019, the MJ field is located in water depths of up to 1,200 metres about 30 kilometres from the existing onshore terminal at Gadimoga on the east coast of India.

MJ is a high Pressure and high Temperature (HPHT), gas & condensate field. The field will produce from eight wells and reach a peak gas production of around 12 MMSCMD gas and 25,000 barrels of condensate per day. •

The development includes a new Floating Production, Storage and Offloading (FPSO) vessel – the ‘Ruby’ – to process and separate the condensate, gas, water, and impurities, before sending the gas onshore for sale. Condensate is stored on the FPSO before being offloaded to shuttle tankers for supply to Indian refineries.

RIL is the operator of the KG D6 block with a 66.67% participating interest and bp holds a 33.33% participating interest. •

Proposed Acquisition of Neptune Energy by Eni and Vår Energi

Neptune

Energy today announced that Eni International BV (“Eni”) has signed a sale and purchase agreement to acquire Neptune Energy Group Limited (“Neptune”), with Vår Energi ASA (“Vår Energi”) simultaneously signing an inter-conditional sale and purchase agreement to acquire Neptune Energy Norge AS for an aggregate enterprise value (subject to customary adjustments) of $4.9 billion.

Neptune’s business in Germany is not part of the transactions and will continue to be owned and operated by the ultimate existing Neptune shareholders as a standalone group.

Clear strategic and value drivers

The Boards of Eni, Vår Energi and Neptune believe the proposed combinations will enhance their technical and financial capabilities to provide energy security and participate in the energy transition.

The existing upstream portfolios of the companies are low carbon intensity gas-focused, with complementary geographic exposure, providing Eni and Vår Energi with increased scale in growth areas and high-value markets, and enhanced decarbonisation opportunities.

Conditions for completion

Completion of the acquisitions is conditional upon, among other things, the receipt of necessary regulatory and governmental clearances. The transactions are expected to close by the end of Q1 2024.

Sam Laidlaw, Executive Chairman of Neptune Energy, said: “Since Neptune’s formation in 2018, we have invested in the business and transformed the organisation, resulting in material improvements in safety, operational performance and cost efficiency.

“I am incredibly proud of Neptune’s achievements over the past five years – and the hard work and dedication of so many people across our organisation, who, together with our shareholders, have contributed to the growth and success of the business.

“This transaction offers a new and exciting phase for Neptune, with significant growth opportunities supporting energy security and the energy transition, which will benefit from Eni’s and Vår Energi’s larger scale and available resources.” •

Octavio Romero Oropeza Inaugurates the XVII Edition of the Mexican Oil Congress in Campeche

• The CEO stressed that the oil industry is extremely important for Mexico because it is a pillar for the wellbeing of the people

• He stressed that fossil fuels, particularly crude oil and oilbased products, will continue to be a key component of the world’s energy industry

• What has been achieved by the Fourth Transformation in Petróleos Mexicanos over more than four years leaves behind the pessimistic and ill-intentioned predictions regarding the institution

CEO Octavio Romero Oropeza inaugurated the XVII edition of the Mexican Oil Congress (initials in Spanish CMP). Held for the first time in Campeche, with the slogan “Strengthening the oil industry to consolidate the future of Mexico’s energy”, the PEMEX CEO emphasized during the ceremony that this is the most important event in the field, as it not only allows sharing knowledge and experiences, but is also a good opportunity to take a break to reflect on the present and future of the industry.

During his presentation, the Petróleos Mexicanos CEO shared the positive results achieved because of the instructions issued by Mexican President Andrés Manuel López Obrador, aimed at rescuing oil activity and national energy sovereignty in an integral manner. Among these, Romero Oropeza highlighted that, within the scope of responsibility of Petróleos Mexicanos, the goal is to serve as agents of change and improve all the production indicators of the institution while taking the global energy industry into consideration.

He underscored the fact that, nine years after the 2014 energy reform, it proved to be a failure, but PEMEX continues to be practically the only hydrocarbon producer in the country. He assured that it has been possible to optimize drilling times in newly developed fields, thus reducing costs, advancing production and increasing physical activity.

He added that the goals for 2023, in terms of exploration and production, are to drill approximately one well each day, thus conserving reserves and increasing liquid hydrocarbon production to an average of 1,959,000 barrels per day.

