OGI Summer 2021 by Oil and Gas Innovation

Oil and Gas

INNOVATION®

Summer 2021

THE BIG HEALTH SAFETY AND ENVIRONMENT ISSUE!

COLONIAL PIPELINE: HOW TO PROTECTION YOURSELF SO IT DOESN’T HAPPEN TO YOU

Business Information. Industry Solutions.

A NEW TYPE OF CREW TRANSFER SYSTEM, YOU MIGHT NEED IT

www.oilandgasinnovation.co.uk

Summer 2021 CEO Matthew Patten Managing Editor Simon Milliere Publishing Director Edward Findlay edward@oilandgasinnovation.co.uk Commercial Director & Advertising Enquiries Nicholas Parker nparker@oilandgasinnovation.co.uk Technical Director and Website Nathan Bedmann web@oilandgasinnovation.co.uk Office Assistants Janet Elseberg admin@oilandgasinnovation.co.uk Contributing Journalist Emma Patten Business Development Executives Mylene Daugan mylene@oilandgasinnovation.co.uk Augusto Trinidad Jr augusto@oginnovation.co.uk Phoebe Ziregbe phoebe@oginnovation.co.uk Janna Garcia jannagarcia@oginnovation.co.uk Anjel Miller anjel@oginnovation.co.uk

Emery Hill Media Dalton House 60 Winsor Avenue London SW19 2RR Tel: +44 330 043 4969

CONTENTS COVER STORIES & SPECIALS

Subsea Focus

Oil and Gas Innovation sits down with Swiss Fire Protection Research & Development AG to talk about their firefighting technologies. One of the main solutions they offer is the Pi Foam System, which is quite interesting as it doesn’t require a water source to be deployed.

Launching the New FROG-XT2

In November this year, Reflex Marine is launching their long-expected solution to low-volume crew transfers for small landing areas: the FROGXT2 personnel transfer carrier.

Local Support Around the Globe

OGI sits down with Stuart Bell, Vice President Global Sales, Klippon Engineering UK Ltd, to learn more about the work they do for the future of the process industry. Klippon Engineering is the internationally renowned partner of the Weidmueller Group and is here to help us understand more about the most important factors facing the industry today.

Colonial Pipeline & Cyber Security

Lucas Young of Axis Communications addresses the importance of ensuring that network security devices do not become a weak link in the cyber security systems of energy providers.

WORLD INDUSTRY NEWS Europe North America Russia & CIS MENA Asia Pacific South America Africa

20 28 30 74 80 84 86

EXPLORATION & PRODUCTION Wellheads and Ball Valves Optimized for the high demands in oil and gas production, storage technology, petrochemistry as well as in geothermal and hydrogen applications durable wellheads with metal-to-metal seated ball valves are an important factor for safe and reliable operation.

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CONTENTS EXPLORATION & PRODUCTION Identify Your Failure Points, Before It’s Too Late

OGI sits down with Tony Dale, Managing Director of Geo Therm Ltd in the United Kingdom. Geo Therm Ltd provides SME’s with thermographic inspections which help companies with their maintenance and warranty surveys.

MIDSTREAM & PIPELINES Fulfilling the Mission to Eliminate Man Entry Tank Cleaning

Fintan Duffy, Managing Director of Re-Gen Robotics discusses why his robots are successfully revolutionising the oil tank cleaning industry and why they are outclassing humans in this task.

Drilling Holes in Pipe. Sounds Simple, but is it?

54 56

Just Drill a Few Holes and Forget About It? Well, Maybe Not.

PROCESSING Why Gas Quality Matters OGI sits down with Dr. Philippe Prêtre, CTO of Mems AG, to learn more about the work they do with gas measurement technology.

Efficient Temperature Control HEALTH, SAFETY & ENVIRONMENT Carbon Capture Explained

OGI sits down with Gas Liquids Engineering (GLE) to find out more about their work in the area of CO2 processing and sequestration, or CCS (Carbon Capture and Sequestration).

OE21 Offers Unique Opportunity for the Energy Transition EVENTS CALENDAR

72 95

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Effective – operations start from the integrated control room. Remote operations – can be operated from shore. VideoRay ROV and E-TMS with 200m tether. Operational support – highly skilled Depro personnel to supervise the operation. 2000m rated and a wide range of operational alternatives. Easy to operate – training for customers can be provided.

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CONSIDER IT DONE

SUBSEA FOCUS Subsea Integration Alliance Awarded EPCI Contract Offshore Norway

ubsea 7 today announced the award of a sizeable(1) contract by OKEA to Subsea Integration Alliance(2) for the Hasselmus project, seven kilometres north west of the Draugen platform in the southern Norwegian Sea. The project work scope covers the engineering, procurement, construction, and installation (EPCI) of the subsea production systems (SPS) and subsea pipelines (SURF) for a single subsea well with direct tie-back to the Draugen production platform. The SURF scope comprises approximately nine kilometres of pipe-in-pipe flowline and associated structures in water depths of approximately 250 metres. Project management and engineering will commence immediately at Subsea 7’s offices in Stavanger, Norway. Fabrication of the pipelines will take place at Subsea 7’s spoolbase at Vigra, Norway and offshore operations will be executed in 2022 and 2023. Monica Bjørkmann, VP Subsea 7 Norway said: “We are delighted to be awarded this contract by OKEA. It acknowledges the value potential of Subsea Integration Alliance’s seamlessly integrated and optimised offering, and extends our relationship with OKEA that began with conceptual studies. We look forward to continuing the journey on the Hasselmus field development with safety, reliability and quality at the forefront throughout.” Stuart Fitzgerald, CEO Subsea Integration Alliance LLC said: “This award to Subsea Integration Alliance supports our strategy for early engagement, full subsea system delivery, and our track record with OKEA. Working in partnership with OKEA has supported optimised solutions, early decision making and shortened delivery time, ultimately improving cost efficiency throughout the entire field lifecycle. We look forward to continuing to support this objective for the Hasselmus project”. •

OTC Spotlight on New Technology® Award

ubsea 7, a global leader in the delivery of offshore projects and services for the evolving energy industry, and Xodus Group, an autonomous subsidiary of Subsea 7, are to be recognised at the 2021 Offshore Technology Conference (OTC) in Houston with a Spotlight on New Technology® Award for Subsea 7 Nano Engineered Sensor Platform (Subsea 7 NESP). The advanced nano engineered sensor platform was selected based on its innovative technology, broad appeal to the energy industry, and significant impact with benefits beyond existing technologies. Steve Wisely, Senior Vice President of Subsea 7’s UK and Global IRM region, said: “The Offshore Technology Conference’s Spotlight on New Technology® Award highlights the global innovations that are leading the transformation of the energy industry, and we are proud to be recognised for that. “We see Subsea 7 NESP as a promising step towards our key strategic priorities of environmental sustainability and operational efficiencies and we believe it can have a significant impact on the wider industry.” Subsea 7 NESP, developed in collaboration with Xodus, is a transformative solution that can continuously monitor fatigue and corrosion offshore, reducing OPEX in these areas. The wireless nanotechnology sensor can be deployed efficiently and easily across any operating asset. Subsea 7 NESP, which requires no power supply or batteries, offers a scalable, cost effective, zero maintenance solution to extend asset life and improve uptime. Steve Hamilton, Xodus’ Chief Technical Authority – EMEA added: “We are proud to have worked in collaboration with Subsea 7 to bring this this innovative technology to market quickly and for it to be recognised by the OTC. “The NESP technology fully integrates with our Xodus Asset Management & Integrity Network (XAMIN) tool which allows our experts, infrastructure owners and operators to capture design, installation, testing, operating, inspection and decommissioning information within a single system. This additional capability means we can further increase efficiency, ensure regulatory compliance, and help optimise the performance of assets.” In announcing the award win, Leigh Ann Runyan, Executive Director of the Offshore Technology Conference said: “The Offshore Technology Conference showcases the best and brightest in the offshore energy sector, and the winners of the OTC’s Spotlight on New Technology Award are paving the way for our industry for years to come. As demonstrated by the Nano Engineered Sensor Platform, Subsea 7 and Xodus are creating the step-change innovations needed to power the future of subsea development.” •

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SUBSEA FOCUS New EPCI Contract for Bacalhau Field

quinor awards Subsea Integration Alliance an contract on its Bacalhau field development located 185 kilometres from the coast of the state of São Paulo, Brazil. The contract scope brings together field development planning, project delivery and total life cycle solutions under an extensive technology and services portfolio. The project work scope covers the engineering, procurement, construction, and installation (EPCI) of the subsea production systems (SPS) and subsea pipelines (SURF). The development will include 19 trees as well as associated subsea equipment including subsea wellheads, subsea controls and connection systems, and a full completion workover riser. The SURF scope comprises 140 kilometres of rigid risers and flowlines, and 40 kilometres of umbilicals in water depths of approximately 2050 metres. The Subsea Integration Alliance team established during the initial front-end engineering design phase, awarded in January 2020, will now transition into the full EPCI phase. Project management and detailed engineering will take place in Rio de Janeiro, Brazil, with support from Subsea 7’s Global Project Centre in the UK and France and various OneSubsea® offices. Offshore activities will take place from 2022 to 2023 using Subsea 7’s reel-lay, flex-lay and light construction vessels. Stuart Fitzgerald, CEO Subsea Integration Alliance said: “The award to Subsea Integration Alliance of the EPCI contract is a result of our strategy for early engagement and track record of major integrated projects. It underlines the strength and breadth of our global project management capabilities which underpin our delivery of large and complex integrated projects.” “We have worked closely with Equinor since the FEED award back in 2020”, said Steve Tate, Deputy CEO, Subsea Integration Alliance LLC. “Now in the EPCI phase, we will support Equinor in maximizing the Bacalhau field’s potential through access to an extensive portfolio of technologies and services, and a ‘one team’ approach to project delivery.” Bacalhau is Brazil’s first integrated SPS and SURF project. The award is a significant endorsement of Subsea Integration Alliance’s strong position within the integrated market, our long-established local presence in Brazil, and a commitment to support Equinor’s strategy of long-term growth in the region. •

Jansz-Io Compression Project to Proceed

hevron Corporation today announced that its wholly owned subsidiary Chevron Australia Pty Ltd. (Chevron Australia) as operator and the Gorgon joint venture participants will proceed with the approximately $4 billion (AU$6 billion) Jansz-Io Compression (JIC) project. Nigel Hearne, Chevron Eurasia Pacific Exploration and Production president, said J-IC represents Chevron’s most significant capital investment in Australia since the sanctioning of the Gorgon Stage 2 project in 2018. “Using world-leading subsea compression technology, J-IC is positioned to maintain gas supply from the Jansz-Io field to the three existing LNG trains and domestic gas plant on Barrow Island,” Hearne said. “This will maintain an important source of clean-burning natural gas to customers that will enable energy transitions in countries across the Asia Pacific region.” A modification of the existing Gorgon development, J-IC will involve the construction and installation of a 27,000-tonne normally unattended floating Field Control Station (FCS), approximately 6,500 tonnes of subsea compression infrastructure and a 135km submarine power cable linked to Barrow Island. Construction and installation activities are estimated to take approximately five years to complete. J-IC follows the Gorgon Stage 2 project, which is nearing completion of the installation phase, to supply gas to the Gorgon plant from four new Jansz-Io and seven new Gorgon wells. The Chevron-operated Gorgon Project is a joint venture between the Australian subsidiaries of Chevron (47.333 percent), ExxonMobil (25 percent), Shell (25 percent), Osaka Gas (1.25 percent), Tokyo Gas (1 percent) and JERA (0.417 percent). Chevron is one of the world’s leading integrated energy companies. We believe affordable, reliable and ever-cleaner energy is essential to achieving a more prosperous and sustainable world. Chevron produces crude oil and natural gas; manufactures transportation fuels, lubricants, petrochemicals and additives; and develops technologies that enhance our business and the industry. To advance a lower-carbon future, we are focused on cost efficiently lowering our carbon intensity, increasing renewables and offsets in support of our business, and investing in lowcarbon technologies that enable commercial solutions. •

Solving subsea complexity

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COVER STORY

Reflex Marine Launching the New FROG-XT2 In November this year, Reflex Marine is launching their long-expected solution to low-volume crew transfers for small landing areas: the FROG-XT2 personnel transfer carrier.

nnovation seems to be one of the trending themes in the current era of struggling global economies and collapsing markets. Yet, the concept is only useful and effective when employed for a reason and with clearly defined benefits. Reflex Marine has been at the forefront of innovation in marine crew transfer for nearly 30 years now. At the beginning, nearly 3 decades ago, Reflex Marine introduced the FROG personnel transfer carrier which changed the perspective on marine crew transfer across the world and created a global benchmark for safe crew transfers. In the last 10 years the company grew their portfolio significantly, prompted by the growth and changes in the global energy market. From upgrading the original range of carriers with new features and improved systems (to the current FROG-XT range) to the first carrier for standing passengers (WAVE-4) and the ingenious work-basket with soft-touch features and passenger protection (STORMWORK) – Reflex Marine don’t stop innovating. Despite the turbulent year in the energy market and the global economic crisis, Reflex Marine’s Innovation Team continued to work hard in order to complete the development of their latest release: FROG-XT2 personnel transfer carrier. Part of the FROG-XT range, FROG-XT2 boasts all the features we’re familiar with but is a model customised for smallest footprint and highest operating envelope. “The latest addition to the FROG-XT range of personnel transfer carriers, the two person FROG-XT2 combines all of the performance characteristics of its sister products in the range and the small footprint of WAVE-4, our standing carrier” says Reflex Marine’s Operations Support Manager, Andrew Grimes. “It was designed to satisfy a gap in the market, in response to client and industry need for access to platforms and decks with more restricted landing areas.” In those industries where crew transfer occurs infrequently or is required to access difficult landing areas, FROGXT2 is the optimal solution guaranteeing safety of passengers. Safety as standard FROG-XT2 is a compact and safe personnel transfer carrier with capacity for 2 passengers. Belonging to the FROG-XT range (XT for extreme) means that the new model has a high operational envelope often exceeding crane’s operational window. The small footprint (1.6m by 1.6m) and the cleverly designed hook-up system allow for easy maneuvering and safe access even to confined spaces. The maneuvering is further secured by contoured profile of the

carrier engineered as an anti-snagging measure. Snagging is a concern during lifting operations of both cargo and crew and is an issue recognized and addressed in all Reflex Marine’s designs (including cargo transfer box STORM-Pro). Passengers in the FROG-XT2 are seated in ergonomically designed saddle seats with 4-point harness system allowing for fast emergency evacuation but also protecting them from falling out of the carrier. Reflex Marine carriers’ designs emphasize the high safety factor achieved, among other features, by eliminating the dependence on human factor during transfer: safety harness ensures the passengers are securely strapped inside even if they don’t feel well enough to hold on to handles provided. Further to that, in a scenario where the control over the carrier in transit is lost and the device falls into water, FROG-XT2 will float and self-right in all loading configurations, ensuring the water remains below passenger’s head level. Finally, the buoyancy panels also act as a measure protecting the passengers from side impact on collision. That feature further translates to reduced risk of damage to other assets – a problem often encountered during lifting operations. Last but not least, spring-damper and shock-absorbing suspension system in the seats as well as EVA foam landing feet protect the passengers from heavy landing’s impact.

“The passenger shock-mitigation performance is verified to mitigate injury from heavy landing in up to 4.2m sea state (platform to vessel). Likewise the flotation performance of FROGXT2 has been verified in full scale immersion and inversion tests” assures Andrew Grimes, Operations Support Manager. The safety features have all been tested and testing videos are available for anyone to see online. That’s an unusual practice for the industry but a standard for Reflex Marine who are proud to be the only company in this market segment openly showing data and results of any such tests completed on all their carriers. LNG operational benefits FROG-XT2 is made out of light-weight and composite materials in order to reduce potential crane loads. “The FROG-XT2 carrier has a low tare weight of 258kg and a low maximum gross mass of 500kg which opens a wider window for performing safe crew transfers vessel to vessel” explains Victor Suarez, Senior Trainer at Reflex Marine. “In the shipping sector, there are vessels that have man-riding cranes on board with a low working load limit (between 1000 and 2000 kg safe working load). With the low maximum gross mass of the FROG-XT2 their operating envelope is increased.” The lightness and manoeuvrability of the carrier are clear operational benefits among others for the LNG and merchant shipping industries. Crane

operators involved in crew transfer would also appreciate the small footprint of the FROG-XT2 carrier. “Due to the small footprint of the XT2, during transfer operations the unit does not require large landing areas on vessels. Small footprint also allows operators to store the unit on a small deck area” adds Victor Suarez. Where crew transfers are infrequent such as pilot transfers or in port or terminal crew changes, the need for a safe method for this crucial activity is still of vital importance. The FROG-XT2 carrier is a game changer with its small footprint, minimised weight and uncompromised passenger protection features. Sustainability in design Passenger safety is of the utmost priority for Reflex Marine’s team of designers and engineers. However, the best safety track record in the entire offshore crew transfer total product universe (15 years without a lost time incident) is not the only area in which the FROG-XT carriers excel. Paul Onions, Reflex Marine’s Engineering Manager comments on the sustainability considerations: “All our products are designed for durability and ease of maintenance. This philosophy helps cut down the needless consumption of raw material required to keep a product in service. The modular design of the units allows for any damaged components to be switched out relatively easily without the need to scrap an entire unit. Our products are also designed to try and minimise the mass of them. This means less raw material is required to build them but also, as they are designed to be moved, less power and therefore less fuel is required to mobilise them. In terms of the material selection, we opt for stainless steels wherever possible. The use of this material is beneficial in two ways: stainless steel is more environmentally friendly to produce than aluminum and the high grade stainless steel used also means that no secondary operations such as painting (using environmentally unfriendly products) need to be performed to help prevent corrosion.” The careful selection of materials used also ensures that FROG-XT2 has a long lifespan (10 years as standard in the medium usage category,

which can then be extended further). The carrier is resistant to environmental factors, but for added reassurance, users can opt for a cover to prolong the life of external components even further. With users in mind Reflex Marine’s designers and engineers consider all aspects of product life-cycle and use: from materials used through ergonomic and safe design to how the carrier is being exploited and maintained. Each carrier is provided with a User Manual and a set of recommendation on inspection and maintenance which are developed based on true utilisation rate calculations to eliminate unnecessary maintenance. The design allows for simple and quick pre-use inspection with all crucial components easily visible and weld-free critical path ensuring inspection procedures can be executed in the field without sophisticated equipment. These features translate to real time savings. Further in the product’s life at sea, the inspection and maintenance processes are supported by Reflex Marine’s Operations Support Team led by Andrew Grimes: “As with all of our products we will develop Operational Training and Inspection and Maintenance Training courses. In the last few months, we have adapted our training and service support to the work and travel

restrictions relating to the global pandemic: we moved all of our training online, with webinar training and online testing. We now also offer remote oversight and review of service works conducted by our trained personnel, issuing an Approved Service Certificate on completion. Our Operations Team is always on hand to respond to technical, maintenance, and operational queries from our clients.” With a network of Approved Service Centres, Reflex Marine-trained technicians are available to support servicing requirements onshore and offshore anywhere in the world. In terms of streamlining processes, Reflex Marine’s support team offers free of charge assistance in scheduling consignments of replacement parts in line with client’s existing stock routing and the I&M recommendations for the carrier used. All these services add value and save time and are highly appreciated in the current economy. • Reflex Marine has been supplying crew transfer carriers to the offshore and marine industry for nearly 30 years now. The FROGXT range of carriers is the most advanced, safest and most cost-effective product in the this product group with the best safety record in the world. Crew transfer by crane remains the safest and most versatile method of moving workers in the offshore universe. As Reflex Marine’s FROG-XT range expands to accommodate the needs of industries beyond traditional oil & gas projects, more and more operators can confidently use FROG-XT carriers for safe and cost-efficient crew transfer in a wide range of set-ups and configurations. If you would like to know more about how Reflex Marine can help your company and its operations, please contact them at: Reflex Marine T: +44 (0) 1872 321155 E: info@reflexmarine.com W: https://www.reflexmarine.com

COVER STORY

Local Support Around the Globe OGI sits down with Stuart Bell, Vice President Global Sales, Klippon Engineering UK Ltd, to learn more about the work they do for the future of the process industry. Klippon Engineering is the internationally renowned partner of the Weidmueller Group and is here to help us understand more about the most important factors facing the industry today.

OGI: Could you start by explaining Klippon Engineering’s credentials and experience in terms of your products and services for the oil and gas sector? Could you tell our readers the breadth of your experience, how long the company has been active, and its reach? Stuart: In today’s oil and gas sector, plant availability, modularisation and digitalisation are among the most important factors for being competitive on the international market. Our goal as Klippon Engineering, the internationally renowned partner of the Weidmueller Group in the field of process engineering, is to support our global customers along that process with our customised solutions. Therefore, we have dedicated experts with long term experience from over 15 countries that are focusing on this task. For our customers, it means local support out of a globally operating network. We called this formation Klippon Engineering after our globally known brand Klippon® and headquartered it in the UK, honouring where we started producing the first fully certified terminal blocks and enclosures more than 60 years ago.

OGI: Could you talk a bit about the work that you do in the oil and gas industry? Stuart: Our globally operating network focuses on the development and supply of solutions that extend the service life of plants, increase production efficiency, reduce investment costs, and enhance safety – always in accordance with the latest internationally recognised certifications and standards. OGI: What is the scope of your solutions? Stuart: Our offering ranges from connectivity solutions, power and signalling protection products and systems, to complete solutions and technologies for communications, retrofit and migration, automation, translation, IoT and data acquisition/analysis. Currently, many of our experts are working on projects focusing on PLC migration where it is often a requirement to exchange the control units

Stuart Bell, Vice President Global Sales, Klippon Engineering UK Ltd. Stuart Bell is currently the Vice President of Global Sales at Klippon Engineering, a Weidmueller Company. A Sales focused and driven customercentric leader with over 25 years of International experience in the oil & gas and electrical services markets of the UK and the Middle East.

with minimum downtimes and in areas with limited build-up space. Another key topic we are working on, is the integration of data and Industrial IoT driven solutions, like condition monitoring, into existing systems. OGI: What does “connectivity” mean to Klippon Engineering, and why is it so important nowadays to industries such as oil and gas? Stuart: We at Klippon Engineering identified connectivity as the key to meeting the industrial needs of the present and the future. For example, increasing production efficiency by using the benefits of data analysis and automated machine learning. That’s why our “Best in Market” solutions from the wellknown Klippon® brand have a close connection to all areas of the process industry. Whether oil and gas, chemicals and pharmaceuticals, water treatment, heavy industry, glass, or paper production. We are involved in all branches of the industry. OGI: The use of IoT (Internet of Things) is continuously ramping up in the processing sector, could you talk a bit about that and your role in it?

The Klippon Engineering ranges from connectivity solutions, power and signalling protection products and systems, to complete solutions and technologies for communications, retrofit and migration, automation, translation, IoT and data acquisition/analysis.

Stuart: We have identified this topic as one of our focus areas, our background within the Weidmueller Group offers us a wide range of solutions that we can apply to the individual needs of our oil and gas customers. With our modern IoT controllers, I/O systems, and edge devices, we provide compact, individually scalable connectivity solutions for process

Customers benefit from the global Klippon Engineering Expertise Network.

control, monitoring and predictive maintenance. Within our Single Pair Ethernet (SPE) System Alliance we and other partners from the field of electrical connectivity rely on Single Pair Ethernet technology when developing the new industry standards of Ethernet cabling, meeting the future requirements with regards to space and installation effort for our customers. OGI: Earlier you mentioned your international network, can you explain how this meeting the needs of your customers and partners. Stuart: We have established manufacturing, assembly, engineering and application sites as well as key partners in focus areas to enable us to reduce customer and partners shipping costs, reduce the shipping time of goods and equipment and more importantly bringing us closer to our customers.

Wherever in the world, the client can get the same solution from our network, this means if they have global sites, we can support them locally, in the time zone, language and working time. Importantly we have the necessary global certifications to cover many of the nation and international al standards needed by the market. OGI: What migration or retrofit solutions are you offering and how is the customer benefiting from it? Stuart: We offer a variety of PLC migration interfaces, migration platform solutions, universal PLC systems as well as front connectors and assembled cables for all commercially available PLC systems. Our

customers benefit from a fast and safe rewiring of controls, sensors, or actuators, even for these complex machines and systems. Our migration and retrofit solutions speed up installation and avoid wiring errors. This saves time and money. If required, we also supply our customers with an individual PLC/DCS migration solution including approval. OGI: Thank you for your time. • If you would like to know more about how Klippon Engineering UK Ltd can help your company and its operations, please contact them at: Klippon Engineering UK Ltd. T: +44 1162 823470 W: https://www.klippon-engineering.com

Klippon Engineering migration and retrofit systems facilitate the easy introduction of new systems and accelerate the upgrade of DCS, PLC, and automation systems.

COVER STORY

Protecting the Environment and Your Wallet OGI sits down with KVT Process Technology (Kanzler Verfahrenstechnik GmbH) to learn more about their development, design, and implementation of innovative process solutions. Their main technologies applied to oil and gas are OXYSULF and THERMODEC. These are two technologies which deal with waste gas and sludges respectively. The technologies are developed to protect the environment while also recovering resources from waste gas stream or waste sludge. We learn more below.

OGI: Could you start by explaining KVT Process Technology’s credentials and experience in terms of your products and services for the oil and gas sector? Could you tell our readers the breadth of your experience, how long the company has been active, and its reach? KVT: KVT Process Technology is an engineering company with worldwide operations and long experience in development, design, and implementation of innovative process solutions. KVT offers a full range service from the first concept to a turnkey industry plant. The work of KVT is done in close cooperation with customers, delivering innovative efficient and tailor-made solutions. More than 30 years ago Kanzler Verfahrenstechnik GmbH began with the design of off-gas treatment plants, continuously offering innovative solutions to achieve closed loops, renewable feedstocks, and clean emissions. The KVT technologies are grouped in 3 main Business Units: Environmental technologies This includes off-gas treatment plants, industrial brine treatment, and sludge treatment. The KVT environmental technologies perform clean emissions with recovery of resources. Renewables technologies This business unit includes plants for the production of sustainable chemicals from renewable feedstocks.

Wet sulfuric acid technologies We develop plants for the treatment of off-gas containing sulfur compounds, plants for the production of sulfuric acid as well as plants for the regeneration of spent sulfuric acid. OGI: Could you talk a bit about the work that you do in the oil and gas industry? KVT: In the oil and gas industry we offer solutions for waste gas and sludge treatment. Our technologies are developed to protect the environment, efficiently achieving results below the emission limits. Beside the

environmental protection aspect, our technologies offer the possibility to recover valuable resources from the waste gas stream or waste sludge. Our main technologies applied in the oil and gas Industry are OXYSULF and THERMODEC. OXYSULF: The technology is based on a wet process. It can treat waste gas containing sulfur compounds with recovery of concentrated sulfuric acid, a valuable raw material. The OXYSULF technology enables plant operators to eliminate sulfurous emissions and enhance plant economics. Developed in the 1990s, the technology is continuously being improved and adapted to the constantly increasing requirements of customers and governmental regulations., Oxysulf is largely used in the oil and gas industry: Refineries & Petro-chemical Industry (SRU) • After the Gas Sweetening Unit based on amine wash system. • After Sulfur Burner in sulfuric acid production plants. • Spent acid regeneration after the alkylation phase that use sulfuric acid. Natural Gas Processing • Treatment of acid gas coming from the sour gas treatment unit. • Tail gas treatment of Claus Process.

Oxysulf is applied in many cases also in the textile, metallurgical industry, Coal based Fertilizer and Chemical Industry (Syngas SRU), Power Industry, Cokes Manufacturing. THERMODEC: Sludges obtained as byproduct or as residual of washing system in several process plants, represent a big challenge for operators that should meet environmental regulations and operate the processing plant economically. Often expensive disposal contracts are not practicable. Other treatments based on drying systems are very energy consuming. We have developed the THERMODEC technology, a thermal decomposition treatment able to treat sludge and recover energy and recover valuable raw materials.

Beside the above-mentioned technology OXYSULF and THERMODEC for the treatment of waste gas streams our portfolio includes: 1.

The technology CHLOROX for the treatment of gas stream containing chlorinated compounds with the recovery of HCl and energy.

Various VOC reduction system with heat recovery system

Integrated Flue Gas cleaning solutions:

•

Hot Gas Filtration

•

WESP Filters

Originally developed for Glycerine MONG (matter organic non Glycerine), the area of application now includes many other industrial sludges. The technology has the advantage of separating solid compounds from challenging sludge streams, generating energy, and allowing for recycling of sludge components (salt, carbon black…) or gaseous components. The vapor stream and the remaining system gas – if applicable - together with other waste gases can be fed into an incinerator to provide full oxidation of the combustible compounds. If required, liquid or gaseous waste streams from other sources can also be added to the incineration unit. Organic compounds are converted to H2O and CO2.

•

De-Dusting Systems

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DeNOx Systems

•

Scrubber Systems-various types

•

Filter Systems-various types

•

Quenching Units

•

Catalysts

OGI: What are your various production technologies and their purposes?

The focus of our technological developments is concentrated mainly in the fields of:

KVT: Our producing technologies are: •

Technology for the production of Glycerol from raw Glycerol.

•

The raw glycerine coming from different industrial process as by-product is treated in our plants until it reaches the requested purity. The glycerine is a chemical molecule, versatile applied in several products in cosmetics, pharmaceutical industry, food industry as well as raw materials for the production of several chemical intermediate products.

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Technology for the production of Epichlorohydrin from Glycerol. Epichlorohydrin is an important chemical intermediate mainly used for the production of epoxy resins.

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Technology for the production of epoxy resins. The epoxy resins are pre-polymers largely used in the paints and coating products, aeronautical construction part, in petrochemical industry, wind turbine technology e more other.

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Technology for the production of sulfuric acid from waste gas or from solid sulfur.

OGI: What type of work do you do in terms of waste processing, fuel recovery for example? KVT: We develop technologies to valorise industrial waste streams. Our technologies for the treatment of waste gas can recover valuable raw materials and recover energy.

OGI: Could you elaborate on your R&D activities? KVT: KVT invests constantly in R&D activities to develop and test new and innovative processes, improve already existing technologies, and offer more beneﬁts to customers in terms of efﬁciency, reliability, competitiveness.

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Production of chemicals from renewable feedstocks (vegetable oil, sugar, lignin).

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Waste gas and waste water cleaning.

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Waste to energy.

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Reuse of by-products and waste streams from industrial processes

The results of our R&D activities are innovative technologies, protected by international patents. In our headquarters, the R&D team uses an advanced laboratory, and complex installations of pilot plants to develop and demonstrate the beneﬁts and functionality of our processes. A lot of our development activities are realized in close cooperation with local universities and industrial partners. OGI: Finally, could you enlighten our readers of a case study where you helped a client with your solutions? KVT: KVT has been engaged for decades in the development of solutions tailored to individual customer requirements for the treatment of industrial effluents or the production of new chemicals. The origin of our company is based on such a tailor maid solution for the pulp industry. In 1979 our founder Walter Kanzler has started to develop a technology for furfural and acetic acid recovery by liquid/liquid extraction which was implemented in the beginning of the 1980’s in Austria. About 10.000 to 50.000 tons of furfural and

acetic acid are burned yearly in a leaf wood pulp plant together with the sulfite waste liquor. With our extraction technology the vapor condensates are subjected to a liquid/liquid extraction and the extracts furfural and acetic acid are purified by fractional distillation. Among the most economical solutions for the recovery of furfural and acetic acid, the process allows vapor purification of condensates of up to 90%. The technology offers economical advantages while protecting the environment by reducing emissions. The technical process is as follows: The furfural enrichment plant increases the furfural content of spent liquor by transforming the xyloses into furfural. This transformation takes place in a reactor under precisely defined conditions (temperature, pressure, reaction time) after heating up in a heat exchanger system. The furfural still contained in the thin liquor leaving the reactor is subsequently (owing to its high volatility) vaporized and taken up by the vapor condensate in the evaporation plant. The furfural contained in the vapor condensate is obtained by extraction or distillation. The technical advantage of the extraction method is a reduction of energy consumption by about 80% compared to the conventional method of distillation. By use of a special extraction agent, some 90% of furfural and acetic acid are extracted and recovered from the vapor condensate. In distillation units, the furfural and acetic acid are separated from the extraction agent to obtain a high purity level. The product range includes plants for both processes (extraction and distillation). With the application of this technology the client has achieved two sellable products which are acetic acid and furfural instead of building up a biological treatment plant. This has allowed them to make profit instead of paying money for the waste water treatment. OGI: Thank you for your time. • If you would like to know more about how KVT Process Engineering can help your company and its operations, please contact them at: Kanzler Verfahrenstechnik GmbH T.: +43 316 321404 0 E: office@kvt.technology W: https://www.kvt.technology/en

SPECIAL: CYBER SECURITY

Don’t Let Physical Security Vulnerabilities Compromise Oil and Gas Cyber Security Lucas Young of Axis Communications addresses the importance of ensuring that network security devices do not become a weak link in the cyber security systems of energy providers. Oil and gas are key elements of our critical national infrastructure and require ever more advanced levels of protection to guard against threats that are growing in seriousness and complexity. In May 2021, The Colonial Pipeline in the US, which carries 100m gallons of fuel each day and services seven airports, suffered a major cyber attack. This latest attack on critical infrastructure reinforces the fact that such sites continue to present a target for criminal gangs, terrorist units and nation-state threat actors. It serves as a reminder that, if and when they succeed on a significant scale, the effects are catastrophic.

he World Economic Forum cites cyber security failures as being among the top mid-term threats facing the world in its 2021 Global Risks Report . Globally, the providers of essential services remain vulnerable to cyber attacks, necessitating a greater focus by governments on securing oil and gas supply lines and infrastructure, and protecting the people that work in such environments. While no industry or sector is immune to the potential of being attacked, the key is to take appropriate measures to mitigate that risk where possible. One such measure is to select and install physical security technologies that are manufactured with cyber security as a prime consideration. Physical and cyber protection through ‘defence-in-depth’ As a crucial part of our critical national infrastructure, each site must be protected using the best physical security tools and technologies available to maintain high levels of protection. When seeking to roll out appropriate solutions it is essential that devices have a hallmark of quality and are themselves deemed to be secure from a cyber security perspective. A security system is only as strong as its weakest link and its imperative that these systems are not left

open to attack, compromising the physical security of a site or multiple sites. Modern solutions to guard and detect can be customised from site to site depending on requirements, with a combination of traditional intrusion detection measures and the latest cyber secure physical security technologies resulting in a robust system. An example of such a solution might include surveillance cameras with onboard analytics, infrared motion detection, access control devices and a video management system (VMS) providing alarm verification, ensuring effective physical security of assets and operations. This multi-layering of different measures, commonly referred to as ‘defence-in-depth’ , ensures that security is not significantly reduced with the loss of any single layer. Strengthening the system through device cyber security As with all technology, there are inherent risks when improperly secured IoT devices are installed on an IT network. Network surveillance cameras, for example, which are not cyber secure can be used as a backdoor to gain access to the IT network, either from an insider threat or a remotely triggered assault. Technologies manufactured in regions with lower standards of regulation and compliance might appear to offer adequate protection, but in reality, come with none of the assurances around quality of manufacture or adherence to cyber security principles. Secure technologies, built with cyber security considerations at the forefront, should form an essential part of any enterprise asset protection strategy. The oil and gas sectors should look for guarantees from the providers of such technologies,

such as Secure by Design, Secure by Default, an accolade awarded by the Surveillance Camera Commissioners (SCC), and Cyber Essentials Plus, offering evidence of operation in accordance with advanced security principles, aligned with regulation and best practice. From a network perspective, the success of the IoT should not be hampered by weaknesses in physical systems and should be secured across every touchpoint and unexpected vulnerability. Hardening security networks will lock down exposed connections, reducing access to IP-based Industrial Control Systems (ICS), while automating the 24/7 health and cyber security monitoring of devices also adds an additional layer of cyber protection. The importance of working with trusted partners and vendors According to the International Association of Oil and Gas Producers (IOGP), managing security risks is an essential business activity within the global upstream oil and gas industry . Risk management extends to the forging of trusted relationships with partners and vendors, helping to ensure that smart and effective cyber secure solutions are in place to mitigate risk. Whether the threat takes the form of low-level criminal damage, or largescale cyber attack, a converged approach whereby trusted partnerships are formed with the reliable vendors of high-quality security systems, is the best line of defence. Such partnerships will enable vulnerabilities to be addressed and resilience to be maximised across all sites. Regulations such as the GDPR, and the NIS Directive, are placing more onus on industry sectors to demonstrate security understanding and compliance and to ensure the integrity of their systems. Through implementation of a scalable, future-proof physical security solution, built with cyber security considerations front and centre, and backed by the full support of a trusted partner, today’s oil and gas providers will be ready to face whatever challenges lie ahead. •

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NEWS - EUROPE Air Liquide, Borealis, Esso, TotalEnergies and Yara Collaborate Air Liquide, Borealis, Esso S.A.F., TotalEnergies and Yara International ASA have signed a Memorandum of Understanding (MoU) to explore the development of a CO2 infrastructure, including capture and storage, to help decarbonize the industrial basin located in the Normandy region, France. With the objective to reduce CO2 emissions by up to 3 million tons per year by 2030, which is equivalent to the emissions of more than 1 million passenger cars, the first phase will consist in studying the technical and economical feasibility of this project. This partnership, which will seek funding from European, French and Regional schemes, is open to other industrial parties. The ability of industrial players to reduce their CO2 emissions in the medium and long term is a key issue for the sustainability of industrial activities and ecosystems in the area of Axe Seine/Normandy. The companies involved in the MoU have agreed to collaborate to assess the technical and economical feasibility of implementing an industrial CO2 capture and storage (CCS) chain, from their industrial facilities to ultimate storage in the North Sea. François Jackow, executive vice president and a member of the Air Liquide Group’s Executive Committee supervising Europe Industries activities, said: “Air Liquide is pleased to contribute to this project its unique expertise in CO2 capture and liquefaction technologies. Since 2015 Air Liquide has successfully implemented CryocapTM in its plant in Port Jérôme, Normandy, an innovative proprietary CO2 capture and liquefaction technology, which allows to capture up to 90% of CO2 emissions. This wider initiative illustrates how industrial players can mobilize to decarbonize key industrial basins and contribute to the fight against global warming. It is in line with Air Liquide’s Climate Objectives, which target carbon neutrality by 2050.” Leo Alders, chief operating officer of Borealis Fertilizer, Technical Nitrogen and Melamine business, said: “Our strong interest in this project is in the first place driven by the significant GHG reduction that can be achieved. It is our responsibility to society to seek for and engage in solutions for climate challenges. At the same time the project is an innovative and collaborative approach across the leading regional industries, creating new value chains.” Charles Amyot, CEO of Esso S.A.F. and president of ExxonMobil activities in France, said: “ExxonMobil has more than 30 years of experience in CCS technology and is advancing plans for more than 20 new CCS opportunities around the world. We are pleased to collaborate on a joint study to assess the feasibility of the deployment of CCS in the Axe Seine / Normandy area, one of the most important technologies required to achieve society’s climate goals.” Bernard Pinatel, president of Refining & Chemicals and member of the Executive Committee at TotalEnergies, said: “We are pleased to join forces with some major industrial players of the industrial basin of Normandy to collectively engage into a cooperation to reduce the CO2 emissions from our facilities. This collective effort will be facilitated by TotalEnergies’ actions in developing, with partners, CO2 storages in the North Sea such as the Northern Lights and Aramis’ projects. This CCS initiative will contribute to the decarbonization of our Normandy platform and is fully aligned with TotalEnergies’ ambition to get to net zero emissions by 2050.” Jorge Noval, president, Yara Industrial Solutions, a global division of Yara International ASA, said: “This alliance will support Yara Industrial Solutions’ journey to decarbonize production units and all of our value chains. Carbon Capture and Storage is essential in achieving our midterm ambition of a 30% reduction in absolute CO2 emissions in 2030 compared to 2018, meaning a reduction of 200,000 tonnes of CO2 emissions, equivalent to 100,000 tonnes Blue Ammonia at Le Havre production plant. We will implement future technologies to reach carbon neutrality in 2050 in line with Yara’s ambition. The decarbonization of our site in France will allow us to continue developing innovative applications for our industrial customers, and the impact on society will be significant. Our chemical industrial applications are all around

us, from construction to automotive, in animal nutrition and NOx emission reduction as examples.” •

Martin Linge on Stream

n 30 June at 21.56 CEST, the Martin Linge oil and gas field in the North Sea came on stream. The field is powered from shore, resulting in low CO2 emissions, and operated from its onshore control room. “This is a big day for everyone working on the Martin Linge project, for Equinor and for our partner Petoro. I would like to thank everyone who has worked hard to deliver this project,” says Arne Sigve Nylund, Equinor’s executive vice president for Projects, Drilling & Procurements. Expected recoverable resources are approximately 260 million barrels of oil equivalent (boe). At plateau the field will produce around 115 000 boe per day. “Martin Linge is an important contribution to Norwegian oil and gas production. Thanks to new infrastructure in this area it will be possible to realise new discoveries in the future. Equinor has formed a crossdisciplinary team who is looking into the opportunities of a wider area surrounding Martin Linge,” says Rune Nedregaard, senior vice president for operations south of Exploration & Production Norway. The Martin Linge platform receives power via the world’s longest alternating-current sea cable measuring 163 kilometres from the onshore substation at Kollsnes in Western Norway. “Electrification is one of our main measures for reducing CO2 emissions from our activities,” says Nedregaard. The platform was connected to shore power in December 2018 and was soon followed by the storage vessel on the Martin Linge field. This is the world’s first storage vessel receiving power from shore. Martin Linge is also the first platform on the Norwegian continental shelf to be put on stream from shore. The production wells and processing plant are operated from the control room in Stavanger, and the offshore operators use tablets in the field to interact with their colleagues in the onshore control room and operations centre. Onshore control room will reduce costs in the operating phase. The Martin Linge project has faced many challenges. Production was originally scheduled to start in 2016. The costs of the Martin Linge field development have risen to BNOK 63 (2021 NOK), compared to the original 31,5 in the 2012 plan for development and operation (PDO). Equinor acquired Total’s interests in the field in March 2018. At the same time, it took over the operatorship and responsibility for completing the field development project. Approximately 2500 people offshore and onshore have worked on preparing the platform for production. In general, offshore completion is challenging for a project extending over several winter seasons. The corona pandemic, with restrictions on personnel and other infection control measures, have also led to further delays. “It has been a very demanding job, and more challenging than expected, but we have reached the finish line together with our suppliers and our partner Petoro. Martin Linge will now produce and create jobs and value for society for many years ahead,” says Nylund. •

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NEWS - EUROPE Developing Lavrans and Kristin Q in the Norwegian Sea

quinor and the partners Petoro, Vår Energi and Total E&P Norge have decided to develop the Lavrans discovery and the Kristin Q-discovery which is a part of the Kristin field. This constitutes phase 1 of the Kristin South project, and today the plan for development and operation (PDO) will be submitted to the minister of petroleum and energy. Capital expenditures for this first phase will total about NOK 6.5 billion. “The decision to develop the Kristin South area will generate substantial value for society and the owners. We exploit the resources and the existing infrastructure in a favourable way, while contributing to further development of the Norwegian Sea. We have also awarded contracts worth about NOK 2.2 billion. These assignments will help maintain jobs in Norway,” says Equinor’s executive vice president for Projects, Drilling and Procurement, Arne Sigve Nylund. Production from Lavrans and Kristin Q will be tied into the Kristin platform. A subsea template will be installed at Lavrans, while at Kristin Q an already installed subsea template will be reused. A total of five wells are planned to be drilled, four at Lavrans and one at Kristin Q. The Kristin field was put on stream in 2005. The technical life of the Kristin platform is estimated to end in 2034, with possibilities of further life extension to 2042. “Our ambition is to transform the Norwegian continental shelf to create great value while helping Norway achieve the Paris goals. Extending the productive life by utilizing the infrastructure we have on the NCS for satellite developments is very important and ensures good profitability and low CO2 emissions,” says Equinor’s executive vice president for Exploration and production Norway, Kjetil Hove. The Lavrans discovery was discovered in 1995. The discovery has a large gas volume, and a high value potential. Lavrans is a complex reservoir and the production qualities are uncertain. The Lavrans wells are therefore designed to reduce this uncertainty by having long horizontal production zones in the reservoir. Kristin Q is located in the southern part of the Kristin field. Like the rest of the Kristin field, Kristin Q is a high-pressure, high-temperature reservoir. Lavrans and Kristin Q will be developed as one project with a shared pipeline to the Kristin platform. The expected production in phase 1 of the Kristin South project is estimated at 6.2 GSm3 of gas and 1.9 MSm3 of oil (a total of 58.2 million barrels of oil equivalent). The plan for development and operation also includes a description of possible future phases of the Kristin South project, including a possible next phase of Lavrans, as well as possible development of the Erlend and Ragnfrid discoveries. The CO2 intensity for extraction and production of Kristin South phase 1 is very low - less than 1 kg of CO2 per barrel of oil equivalent. The emissions will mainly be generated from the project’s drilling activities. Lavrans and Kristin Q will be operated by the Kristin organisation, which is located at Stjørdal in Mid-Norway. Production from the first three wells, two at Lavrans and one at Kristin Q, is scheduled to start in 2024. Production start for the two last wells at Lavrans is scheduled for 2025. Spin-offs for Norwegian suppliers and business activities In connection with the development of the Kristin South area there will be a demand for substantial deliveries of goods and services. This will generate value and employment effects for Norwegian trade and industry and the Norwegian society. It is estimated that more than 60 per cent of the investments in the project will go to Norwegian suppliers, and about one-third will go to companies in Mid-Norway. A study of ripple effects performed by Kunnskapsparken Bodø shows that national employment effects of phase 1 of the development is estimated at slightly less than 4000 person-years of employment divided on six years in the period 2020-2025. Regional employment effects of

the development in Mid-Norway are estimated at about 800 personyears of employment in the same period. Aker Solutions has been awarded the contract for subsea production facilities. The contract has an estimated value of about NOK 1 billion, and includes subsea template fabrication at Aker Solutions in Sandnessjøen, deliveries from Tranby and Egersund in Norway, as well as from Brazil, the UK, and Malaysia. The supplier estimates that more than 200 person-years of employment will be generated by the project in Norway. TechnipFMC has been awarded the contract for fabrication of pipeline, pipelaying and subsea installation services. The project will be managed from Technip FMC’s Oslo operations centre. The pipelines will be fabricated at the spool base in Orkanger. TechnipFMC will also deliver the umbilical, which will be produced in the UK. The total contract value is estimated at about NOK 1 billion. Aibel has been awarded the contract for engineering, procurement, construction and installation (EPCI) for the modification of the Kristin platform. Worth about NOK 190 million the contract will generate about 80 person-years of employment for Aibel in the engineering period. The work will take place in Haugesund. The contracts are subject to government approval of the plan for development and operation. Partnership In connection with the investment decision and plan for development and operation for the Kristin South project, the partners have signed an agreement to extend the area for the partnership Haltenbanken West Unit, making the discoveries Lavrans, Erlend and Ragnfrid in addition to the Kristin field part of Haltenbanken Vest Unit as of 1 June 2021. •