Concerning the crude oil process in the country’s six refineries, Octavio Romero stated that the crude oil process has doubled and it is projected that, by the end of 2023, it will amount to 1.6 million barrels per day on average, and that it is expected to reach 1.85 million barrels per day by 2024, when the Dos Bocas Refinery will be operating at its maximum installed capacity. And once the Salina Cruz coker comes into operation, fuel selfsufficiency will practically be achieved.

He stressed that austerity is highly profitable and what the Fourth Transformation has achieved in Petróleos Mexicanos in over four years leaves behind the pessimistic and ill-intentioned predictions of its detractors. He also reiterated that all these achievements are thanks to the workers, as well as to the energy policy applied in PEMEX led by Mexican President Andrés Manuel López Obrador. •

Petrobras on Renewable Electricity Certificates

Petróleo Brasileiro S.A. – Petrobras informs that it has acquired international certification that ensures that 100% of the electricity used in its industrial and administrative operations in Brazil is generated by renewable sources. This seal - called I-REC certification (Renewable Energy Certificate) - attests that the electricity Petrobras acquires from external suppliers is generated exclusively by renewable sources, such as hydroelectric, wind, or solar energy.

The goal is to neutralize scope 2 emissions, a term used by the global industry for emissions associated with the consumption of energy obtained from an external supplier. The practice was incorporated by the company as of 2022. The certificates were acquired from the main companies that supply electricity to Petrobras: AES Brasil, CPFL Soluções and Cemig.

“The neutralization of Scope 2 emissions is an important milestone in our energy transition journey and shows that we are reaping concrete fruits from this journey in partnership with our suppliers. It is an advance that makes us proud, proving that we remain determined to lead the energy transition in Brazil, hand in hand with the national production chain and in tune with the demands of society,” said Petrobras CEO Jean Paul Prates.

The certificates are part of the first initiative in the portfolio of actions that counted with resources from Petrobras’ Decarbonization Fund. They cover 100% of the electricity purchased and correspond to the total scope 2 emissions of the company’s operations in Brazil in 2022.

“The acquisition of the certificates is aligned with our ambition of achieving operational emissions neutrality by 2050 and reinforces our commitment to the decarbonization of our operations, contributing to a safe energy transition,” says Petrobras’ Chief Energy Transition and Sustainability Officer, Maurício Tolmasquim.

The Petrobras Decarbonization Fund was created to support actions to decarbonize the company’s operations in the exploration and production, refining, gas and power, and logistics segments. Petrobras has the commitment to reduce its total operational emissions by 30% by 2030 and, in the long term, the ambition to neutralize its operational greenhouse gas emissions by 2050 and to influence partners to achieve this ambition.

The Renewable Energy Certificate (I-REC ) is a type of renewable energy certificate that represents the environmental attributes of generating one megawatt-hour (MWh) of energy from renewable sources. It consists of a global renewable energy attributes tracking system, designed to enable the reliable registration of energy from renewable sources. The certificate is used by specific customers for Scope 2 accounting purposes, in accordance with the most stringent international standards. •

2023/24 IMPORTANT EVENTS CALENDAR

Baku Energy Forum

Dates: 01.06.2023 - 02.06.2023

Venue: Baku, Azerbaijan Website: https://bakuenergyforum.az/en/main

SPE Offshore Europe 2023

5-9th Sept 2023

Aberdeen, Scotland, UK https://www.offshore-europe.co.uk

ADIPEC 2023

2-5 OCT 2023

Abu Dhabi, UAE https://www.adipec.com

World Hydrogen Congress

10.10.2023 - 12.10.2023

Rotterdam https://www.worldhydrogencongress.com

World Hydrogen Week

09.10.2023 - 10.10.2023

Rotterdam https://www.worldhydrogenweek.com/

OSW O&M/ Health & Safety Summit

18.01.2024 - 19.01.2024

Virginia Beach https://offshorewindus.org/omhse/

World Hydrogen Latin America

28.11.2023 - 30.11.2023

Santiago Chile https://www.worldhydrogenlatinamerica.com/

Offshore Technology Conference

1-4 May 2024

Houston, Texas, USA

AUVSI XPONENTIAL 2024

APRIL 22, 2024 - APRIL 25, 2024

San Diego, USA

https://www.auvsi.org/events/xponential/xponential-2024

Global Energy Show 2024

Calgary, Canada

June 13-15 June 2024

https://www.globalenergyshow.com