NEWS - EUROPE Supply Chain Bosses Diversifying Away From Oil and Gas

ow in its fifth year, the highly acclaimed EIC Survive and Thrive Insight Report surveyed more than 60 energy supply chain businesses and confirmed that, for the second year running, the most popular growth strategy in challenging markets was to move away from oil and gas and into other areas in order to ‘survive’. With governments on a global scale pursuing net zero policies, but little being done to help the energy sector to diversify into green energy markets, the report also once again showed three quarters of companies that diversified preferred to move out of energy completely. EIC CEO Stuart Broadley said: “This move away from oil and gas is both good and bad news. On the positive side, it is sensible for business leaders to spread their risk and diversify into as many sectors as they can, including to non-energy markets like infrastructure and defence, to protect against further market uncertainty and economic shocks. “On the negative side though, it also reveals that businesses do not see enough opportunity for them to simply switch from oil and gas to renewable and transition technologies like wind, hydrogen and CCUS. The pipeline of green opportunities is too small, inconsistent and with lower CAPEX value and there is still inadequate support available for companies to transition. “Indeed, supply chain companies will need to stay in oil and gas, now without government support following recent anti-oil policy changes, in order to survive and to meet the widely expected bow-wave of new oil and gas work following the end of the pandemic, both domestically and internationally. “The future for companies will surely include involvement in exciting new energy transition projects such as Acorn too, which will be helpful, but these are still years away. I would therefore not be surprised that we see companies rebounding back to oil and gas in the next couple of years.” As the UK government looks to establish its position as a global leader in the Net Zero transition, it is in danger of pursuing strategies which assume that transition and diversification for all is easy, whereas EIC data shows that many supply chain companies need at least five years to transition, and longer to be globally competitive. The EIC will continue to work with government to ensure that these concerns, and other findings from EIC’s 2021 Survive and Thrive Report, such as how developing new export markets is once again the least used growth strategy for the fifth years running, are represented at all levels and regions in order to appropriately and successfully take action to address the needs, challenges and opportunities of the entire UK supply chain. •

Neptune Energy Pilots VR Technology

eptune Energy today announced the successful completion of a virtual reality pilot on its operated Gjøa platform in the Norwegian North Sea, enabling teams to make highly realistic virtual visits to the facility. The technology, developed by PaleBlue and used to train astronauts travelling to the International Space Station, will reduce the need for offshore travel, lower costs and associated emissions and support safe operations. It is the first time PaleBlue’s technology has been applied to an offshore installation of such complexity. Using a VR headset, offshore workers interact with a realistic 3D model of the Gjøa platform from onshore. Martin Borthne, Director of Operations in Neptune Norway, said: “The new virtual reality solution allows employees and contractors to build up knowledge and awareness of the complex multi-level facility without the need to travel. Planning work operations will be safer and more efficient. “The initiative will together with other projects see an estimated reduction of 30 offshore trips per year. We expect this to grow in the years ahead as digitalisation further enhances collaboration over distance, bringing immediate access to expertise and enabling preparation of activities to be carried out from onshore.” As a first step, Neptune will use the technology for familiarisation and safety training, but the scope will be expanded to other complex operational activities such as simulations related to HSE events or to better understand how platform modifications will appear before they have been carried out. In addition, expansion to a multi-user function will enable offshore personnel to meet onshore personnel in the virtual world. Egil Thomas Andersen, Account Director at PaleBlue, said: “The restrictions and all the consequences of COVID-19 have introduced challenges to operations for many companies. By doing the familiarisation training in a virtual world, even from home, companies can overcome travelling restrictions, save time, costs and emissions, and will be 100% prepared with crucial knowledge of the facility when they physically arrive offshore.” Digitising operational assets to improve safety, efficiency and reduce environmental impacts is a key component of Neptune Energy’s digital strategy. The company has created digital twins of platforms in the Norwegian, UK and Dutch sectors of the North Sea, enabling offshore site inspections and planning work to be carried out onshore. Neptune also uses laser scan technology to carry out detailed engineering work for subsea productions developments which will be tied back to Gjøa. •

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NEWS - EUROPE Approved Development Securing Activity and Jobs

he plan for development and operation (PDO) of the Breidablikk field in the North Sea has been approved by Norwegian authorities. Field investments are approximately NOK 18.6 billion. Production from the field is scheduled to start in the first half of 2024. Equinor and its partners Petoro, Vår Energi and ConocoPhillips Skandinavia, submitted the development plans for the area to the authorities in September 2020. Estimated recovery from the field is around 200 million barrels of oil. “We are very pleased that the authorities have approved the development plans for the Breidablikk field. The development of one of the largest undeveloped oil discoveries on the Norwegian continental shelf (NCS) will create substantial value for Norwegian society and the owners, while securing high activity and jobs for many years ahead,” says Arne Sigve Nylund, Equinor’s executive vice president for Projects, Drilling and Procurement. 70% of the value creation in the development phase goes to Norwegian companies, and contracts totalling NOK 8 billion have already been awarded to companies in Norway. The Breidablikk development will include a subsea solution of 23 oil producing wells from four subsea templates. The field will be tied back to the Grane platform for processing before the oil is piped to the Sture terminal. The production will be monitored by high-tech digital tools from Equinor’s integrated operations centre at Sandsli, securing high value creation from the wells. “There are still large resources left in the ground and we have a worldclass infrastructure on the NCS. The Breidablikk development shows how a competent Norwegian petroleum industry keeps developing innovative, cost-effective and future-oriented solutions with good social economy,” says Kjetil Hove, Equinor’s executive vice president for Exploration and Production Norway. The Breidablikk field development will include a separate cable for the supply of electric power and fiber optic communication from the Grane platform. This is a relatively new technology that can reduce the costs associated with any further development of the field, in addition to facilitating the use of docking stations for subsea drones on the seabed. Breidablikk will be phased in during a period of falling oil production from Grane and will therefore help maintain the platform activity level. The project has started the modification work on the Grane platform. Competitive Norwegian supplier industry All the major suppliers have been chosen and the Norwegian supplier industry has received several important assignments. •

Aker Solutions has been awarded the contract for subsea production facilities. The contract covers the delivery of four subsea templates and up to 23 subsea trees and associated components. Around 300 man-years in Norway will be involved in the project for the supplier, with project management and engineering at Fornebu and Tranby, fabrication in Egersund and a service organisation at Ågotnes. In addition, there will be deliveries from the UK, Malaysia and Brazil.

•

Wood has been awarded the contract for required modifications and upgrade of the Grane platform to be able to receive oil from the Breidablikk subsea facilities. The assignment is expected to create over 500 man-years in Norway. The engineering work will be performed in Sandefjord and the fabrication will take place in Stavanger.

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TechnipFMC has been awarded a contract for pipelaying and subsea installation services. The award contributes to sustaining workplaces for TechnipFMC in Norway, including the Orkanger spool base, where the pipelines will be fabricated before they are reeled onto the installation vessel. TechnipFMC will also deliver an umbilical for power which is being produced in the UK.

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Odfjell Drilling and the Deepsea Aberdeen rig have signed an agreement for drilling wells on Breidablikk. The contract is expected to secure 200 man-years in Norway associated with the rig, and a further 20-40 man-years associated with support functions.

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Schlumberger Norge has been awarded a letter of intent for integrated drilling and well services on the Breidablikk field. The scope will create important activity for the supplier’s organisation in Norway. The services will be performed offshore supported by the supplier’s facilities and organisation in Norway.

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Alcatel Submarine Networks has been awarded a contract for fibre-optic and electrical infrastructure from the Grane platform to the subsea production facility. Production will be carried out in France and the UK.

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Floatel International has been awarded the contract for floatel services. The company delivers a floating accommodation rig to be gangway connected to the Grane platform for accommodation and catering purposes. Catering and base services will be provided by Norwegian sub-suppliers.

•

H. Butting GmbH & Co. KG and Mitsui & Co. Norway AS has been awarded the contracts for linepipe deliveries. The production has been carried out in Germany and Japan. •

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NEWS - NORTH AMERICA Market Update

The Digital Exhibition Continues

onocoPhillips (NYSE: COP) will host a market update today to reaffirm its commitment to the disciplined, returns-focused strategy it launched in 2016. The company will outline details of a compelling 2022-2031 operating and financial plan that reflects numerous transformational activities undertaken over the past 18 months, most notably the acquisition of Concho.

“We’re looking forward to providing today’s market update, which comes at a defining moment for our sector,” said Ryan Lance, chairman and chief executive officer. “We believe we’re entering a constructive environment for the business, but we also recognize that we’re in a period of evolving energy transition. ConocoPhillips is meeting this moment with a very compelling plan that is resilient and durable, but also flexible. We can and will adapt as the future plays out, all while remaining focused on delivering superior returns to shareholders through cycles. We don’t believe any other company in our E&P sector offers a more investable plan for this vital business.”

The feedback from the regions was very positive, over 6,000 registrations showed the great interest in the offering. More than 150 live webinars and presentations were held with over 7,000 attendees, and the video messages in the industry-specific exhibition rooms were watched over 10,000 times. Due to the great interest in the live weeks, KROHNE Insights will be continued. The digital exhibition is accessible in 12 languages and offers an overview of trends and industry topics in the form of industry-specific exhibition rooms. All webinar recordings can be accessed, and guided tours can also still be booked.

Today’s market update includes the following highlights:

ROHNE decided to continue the digital exhibtion “KROHNE Insights”: launched on June 7, the exhibition started with three “live weeks” that focussed on one region per week. EMEA, the Americas and Asia were individually addressed by presenting specialised content and topics in the live webinars, and the possibility to chat live with local product or industry experts.

KROHNE Insights is the company’s first digital exhibition and has been launched on the occasion of the 100 year anniversary of KROHNE in 2021. The anniversary-related contents such as the message from the executive board, the local welcome messages, the factory tours as well as the KROHNE art collection video were among the most viewed contents. •

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Increasing anticipated Concho transaction-related synergies and savings to $1 billion annually;

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Reducing 2021 capital expenditures and adjusted operating cost guidance by $200 million and $100 million, respectively, due to stronger-than-projected business execution;

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Increasing 2021 planned share repurchases by $1 billion, bringing total planned distributions for the year to approximately $6 billion, or 7% of current market capitalization;

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Expected cash from operations of ~$145 billion and free cash flow of ~$70 billion over the 10-year plan period at $50 per barrel WTI based on 2020 real prices, escalating at 2% annually;

•

Capital expenditures expected to average approximately $7 billion annually, resulting in approximately 3% compounded annual production growth at an average reinvestment rate of ~50%;

•

Over $65 billion in estimated shareholder returns of capital across the plan period, fully funded from cash from operations;

•

Return on capital employed projected to grow 1 to 2 percentage points annually, with balance sheet strength further improving throughout the plan period; and

At a press conference on April 28, 2021, Michael Rademacher-Dubbick, Chairman of the Advisory Board and spokesman for the owner family, and Dr Attila Michael Bilgic, CEO and Spokesman of the Executive Board of the KROHNE Group, explained the core values that have accompanied the company’s success story from its foundation in 1921 to today, and how it will remain true to them in the future.

•

Progress on the company’s ambition to become net-zero for operational (Scope 1 and 2) emissions by 2050.

Lance continued, “We have embraced a new imperative for the business that we call the Triple Mandate. We want to play a valued role in whatever pathway the energy transition takes by investing in the lowest cost of supply barrels, delivering competitive returns of and on capital, and achieving our net-zero emissions ambition. Since 2016, we’ve been on a continuous path to be the most relevant, sustainable E&P company in the business. Today’s strong 10-year plan takes another step forward in that direction.” •

The Spirit of Creativity ROHNE is celebrating its 100th anniversary under the main message “THE SPIRIT OF CREATIVITY”. The start of the digital fair “KROHNE Insights” on June 7 marks the anniversary kick-off.

With the main message “THE SPIRIT OF CREATIVITY”, the anniversary highlights the sides of the company that go beyond measuring technology: “KROHNE is a multi-layered combination of values. Our goal is to offer added value with our products, solutions and services. We can achieve this only by knowing or even anticipating the wishes of our customers from various industries and their applications,” explains Dr Attila Michael Bilgic. “Meeting them requires creative ideas that equally drive technical innovation and organisational development, and continue to help KROHNE to accomplish pioneering achievements.” “The foundation for this is our family-oriented and appreciative corporate culture and KROHNE’s special connection to art” adds Michael Rademacher-Dubbick. “THE SPIRIT OF CREATIVITY” stands for an open approach to unconventional ideas and shows that 100 years of KROHNE have been all about creativity and the company’s innovative strength. The anniversary kicks off with the start of “KROHNE Insights”: the digital fair offers an overview of trends and industry topics in the form of industry-specific exhibition rooms with video messages as well as live presentations. At the same time, visitors have the opportunity to learn more about the “spirit” of the company and the anniversary in a 100 year KROHNE showroom. “KROHNE Insights” will be accessible worldwide and in 12 languages from June 7. Registration free of charge is possible at insights.krohne.com (https://insights.krohne.com/). Parallel to the opening of “KROHNE Insights,” KROHNE is also going live with the anniversary website 100-years-krohne.com ( https://100years-krohne.com/ ) It bundles all information on the anniversary that will include many different activities to which KROHNE will to invite and involve customers, partners and employees alike. •

Terra Inspectioneering

NEWS - RUSSIA & CIS Start-up and Commissioning Underway at Second Train Of Amur Gas Processing Plant

he Gazprom Management Committee took note of the information about the progress of the Amur Gas Processing Plant (GPP) construction project. Particular attention was paid to the launch of the first production train, which took place on June 9, and to the ongoing start-up and commissioning operations at the second train, where the auxiliary and core equipment is now fully assembled.

soon be put in operation. The center is needed to deliver liquid helium from the Amur GPP to the global market.

It was highlighted that the GPP forms the backbone of the state-of-theart gas processing and gas chemical center that is currently being set up in Russia’s Far East.

The Amur GPP is being built near the town of Svobodny in the Amur Region. The plant will have a design capacity of 42 billion cubic meters of gas per year.

The construction of the Amur GPP is going on schedule. The project is 76.5 per cent complete. On the third and fourth trains, the equipment for gas separation is fully installed, pipes and cables are being laid, insulation materials are being applied, and metal structures are being assembled and provided with fire-retardant coating. On the fifth train, the foundation works are completed, and preparations are underway for the installation of the ethane and methane separation columns, as well as gas compressor units. On the sixth train, the pouring of foundations and the assembly of metal structures are in progress. The latest campaign for the delivery of heavy equipment to the GPP by river and sea vessels is now running. During the navigation season of 2021, it is planned to bring 51 pieces of heavy cargo with a total weight of 5,500 tons to the construction site. In addition, the logistics center for the servicing of thermally-insulated helium containers (the helium hub) near the city of Vladivostok will

Containers with liquid helium will be transported between the GPP, the hub, and the ports of the Primorye Territory via freight trucks powered by liquefied natural gas (LNG). A small-scale LNG plant was built at the hub with the purpose of refueling vehicles.

On June 9, 2021, the commissioning ceremony for the first production train of the Amur GPP, one of the largest plants of its kind in the world, took place with the participation of Vladimir Putin, President of the Russian Federation. The implementation of such an ambitious project in the area of gas processing has no parallel in the history of Russia’s gas sector. The construction of the first production train was finished strictly on schedule. The commissioning of the next five trains is synchronized with increases in the volumes of gas transmitted via Power of Siberia. In 2025, the GPP will reach its full design capacity. The products of the Amur GPP include sales gas (methane) and the components extracted from this gas, which are valued in the gas chemical and other industries. Operating at full capacity, the GPP will use cutting-edge equipment and state-of-the-art cryogenic technologies to produce 2.4 million tons of ethane, 1.5 million tons of liquefied petroleum gases (LPG), and 200,000 tons of pentane-hexane fraction. •

Under the Patronage of His Highness Sheikh Mohammed Bin Rashid Al Maktoum, Vice President and Prime Minister of the United Arab Emirates and Ruler of Dubai Supported By

Co-Hosts

21-23 September 2021 Dubai World Trade Centre United Arab Emirates

The First Major Energy Event to Take Place Live & In-Person this Year!

The Gastech 2021 Conference will convene the full energy value chain as the industry moves to decarbonise and transition to a more sustainable future. Hear from over 300 policymakers, industry leaders, and disrupters as they present new business models, strategies, and innovations that will be instrumental in addressing growing energy demand and tackling climate change obligations.

2,500+

300+

70+

16+

Expected In-Person Delegates

In-Person Speakers

In-Person Speaking Energy Business Leaders

In-Person Speaking Energy Ministers

Strategic Sessions

Technical Sessions Organised By

UK Sampling Gauges Ltd ‘The Analysis Is Only as Good As The Sample!’ Today’s environmental issues demand minimisation/ elimination of all gas emissions to the atmosphere, which affects manual sampling in the oil industry.

Closed sampling is a solution to sampling most oil types This however causes concern over the quality of drawn samples and operator friendliness. UK Sampling Ltd. offers ATEX/IECEx closed sampling equipment using 0.5L and 1L capacity samplers (decanting/non-decanting) for spot, running, all-level and bottom sampling of oil, and even oil residues. RNS /ALSBV Results

Conventional Running Sampler Results

Samples taken are reliable, reproducible and as accurate as they can be, without any possibility of sample contamination. The graphs show the obvious superiority of comparison tests of UKSGL samplers against conventional methods.

Please contact us to discuss how our equipment can help Download our free UKSGL app from the app store to gain access to our product brochures and training videos. E: sales@samplinggauges.com W: samplinggauges.com

EXPLORATION & PRODUCTION

Wellheads and Ball Valves for Challenging Applications By: Norman Holenstein, Sales & Project Manager Wellheads and Storage Technologies

Optimized for the high demands in oil and gas production, storage technology, petrochemistry as well as in geothermal and hydrogen applications durable wellheads with metal-to-metal seated ball valves are an important factor for safe and reliable operation.

ellheads form the secure interface between underground and aboveground plant and their reliability is crucial for safe operation. In oil and gas production harsh operating conditions and aggressive media call for especially durable equipment. Since 75 years Hartmann products, with their robust and individually tailored design, have provided the highest level of safety – even with dangerous and corrosive media such as sour gas, sour oil (H2S) and CO2. With their gastight components and long service lives these wellheads and valves are also ideally suited for the equipping of underground storages. As leading system supplier in Germany several hundreds wellheads are installed at crude oil, natural gas, helium storage facilities and in these days also the first welheads for European hydrogen storage projects have been delivered. In regards to renewable energies the oil and gas expertise has been also highly demanded in deep geothermal applications. Since the first pioneer projects Hartmann has provided equipment, consulting support and service in 40 European projects. Adapted to project-specific requirements and designed for the highest flow rates and temperatures, the wellhead equipment provides maximum operational safety and plant

Below: A comprehensive pressure test with hydrogen provides assurance, that the threshold values are adhered to and fugitive emissions are minimized.

availability - even with demanding conditions and scaling formation. Reliable combination Hartmann API 6A conformant wellheads are

fitted as standard with metal-to-metal sealing ball valves which are also gas-tight. In comparison to gate valves they offer a very high level of safety as they have a lower tendency towards blocking, are subject to less wear and don’t have to be filled with grease which can contaminate downstream plant parts. Thanks to the metallic sealing between ball and seat ring, Hartmann ball valves fulfil a leak rate of A or 0 and are especially robust and require only little maintenance. Decisive for the long service life is an appropriate material selection as well as surface treatments and special coatings – against corrosion, for example. Furthermore, at the wellhead doubled sealings at the flange connections as well as additional metallic sealings can be integrated. In order to reduce flange connections also a solid block design is possible, which integrates several components in one block. Further special designs for control lines, load measurement using strain gauges or electric pumps

The Hartmann pigging ball valve combines shut-off functionality with integrated pig launch.

3D printing and real wellhead: At this crude oil cavern the storage wellhead offers a maximum of integration and thus a maximum of safety.

are available. An experienced service team is available around the clock for assembly service, repairs and maintenance work. The wellhead shown at the picture for a crude oil cavern storage offers a maximum of integration and thus a maximum of safety at NWKG, Germany. Its design with integrated double barrier ball valves saves space and reduces flange connections. An optional 3D printing model, here on a scale 1:5, can be provided as demonstration objects for technical training or public relation activities within the various project phases. Secure Shut-off in tailor-made design High Performance ball valves are not only implemented at the wellhead but also in various application areas in different industries. Designed to customer and project specific requirements the metal-to-metal sealing ball valves are gas-tight, even at high pressures up to 690 bar. Special designs for temperatures up to 550°C are available. Also at high cycles up to 200.000 per year, ball valves offer a secure and reliable shut-off requiring little maintenance effort. Additional safety is provided by the Double Isolation and Bleed (DIB) option or the Twin Ball Valve (TBV) design – double ball valve with up to four barriers in one valve. Testing in the pipeline can be facilitated with the appropriate valvework selection by means of the double block and bleed (DBB) function. Clever concept: integrated Pigging Valve Hartmann pigging valves provide a space and

cost-saving substitution for expensive scraper launching systems. In addition to its classic use as shut-off valve, the pigging ball valve functions as pig launcher or receiver valve. The simple, secure, and fast insertion or removal of pigs take place through an interlock that is integrated on the side of the pigging valve and that is locked and secured through a bayonet system. Ball valves for gas turbines Special ball valves also assure safety in gas turbine applications worldwide. For special types standard shut-off or special designed multi-way Hartmann ball valves are available as reliable combination with different actuators. They are implemented for diverse services with the media fuel oil, fuel gas, natural gas, air and water. Components and testings for safe hydrogen applications Special valves, which have evolved for the demanding hydrogen medium, have been used in the petrochemical industry for decades. With energy transition, hydrogen will be found increasingly in other fields of application– from electricity generation (such as power-to-gas), through transport (in natural gas grids or hydrogen pipelines), to processing and mobility. The underground storage of hydrogen in salt caverns constitutes an environmentally friendly and safe solution for storing large amounts of energy to balance between power generation and demand. Reliable shut-off valves, the right material

“Hartmann Valves GmbH is one of the leading manufacturers of ball valves, pigging valves and wellheads. With worldwide references in the fields of mineral oil, natural gas, petrochemicals, power plant technology, geothermal energy and renewables such as hydrogen.” selection as well as standardised pressure tests help increasing operational safety in existing and new hydrogen application areas. For all metallic components in direct contact with the challenging media hydrogen Hartmann offers standardised material suitability tests. Within the test scope the metallic material selection is evaluated regarding its resistance against hydrogen embrittlement to make sure that it is fit for hydrogen service. Furthermore, a comprehensive pressure test with hydrogen provides assurance, that the threshold values are adhered to and fugitive emissions are minimised. Thanks to these professional tests also inventory valves can be upgraded. • If you would like to know more about how Hartmann Valves GmbH can help your company and its operations, please contact them at: Hartmann Valves GmbH Bussardweg 15 31303 Burgdorf Germany www.hartmann-valves.com sales@hartmann-valves.com

EXPLORATION & PRODUCTION

Identify Your Failure Points, Before It’s Too Late OGI sits down with Tony Dale, Managing Director of Geo Therm Ltd in the United Kingdom. Geo Therm Ltd provides SME’s with thermographic inspections which help companies with their maintenance and warranty surveys. One of the major benefits of working with Mr Dale and his team is they help companies limit their unplanned outages. How does that work? Mr Dale will get into that in detail in the interview, but essentially, using thermal infrared inspection, Geo Therm Ltd can help identify and trouble-shoot potential failure points in your company’s assets. We get into this and much more below.

OGI: Could you start by explaining Geo Therm Ltd’s credentials and experience in terms of your products and services for the oil and gas sector? Could you tell our readers the breadth of your experience, how long the company has been active, and its reach? Dale: Geo Therm Ltd is an independent, third party SME inspection and condition monitoring services company that has global reach. For the past 20 years Geo Therm Ltd has continued to grow aligned to customer needs and has conducted thermographic inspections in forty countries covering annualised offshore rig maintenance and warranty survey requests. In providing reliable and cost-effective services on board offshore installations, FPSO’s, drilling rigs and ships throughout Europe, West Africa, Middle East, and Australasia. The company MD Tony Dale has over 30 years’ experience in the offshore energy sector. The company is based in the Easterly port town of Lowestoft, in the United Kingdom, with surveyors strategically placed for rapid mobilised internationally via Norwich and Schiphol airports to meet global operational demands. Where Geo Therm Ltd offer services tailored to maintain customer operational uptime and regulatory compliancy. Acknowledging Geo Therm Ltd brand is synonymous with responsiveness, affordability, and quality. OGI: Could you talk a bit about the work that you do in the oil and gas industry?

Left: Geo Therm Ltd’s thermographic inspections in action, drilling derricks and engine exhaust cowling issue. Below: Company logo. Over page: Donning a full arc flash suit to perform a drilling transformer inspection.

Dale: Our customers call upon Geo Therm Ltd to carry out offshore oil and gas equipment inspections, which are typically employed on jack-ups, semi-submersibles, and drill-ships. By far the most utilised services Geo Therm Ltd perform are annual Thermographic and Ex-inspections to comply with the asset PM regimes, guided by regulatory and class specifications. These services further help to trouble-shoot potential failure points and support system longevity, so limiting unplanned outages. Upon rig arrival and completion of a safety induction, our surveyor

will complete a detailed thermographic survey within four to five days assisted by the RPE, while two inspectors undertaking an Exinspection can take up to seven days to two weeks depending on the asset size, equipment isolation and availability. Whenever critical issues are found these are red flagged and immediately relayed to management and rechecked after corrective actioning. During any typical twelve-hour daily work schedule, at least three quarters of the day is allocated to the physical inspection while the remaining time is taken up report writing to permit interim report generation, and its handover at time of vessel departure. Thereafter, all formal reports are completed within two weeks and sent to the rig manager. OGI: Could you explain to our readers what a “Thermal Imaging Inspection” is? Dale: A thermal infrared inspection or Thermographic Survey is a means to obtain an accurate non-contact temperature image to address the thermal performance and or thermal properties of individual components to building exteriors. This non-contact, non-invasive inspection method does not influence the system or process, nor does it require external illumination, it is a safe and best practice method encouraged by all classification and maintenance guidance notifications to locate potential system

deficiencies that if left unchecked can lead to downtime or fire. When a handheld or fixed monitoring thermal camera is used correctly, a wide range of system deficiencies or processes activities deviating from the norm can be achieved, for instance in electro-mechanical, cooling, and cladding systems. A thermal camera works by focusing infrared energy emitted from the surface of a warm object on to a microbolometer array while concurrently processes operator defined parameters, assigning a false colour and temperature value to each image pixel to create an accurate thermographic heat image for a certified surveyor to analyze and interpret. OGI: What are various inspections that you carry out for the industry? Dale: There are seven main offshore energy services Geo Therm Ltd currently provide, these include: 1.

ABS and LR approved Thermographic Inspections, used to identify early failure in electrical equipment and locate missing or degraded insulation and other hotspots in rig engine rooms.

Supply and retrofit infrared inspection windows to support asset safety initiatives and safer electrical thermography PM’s.

Acoustic Ultrasound Services to listen, and identify failing components emitting high frequency ultrasounds above the human hearing range indicative of electrical arcing, partial discharge, and transient earth voltages in main switchboards.

Acoustic Ultrasound Service for Vessel cargo hatch and door testing to ensure water/weathertight/gas enclosure integrity and seaworthiness.

Portable Appliance Testing (PAT) visual and electronic testing of in-service handheld power tools, cables, and appliances to ensure items are safe and fit for purpose.

Ex-inspections of electrical fittings located in hazardous zoned areas.

Circuit breaker injection testing to confirm 5 yearly operational performance.

OGI: How important is it to work with a partner that has multiple accreditations with various international trade bodies and associations, and why? Dale: Geo Therm ltd.’s accreditations address industry requirements as an inspection company. Assuring stakeholders of service conformity by having the technical capacity to implement and perform inspections in a professional and impartial manner. Accreditation increases trust in the conformity assessment and reinforces the mutual recognition of products, services, systems, and bodies across the offshore energy industry. Geo Therm Ltd.’s hold accreditation with the American Bureau of Shipping and Lloyds Register - both world leading certification bodies, that recognize Geo Therm Ltd’s specialist service supplier status, through management systems certification, verification, assessment, and training. Likewise, Geo Therm Ltd has the ISO 9001:

2015 Quality Management System accreditation. The purpose of the standard shows that Geo Therm Ltd meet statutory and regulatory requirements by achieving excellence in customer service, products and delivery, and a means to continually improve upon our business performance. Geo Therm Ltd is also FPAL verified, which identifies and qualifies suppliers that help create an effective supply chain network within the offshore energy sector buyer-supplier community. Furthermore, Geo Therm Ltd is Safe Contractor accredited, a key measure in validating the company’s operational health and safety, equal opportunities, and diversity and environmental management best practices. Accreditation to the above shows Geo Therm Ltd.’s business activities are credible and compliant whenever and wherever its international services are contracted, with services performed by certified personal compiling detailed reports to facilitate compliance needs. OGI: What are some of advantages for asset managers in working with Geo Therm Ltd? Dale: Regardless of a survey being a one-off spot check or an annualized repeat service, every asset survey (and report) are impartial, and undertaken with care, consideration, and professional due diligence. Red-flagged observations are immediately conveyed to the rig maintenance supervisor to implement corrective actions to assure rig uptime. Furthermore, surveys are performed by experienced and certified surveyors who have safety at the forefront of any inspection task, and who in turn follow clear and concise procedures and specific work instructions. Geo Therm Ltd survey teams are historically long service employees which extensive offshore and maritime working experience. This fosters a sense of mutual respect and camaraderie, facilitating open and engaging dialogue and effective work planning when offshore, to deliver each survey request within time and agreed budget.

OGI: Finally, could you enlighten our readers of a case study where you helped a client with your solutions? Dale: For optimum thermographic survey results a direct line of sight is required between the thermal camera lens and the item of interest. This has inherent safety implications during electrical inspection as equipment must be energised at 40% load when thermal tests are performed. To safeguard the surveyor from electrocution and arc-flash potential a residual survey can be performed, albeit this involves temporarily shutting down and opening MCC’s to immediately scan the de-energised equipment. These options have clear operational impacts. A more favourable method and one that Geo Therm Ltd has adopted with its customers consist of the installation of infrared inspection windows during planned outages to negate the need of shutting vital systems down when performing a thermal survey. Should the asset manager choose this option and procure the inspection windows from Geo Therm Ltd then the benefits are tangible. Once installed, it is possible to regularly perform safe routine visual and thermographic inspections into vital equipment without service interruption. From a client and service supplier perspective this is a win-win scenario, with asset safety being vastly improved, and the ROI achieved after the first few inspections, especially when service discounts are applied. OGI: Thank you for your time. • If you would like to know more about how Geo Therm Ltd can help your company and its operations, please contact them at:

Geo Therm Ltd, T: +44 (0)1502 723241 E: tonydale@geothermltd.co.uk W: https://www.geothermltd.co.uk

EXPLORATION & PRODUCTION

Asbestos Free Friction Materials For The Oil & Gas Industries Brake and clutch applications within the Oil and Gas industry have always been an extreme challenge for friction material manufacturers to satisfy. From a tribology perspective the inherently heavy duty, harsh and often dirty nature of the industry pushes friction linings to their limits. Those intense performance demands serve to focus the need for reliable frictional and mechanical performance, particularly when considering an operating environment where health and safety standards are vital and machine downtime comes at such huge expense to the equipment operators.

Oil & Gas Friction Linings.

he industry provides a multitude of safety critical scenarios which require motion to be either controlled or prevented, needing various sizes and configurations of brake and clutch linings, in both flexible and rigid materials. The contrast in frictional demands can be wide ranging, from a safety pipe clamp insert liner, requiring a soft and flexible high static friction material, to an emergency friction plate brake which requires a rigid, extremely strong and aggressive friction formulation to dissipate huge amounts of energy during dynamic braking. In order to satisfy this wide variation of brake systems, there are a broad range of friction materials available, including press moulded (resin based), woven and roll-formed (rubber based) qualities, these can be organic, semimetallic or sintered formulations, each offering their own individual frictional and mechanical characteristics. The Trimat range has been completely nonasbestos for over 25 years and all products are manufactured within a modern UK factory, with the highest quality of performance and service at the heart of the business model. All aspects of production from weaving, chemical mixing, pressing, curing and machining are

conducted in-house. To ensure materials are traceable and offer the performance consistency demanded by original equipment makers and drilling operators, every production process is regulated by stringent

quality controls and a quality management system accredited to ISO 9001:2015. Furthermore the entire product range is REACH, RoHS and Conflict Mineral complaint. Product innovation is crucial to keeping speed with brake and clutch development, as brake system developers expect increased efficiency and try to save space and weight by reducing the size of their equipment, the friction material has less surface area and less stopping time so the braking energy per mm² is dramatically increased. Through the use of the latest raw material technologies and manmade fibres such as Panox, Triton and Kevlar, Trimat friction materials can absorb more energy and stress than ever before, providing safer and more efficient operation over a longer period of time.

Combat Brake Block.

The formulation ingredients however are only part of the equation, it’s equally important the brake lining is processed in a well-engineered, consistent and precise way. The ultimate objective is evenly distributed braking pressure and from years of processing experience and collaboration with brake/ clutch manufacturers, Trimat implement the

Oil & Gas Brake Linings .

benefits of well machined groove patterns, leading edges, cut-off corners and adhering to tight flatness specifications, which can all impact performance. This strive for innovation and attention to detail has delivered many successes, notably Trimat “Combat Brake Blocks” designed for us on draw-works systems. These braking systems are arguably the greatest challenge in the industry, designed to reel in and out the drilling line on both off-shore and land rigs, they control loads of up to 500 tonnes with a manually operated brake lever. After years of the industry suffering significant performance and maintenance issues with traditional solid woven brake blocks, Trimat innovated a new hybrid product combining both a traditional woven insert and a more technologically advanced composite outer. This novel idea was the result of a joint engineering exercise with National Oilwell Varco and the advanced friction technology incorporated into the construction of the Combat Brake Block has produced a world beating product, solving performance issues around the globe. First installed on Drawworks more than 10 years ago, Combat Brake Blocks have proven to provide significant advantages and benefits as follows: •

No relaxation of material under the bolt head, so attachment bolts maintain their initial torque, preventing movements and loosening of brake blocks.

•

Improved fade resistance

•

Improved brake block life

•

Reduced noise during operation

As an alternative to the traditional brake block and band configuration many other Drawworks use a disc brake system using brake pads. Trimat manufacture a specifically developed range of

friction products for use on these particular systems, materials are available in a variety of friction levels and configurations to suit both service/ dynamic and park/ emergency braking systems. The excellent wear properties, stable friction level and disc friendly performance allow Trimat materials help achieve faster pipe dropping, resulting in increased efficiency and productivity. Linings are proven successful handling hook loads in excess of 400,000 lbs and offer up to 300,000 H.P hours of life before requiring replacement. The most recent significant development challenge set out by the industry has been to develop non asbestos friction linings for use in ATEX environments. Trimat recognise that the ATEX regulations present a considerable challenge to brake and clutch manufacturers as naturally the act of braking requires the dissipation of energy which in turn creates excess heat, smouldering debris and in some cases sparking. Explosive atmospheres can easily be caused by combustible gases or

flammable dusts mixing with the surrounding air, once a volatile environment like this exists, only an ignition source such as spark is required to create an explosion. The Oil & Gas industry regularly requires employees to operate in such hazardous environments so the battle to prevent any form of ignition source is key and ATEX certified equipment is a regulatory requirement. In the knowledge that a piece of brake lining or friction material cannot be ATEX certified in its own, Trimat have tested the entire friction range and worked together with original equipment makers to rate the materials as part of a brake/clutch system with agreed operating parameters. The Trimat material flammability guide provides information for designers of equipment that may be used in an explosive environment controlled by ATEX regulations. These flammability tests have been conducted in accordance with DIN Spec 22100-007, section 5.9 which is a fire test for brakes and friction clutches. The table can be found at www.trimat.co.uk and lists the Trimat materials tested, with the results shown as a pass or fail. In addition, to assist with selection of a suitable material, Trimat have also shown the temperature measured at the end of each test run and the Delta rise in temperature. Temperature was measured in two locations, one using a thermocouple and the other using infrared. This information combined with thickness loss demonstrates that the material has genuinely been working as a brake material during the test procedure and generating wear debris. The ATEX recommended formulations are of a non-metallic construction and most contain an active flame retardant which behaves as a spark, smoke and afterglow suppressant, these characteristics are vital to the brakes success. Contact Trimat today to discuss your friction needs. T: +44 (0) 1384 473400 E: mail@trimat.co.uk

Slotted Disc Brake Pad.

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

MIDSTREAM & PIPELINES

Re-Gen Robotics - Fulfilling the Mission to Eliminate Man Entry Tank Cleaning Fintan Duffy, Managing Director of Re-Gen Robotics discusses why his robots are successfully revolutionising the oil tank cleaning industry and why they are outclassing humans in this task. By developing a game changing solution to service oil tanks, unparalleled in terms of safety and delivery, Re-Gen Robotics has introduced a paradigm shift in the tank cleaning sector, removing dangerous ‘man entry’ tank cleaning procedures, that are outdated and time consuming.

ts award winning, state-of-the-art, explosion proof, Ex Zone 0 rated robots, are the most ergonomically and technologically advanced, in operation today and according to Mr Duffy, the success of his robots comes down to several irrefutable facts. By sending robots into hazardous confined spaces, operators are not only eliminating the dangers and liabilities associated with confined space entry but are also saving time, money and reducing operational downtime for their tanks. Using Re-Gen Robotics’ tank cleaning solution has very clear advantages for tank terminals; there are fixed costs, reduced paperwork and permits, and no requirement for capital outlay, spading of tanks, standby rescue teams. The team understands the unique complexities of high hazard environments and their customers’ high value assets and facilities. Combined with their in-depth project experience, they are equipped and experienced to surpass clients’ expectations. Since 2019, Re-Gen Robotics has invested over £4 million in creating three 100% no man entry, Ex Zone 0 rated robots, with a fourth on order for Q4. These large robots designed to fit through a standard 600 mm entry hatch via an extending ramp, can de-sludge, wash and clean large-scale tanks, including Fixed Roof, Floating Roof, Heavy Fuel Oil and Coned Floor Tanks. They are designed to operate in the most inhospitable environments and their selfcontained systems include vacuum, jetting, cranage, ramps and telemetry systems, with

nothing extra to hire or buy, simplifying the entire tank cleaning process into a one-stop shop for tank cleaning requirements. The technical crew remains a safe distance from the tank, operating the cleaning system. Progress is remotely monitored through a series of ATEX cameras, fixed to the robot. Their systems also have CCTV recording capability and inbuilt, intelligent reporting facilities to help clients understand and respond to what’s happening inside their tanks. The robots are waterproof and can work fully submerged, they have the power to clean the largest oil tanks with minimum hassle. There is no human exposure to sludge or waste materials during the cleaning process and once cleaning is complete, the robot safely exits the container via its ramp and is returned to the control unit. The unique, closed loop cleaning system reduces cleaning time by 45%, significantly decreasing tank downtime and loss of production during a clean. The service requires only two crew members to complete the entire operation, one to control the robot and the other to operate the tanker.

Large Robot.

In the last two years Re-Gen

Above: Self Contained Craneage System. Robotics has built up an impressive order book with all UK oil majors now adopting our robots as their only preference for tank cleaning, procuring the service to sit at the core of their safety strategy. Up until recently we have concentrated on growing the GB market but with the rapid evolution of our technology, our UK contracts with oil majors are expanding into Europe and the rest of the world. Interest from oil companies and terminal operators in the US is growing rapidly and the company is presently in discovery talks with several oil majors there. Re-Gen Robotics’ technology has systematically transformed safety within the industry while adding value to clients’ bottom line, with the higher level of output, better quality of service and zero possibility of accidents. In preparation for significant international growth, the company has made substantial investments across several key areas including state-of-the-art headquarters with R&D facilities and service bays for robotic equipment and trucks, its people and its service offering. • For more information visit: www.regenrobotics.com

Tank Farm Services Ltd

Contract Services

Equipment Sales & Hire

Hydraulic single or double PowerPack Hydraulic sludge pumps - Mono type, Rotary Lobe or Submersible Hydralic sludge dozer - Ride on or remote operaPon, opPonal aVachments JeXng nozzle, blade, sucPon blade, clam bucket, auger, submersible pump. Remote operaPon and bespoke design available Tank desludging systems Centrifugal pump 6" - 12" upto 1200m3/hr

T: 01159761123 E:Tank.farm@bPnternet.com W:tankfarmservices.com

NO MAN ENTRY TANK, PIT, CULVERT INTERCEPTOR, LAGOON DESLUDGING

Full turnkey sludge management No man entry tank desludge, cannon system manway mounted or installed onto live tanks though 4 - 12" valves Hydraulic dozer sludge removal RouPne topographic survey sludge quanPﬁcaPon RouPne No man entry desludging programmes

MIDSTREAM & PIPELINES

Corrosion Rate Measurements – A Powerful Addition to Remote Monitoring of Cathodic Protection. Cathodic Protection has been an effective corrosion protection strategy for more than a century and its operation has been continuously improved over the years, with increasing knowledge about the materials to be protected, the introduction of modern and continuously improving coating systems and possibly corrosion inhibitors. But still, it is far from an easy task to verify, quantify and document the effectiveness.

Above: AC interference on buried pipelines means that the past understanding of “safe CP operation” is being challenged. Above right: Offshore structures, such as wind power foundations, fitted with CP are extremely difficult to inspect, and the lifetime effectiveness of the CP system is hard to predict. In both cases, a remote monitoring system with corrosion rate measurement will provide continuous insight into the effectiveness of the CP system applied under constantly changing conditions.

or many years, the primary verification of cathodic protection has been measurement of the polarized potential of the structure. But which potential offers sufficient protection? Different materials, environments or interference situations yield different target potentials to ensure effective cathodic protection operation. Not to mention the difficulties of obtaining a trustworthy measurement of the polarized potential. Careful measurements and analysis are often required to determine whether a CP system is operating as intended, but still

there is always the question remaining: “Are we confident now, that our assets are not corroding?”. Today, another verification parameter is gaining still more acceptance amongst different industries. Corrosion rate measurements. While weight-loss coupon measurements have a long and effective track-record, they are extremely timeconsuming and have never become more than a supplement to normal CP testing outside the labs. Various electrochemical techniques are gaining momentum, but they are not always optimal for field application (especially in interference conditions). Electrical resistance (ER) probes on the other hand, can easily be applied in practically any environment. ER probes exist in a range of shapes, sizes, and materials to match the structure under investigation. When connected to the structure through a logger, the ER probe will behave as a well-known coating holiday on which

A pipeline operator’s futile attempt to evaluate the effectiveness of an underground cathodic protection system.

Above: The online CP*Manage remote monitoring tool from MetriCorr lists the corrosion rate measured on ER probes above all other CP parameters. The real question is: “Is it corroding?” - All other parameters are used to explain why.

corrosion rate, potentials, current densities, interference levels, solution resistance and temperature can be measured with e.g. hourly intervals. Having these measurements available will provide the basis for optimizing CP operation and verify effectiveness continuously. Some standards (e.g. ISO 18086 and NACE SP21424 on AC corrosion) already recognise the measurement of an acceptable low corrosion rate as a valid protection criteria to verify effective cathodic protection operation. This offers a simple monitoring strategy to the very complex corrosion challenge that AC corrosion of cathodically protected pipelines is. MetriCorr (derived from “Measure Corrosion”) was founded on the premise that knowledge about corrosion is the key to stopping it. Over the years, MetriCorr’s patented ER technology has helped hundreds of CP technicians and engineers in understanding their CP systems better and stopping corrosion. Ultimately saving millions of dollars. MetriCorr offers a complete suite of loggers for remote monitoring of cathodic protection systems both on- and offshore. Measurements include structure ON and OFF potentials, AC/ DC interference levels, line-currents, rectifier monitoring, anode currents, isolating joints, casings, coupon ON and OFF potentials as well as current densities and more. But the ER probe and the ability to detect critical corrosion within hours is still a central part of the corrosion and cathodic protection remote monitoring system. • MetriCorr

ER probes come in many shapes, sizes, and materials to mimic the structure under investigation best possible in almost any environment.

T: +45 9244 8080 E: info@metricorr.com W: https://www.metricorr.com

MIDSTREAM & PIPELINES

Tethered Tools Protect Lives When Working At Height Oil and gas engineers and technicians required to work at height, often in challenging offshore locations and appalling weather, are well aware of the risk of hand tools or equipment falling or being dropped – and of the potential consequences. As well as posing a major threat to anyone working below, falling tools can also cause serious damage to vital systems and machinery, causing highly expensive downtime.

ropped objects are consistently the third most frequent cause of death or serious injury in the oil and gas industry. A hand tool such as a torque wrench falling from height will accelerate to around 80mph before it hits the ground, with a force of impact similar to that of a plunging domestic washing machine. The success of the safety focused Tools@Height programme from Snap-on Industrial depends upon tethering all tools to prevent them inadvertently falling or being dropped. All tools are designed with strong, integrated fixing points to enhance safety and functionality when used at height or near critical assemblies. Says Richard Packham, Snap-on Industrial’s Director, UK & Europe: “No responsible engineer or technician wants to work at height, with all its challenges, without knowing they can rely totally on their safety equipment to protect both themselves and others working below them, as well as safeguarding vital systems and machinery from damage.” “At Snap-on we follow an extensive research, development and quality management programme which has resulted in advanced design, manufacturing, testing and operating

procedures covering object prevention.”

safety and dropped

offering the highest standard of safety and productivity solutions.”

“Our objective is to continue being a totally professional, dependable company which contributes to its customers’ wellbeing by

The oil and gas industry has taken a global lead in working to combat the threat caused by falling tools and other objects. Tethering tools to their users is one of the many vital precautions which companies require of those working on platforms or onshore. Years ago Snap-on pioneered anti-drop solutions to benefit construction workers building skyscrapers in the USA. Its Tools@Height range has been developed in consultation with the most demanding users to understand exactly what functionality is required. The result is a wide range of tools which incorporate fixings to enable hand and power tools to be securely tethered to Snap-on lanyards, bags, pouches and belts. This is not only ideal for using tools but also provides secure tool transportation to the workplace. Four holes are better and safer than one. Snap-on Tools@Height sockets, adapters and extensions have a locking hole on all four sides. Drive tools and ratchets have a locking pin which fits into the side locking hole to

ensure positive locking. Less secure attachments with a hole only on one side are at risk of falling apart. The Snap-on Tools@Height range reduces the risk of damage to equipment engineers are working on and, more importantly, to the people they are working with. There is compelling evidence that using tools designed and manufactured to be tethered is a lot safer than adapting existing tools for working at height. Engineered attachment points do not interfere with the functionality or efficiency of tools designed to be tethered. When working at height engineers or technicians should retain three points of contact for their safety: two feet on a platform and one hand on a secured infrastructure. To address the risk caused when it’s necessary to use both hands to attach a tool to a tethering device Snap-on have developed safety solutions. For example, a tool belt in which each tool as its own pouch or holster with a tethering device already installed. This enables tools to be accessed and replaced with just one hand. Turnkey solutions: Snap-on supplies individual tools or customer specific kits. Components are delivered to customers’ premises fully assembled and ready for immediate use. Snap-on Account Managers have the knowledge and experience to train customers’ teams in the safe and efficient use of Tools@Height products. Standardised positioning of the fastening elements reduces time spent in training. Tools@ Height can be implemented for a fraction of the cost of in-house systems.

Fixings: include safety chucks, Kevlar strings or Dyneema strings for screwdrivers, spring connections for wrenches, loops, eye bolts, shackles and safety pins for pliers, hammers and other tools. Lanyards: retractable Snap-on lanyards are certified against international standards. They are quality tested in both static and dynamic tests in conditions more rigorous and demanding than any likely to be encountered. For the dynamic test a security coefficient 2,

factor 2 test is performed. Their lanyards, capable of holding up to 12kg, feature universal attachments for tools which do not have any integrated attachment point. Several types of lanyard are available, including carabiner, fixed loop, exchangeable loop, retractable and wrist lanyards. The carabiner lanyard, manufactured in high tenacity polyester, fully extends to 120cm and can hold up to 3kg maximum tool weight (3 daN). Its carabiners are non-removable and high strength webbing and self-retracting inner coil jointly absorb shock. Snap-on’s wrist lanyard extends to 60cm, holds up to 1kg weight and features an exchangeable loop with barrel lock. Additional quick release connections are available but, for safety reasons, their locking system is compatible only with the specific lanyard they are intended to be used with. Pouches and belts: designed to make life easier, as well as safer, Snap-on tool pouches and belts are made from hardwearing 600x600d polyester to resist heavy duty wear and tear. They provide flexible solutions with rings to attach lanyards and hooks to hold tools in loose connectors. Multiple inner compartments offer tool organisation, while quick-access external pockets include one to hold a socket set and another for a water bottle. Adjustable chest and shoulder safety straps provide maximum comfort. Belts are available in different versions, providing up to four hooks for loose connectors, each capable of holding up to 3kg per hook, plus up to three rings for lanyards, with a capacity of 100 daN per ring. Separate power drill and hammer holders are also available. • Snap-on UK T: +44 (0)1536 413904 E: ukindustrialmarketing@snapon.com W: snapon-industrial.co.uk

MIDSTREAM & PIPELINES

Drilling Holes in Pipe. Sounds Simple, but is it? Just Drill a Few Holes and Forget About It? Well, Maybe Not. One way or another oil and/or gas needs to move into a pipe and be transported to the surface. Completion Tool Manufacturers have traditionally drilled holes or sawcut slots in steel or alloy pipe. To minimize the transport of sand with the oil manufacturers wrap or slide over the pipe an additional filter element. For this article we will focus on the drilling of holes.

onventional drilling techniques use large machines with many drilling spindles. Traditionally these machines are somewhat unsophisticated and use conventional drills and air or hydraulic cylinders to provide the force to make the holes. In practice there is quite a lot of expense in changing dull drill bits and cleaning the interior of the pipe after drilling. In any circumstance a normal drill bit will leave a ridge on the under side of the wall of the pipe together with a round piece of thin metal called a coupon or chad. A dull drill bit will leave a ridge around the exterior of the hole. This ridge can affect the process of sliding on a filter or wrapping a filter on a pipe creating unwanted gaps in the filter element. To combat these issues manufacturers are forced to spend a lot of time cleaning the interior of the drilled pipe and even sanding the outside. Many hours are spent pulling a plug through a pipe over and over again or deburring the holes by hand. Inspection over the full length pipe can rarely be certain every piece of debris or burr was eliminated.

Interior of Pipe Deburred.

Since 2004 Toolmen Corporation has introduced even more sophisticated pipe drilling machines in order to minimize after drilling processing and combat some of the other problems encountered in the process. Their latest Pipe Drilling Machine utilizes a whole host of sophisticated technology. The machine has been built around the use of a special carbide drilling bit with an integrated deburring bit from the Swiss tool manufacturer Heule Tool. This technology and usage was first introduced by Toolmen in 2007 but was considered too expensive at the time. With increased pipe cleanliness standards and costs associated to clean the interior of the pipe the

“We’ve supplied many machines around the world and have developed the skills to support our customers no matter where they might be.”

use of the Heule drill bit became much more attractive and affordable as time went by. Finally, in 2017 a 48 Spindle Machine was put into production by Toolmen with great success. After drilling pipe cleaning dropped from 1-2 hours to 15 minutes. Sanding of the pipe was no longer needed. With this success, Toolmen has embarked upon the development of its most ambitious machine yet, an 88 Spindle CNC machine. This 40 kilo ton machine can drill and debur an entire 44 feet of pipe at once with just a few rotations of the pipe. The machine (bottom 2nd page) features several Innovations in order to optimize the drilling process. Some of the more interesting and important ones are explained below. 1. The Drill Spindle movement is controlled by a servomotor. The CNC control enables slower feeds while the drill is cutting the pipe wall and faster speeds when approaching, retracting, and using the deburring bit. This is done to minimize the drill cycle time.

Heule in the Machine.

Main with Spindle Monitoring. 2. The Spindle Rotation is controlled by a permanent magnet servomotor. This enables high torque even at low speeds. With short term power to 8 times continuous rating, it keeps the drill bit turning at speeds up to 3000 RPM with no RPM sag even with the intermittent cutting found at the start of drilling and the breakout on the wall of the pipe. 3. To maximize tool life and take the guesswork out of changing a drill bit Toolmen has developed a Drill Bit Wear and Drill Bit Broken detection system that is integrated into the process. By monitoring the electrical current consumed by each motor a drill bit can be changed or stopped before catastrophic failure. 4. Cooling high speed drill bits becomes more important when higher speeds are used. The machine features (4) 18.5 Kw coolant pumps capable of delivery up to 2 Mpa of pressure. This coolant can be delivered externally through a coolant hose or internally through the drill bit. 5. The control system (top right) features a touch screen computer, an integrated web cam, full internet capability wired or wireless and Windows 10 Operating System. Remote Access using TeamViewer allows the machine to be viewed from any location in the world. A Wireless pendant has been developed that allows the operator to control major functions of the machine even when far from the control panel. This is especially useful in the case of a worn or broken tool. The machine can be paused, the

convenient push button panel on the front of the drill can take the spindle out of service, raise it to a convenient location for drill bit changeout, lower it back to the original position and then put back into service. All without the lengthy walk back to the operator control station. 6. The operator system features fill in the blank programming making it easy for the operator to adjust to any pipe size. The program also features the ability to drop out a spindle from the program for the case of shorter pipe or pipe with a hole gap in the middle.

7. In all cases potential vibration from so many drills operating at once has been identified and minimized. The 40 kilo ton weight of the machine is only the start. The hydraulic clamping system pulls the pipe downward onto “v” grooves with tooled inserts which are connected into the into the frame of the machine. The Twin Spindle Housing is cast and a conventional 30 Taper toolholders are used to hold the tooling. The Spindle Bearing system is optimized for the axial loading that occurs during the drilling process. The Linear Bearing for the slide movement uses rigid “roller” type bearings. 8. The chip conveyor is integrated into the base of the machine. Chips are carried to the far end of the machine where they are dumped into an elevating conveyor. 9. The Rotation and Indexing of the Pipe is controlled by a hydraulic Chuck which provides sure clamping force to the end of the pipe. An elevating axis is also included to move the chuck up and down for rotation and loading from the internal roller system. This means the pipe is never bent or stressed during the drilling process. 10. The internal roller system is integrated to the external loading conveyor and smoothly brings the pipe into and out of the machine. These rollers move up and down with servo-controlled movement to make the loading easy. Each generation of the multi-spindle drilling machines by Toolmen Corporation come closer to making the actual drilling process and the result a simple one. This latest generation promises true cost savings and production increases over previous generations. • Toolmen Corporation http://toolmen1.com

Overview of Drill Machine.

MIDSTREAM & PIPELINES

Articulated Arm Designed and Built for Amarinth Ltd Rotaflow is a global leader in swivel joint design and manufacture. We engage with clients all over the globe to produce swivel joints for a wide range of industrial uses, from food and drink production, pharmaceutical, process & plant to subsea oil and gas extraction. If there’s a need for a swivel joint in an industry, there’s a better than not chance we’ve supplied it!

large part of our business is in the custom building of swivel joints. When clients have specialist needs, or an off-the-shelf solution simply won’t do, our in-house team of designers and engineers will produce swivel joints fit for specific purpose. Thanks to the tried and trusted reputation Rotaflow has built up over 4 decades, clients return to us again and again for their swivel joints. One such custom design was for Amarinth Ltd, the global pump manufacturer. They had approached us with a problem that was going to require a custom solution, because off-the-shelf simply wouldn’t work. They asked us to design and build an articulating arm that will serve as a part of their pump testing equipment. The arm is designed to enable efficient connection to variously sized pumps. Our design ensures that the pump testing process is smooth and effective, saving a lot of wasted time for Amarinth and their customers. In a world where time and efficiency are of utmost importance, any delays can be costly. By engaging Rotaflow to design the articulating arm, it reduces the time taken to test the pumps. In manufacturing every small saving of time adds up, shortening the overall process and reducing the time is takes to deliver products to customers.

Technical Aspects of the Articulating Arm The arm has 4 10” Swivels to provide the range of articulation required. It has to cope with a lot of positional manipulation, so having 4 points of rotation make this possible. We design as efficiently as possible and this was the minimum we could fit into the arm and still enable it to deliver all of the movements and functionality required. The arm is designed for operation 50 Bar. At

Rotaflow we have the capability to pressure test every joint we produce even in our custom-built hyperbaric testing chamber if the application requires. We have tested the arm at Rotaflow to 75 Bar, so can be satisfied it is more than able to cope with the tasks set for it. By testing in-house we can adapt designs based on data and can be confident that everything we send out of the door is absolutely fit for purpose and certified as so. It also reduces our lead times on equipment – all of our designing, manufacturing and testing is done in-house, so we don’t have to factor in long delays as products are sent off site for testing. This element of control also allows us to accurately forecast a completion date for a project, so both our team and our customers know what to expect and when to expect it. The dynamic sealing surfaces have been overlaid with Stainless Steel to provide corrosion protection to the most important sealing surfaces. We have our own multi-stage method of overlaying stainless steel that has been developed over many years. It’s a process that means we can be very confident about the level of corrosion resistance the sealing surfaces have.

Packed and ready for despatch from Rotaflow.

This design allows for the use of lower cost Carbon Steel for the rest of the structure without compromising build quality. This approach provides strength and structural integrity where it is needed most, but the appropriate use of lower-cost materials saves the customer significant amounts of money.

Arm successfully installed at Amarinth.

Lifting lugs were provided at positions as required by the customer. The custom design process means that we can adapt our products to suit the exact requirements of the client. We produce equipment for a huge range of spaces and conditions, so our designers have a lot of experience in this area. The final connection flange is a ‘Lap Joint Flange’ which allows the final connection to the pump to be orientated as required. This is a particularly important detail because it’s the final connection between the arm and the pump. It has to be sufficiently secure, easy to connect and disconnect and able to move wherever the testing dictates. The arm is PED cat I certified. In order for the unit to be despatched in the most customer friendly fashion we organised specific same day despatching as this removed any issues faced with dealing with the somewhat awkward size and shape of this bespoke unit. Rotaflow Quality Speaks for Itself As a global supplier of swivel joints, Rotaflow have built a reputation for excellence. Our inhouse team manage the job from end to end, so we do the design, manufacturing, testing and shipping. This streamlined operation removes

“If there’s a need for a swivel joint in an industry, there’s a better than not chance we’ve supplied it!” all unnecessary costs and time delays from the process, making working with Rotaflow a faster and often less costly experience. With 4 decades of experience and a global reputation for excellence, working with Rotaflow will guarantee your project is in the safest possible hands. From consultation to shipping, we’re experts in project delivery. Having designed and manufactured thousands of swivel joints for a huge range of purposes over the years, there’s little we haven’t seen before. We build deep, long term relationships with our customers that see them returning time and again for different products on their other products. We also offer a refurb and replacement service, whereby we’ll refurbish Rotaflow parts if it’s appropriate to do so. It’s a testament to the quality of our products that some clients have had our swivel joints in place for literally decades! Working with Rotaflow We’re based in the Peak District and our central location means we’re easily accessible for all corners of the UK. If you have an engineering problem and would like to speak to the team at Rotaflow, you can reach us via the following options. •

Factory pressure test at Rotaflow.

Phone: + 44 (0) 1663 735003 Email: websales@rotaflow.com Web: www.rotaflow.com

MIDSTREAM & PIPELINES

MannTek LNG Transfer System – Nitrogen in Harmony With Physics Today LNG is being used more and more widely especially when it comes to the maritime industry. LNG has been transported around the world for over 50 years with an incredible safety record. Today more and more vessels are transitioning their marine fuels towards the use of alternative fuels one of those being LNG. Whether it is LNG carriers, FSRU’s, FSU’s or the use of LNG for bunkering all of these need to be able to transfer LNG safely either from ship to ship or from ship to shore or shore to ship.

he LNG industry and such organisations as ISO, SGMF, Class societies have recognized that transfer of LNG from or to a vessel carries a high degree of risk and as such have driven rules and standards into the industry to make sure that all methods of transferring LNG is as safe as possible. The first hose based LNG transfer system was developed and used in 2006 in the Gulf of Mexico using a hydraulic system but over time and driven by the increasing need to develop and innovative safer systems, Manntek has become the leading manufacturer of LNG transfer systems and SIL2 systems designing and developing its LNG transfer systems to enable the safest transfer of LNG between ship to ship and shore to ship with its innovative and uniquely designed nitrogen LNG hose transfer systems. Based on feedback from operators and owners it became clear that these original systems were overly complicated, heavy and due to the hydraulics used fairly prone to leakage and both

operators and owners wanted to use a simpler, lighter, more reliable and easier to use system. The purpose of the Manntek LNG transfer system with powered emergency release coupling (PERC), is to protect both the LNG transfer line from stress and damage during transfer and the manifold from unnecessarily high forces during mooring line failure, vessel drift, fire, gas leak etc. whilst maintaining compliance to all the relevant and current standards, rules and levels of safety required by the industry. So, after thinking carefully as to how we could improve on the then existing hydraulic systems, MannTek decided to investigate the use of nitrogen (N2) as a means to operate the system. By using nitrogen which is a similar cryogenic temperature to that of LNG we were able to utilize nitrogen in harmony with physics. What are the advantages of using nitrogen? Well nitrogen has a lower boiling point than

LNG which means no additional heating or circulation system is required unlike hydraulic systems that need to find a way of preventing the hydraulics from freezing. We use no hydraulics in the MannTek LNG transfer system and therefore we have no hydraulic leaks. We are able to monitor the pressure right to the point of activation rather than to an actuator with a mechanical linkage to the release point. The system is lightweight and compact and both the PERC and the DCC can be lifted to the receiving vessel. Why is this important, many customers taking LNG from an LNG bunkering vessel do not want to have the responsibility of the hose in the event of an activation and release of the hose system. They want the LNG bunker vessel or LNG terminal to have this responsibility. Therefore, the PERC needs to separate on the receiving vessel and not the LNG bunker vessel or LNG terminal and therefore the PERC has to be lifted to the customer vessel. MannTek has developed its PERC to be lightweight and compact, but they have also designed into the PERC a safety redundancy dual functionality. Its primary function is to be activated on an ESD 2 signal but in the event of a blackout the MannTek PERC has a redundancy built in of a passive breakaway separation. This is achieved by holding the two halves of the PERC together using industry proven and widely used break stud technology. These breakstuds are designed as the weak point and are set to ‘break’ just below the maximum forces of the ships manifold, thereby always protecting the ships manifold. The main components of the MannTek LNG transfer system are: Dry Cryogenic Coupling - is a QCDC which connects and disconnects the transfer line to the client vessel during LNG transfer, opening and closing integrated valves automatically when operated. Powered Emergency Release Coupling (PERC) – acts as a safety component in the transfer line. The internal valves immediately close with 100% shut off on both halves and incorporates both an active system in the

LNG System. N2-operated release function to separate the PERC and also a redundant cryogenic breakaway coupling function which operates as a passive system if there is a blackout and failure of N2. Nitrogen cabinet – Is used to monitor the high-pressure release line to the PERC and to the PERC internal pressure chamber at a low 2 bar pressure. On the ESD2 signal the system changes from a low-pressure monitoring system to a high-pressure release system and over 150 bar of nitrogen is sent to the PERC internal pressure chamber which will sperate the PERC with 100% shut off on both halves. The cabinet also has a manual override system to enable manual activation of the PERC. Transfer Hose - connected between vessels and to the PERC on the ship side. The Composite Hoses are specially designed for offshore use in rough conditions with fully refrigerated liquids down to - 196°C in, such as Ship to Ship operations of LNG at -164°C. The hoses are produced and tested according to international standards like EN 13766, IMO IGC and EN 12434 and are individually pressure tested. The pressure tests are carried out by the hose manufacturer under supervision of a notified body. The tests are documented in a “Hose certificate”, which is included in the delivery. Vessel Separation Device (VSD) - is connected to the drift protection wire between the vessels. If the wires are stretched, the cabinet first sends an ESD1 signal which is integrated into the vessel ESD system to enable pump shut down and ESD valve closure. If the drift continues, it sends an ESD 2 signal (PERC release signal) to the N2-cabinet. The drift protection wire - is an electrically insulated stainless steel wire fitted between the ESD control box and a designated strong point at the customer vessel. There are 3 different length wires allowing for visual/audible alarm, ESD 1 and ESD 2. The wires consist of the main wire (length typical 10-15 m) fitted with a heavy-duty electrical insulator. On one vessel it is connected to three trigger wires of different lengths - The

short “trigger A”, (ca 0.5 m), the medium “trigger B” (1- 2 m) and the longest “trigger C” (3-6 m). Each of the pendant wires are connected to a breaking bolt with a designated break force of 1200 N. Saddle - is a hose support/guide for the hose as it goes over the side of the vessel. Fall Arrest System - is a friction device used to control the rate of descent of the hose after an emergency release and as it goes over the side of the vessel after the PERC has separated on an ESD2. How does the system work? Using the vessel separation device (VSD) and drift protection wire we monitor the movement of the vessels, if the mooring lines slip and the vessels move apart the VSD is activated to firstly by trigger A to create an audible/visual alarm and then trigger B which will create the ESD 1 signal. This signal is used by the vessels to shut down transfer pumps and close manifold isolation valves/ESD valves. If the ships continue to move apart then trigger C is activated to generate the ESD2 signal. This ESD 2 signal is used to change the nitrogen cabinet from a monitoring system to release system and the PERC is activated and the hose is separated.

MannTek Compliant SIL2 LNG Transfer System MannTek has also developed a SIL2 PLC LNG transfer systems have been assessed by DNV-GL and declared compliant to SIL2. This extra safety feature has been developed in accordance with IEC 61508 and IEC 61511 with input data from the PDS Data Handbook 2010. Identifying mean time between failure (MTBF), probability of failure on demand (PDF), all safety instrumented functions (SIF) and achieving a minimum probability of failure on demand is compliant with safety integrity level SIL2. The SIL2 compliance is on the whole LNG Transfer System and includes PERC, DCC, HPN2 PLC control system, ESD1&2 functionality, the logic solver i.e. Siemens PLC controller and software, sensor elements and final elements. PLC – Monitoring and control unit – The software used has been specially developed for use with the MannTek SIL2 system and is programmed under the supervision of a third party. Each application is different and therefore the program is designed uniquely for each application. The PLC monitors the whole system from when it is switched on and though out the whole of the transfer operation which eliminates the human factor and ensures that all steps in the periodical tests are carried out safely and thereby reduces risk. To date Manntek has supplied over 42 systems worldwide since 2013 of these 10 have been fully compliant SIL2 systems, these systems have collectively undertaken over 35,000 LNG transfers and transferred over 3 million M3 of LNG and MannTek has a 100% safety record. • If you would like to know more about how MannTek can help your company and its operations, please contact them at: MannTek T: +46 501 39 32 00 E: sales@manntek.se W: https://www.manntek.se

MIDSTREAM & PIPELINES

EXOLUM INVESTS IN INNOVATION Ignacio Casajús López, Exolum’s North West Europe Lead explains how the company is using its extensive experience in the management of liquid products to diversify and innovate for a zero carbon future. Global challenges As an international leader in bulk liquid storage and transportation, and with over 90 years of experience in the energy sector, Exolum recognises its responsibility to develop innovative solutions to the global challenges that face us all, from climate change to resource depletion. With this aim in mind we are growing and adapting our business to meet these challenges and to play our part in the decarbonisation of the economy, the energy transition, and the sustainable use of raw materials.

he Group’s acquisition in 2020 of 15 terminals in four countries from Inter Terminals reflects our vision for the future and a strategy of international expansion and diversification beyond hydrocarbons in response to climate change. This major investment has made Exolum the leading bulk liquid logistics company in Europe and expanded our knowledge of chemical products and biofuels storage. Sustainable Development Goals Exolum incorporates in its business and operational strategy the Sustainable Development Goals (SDGs) approved by the UN in 2015 to build a better future for people and the planet. The company is also a full member, at signatory level, of the Spanish Network of the United Nationals Global Compact. The main focus of Exolum’s SDGs is to conduct the global management of our infrastructures in such a way as to guarantee affordable, safe and sustainable access to energy, as well as expanding our field of vision to study new business opportunities and offer innovative, sustainable and efficient

solutions. Exolum’s infrastructures and new business ventures, based on innovation and energy efficiency, are helping us to create more sustainable cities and communities. Furthermore, the way we do things, characterised by a responsible use of natural resources, contributes to guaranteeing more responsible production and consumption patterns and fostering a green economy. And to strengthen this commitment, we maintain strategic collaborations with other companies, suppliers and customers. The company also supports educational, social inclusion and environmental protection initiatives, which allow us to contribute to the transformation and improvement of the communities where we operate. We assess the environmental impact of all projects we carry out, studying different routes, locations and alternatives and always choosing the ones that have the lowest environmental impact. In the case of pipelines, when the works are complete, we restore the land to its original

Ignacio Casajús López, Exolum’s North West Europe Lead.

state and revegetate the area affected if necessary. Growth potential Although the energy transition will reduce demand for hydrocarbons and oils, it will increase market demand for sustainable alternatives. At Exolum we have recognised this emerging opportunity and are already developing business models for the production, distribution and use of green energy solutions, such as sustainable aviation fuels and other non-oil products. Indeed, one area in which Exolum is currently very active is in the supply of Sustainable Aviation Fuel (SAF) which is produced from sustainable feedstocks and is very similar in its chemistry to traditional fossil jet fuel. Using SAF results in a reduction in carbon emissions compared to the traditional jet fuel it replaces over the lifecycle of the fuel by up to 80%. Furthermore, our Exolum Pipeline system supplies ~ 35% of the Jet fuel to London Heathrow Airport and we do this via a cross country pipeline system, which is the most efficient and green/sustainable way of delivering fuel (rather than by alternative trucks or trains). We believe usage of the Exolum Pipeline System will enable rapid scalability of SAF in the future.

New technologies As we journey towards a decarbonised world there is still some uncertainty about the prevalent technology of the future. It is for this reason that Exolum is taking an active yet cautious approach to the various solutions, like hydrogen, for example. Hydrogen may be considered a hot topic in green energy but it does not offer a credible alternative to traditional fuels yet. However, we believe it could play a part in the future energy mix, particularly in areas that are difficult to electrify, and so we are currently participating in various projects to produce ‘green’ hydrogen using solar power. We believe our industry can play a major role in the global energy sector’s transition from fossilbased systems to renewable energy sources. Although demand for bulk liquid storage of hydrocarbons and oils is expected to remain high, storage operators must be ready for the inevitable transition to green energy. The market for storing and handling biofuels and eco-fuels is experiencing rapid growth and becoming increasingly sophisticated, with the use of waste or sustainable raw materials as feedstock, as well as the development of specialist blending and pre-treatment processes for these new materials. For its part, Exolum is already responding to this trend by exploring the potential for developing new capabilities in this area. Environmental pledge Exolum is committed to minimising the environmental impact of our activities and to optimising the use of resources. As an organisation we have pledged to reduce our CO2 emissions by 50% by 2025 and to achieve Net Zero emissions by 2050. The power our business consumes is the biggest source of emissions, particularly in the pump stations used by our

pipeline network, which make up between 40% and 50% of these emissions. To address this we are building solar panels at our facilities to generate our own green power. We are also harnessing the benefits of Artificial Intelligence to manage energy consumption more efficiently throughout our network. In addition to optimising energy consumption we also aim to minimise our water usage. This is particularly relevant at our facilities in southern Europe where there is less rainfall and so we have introduced a number of initiatives in these regions, including rainwater capture and storage systems. Fostering innovation Established around 18 months ago, Exolum Ventures is a clear demonstration of the company’s commitment to foster innovation by teaming up with technology entrepreneurs who can help us fast-track new developments that contribute to the sustainability of the planet. One such development is Avikor, the

“Exolum recognises its responsibility to develop innovative solutions to the global challenges that face us all” Exolum platform that offers individuals and companies the opportunity to reduce the emissions of their commercial flights for a small extra charge. This new digital business is built on the infrastructure we already have at some Spanish airports. When booking a flight from Madrid or Barcelona travellers can use the Avikor application to request that their seat is ‘fuelled’ by SAF, which is then supplied by Exolum. Adapting to change Some believe that the Covid-19 pandemic has acted as a wake-up call for the world to take a more sustainable approach to the way we live and work. For Exolum, it has renewed our commitment to deliver innovation, diversification and sustainability throughout our organisation and to make our business more agile and flexible in a changing world. Exolum has been a pioneer in the automation of its activities, investing in digitalisation, AI and satellite monitoring technology, for example. This has enabled highly efficient processes and has been key to our ability to adapt to change and the needs of our customers. However, despite the current and necessary trend towards decarbonisation, it is widely expected that our society will continue to depend on oil products for some time to come. We will, therefore, continue our commitment to optimal management of oil product logistics, whilst evolving our business progressively, and prudently, towards a cleaner, greener future for our planet. For more information visit: www.exolum.com Or follow us on social media. •

MIDSTREAM & PIPELINES

More and More Heavy Lift Projects are Using Vacuum Technology Ceti Suxxesion B.V. was established by myself in 2000. We are specialized in the design and production of so called end of the line attachments. At the end of 2015, the company’s name was changed into Suxxesion B.V. with the brand name, SUXXESION. By Harry Crone

he custom made tools are designed to handle by means of vacuum or hydraulics loads such as steel or concrete pipes, steel sheets and billets, concrete elements, wing skins, paper reels or any other object which can be lifted by means of vacuum. Ever since I started Suxxesion our main business was and is pipe handling and we have been able to develop equipment which meet today’s requirements of handling speed and safety, thanks to the input from our international customers. Over the past years we have built a variety of devices to handle pipes for pipe manufacturers and pipe coating companies. We also work in harbor areas, railway / road shipping, storage yards and at the pipe stretch, either hydraulically or by means of vacuum. We are glad and thankful that so many people have contacted us leading to long term business relationships. My company is based in a small city called Buren in the heart of the Netherlands. Like many companies we subcontract steel constructions to regionally based qualified suppliers. We have a long term relationship with these companies and where quality is concerned, we constantly strive to achieve higher standards to meet today’s requirements. As a result we are able to meet all the off-shore requirements.

As previously mentioned, the logistic situation is different per site. A typical example is the Multitool 320 DVHKI built for Data Steel in Pakistan. This device is fully integrated in the Reach stacker. Up front we only need a hydraulic oil feed from the carrying machine and 24 V= controlling by means of blue toot data exchange. A new feature is the hydraulic adjustment of the c-c between the suction pads. This in contradiction to equipment earlier supplied to MPC in Germany.

Both applications are typical arrangements that the handling material is dedicated to handle pipes only. The recently built and developed 320DVHKI is a multi-tool solution which can be equipped with pipe spreaders or with a beam with flat pads to handle steel sheets or concrete. Knuckle boom suspended lifting equipment is used in every site situation which handles pipes to load and off load pipes. As far as harbor applications are concerned we are very experienced in handling pipes in combination with HMC’s Reach stackers and Knuckle boom cranes. Case Studies Double pipe lifters operating in Kotka, Finland and Sassnitz Germany suspended from mobile harbor cranes: Devices were in use to load out the concrete lined pipes for the North Stream Project. Before the concrete lining the pipes were handled by means of vacuum. For that purpose we equipped a.o. two container reach trucks with our vacuum system to load and off load the train wagons. For Cogema in Dunkirk France and Adani Port in India we supplied double pipe spreaders to equip container reach stackers. With simple modifications the reach stacker was adapted to use the Suxxesion attachment suspended from the twist locks. After the break bulk job was finished the reach stacker could be used directly when the attachment was released by the twistlock and the hydraulic connections were uncoupled.

“

Suxxesion is a leading Dutch company for the design and manufacturing of end of the line attachments. Suxxesion has developed the multi- tool to handle pipes by means of vacuum or with hydraulic spreaders for the pipeline industry. The multi tool is available to be attached to the twist-locks of container handling equipment in portal areas, knuckle boom cranes and excavators. Suxxesion vacuum lifting equipment is also used in concrete precast industries, steel sheet handling, aircraft and paper industry.

“ We have supplied vacuum handling equipment to J. Müller in Brake Germany suspended from container bridge cranes and container reach stackers.

For both harbors we have built several other sets of equipment suspended from harbor cranes and gantries. As for Adani Ports we have built a so called multi tool able to handle pipes by means of vacuum or hydraulically. This device operates in the pipe stockyard suspended from a gantry crane.

For the Polar LED pipe line disclosing the Aasta Hansen gas field, we supplied vacuum handling equipment and a double pipe lifter to Mo I Rana port in Norway to load in coated pipes and load out concrete lined pipes. This job is finished now and we were the hands to enable All Seas to set the off-shore pipe laying record of more than 6 km of pipe per day. All the 33.500 pipes produced for this pipeline have been handled with our equipment. Every pipe has been in our hands at least two times.

Having done all this, Suxxesion has designed a tool for easy conversion of a container terminal into a break bulk terminal. We have done this with minor changes to the container spreaders suspended from container bridge cranes, reach stackers, mobile harbor cranes or any other loading means equipped with a container spreader. The possibility of suspending our multi-tool to existing equipment is very interesting when pipeline projects need temporary pipe storage or when construction takes place close to the container terminal for which materials such as steel sheets or concrete elements are required , that come in over seas. In such cases it will not be necessary to arrange for a temporary break bulk terminal, but the local container terminal can be converted very quickly and the investment will be limited to equipment only. The advantage is that infrastructure behind the container terminal such as roads and railways will be available. When the construction or pipe line project is finished, the container terminal can be operated as container terminal after the Suxxesion attachments have been put away. This will not take much time. All pipe manufacturers, coaters and contractors are familiar with vacuum handling equipment. We want to build and supply equipment distinguishing itself through efficiency and low cost of ownership. • For more information about Suxxesion and our many solutions please visit our web-site: www.suxxesion.com Inquiries can be sent directly to: harry@suxxesion.com

PROCESSING

Why Gas Quality Matters OGI sits down with Dr. Philippe Prêtre, CTO of Mems AG, to learn more about the work they do with gas measurement technology. Dr. Prêtre is here to help us understand a bit more about gases, and why gas quality matters. For example, they help companies in the oil and gas industry with “Gas Sensing” which monitors gas concentrations, that can reach dangerous levels. Mems AG are experts in the field and offer quality meters which are basically maintenance free, plus technical support and after care for their customers. We learn more below.

OGI: Could you start by explaining Mems AG’s credentials and experience in terms of your products and services for the oil and gas sector? Could you tell our readers the breadth of your experience, how long the company has been active, and its reach? Pretre: Mems AG - that means almost 20 years of experience and projects in gas measurement technology and electronics. Mems AG regularly works on behalf of ABB for projects in the field of subsea equipment (power electronics). In the field of “gas sensing” we are often asked about safety related aspects of the oil & gas industry (tightness of gas pipeline flanges, reaching dangerous gas concentrations in the environment). When using mine gas, associated petroleum gas or the like gases, our gas quality measuring instruments are in demand, because our gasQS technology is one of the only ones best suited for the measuring task for such gases. OGI: Could you explain to our readers the different types of gases which are in use today? Pretre: Conventional natural gas from reservoirs with moderate to high permeability for gas still accounts for the majority of global gas consumption. Unconventional natural gas comes from deposits with low permeability (shale gas, tight gas, coalbed methane (CMB)), which is more expensive to extract than conventional natural gas. In the past, natural gas for local consumers usually came from the same source (e.g., the North Sea), but natural gas is increasingly being transported in liquid form (LNG) across the globe, so that the origin of the gas on site can no longer be from just one source. In the pathway of decarbonization of fuels, gas from renewable sources will play a major role. Biogas produced from organic material (food waste, wastewater, renewable raw materials), as well as hydrogen produced from surplus electricity or methane produced from it together with carbon dioxide, will be found more and more in

Calibration at Mems.

Series Production at Mems.

Installation on LNG Vessel.

the already existing gas distribution networks as well as in new ones built especially for these gases. OGI: Could you talk a bit about gas quality and why it’s important? Pretre: Due to the possible origins of the gas shown in the last question, its composition is also different. However, different composition also means different gas quality in terms of energy content, combustion and exhaust gas behavior. The former is important for fiscal accounting (custody transfer, end customer billing), the latter for safe and environmentally friendly operation of combustion plants (boilers, engines, fuel cells). If gas quality did not change over time, a one-time determination of gas quality would be sufficient to account for local conditions. However, as the origin of the gas changes more and more frequently, so does the gas quality, and without determination of the latter, this inevitably leads to process inefficiency, faster wear of machinery and increased environmental pollution. OGI: What is gas quality sensing? Pretre: As described above, gas quality goes hand in hand with gas composition. Therefore,

gas chromatographs (PGC) are mainly used for gas quality measurement, as they can be used to determine the gas composition. This data can then be used to calculate relevant gas qualities such as calorific value, air demand or methane number according to specified standards. However, since a PGC is a relatively complex measurement system that is expensive both to purchase and to maintain, there are also alternative technologies for determining gas quality. These include correlative measurement systems that correlate gas qualities using metrics other than gas composition. While not quite achieving the accuracy of a (perfectly calibrated) PCG, such systems are robust, lowmaintenance, and can be used wherever a PCG cannot be deployed due to space or cost considerations. OGI: What are the advantages, i.e. cost saving, time saving, with your solutions? Pretre: Our solutions offer gas quality meters or entire systems of compact size that operate virtually maintenance-free for many years. They do not require calibration or reference gases, which allows for quick installations. In addition, they measure quickly compared toa PCG, which is a great advantage especially for process control applications. These systems are ideally equipped for future tasks: Practically applicable for all gas types, also for those with high hydrogen or inert gas content.

CHP Plant Installation.

technical support, accompanies customer projects from the idea to the market launch and helps to lead them to technical and commercial success. Due to the broad spectrum of existing education and experience in our team, we are able to approach the tasks given to us with a technical-scientific approach and to solve them comprehensively. For our customers from the industrial and service sector, as well as for the public sector, we develop electronics and sensor technology and bring them to market maturity upon customer request. Since 2008, with the support of several distribution partners, we have been marketing the self-developed technology for gas quality measurement under the trade mark gasQS™ technology. OGI: Finally, could you enlighten our readers of a case study where you helped a client with your solutions? Pretre: For the network operator in the vicinity of a large German city, we are installing several dozen measurement systems to track hydrogen dispersion in a gas distribution network. In addition to sensors to determine the hydrogen content at the feed-in, the installation also includes remote reading systems of the sensors to determine the hydrogen content at different points in the network without much effort. We use Mems AG internal synergies between gas specialists and electrical engineers to set up a gas quality measurement network for the customer in the shortest possible time. OGI: Thank you for your time. • If you would like to know more about how Mems AG can help your company and its operations, please contact them at: Mems AG

OGI: What are some of advantages when working with Mems AG?

Telephone: +41 (0)56 470 92 00

Pretre: Mems AG offers competent

Website: www.mems.ch

E-mail: info@mems.ch

PROCESSING

Efficient Temperature Control in Sulfur Recovery Unit By Advanced Energy: Joerg Roessler, PM Oil & Gas, LumaSense Technologies GmbH

With the International Maritime Organization’s (IMO) plan set to take effect January 1, 2020, banning shipping vessels from burning fuel with a sulfur content higher than 0.5 percent (down from the current 3.5 percent), refiners will be under increased pressure to produce cleaner, low-sulfur fuels. While these regulations are necessary to curb sulphide gas emissions and sulphur content, it is no easy task. Due to the complex reactions involved, accurate temperature control is required, particularly in the reaction furnace. Given the high temperatures and corrosive nature of the process, however, it is a challenge for temperature instrumentation.

Today, most refineries use the modified Claus process for sulphur recovery, which takes place in the Sulphur Plant or Sulphur Recovery Unit (SRU) where hydrogen sulfide (H2S) is converted into elemental sulphur through thermal and catalytic processes. Sulphur recovery is usually a back-end process in a refinery. Removing sulphur compounds from sour oil and gas requires a carefully controlled band of temperatures, especially in the first stage of an SRU, the Reaction Furnace (RF). If temperatures are too cold the reaction becomes less efficient and instable leaving undestroyed BETX and Ammonia in the catalyse bed. In case of too hot temperatures the reactor could be critically damaged. That makes sulphur recovery units expensive to install and difficult to run. There are two common ways to measure temperatures in the Reaction Furnace and control the SRU: •

One is typical using thermocouples for monitoring temperatures, but due to their composition and nature, thermocouple lifetime is relatively short because of potential thermal shock or crack of protection insulation caused by process related furnace vibrations. In addition, thermocouples are only capable to monitor refractory temperatures, they cannot measure combustion gas temperatures.

•

The other method is using Infrared thermometry. Pyrometers are able to instantly measure temperature inside the RF and on refractory wall and in addition they can detect the combustion-gas temperature, which is the most important information for operators to run SRU on highest efficiency.

Optimal operation of Sulfur Recovery Unit (SRU), Sulphur Burner, and Thermal Oxidizer furnaces require accurate measurement of process gas (flame) and accurate refractory temperatures for highest efficiency and under safety conditions.

*Above: E2T Pulsar 4. Infrared Thermometry for Sulfur Reactors and High Temperature Furnaces.

In case of too low combustion gas temperature (means: less than 1250 °C for Ammonia destruction or lower than 1050 °C for BETX) at the catalyst bed, which is the second or third stage of the process, this might cause significant efficiency reductions, or even the possibility of deactivation. Replacement or exchanging of the catalyst bed will not only generate cost but also downtime of the SRU, which leads to reduced overall plant output due to non-existent backup capacity on SRU. As a possible consequence operators try to avoid unplanned shutdowns and run the RF at too high temperatures,

Typical Installation of the Pulsar 4 Unit.

which not only leads to additional energy cost but also to risking a severe lifetime reduction of the refractory wall. Of particular importance is a constant control of the furnace process temperatures to prevent damage to the furnace refractory and assurance that reaction or destruction temperatures are reached and maintained. The E2T Pulsar 4 Advanced measures two wavelengths for continuous and instantaneous measurement of refractory temperature (RT), gas temperature (GT) and integrated temperature (FF), reporting both readings simultaneously in one instrument. A single system installation with two independent IR filtered detectors that provides both gas (flame) and refractory measurements simultaneously. The innovative Smart FMA™ Flame Measurement Algorithm allows for accurate real-time flame transparency compensation and correction. Applying the flame transparency calculation with FMA removes the flame transparency errors due to the gas (flame) temperature, providing the highest accuracy in process gas temperatures. The gas (flame) measurement is used by the operator to detect thermal events before IR energy is absorbed by the refractory, creating a refractory thermal event. This method of early warning by use of the gas (flame) temperatures, allows added time for operators to make process changes and reduce potential refractory Below: Pulsar 4 Installation Schematic

thermal events before they can become critical by triggering a high-level alarm system based on the refractory temperature measurements set point. Given the importance of the data, plants are rarely to be found that do not monitor temperatures at least to some extent. Consequently, temperature control of the reaction furnace in the SRU has taken on a new importance with the advent of processes like oxygen (O2) enrichment, which increase operating temperatures. Functioning much

closer to the refractory temperature limit, this makes reliable temperature measurements a critical requirement, not only for preventing damage to the furnace refractory, but also ensuring that proper gas (flame) temperatures are reached and maintained. While estimates put overall refinery efficiency at approximately 90%, many of the processes such as SRU, distillation and reforming require high temperatures that are very energy intensive. Small efficiency improvements in these processes can improve yields and provide immediate return on investment. To realize these efficiency improvements, operators need to implement gas and temperature sensing solutions to understand how their equipment is performing and detect developing failures. Temperature solutions by Advanced Energy provide highly accurate data to help operators realize condition-based maintenance with continuous and remote monitoring in order to optimize critical processes. Over the years more than 550 refineries, gas plants, and petrochemical companies look to the E²T product line by Advanced Energy for accurate infrared temperature data. With over 1,700 installations worldwide, E2T petrochemical sensors deliver proven experience, superior performance, and cost savings for a wide range of refining applications. • Advanced Energy Contact: www.advancedenergy.com info@aei.com

PROCESSING

Combining Rupture Disks with Safety Relief Valves Protecting process systems from over-pressurization is vital throughout the oil and gas industries. Safety relief valves and rupture disks can be used for this purpose. Sometimes the combination of a relief valve with a rupture disk can add service life to the relief valve and prevent process leakage, which is important from safety, conservation, and financial standpoints.

he advantages of a disk and valve isolating a safety relief valve with a rupture disk prevents process materials from coming in contact with the safety relief valve under normal operating conditions. This barrier stops the process from entering the mechanics of the relief valve, which keeps the relief valve from coming into contact with caustic materials. The rupture disk also protects against highly viscous materials that risk potentially “gumming up” the relief valve. In the case of over-pressurization, when both a rupture disk and relief valve are used, the rupture disk will burst followed by a release from the relief valve. Once the pressure drops to a safe level, the valve reseats itself and continues to protect the system. Under normal operating conditions, the rupture disk barrier keeps process fluids from leaking into the atmosphere. Consider, for instance, that on conventional safety valves, API Standard 527 allows for an orifice size of F and smaller to have the

maximum allowable leakage rate of 40 bubbles per minute. Unchecked, this leakage seeps into the environment, loses expensive product every hour of every day eroding profits, or requires the installation of a means to either recover or handle this leakage as waste. Rupture disks stop the leakage to protect the environment and to protect plant profits.

rupture disk and the safety-relief valve inlet. The test pressure is increased until a popping action is heard from the valve. The observed test pressure should be within the set pressure tolerance of the valve. Upon removal of the portable pressure source, both the rupture disk and relief valve are ready to immediately resume service.

Besides zero process leakage, another advantage of using a rupture disk at the inlet of a safety relief valve includes the allowance of safety relief valves to be ‘tested in place’. When a rupture disk is used to isolate a safety relief valve, the valve can be field tested in place. With a suitable, reverse-buckling rupture disk installed at the valve inlet, the safety relief valve can be tested on the spot by a single person with a portable pressure source. To accomplish this without opening up the process piping, itself, air, nitrogen or another acceptable fluid is injected from an outside source into the chamber between the

Valve life is extended. Extending the life of the safety relief valve is a major advantage of using a disk-valve combination. The rupture disk acts as a solid barrier between the valve and the process. The disk prevents product buildup from adhering to mechanical components of the valve that otherwise would affect valve performance and safety of the pressurized system. Since the process fluid will not come in contact with internal surfaces and components of the valve, it will remain in pristine condition until called upon to relieve pressure. A question often posed is to when use a rupture disk by itself and when to use a rupture disk combined with a safety relief valve. The benefits of using only a rupture disk begin with cost. Rupture disks are significantly less expensive than safety relief valves and require little to no maintenance. The quick bursting action of a rupture disk makes it a first consideration when the potential for runaway reactions exists. Safety relief valves, by themselves, will not react fast enough to protect from the pressure of a deflagration or a detonation. Also consider that some liquids may freeze or cause icing under rapid depressurization leading to blockage within a safety relief valve, rendering it ineffective. Highly viscous liquids, such as polymers, may not relieve fast enough through a safety relief valve and create a danger of plugging the valve. When in business for your next rupture disk or relief valve, be sure to check in with Granzow A/S. We have an extensive track history with more than 85 years worth of experience and know-how, and we’re experts in ensuring the safety of your production. Visit us at www.granzow-solution.co.uk and learn more about how we can make a difference in your safety of production. •

Hetraco

“We make special fasteners an experience”

• • • • •

Specialist in thread rolling (M5 – M200) Own production facility in The Netherlands Large stock of raw materials Fast delivery times (same day possible) Small quantities possible, from 1 piece

Hetraco BV T: +31 55 303 21 80 W: https://www.hetraco.com E: sales@hetraco.com SEE OUR VIDEOS HERE: https://www.hetraco.com/downloads-2/?lang=en

Hi Vent Ai r Rel ease Val ves Designed For The On/Offshore Petrochemical Industry

Air vent - Air release - Vacuum Relief valves

Introduction GA Valves Sales Limited has established itself in the supply of Engineered solutions in a wide range of exotic materials. We meet the diverse demands of the oil industry with the venting or admission of air into or out of pipelines and vertical risers, both wet and dry. We have supplied valves to a wide range of customers and countries throughout the world. Many of which revert back to GA after the valves reach their specified ‘life cycle’ for a new unit to be supplied, these life cycles are determined by the oil companies and can vary widely. All consumable spare parts are stocked on site for despatch around the world.

Documentation The critical nature of fire-fighting systems in the oil industry demands high quality of both material and traceability of components used. Every order is supplied with a document handbook available as electronic and/or hard copy if required. The document includes an arrangement drawing detailing all parts, operation and maintenance Manual, spares recommendation and pressure test certificate. Additional documents are available on request to be added as an extra, this includes but not limited to: material certification, radiography results, ferrite determination, micro examination, G4S/G48A corrosion test, charpy test, integral test block, dye penetrant, pickle & passivation, all to international standards. Due to the diversity of required material specification documentation, these units are custom made for each client, offering an extremely flexible and adaptable supply chain. Specifications for the following materials are available: Aluminium bronze, super duplex, titanium, lnconel, gunmetal and various grades of stainless steel.

JE-November 20

GA Valves Sales Ltd Johnstone House, Birds Royd Lane, Brighouse, HD6 1LQ Tel: 01484 711983 Fax 01484 719848 Email: sales@gavalves.co.uk Web: www.gavalves.co.uk

Hi Vent Air Release Valve s Designed For The On/Offshore Petrochemical Industry

Air vent - Air release - Vacuum Relief valves

References Many of our clients require that the details of supply are confidential so we are limited in the specific information we can release, end users include:British Petroleum, Exxon Mobil, Shell, Woodside Petroleum, Nexan Petroleum, Conoco Phillips, Total, Wartsila Oil and Gas.

Available configurations We offer an extensive range of configurations including custom request to suite your deign needs. We can offer the following: - All international or custom flange drilling’s - Threaded or flanged connection on inlet of the valve - Threaded or flanged connection on the outlet of the valve - Cowled outlet - Surge arresters - Inflow/outflow checks - Adjustable Throttled outlet - to control surge created by converging columns

Coatings Where required we can offer a wide range of both decorative and protective coatings with relevant certification, please ensure this is specified at time of enquiry.

JE-November 20

GA Valves Sales Ltd Johnstone House, Birds Royd Lane, Brighouse, HD6 1LQ Tel: 01484 711983 Fax 01484 719848 Email: sales@gavalves.co.uk Web: www.gavalves.co.uk

PROCESSING

Twister Gas Processing: Digital Automation and Absence of Chemicals Allows For Unmanned Platforms Twister BV has been in operation for 20 years now and has been at the heart of gas processing for several offshore or onshore plants operating in remote areas. Operational feedback indicates that the Twister units are normally operated by the plant control systems and left largely unattended. Twister BV has now studied these operations and has concluded that the actual capabilities of automation enables the operation of a gas plant without the need for human presence.

When Twister was introduced in 2000, much of the innovation was around the use of the supersonic velocity of the gas. Most operators were sceptical about the combination of high gas velocities and vortex. Likewise, the formation of hydrates following the supercooling of the Twister caused reservations. However, Twister has proven that it can dehydrate and hydrocarbon dewpoint natural gas to common pipeline specifications without the need of chemicals. As the upstream industry is known to be slow in converting new technology into reality because of the lack of incentive, chemicals still play a dominating role in the thinking of the plant designers behind the drawing board. And it is always assumed that chemicals are available on demand and can be acquired easily. The operational reality proves very different and many well-designed gas plants are running into operational issues because of the absence of good quality chemicals, which results in complications for Operations Managers and Finance Managers such as unexpected unavailability, non-performance, loss of revenue and risk of claims. Gas is increasingly found in remote places where availability of commodities like basic chemicals is not guaranteed. As the “lessons-learnt” are rarely a closed loop these days due to the dynamics of the workplace, the operational experience of the previous plant is often not considered when designing a

new plant. Even when there are incentives, the bigger operators have “locked” themselves in by prescribing standard technologies for standard processes and by that excluding innovation from the equation. Because the thinking is that standardization is saving costs by reducing engineering hours, it unfortunately also inhibits improvements like in-company hands-on experience. So real progress in the upstream industry becomes really slow: “we stick by the book” but the book is not updated.

Natural Gas Processing

The why and how for the non-experts:

The reason why we process gas is that we usually do not use the gas where we find it. So, the gas has to be transported and this is usually done by using pipelines. Two potential issues are: 1. The pipeline is made of steel, and corrosion must be avoided, and 2. The pipeline must always flow. The pipeline is laid onshore and/or offshore and is subject to the ambient temperatures which of course, will also be the case for the gas inside of the pipeline. In order to avoid corrosion, the formation of water must be avoided during transport. And to avoid flow-assurance issues, hydrocarboncondensation must be avoided as these hydrocarbons quickly turn into deposits, which can potentially cause blockage. Both phenomena are avoided by cooling the gas to 5ºC below the water-dewpoint and hydrocarbon-dewpoint before it goes into the pipeline. In this way, we avoid condensation of the liquids dissolving in the gas during transport of the gas in the pipeline.

Energy Transition

While the Energy Transition is in full swing and all oil and gas companies are busy converting into energy companies, the pressure to reduce costs on operations remains unchanged. With the energy transition, smaller independent operators are also increasingly participating in the onshore and offshore development of assets, where developments are clearly executed less capitalintensively as by the IOC’s. This sustains the need for new approaches for operating plants at reduced costs. The days of having 5 rotating crews offshore being flown in and out on a daily basis by helicopter, are no longer sustainable.

Digital Automation

These days, we can control any digital event from anywhere by using some sort of controller. These can vary from oldfashioned PLC’s to iPads. Provided that the devices are part of an accessible network and there is communication, everything is possible. The Internet-of-Things (IoT) and the Industrial-Internet-of-Things (IIoT), provide the required architecture and prove the technical capabilities. However, all of this automation comes to an abrupt standstill if human interaction is required. Our studies show that the presence of chemicals also triggers the need for human interactions. Remarkably, most of the actions on a gas plant are related to the logistics of the chemicals, inspection of liquidcontaining equipment and corrective maintenance on this liquidcontaining equipment. Practically, this includes conveying chemicals from supplytrucks or vessels into site storage, and the leak-detection and repairs caused by pipeline connections with leaking seals. As the loss of chemicals and the consequential fill-up procedure is still a manual logistical activity, proving to be the showstopper for further automation.

Surprise!

When Twister BV performed studies to further automate gas plants (as part of preparations for the FEED of a shareholder’s offshore projects), it was discovered that not only was the presence of chemicals preventing further automation, but it was also the only--cause hindering further automation. All other activities on a plant are effectively related to quantifying the process (which is done by process instrumentation), and plant control (which is done by a process control system which drives automated (control) valves). Consequently, when the plant is fully electrified, all equipment can be fully digitally controlled (i.e. it can be controlled from a process control system, which can then be managed from any location).

Life-Cycle-Cost

The studies show that if all equipment required on a gas plant is selected based on maximum operational availability and is fully electrified, CAPEX will increase for the cost of the equipment. However, because this equipment allows you to de-man or even unman the facility, other cost savings outrange the CAPEX-increase for the more expensive equipment and the net result is a significant saving. This observation is supported by recent projects of Equinor offshore Norway, where Equinor replaced gas driven turbines of the export compressors by electrically driven motors. Although the driver was to reduce emissions, Equinor reported that to their own surprise, cost savings were due to increased uptime. “The speed of implementation of new digital solutions has already delivered a cashflow impact of more than 400 million USD in 2019, mainly due to earlier start-up of Johan Sverdrup and increased uptime on assets connected to our integrated operations centre.”

Twister?

Since its first day of operation, Twister BV has always opposed the use of chemicals for operational and environmental reasons: chemicals are rarely necessary and chemicals produce waste. When the gas contains higher amounts of H2S, the operational issues of using chemicals becomes even worse. The mitigation

of these operational issues also increases plant complexity and the risk of plant unavailability. So, the ‘problem-solving’ causes problems.

Availability

When financial staff evaluate assets and do their economic analysis, it’s been observed that availability of a plant is too often conveniently assumed to be 100%. However, reality shows a different number and here again, the use of chemicals does not help. Unexpected loss of chemicals, a poorly running regeneration unit and delayed fill-up logistics, too often cause plant disruptions. These events cause revenue to disappear from the economics spreadsheet and cause complications in the Board Room. Too often, people have to expend all their energy on continuously problem-solving. Were these problems absent, more time could be spent on strategic production management.

The Future Is Digital

Twister BV has always believed that the environmental aspects of their technology would one day become relevant. And today, we see ESG-criteria being applied by more and more investors to justify their investments. Operators in oil and gas who show low involvement in ESG risk are to be left without financing. This is a positive development, but common-sense-economics will drive innovation more than regulation and legislation. For example, Twister BV is enabling digital automation due to the absence of chemicals, because Twister does not require chemicals to dehydrate and hydrocarbondewpoint natural gas. This has now triggered the drive to unman gas processing facilities. This corresponds well with the fact that gas is increasingly being found in remote areas - places where it would be safer not to send operators. The initial cost increase is quickly balanced by larger cost savings, especially offshore. Twister has already substantially reduced platform space and weight. This will be further scaled down because the proposed design of an offshore facility can now be rationalized by the fact that operator-shifts will be replaced by scheduled maintenance visits. People will stay for a couple of hours rather than 21 days, with a safe suppliervessel waiting. Combined with the increased use of robotics and visual inspection using drones, costs can be further decreased whilst at the same time, availability increased, and environmental aspects can be much better served. It sounds like progress. Finally. • Twister B.V. +31 (0) 70 303 0006

Twister Tubes in Shell Nigeria Module.

office@twisterbv.com

HEALTH, SAFETY & ENVIRONMENT

Carbon Capture Explained OGI sits down with Gas Liquids Engineering (GLE) to find out more about their work in the area of CO2 processing and sequestration, or CCS (Carbon Capture and Sequestration). Carbon capture is becoming increasingly necessary for large energy projects due to changing public perception of such projects, so we turn to these experts to learn more about implementation of these measures in a cost effective way.

OGI: Could you start by explaining Gas Liquids Engineering Ltd’s credentials and experience in terms of your products and services for the oil and gas sector? Could you tell our readers the breadth of your experience, how long the company has been active, and its reach? GLE: GLE began in 1987 as a small engineering firm that specialized in gas processing. The company founders were two of the industry leading engineers in the design of amine sweetening and refrigeration systems, and the company went on to design numerous gas processing plants throughout the 1990’s. Many of these facilities required CO2 and H2S to be removed from the gas stream, and GLE was one of the pioneers of sequestering these gases into underground formations. We have now carried

Enhance Energy Clive CO2 Pipelines.

out major gas processing, liquids processing, and geological sequestration engineering in over 25 countries, and designed some of the largest CO2 sequestration facilities in Canada. This year, we will also be an exhibitor at the Carbon Capture Technology Expo in Bremen, North Germany.

environmentally conscious financing availability, the desire to gain social acceptance for major energy projects, and increasing global climate concerns with international political factors have coalesced to generate a renewed interest in carbon capture opportunities throughout the world.

OGI: What is the main aim of carbon capture?

OGI: How does CO2 processing and sequestration (CCS) work?

GLE: From a technical perspective the main approach to carbon capture is to prevent CO2 from being released into the atmosphere, by capturing it and physically sequestering the CO2 into an underground formation, or chemically sequestering the CO2 by utilizing it in products or materials, such as cement. In various countries over the last 12 months, a combination of CO2 credit and

GLE: There are currently many different technologies competing to be at the forefront of CCS, and also Carbon Capture Utilization and Storage (CCUS). Most of these processes are still at the pilot stage, and it will be some time before we see if they can compete with the state-of-the-art. The most commonly used process for removing CO2 from gas streams

Wolf Midstream CO2 Compressor Station.

has historically been amine based systems, which have been used for this purpose since the 1930’s. Amine is a chemical absorbant which is trickled through a tower and intimately contacted with the gas containing the CO2, reacting with it and absorbing it. The amine must then be heated to release the CO2, so it can be compressed and dehydrated. The dehydration step is often necessary because under the right conditions water saturated CO2 forms carbonic acid which is quite corrosive to the compression equipment and piping on the way to the sequestration reservoir. OGI: Could you talk about sustainable business

models and mitigating costs in relation to CCS? GLE: The cost of the equipment to sequester CO2 is quite high, particularly in flue gas applications where the gas pressure is very low. This means the towers used to contact the amine with flue gas will be very large. If the CO2 is not being sequestered as part of an EOR operation, the business model will need to include any available grants, carbon offsets, or credits in the project country. In order to help reduce the cost of these systems, in 2008 GLE developed the most cost effective process for dehydrating CO2, called DexPro. DexPro

was separated into it’s own company several years ago, and the process is now used in major CO2 and EOR operations globally. OGI: Can you talk about the facilities connected to the ACTL? GLE: ACTL stands for “Alberta Carbon Trunkline”, and it is a major CO2 pipeline located in Canada. It transports 5200 tonnes/day of industrially recovered CO2 through a 240 km pipeline to a reservoir for sequestration. The CO2 is collected from a major refinery and fertilizer plant in the region. GLE carried out the two major facilities projects that compressed, dehydrated, and pumped the CO2 as a supercritical fluid into the pipeline. At the other end of the pipeline, we designed the facilities which allowed the CO2 to be sequestered as part of an enhanced oil recovery project. In certain oilfields, CO2 can be injected with the effect of dramatically increasing oil production. A portion of the CO2 comes back out with the oil, however that CO2 is once again collected, compressed, dehydrated, and re-used. The owner companies involved in this project, one of the largest CO2 sequestration projects in the world, are Wolf Midstream, and Enhance Energy Inc. OGI: Thank you for your time. • If you would like to know more about how Gas Liquids Engineering Ltd can help your company and its operations, please contact them at: Gas Liquids Engineering Ltd (GLE) T: +1 (403) 250-2950 E: sales@gasliquids.com

CSV Karr 6-18.

W: https://www.gasliquids.com

HEALTH, SAFETY & ENVIRONMENT

Repsol and Tecnicas Reunidas Will Develop Technologies for Industrial Decarbonization Repsol and Tecnicas Reunidas have reached a strategic agreement to develop new decarbonization technologies while promoting the circular economy. The agreement was signed by Repsol’s Executive Manager of Energy Transition, Sustainability, and Technology, Luis Cabra, and the Executive Chairman of Tecnicas Reunidas, Juan Lladó. In-house technology will be developed to manufacture high added-value products with a low or zero carbon footprint from waste and recycled materials, as well as for the energy optimization of industrial processes.

epsol and Tecnicas Reunidas, the engineering company specialized in the design and execution of projects in the energy sector, have signed an alliance to develop proprietary technology and scale up processes to help transform the industry and advance its decarbonization. Both companies will co-develop technology to produce sustainable biofuels and bio-based polymers from agricultural and agri-food waste. Through this project, Repsol and Tecnicas Reunidas will also promote job creation and wealth generation in rural areas at risk of depopulation. Repsol and Tecnicas Reunidas will also develop a new process for the production of circular materials from used plastics, which will be tested in one of Repsol’s industrial complexes. The energy company already includes a wide variety of 100% circular polyolefins with a lower carbon footprint in its Repsol Reciclex range, with a certified sustainable origin. Another project to be carried out jointly by the two companies involves optimizing the energy efficiency of industrial complexes through the recovery of residual heat. The technology will be implemented first at the A Coruña Industrial Complex, as part of the global efficiency improvement plan that Repsol is already

employing to transform its industrial centers into multi-energy hubs with zero net emissions, with an investment of around €400 million until 2025. Finally, within the framework of this agreement and at an important time for the revitalization of industry, the two companies will make their knowledge, R&D resources, and experience in industrial transformation available to other companies in the sector through consultancy services aimed especially at SMEs, to advance the energy transition throughout the industrial value chain. Technology at the service of the energy transition Repsol and Tecnicas Reunidas share a long history in the energy sector. Both companies are characterized by carrying out their activities in many countries and with a high technological component, to a large extent developed internally thanks to their specific capabilities. The Repsol Technology Lab is a cutting-edge research center where 240 scientists and researchers, experts in different disciplines, implement and test the technologies that Repsol applies in each of its businesses. Its industrial facilities employ advanced analytical capabilities and pilot plants that replicate each of the company’s

industrial processes. For its part, Tecnicas Reunidas’ José Lladó Technology Center, with more than 70 scientists, stands out for its capabilities in equipment design, simulation, process optimization and scaling, and engineering, both basic and detailed. Given the scale of the challenges of decarbonization, Repsol is committed to a multi-technological approach. Tecnicas Reunidas is a strategic ally in this journey. The collaboration of the two companies allows them to complement each other’s capabilities and take advantage of their strengths to catalyze the search for technological solutions aimed at the decarbonization of multiple industrial processes in the energy sector. Repsol, fully committed to leading the energy transition, has established a roadmap for transforming the company over the next few years. In the presentation of its Strategic Plan 2021-2025, Repsol announced intermediate emission reduction targets that were more ambitious than the previous ones, with a reduction in its carbon intensity of 12% in 2025, 25% in 2030, and 50% in 2040. The Strategic Plan contemplates numerous actions to develop its industrial area, of great importance for the creation of employment, competitiveness, and wealth for the country. Thus, it can continue to provide society with the goods it needs, but with a low, zero, or even negative carbon footprint. Repsol is already transforming all its industrial complexes, equipping them with the latest technologies to decarbonize their processes by improving energy efficiency, promoting the circular economy, producing renewable hydrogen, and increasing the capture and use of CO2. For several years Tecnicas Reunidas has been developing a wide range of industrial projects directly related to the energy transition in areas such as waste recycling and other circular economy initiatives, sustainable mobility using hydrogen, bioenergy generation, carbon capture, production of cleaner fuels, etc. •

Aker Solutions Awarded Subsea Gas Compression Contract

ker Solutions has been awarded a major[1] contract from Chevron Australia Pty Ltd to provide a subsea gas compression system for the Jansz-Io field, offshore Western Australia. The company has booked around NOK 7 billion as order intake in the second quarter of 2021 related to this contract. “Globally, this is the second subsea gas compression system delivered by Aker Solutions and demonstrates our pioneering spirit to create value for our customers. Our world-leading technology improves field recoverability while offering carbon emission efficiencies compared to traditional compression alternatives,” said Kjetel Digre, chief executive officer of Aker Solutions. The scope covers engineering, procurement and construction (EPC) of the all-electric subsea gas compression system. It also includes interface responsibility, and assistance during installation and commissioning. The subsea gas compression system will include a complete compression station with three compressor modules and two subsea pump modules, all-electric control systems and actuators, structures including mud mats, high-voltage electrical power distribution system, several spare modules and equipment and various associated tooling. “We are extremely pleased to be chosen for this major contract. This award signifies a huge leap for our world-leading subsea gas compression technology. Aker Solutions has been present in Western Australia for more than 20 years. We look very much forward to working collaboratively with partners such as MAN Energy Solutions on this major development. This award confirms our leading position within subsea technology and system integration globally,” said Digre.

The award follows completion of the front-end engineering and design (FEED) awarded in 2019. The work starts immediately with delivery expected during 2025. The project will be managed from Aker Solutions’ headquarters in Fornebu, Norway. Client interface and operational planning will be handled from Perth, Australia. •

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HEALTH, SAFETY & ENVIRONMENT

Worker Safety Solutions Around the World OGI sits down with Globus Group, based out of the UK to learn more about the work they do in the oil and gas sector, relating to health and safety work wear and personal protection equipment (PPE). Globus Group produces a range of different PPE related safety work wear, from gloves, to eye wear, helmets and more. Globus Group has actually evolved into the biggest British-based PPE manufacturer and one of the biggest UK employers in the sector, so their advice is valued and we learn more below.

OGI: Could you start by explaining Globus Group’s credentials and experience in terms of your products and services for the oil and gas sector? Globus: Globus Group has been active within the oil and gas sector for over twenty years. Starting out with North Sea operations in Aberdeen where we were asked for help by a number of major producers and service companies to develop solution-based products that were designed to offer improved protection, comfort and fit. On the back of this success, we subsequently managed to build the business globally across various territories including the Middle East, Africa, and the USA. Since launching in these jurisdictions, we were able to introduce new ranges and now regularly exhibit to various oil and gas sector exhibitions across the globe. OGI: What innovative protection product solutions do you offer for the oil and gas industries? Globus: Globus Group offer a wide range of market-leading PPE products which incorporate numerous technologies that enhance safety, functionality and wearer comfort when dealing with hazards from heat and flame, contact with

harmful substances and exposure to hydrocarbon releases. Our safety solutions incorporate respiratory protection, hand protection, safety eyewear, head protection, hearing protection and clothing. Leading brands within our range includes Showa and Skytec gloves, Riley safety eyewear, Alpha Solway respirators, chemical clothing and hearing protection, plus ENHA head protection. Our ENHA Radius range, comprises of an

array of lightweight hard hats perfect for the offshore sector when working at height and to protect against falling objects. Exceeding the demands of EN 397, the range includes features such as the patented Crashbox impact absorption technology. We manufacture a variety of flexible hand protection for oily, and greasy handling conditions. Specialist technology ensures a firm grip and resistance to abrasion. Our new Skytec Torq impact glove range includes products such as our Skytec Torq Twister helps reduce hand fatigue and protects against impact with its moulded TPR protection zones across the knuckle whilst also offering high levels of cut protection and grip. For safety eyewear, the Riley Stream Evo incorporates LED lens technology, which is designed to improve contrast and reduce stress to the eye, impacting positively on performance and productivity. OGI: Could you tell our readers the breadth of your experience? Globus: The acceleration of the business’s output in the last year has seen Globus Group evolve into being the biggest British-based PPE manufacturer and one of the biggest UK employers in the sector. We continue to grow our international footprint across multiple markets.

Riley® offers a sophisticated range of high performing safety eyewear.

Our distinctive core value is the innovative approach we take to improving safety for

sectors of all sizes. At Globus, we believe in the safety, reliability and wearability of our products. We are proud to protect customers in their working lives, equipping them to perform their roles safely and empowering them to do the best job possible. As well as providing safety products that our customers trust, our collaborative approach sets us apart. We believe in building lifetime relationships with our customers and being there to respond to their changing requirements. OGI: What are some of the features or characteristics of head protection that employers should be looking out for when choosing hard hats for their workers? Globus: Employers should look for hard hats that protect their workers from falling objects that meet the EN 397 standard. Manufactured with precision in Germany, our ENHA brand develops head protection with the customer at the crux of the design process. With a heritage of over 30 years, our range incorporates patented, award winning technology, providing superior performance and safety for the wearer. We are renowned for producing high-quality PPE portfolio for a variety of industries including the oil and gas sector. Our Radius™ range is engineered as one of the lightest yet most effective industrial safety helmets on the market. Radius™ ensures exceptionally low force transfer to the head, easy connectivity of additional PPE, stable fit in challenging working conditions, complete with a stylish aesthetic. Exceeding the demands of EN 397, Radius incorporates patented Crashbox impact absorption technology, safeguarding the wearer against possible consequences such as brain injuries or skull fractures. We also incorporate virgin granulate into our helmets which provides better UV stability. The Radius helmets also feature innovative, streamlined accessories, including visors, visor carriers, hearing protection and chin straps, to enhance wearer safety.

OGI: How are you helping hospitals and the NHS? Globus: When the Covid crisis struck, our heritage and expertise in PPE meant we were in a stronger position to help than many other businesses who were attempting to do something new. We went through the process set out by the government which was comprehensive and efficient. By commissioning three new sites in the UK, we’re proud to be doing our bit to help NHS frontline staff fighting Covid-19 across Scotland and England do their jobs safely. We are currently producing over 1 billion surgical face masks, 500 million FFP2 and FFP3 respirators and 30 million visors annually. The need for masks to be UK manufactured is well established now within the thinking of healthcare organisations and Government. They recognise the huge value of UK-made products. That’s a fundamental change, and the importance of creating reliability and resilience in manufacturing is now measured with appropriate weight. That’s given us huge confidence to invest for the long-term future and in UK production. OGI: What are some of the steps Globus Group is taking to boost opportunities for women in the sector? Globus: Globus Group is boosting career opportunities for hundreds of women with an increased focus on specialised recruitment initiatives. Our ongoing recruitment drive will see more than 1,000 employees enter the company by the end of 2021. The goal is for half of the new recruits to be women. Manufacturing has remained a maledominated industry and is often perceived to be a challenging work environment for women. However, opportunities in manufacturing are growing and we look to encourage more women into the industry with broader local apprenticeship and training initiatives. We’re developing and furthering our apprenticeship schemes here at Globus Group at an unprecedented rate whilst we’re going through the latest recruitment drive. For the first time, we’re opening up more specific opportunities for women to join the sector.

Sky Toro Gloves.

Designed to continually educate and inform workers about the range of hand hazards onsite backed up through training, support and developing hand protection solutions delivered by the team at Globus, this integrated approach saw a significant reduction in hand and arm injuries onsite As a result, the 300 glove wearers on RWG sites now use a range of Globus gloves including: •

For mechanical engineering work – Skytec Trigata and Skytec Aria 360

•

For manual handling and outdoor work – Skytec Aria 360, Skytec Argon and Skytec Ninja Knight

•

For chemical work - SHOWA 720, SKYTEC Teal and IRIS

The team at Globus has also been integral in helping RWG deliver Handsafe, supporting the company in a number of ways including: •

Organising glove trials across all RWG sites to ensure the right gloves for all tasks were selected

•

Providing onsite training to introduce selected gloves for the tasks carried out

•

Creation of posters providing performance information of the selected gloves

OGI: Finally, could you enlighten our readers of a case study where you helped a client with your solutions?

•

Creation of a glove sizing poster guide

•

Creation of a hand protection glove roll holding all selected gloves used onsite

Globus: RWG is a world leading oil and gas turbine, repair and overhaul specialist which provides services for industrial aeroderivative gas generators and power turbines used in the power generation, oil and gas and marine propulsion industries globally.

•

Regular updating of the glove roll solutions in line with developing glove technologies

•

Attending many Handsafe meetings to provide ongoing support and advice

Having identified hand hazards as a significant safety risk to around 300 of its workers as a result of the manual engineering tasks undertaken, RWG launched its Handsafe campaign in partnership with Globus Group.

Globus Group

OGI: Thank you for your time. • T: +44 (0)161 877 4747 E: sales@globus.co.uk W: www.globusgroup.com

NEWS - HSE Automatic Extinguishing Solutions

ith a growing awareness towards the environment and resources, the amount of recycling and incineration facilities worldwide has increased significantly. The risk of fires in these industries is a rising concern. Solutions to extinguish these fires in the early stages of development is imperative, especially considering that the materials being processed are unpredictable. There is certainly no simple answer to this challenge, but it is an issue that needs addressing. In this article, suitable fire protection systems are discussed, with a focus on automatic extinguishing solutions utilizing heat detection and remote-controlled fire monitors.

capability. Each sprinkler head is designed to protect an area of several square meters. Large areas are exposed to the extinguishing water when several sprinkler heads are activated, and the system usually must be manually deactivated. Depending on the distance between the fire and the sprinkler heads, they may be triggered too late to successfully extinguish the fire. They are mainly used in areas with low ceilings.

Over the last few years, the trend towards recycling materials has grown in many parts of the world. This has led to the division of organic wastes and recyclables and the installation of waste management companies operating incineration plants, composting plants, and recycling facilities instead of landfills. Vast amounts of materials are now temporarily stored. The fire hazards associated with this are growing as relatively dry materials with high energy contents are stored together with potential ignition sources such as Lithium-Ion batteries, household aerosol bottles, paint cans, and propane tanks. In composting facilities, decomposition can lead to temperatures high enough to cause autoignition of the stored material. These types of fire can be difficult to detect and often demand great effort to extinguish when detected too late. This can have serious effects on the environment and public health and jeopardize the safety of firefighters and local communities.

DELUGE SYSTEMS

POTENTIAL FOR FIRE HAZARDS •

Recycling facilities are generally set up in three sections.

•

Delivery and primary storage area of unsorted recycling goods (tipping floor)

•

Sorting and separation facility

•

Storage of separated goods such as plastic, paper, metal, glass, and compost

This article will focus on the first section of delivery and primary storage, the tipping floor. Here the complete variety of mixed waste, as it comes from our households, is tipped from collection trucks onto concrete floors or into waste bunkers. In this conglomerate of waste, both ignition sources and combustible materials are present. Damaged batteries that have developed heat are exposed to oxygen and sparks can ignite gases and vapors leaked from household aerosol bottles, paint cans, and propane tanks or formed due to decomposition of waste. Before being transported into the recycling facility via conveyor belts, workers or machines sort out as much problematic garbage as possible. Unfortunately, these components often end up inside the facilities where they may ignite and start a fire. Fortunately, most of the waste is in constant movement. Hot-spots or a fire can be monitored and quickly dealt with if the proper detection and extinguishing equipment is installed. In incineration plants, the untreated waste is often delivered and burnt without any separation, apart from the removal of metal. The material is stored in bunkers, partially several meters high, where it may be stored for longer durations of time before being transferred to the incinerator. Here a fire may smolder below the surface without being detected and break out over a wider area. FIRE PROTECTION SYSTEMS The main extinguishing systems used in recycling and incineration plants are sprinkler or deluge systems and firefighting monitors. Dependent on the goods that must be extinguished, water or foam can be used as an extinguishing agent. SPRINKLER SYSTEMS Sprinkler systems are mainly used indoors and are generally waterfilled. A fire’s heat will activate individual sprinkler heads that will release extinguishing water onto the area below it. If the fire spreads, additional sprinkler heads are activated to extend the extinguishing

Sprinkler systems can alternatively be filled with a foam premix that generates extinguishing foam once released. The premix is made using specially designed proportioning systems, such as the GEN III water motor-driven proportioning pumps made by FireDos. Deluge systems are sprinkler systems with open nozzles. They can be manually operated or may be equipped with remote-controlled valves that are triggered by heat detections systems. On activation extinguishing will occur in the complete section of a larger area. FIREFIGHTING MONITORS Firefighting monitors, like the distinctive octagonal ‘Oval Flat Design’ from FireDos, are designed for indoor or outdoor use. When a fire is detected, they are either manually operated or can be remotely controlled. Fire monitors allow precise positioning of fire extinguishing media from a safe distance. Dependent on the fire extinguishing system setup, it is possible to switch between water and foam. Firefighting monitors are optimally suited to be combined with detection systems to form an automatic fire extinguishing system. SMOKE DETECTION Smoke detectors are mainly installed under the ceiling to monitor complete halls or sections of a big area. They generally require a large amount of smoke to trigger an alarm. They are mainly used together with manual firefighting equipment utilizing hoses or firefighting monitors as the exact location of a fire must be visually confirmed. They are not well suited as components for modern automatic firefighting solutions. Another possibility for smoke detection is the use of video smoke detection. It is recommended to use these systems only if combined with another type of detection to avoid false alarms triggered by steam, exhaust fumes or fog. These systems also require ideal lighting conditions and only work in areas with low levels of dust. FIRE DETECTION Sprinkler systems are classic fire detectors. They are not suited as components for modern automatic firefighting solutions. Linear heat or fire detectors are sensor cables. They are mainly used to monitor tunnels or garages but may also be installed in big halls. They are generally not suited for use in incineration plants and recycling facilities but may be a suitable option for monitoring covered conveyor belts. HEAT DETECTION Most common heat detection is achieved through thermal imaging by using infrared (IR) detection technology. In contrast to detecting smoke or a fire, the environment is monitored for radiated heat. By continuously monitoring a specific point or area and measuring the actual radiated heat, or analyzing the increase in temperature, fires can be detected, even if they have not yet reached the surface of a pile. The rise of hot gases may be sufficient to detect a sub-surface fire. Usually, temperatures of 80°C are considered strong indicators of a fire. Heat monitoring of an object with an infrared early fire-detection system means a fire is identified in its formation phase. For fire detection, continuous monitoring of the hazardous area is mandatory to detect any changes in the environment. Intentional and known heat sources such as motors from belt drives or vehicles, exhaust pipes, sun and reflections should be automatically identified and ruled out as potential fires to reduce false alarms to a minimum. •

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OE21 Offers Unique Opportunity for the Energy Transition as It Straddles COP26 It’s been two years since tens of thousands of visitors last stepped through the doors of SPE Offshore Europe at the P&J Live in Aberdeen. This year, a worldwide audience will be able to access the opening ceremony, plenary panel and keynote and technical sessions with the first ever virtual conference taking place from 7-10 September 2021, before a live event from 1-4 February 2022. It’s the first time the biennial event has been split in two, with the advantage that it will bookend the UN Climate Change Conference (COP-26) taking place in Glasgow in November 2021. This will enable the industry to reconvene again in February 2022 to advance the energy transition agenda and realign strategies. The SPE Offshore Europe theme - ‘Oil & Gas: Working Together for a Net Zero Future’ - is therefore even more resonant as it reinforces the importance of collaboration and consolidating climate change efforts through innovation, regulation and cooperation.

espite continued uncertainty and caution, the tragic and turbulent impact of the coronavirus has shown society and the energy sector what the world could look like with lower carbon emissions. Innovative and analytical thinking continues apace across the entire energy ecosystem with more than 40 technical presentations covering 14 topical issues including decarbonisation, floating wind, hydrogen and the need for an integrated North Sea, being shared during SPE Offshore Europe’s virtual conference. Sharing solutions for sustainable operations Cutting carbon output is widely acknowledged as fundamental to achieving net zero targets. But, for the oil and gas sector, it is also a pathway to maintaining a social licence to operate. While innovative solutions are contributing to lower emissions, these need to be commercially viable to attract sustained investment. The dedicated technical session on decarbonisation will explore solutions that are being developed to reduce operating emissions at offshore installations and explore options to reduce the risks associated with financing novel technologies. This ties in with one of the keynote panel

discussions to be co-chaired by DNV, the independent energy expert and assurance provider and the International Association of Oil & Gas Producers (IOGP). It will debate if the industry’s actions on its route to net zero can realistically be achieved. Here, global thought leaders from government, industry organisations, as well as operators and supply chain companies, will discuss the key elements of their road maps towards an impactful energy transition. A major part of the drive to decarbonise incorporates offshore wind technologies, in both its fixed and floating forms, as well as the development of a hydrogen economy. The issues and challenges will be covered in depth by a range of speakers sharing details of activities and experiences from around the world. While both on and offshore wind has been widely embraced and upscaled to support more sustainable operations, the move from fixed to floating turbines, however, will draw more on the knowledge and skills of those in the oil and gas sector to harness greater capacity in deeper and more hazardous waters. This area of technical development will be explored across several presentations and chaired by the British Geological Survey and Worley. Hydrogen is fast becoming a focus for major new projects supporting the energy transition. Whilst few projects are operational, a great many are in the identification and concept select phase. With a steep learning curve in this area, this session will share examples of activity in

the UK sector, both on- and offshore, to showcase the new industry, explore the commercial case as a route to market, and the technologies and know-how required to rapidly grow this burgeoning sector. With its roots in Aberdeen, Europe’s oil and gas capital, virtual visitors will learn more about the developments, solutions and projects taking place in and around the North Sea basin. Together, the newly named NZTC (Net Zero Technology Centre), formerly OGTC, and Subsea Technologies Ltd, will chair a session looking at the importance of an integrated North Sea if the UK’s commitment to the Paris Agreement is to be achieved. Attendees will be given an insight into the challenges and opportunities that lie ahead and how the industry must seize the opportunity to develop and deploy technologies and projects that will help the world move to a net zero energy future. Other topics on the digital itinerary of the virtual conference include smarter and more efficient field development, remote operations and unmanned installations, decommissioning, future operations, and reservoir characterisation and modelling. Together again in 2022 A socially distanced exhibition and new energy transition keynote conference content are already being planned for 1-4 February 2022 at the P&J arena in Aberdeen. The show floor will feature an Energy Transition Zone and Theatre, Decommissioning Theatre, a TIDE (talent investment & diversity) programme and numerous networking events. The inherent nature of SPE Offshore Europe, in both its virtual and physical forms, is a platform to learn, adopt and fast-track commitment to investing in and developing cleaner, more sustainable, low-carbon energy production for a brighter, more sustainable, and integrated energy future. •

NEWS - MENA ADNOC and Reliance Sign Strategic Partnership

bu Dhabi National Oil Company (ADNOC) today announced that Reliance Industries Limited (Reliance), has signed an agreement to join a new world-scale chlor-alkali, ethylene dichloride and polyvinyl chloride (PVC) production facility at TA’ZIZ in Ruwais, Abu Dhabi. The agreement capitalizes on growing demand for these critical industrial raw materials and leverages the strengths of ADNOC and Reliance as global industrial and energy leaders. The project will be constructed in the TA’ZIZ Industrial Chemicals Zone, which is a joint venture between ADNOC and ADQ, and represents the first investment by Reliance in the region. The agreement continues the momentum of ADNOC’s downstream and industry growth plans in line with ADNOC’s 2030 strategy. Petrochemical, refining and gas growth projects are currently under construction, with a number of projects also recently completed across the downstream and industry portfolio. ADNOC is gearing up for growth with TA’ZIZ, the world-scale chemicals production hub and industrial ecosystem based in Ruwais, with investment in excess of AED 18 billion and a number of further growth projects in the downstream and industry sector. Since 2018, ADNOC has attracted significant foreign direct investment from international partners in the downstream business including refining, fertilizers and gas pipelines. Under the terms of the agreement, TA’ZIZ and Reliance will construct an integrated plant, with capacity to produce 940 thousand tons of chlor-alkali, 1.1 million tons of ethylene dichloride and 360 thousand tons of PVC annually. The agreement is subject to relevant regulatory approvals. His Excellency Dr. Sultan Ahmed Al Jaber, UAE Minister of Industry and Advanced Technology and ADNOC Managing Director and Group CEO, said: “We are delighted to attract an investor of Reliance’s caliber to partner with ADNOC and ADQ in accelerating growth at TA’ZIZ. This agreement is a significant milestone, as we continue to grow a globally competitive industrial ecosystem and highly attractive investor value proposition. In line with our 2030 strategy, we look forward to creating further opportunities across the entire TA’ZIZ ecosystem for the next generation of local industry. The domestic production of critical industrial raw materials strengthens our supply chains, drives In-Country Value and accelerates the UAE’s economic diversification.” Welcoming this initiative, Reliance Industries Chairman and Managing Director, Mr. Mukesh D. Ambani, said: “We at Reliance are excited to enter into a strategic partnership with ADNOC for establishing a world-class and world-scale chemicals project at TA’ZIZ in Ruwais. This important milestone further bolsters our long-standing relationship with ADNOC, reaffirming our faith in the global vision of the UAE’s wise leadership. It is also yet another testimony to the enormous potential in advancing India-UAE cooperation in value enhancement in the energy and petrochemicals sectors. The project will manufacture ethylene dichloride, a key building block for production of PVC in India. This is a significant step in globalizing Reliance’s operations, and we are proud to partner with ADNOC in this important project for the region.” Chlor-alkali is used in water treatment and in the manufacture of textiles and metals. Ethylene dichloride is typically used to produce PVC. PVC has a wide range of applications across housing, infrastructure and consumer goods. The market for these chemicals is expected to enjoy steady growth supported by the needs of growing demand, particularly in Asia and Africa. Production of these chemicals will create opportunities for local industry to source critical raw materials in the UAE for the first time, creating additional opportunities for In-County Value. For example, chlor-alkali will enable production of caustic soda, essential for the production of aluminum. Ethylene dichloride and PVC have a wide range of applications across housing, infrastructure and consumer goods.

Since its launch in November 2020, TA’ZIZ has made significant progress. Development activities at the site have moved forward, with land and marine surveys already completed. Considerable interest has been received from local and international investors in opportunities across the entire ecosystem and value chain, and agreements with the first phase of investors are nearing finalization. Contracts have been awarded for the first stages of development of the TA’ZIZ site, and work is already underway. This includes geotechnical and topographical surveys, a marine bathymetric survey and health, safety, and environment impact assessments, which have already been completed. The surveys will enable civil engineering works to commence, preparing the TA’ZIZ site for construction as well as dredging for an entirely new port facility. Tenders for the initial design of the seven TA’ZIZ chemicals derivatives projects have been awarded and work is ongoing. Final investment decisions for the projects and awards of related EPC contracts are being targeted for 2022. •

IOCL Awards McDermott Two EPCC Refinery Contracts

cDermott International, Ltd today announced it has received two separate engineering, procurement, construction and commissioning (EPCC) contract awards from Indian Oil Corporation Limited (IOCL) for the Haldia Refinery and the Barauni Refinery. The first award is an EPCC contract for a new diesel hydrotreating unit and associated facilities for the Barauni Refinery Expansion Project in Bihar, India. The second award is an EPCC contract for the catalytic dewaxing unit and associated facilities at the Haldia Refinery in West Bengal, India. The catalytic dewaxing unit will help produce base oil which can be utilized in finished lubricants. India is the world’s third-largest user of finished lubricants but is also, with a deficit of base oil, one of the world’s largest importers of base oil. Both projects contribute to greater independence for India’s domestic energy needs. “These awards demonstrate our commitment to advancing India’s long-term energy market,” said Samik Mukherjee, Executive Vice President and Chief Operating Officer. “We look forward to working with Indian Oil Corporation Limited on these prestigious downstream projects, showcasing our dedication to world-class project execution and sharing our leading health and safety protocols.” In line with India’s Make in India initiative, McDermott’s Senior Vice President, Asia Pacific, Mahesh Swaminathan, emphasized the strength of the local team. “Our 2,000 personnel in India bring global experience with high levels of technical and project management expertise,” said Swaminathan. “These individuals continue to demonstrate the strength of McDermott’s vertically-integrated solutions and the positive impact these bring to the Indian downstream market.” The scope of work across the projects includes project management, residual process design, detailed engineering, fabrication, procurement, construction, transportation, mechanical completion and commissioning. Work will commence in quarter two 2021. Both projects will largely be executed by the McDermott team in Gurgaon, India, with some support from Perth, Australia and Brno, Czech Republic. •

NEWS

NEWS Amazon Filters Launches Contour Gas to Block Pipeline Drills ‘Black Duster Powder’near Johan Sverdrup Field Equinor

U T

K manufacturer Amazon Filters is targeting the global gas industry with its latest company innovationdrilled in meltblown depth filter he Norwegian the well around one cartridges. kilometer west of the Johan Sverdrup oil field and 200 kilometers west of Stavanger. Contour Gas is designed to stop black powder, a common form of contamination accumulates in pipework, reaching downstream According to thethat Norwegian Petroleum Directorate, the objective of the equipment and instrumentation. well was to prove petroleum, as well as to investigate potential reservoir rocks several levels: composed Upper Jurassic Draupne formation Black in powder is mainly of fine(intra but hard particles of iron sandstones), Upper Triassic (Skagerrak Upper down Permian (the oxide (Fe2O3) and iron sulfide (FeS) information), sizes from 100µm to subZechstein group) and weathered/fractured basement rock. micron level. The well was drilled about 110and meters intoinbasement of which Typically caused by corrosion erosion upstreamrock, pipework, the 77 metersareofswept weathered fractured rock with poor to particles along atand high speed inbasement the gas flow. moderate reservoir properties. In the upper part of the basement, the Accumulations can harm downstream equipment, risking costly well encountered traces of oil in a zone of about 19 meters. At this time, downtime and endangering production safety. it is impossible to determine whether the oil is producible or simply Ideal for high-flow, large-diameter applications, Contour cartridges residual. No sedimentary rocks were encountered inGas other levels. are made in a tightly controlled manufacturing process supported by Pending new information and interpretation of collected data, the environmental quality systems. preliminary classification is that the well is dry. It involves high-strength fibres beingbut blown continuously a central The well was not formation-tested, extensive volumesonto of data have mandrel, building into a one-piece, core-free construction resistant to been acquired and samples have been taken. It will now be permanently unloading and media shedding. plugged and abandoned. The well has yielded important information about the potential fortested reservoir properties the basement of rock, as well Efficiency has been in line with theinrequirements major oil as pressure communication in the area. and gas companies using specific challenge levels appropriate to reallife Thisinstallations. is the second exploration well in production license 502, which was in APA Filters’ 2008. Water depthDirector, at the site 105 meters. Karlawarded Pizzey, Amazon Operations said:is“Contour Gas The well was drilled a verticalfiltration depth ofof1988 meters belowinthe sea provides reliable and to consistent the dirt particles gases, surface, was terminated the from basement rock. The well drilled with theand flexibility to captureinsizes 0.3µm to 100µm andwas above. by Transocean Spitsbergen drilling rig,density which will now proceed to “Itthe is available in fine and coarse-graded structures to match the shipyard before welltheoperations up on the field in the process requirements, degree ofstart distribution of Snorre the black powder, northern of the North Sea. and • and the part subsurface elements compounds that are causing the contamination.

“We have engineered Contour Gas as a high-volume filtration solution for offshore natural gas pipelines, other gas-carrying transmission lines, supply tanks and gas processing plants - all essential areas where long service life and ease and speed of change-out is crucial. “Contour Gas offers wide chemical compatibility with a choice of 100% polypropylene and nylon versions, double open-ended formats and two standard element sizes, 508mm (20”) and 1013mm (40”).

“Its flexibility means it can be used forof new installations or as a direct TechnipFMC Picks President New Ventures

retrofit for either core or coreless filters on existing housing designs affected by black powder.”

For ilfield more information, visit Combating Black Powder Accumulation in services company TechnipFMC has appointed a new Natural Gas Transmission Lines (amazonfilters.com). • president of new ventures.

TechnipFMC said on Monday that Catherine MacGregor joined its executive leadership team as the new president of new ventures. Doug Pferdehirt, TechnipFMC chief executive officer, said: “In our rapidly changing and extremely competitive environment, the ability to expand our possibilities and to develop our business in new directions is a critical asset for TechnipFMC’s future. “This is why we have decided to create New Ventures – to explore opportunities to expand our portfolio through innovative models and new business lines. Catherine will be in charge of defining and implementing this new, promising approach.” MacGregor previously spent 23 years with Schlumberger in a succession of leadership positions involving global operational activities. These included being president of Drilling Group, president of the Characterization Group, area president for Europe and Africa, president of Wireline and VP of human resources. •

NEWS - MENA Schlumberger and IBM Announce Data Management Solution

irst hybrid cloud solution for the OSDU™ Data Platform— the industry standard for energy data—is ready for customer deployment Schlumberger and IBM announced today the industry’s first commercial hybrid cloud Enterprise Data Management Solution for the OSDU Data Platform. The hybrid cloud offering is designed to expand access to customers globally—including those in locations where data residency requirements and local regulations may affect the use of global public cloud—and is engineered to reduce time for analysis and accelerate decision-making, with all workflow data available in one place. This solution will provide energy operators with full interoperability, making their data accessible by any application within their exploration to production (E&P) environment through the OSDU common data standard to enable easy sharing of information between teams. This data solution is engineered to minimize the time for data transfers between applications to deliver reduced costs as well as enabling improved decision making. “As momentum grows for the OSDU Data Platform, we are offering the industry’s first commercial hybrid cloud Enterprise Data Management Solution to leverage its advanced capabilities to help customers in all regions make faster decisions and optimize operational efficiency,” said Rajeev Sonthalia, president Digital & Integration, Schlumberger. “Our solution was developed to accelerate digitalization for all by enabling data to be connected and managed at an unprecedented scale, empowering AI and data analytics workflows that deliver new insights for operators to help drive increased production, cost optimization, and improved business performance.” “This collaboration is a game changer for energy operators to drive higher performance and greater efficiencies by now enabling integrated workflows and innovation using AI. The hybrid cloud solution allows clients to maintain the sovereignty of their data and also gives them options as to how they choose to leverage the solution, with the freedom to deploy on a range of infrastructures or a regional cloud provider,” said Manish Chawla, global industry managing director, energy, resources and manufacturing, IBM. “Open Data for Industries on Cloud Pak for Data is one of the key technologies which enables the OSDU solution deployment for Schlumberger.” The collaboration builds on the work between Schlumberger and IBM to leverage the Red Hat OpenShift Container Platform for deployment of the DELFI* cognitive E&P environment in all regions, worldwide. The solution will be offered by Schlumberger; all transition and managed services will be provided by Schlumberger and IBM Services. Schlumberger is an IBM ecosystem partner, and since the initial announcement the two companies have made significant advancements to engage customers in focus regions around the world, including the Middle East. •

Qatar Petroleum enters into three offshore exploration blocks in South Africa with TotalEnergies Qatar Petroleum entered into agreements with TotalEnergies to acquire working interests in three offshore exploration blocks in South Africa. Under the terms of the agreements, which are subject to customary approvals by the government of South Africa, Qatar Petroleum will hold a 25% participating interest in the South Outeniqua block, a 30% participating interest in the DWOB block, and a 29.17% participating interest in the OBD block. Commenting on this occasion, His Excellency Mr. Saad Sherida AlKaabi, the Minister of State for Energy Affairs, the President and CEO of Qatar Petroleum, said, “These acquisitions represent an excellent addition to our South African regional upstream portfolio, and build upon the positive progress following the recent drilling success in the 11B/12B block.” His Excellency Minister Al-Kaabi added, “We are delighted to have the opportunity to work with our strategic partner TotalEnergies to explore these promising and prospective blocks, and to further develop our relationship with the South African Government and other joint venture partners, whilst also pushing forward with Qatar Petroleum’s ambitious growth strategy. I would like to take this opportunity to thank the South African authorities and partners for their valuable support and cooperation.” The South Outeniqua block covers an area of approximately 49,000 square kilometers in water depths ranging between 200 and 5,000 meters. TotalEnergies is the Operator and holds the remaining participating interest in the block. It is located directly south of the 11B/12B block where TotalEnergies, Qatar Petroleum, Canadian Natural Resources Limited and Main Street Limited have announced significant gas condensate discoveries in the Brulpadda and Luiperd prospects. •

McDermott Names Samik Mukherjee Executive Vice President and Chief Operating Officer

cDermott International, Ltd today announced Samik Mukherjee has been appointed Executive Vice President and Chief Operating Officer. In this position, Mukherjee will continue to advance the company’s long-term strategy through solid alignment of its service offerings to meet evolving customer needs. Mukherjee previously led the company’s global operations and project delivery functions as Group Senior Vice President, Projects. “Samik has repeatedly delivered some of the world’s most challenging infrastructure projects with a relentless focus on quality, safety and efficiency,” said Lee McIntire, Interim Chief Executive Officer of McDermott. “I—and the Board—have the upmost confidence that his leadership and experience will continue to deliver strategic value to our customers.” Mukherjee brings nearly three decades of experience in operations, commercial and strategy across the global upstream and downstream oil and gas industry. Prior to joining McDermott in 2018, he was Executive Vice President of Corporate Development, Strategy, Mergers and Acquisitions, Digital and IT for another engineering, consulting and construction company. His career includes leadership positions in Europe, the Middle East, the Netherlands, Africa, India and France across the energy value chain, both onshore and offshore. Mukherjee holds a master’s degree in business administration from the Rotterdam School of Management at Erasmus University in the Netherlands and a bachelor’s degree in chemical engineering from the Indian Institute of Technology Kanpur and has completed the Harvard Business School Executive Program on Aligning and Executing Strategy. •

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NEWS - MENA New Ultra-Compact Flowmeter for Utilities and Industrial Automation

ROHNE introduces the AF-E 400 ultra-compact electromagnetic flowmeter for utilities and industrial automation applications. It is specially designed to fit in applications with little installation space available, e.g. in cooling lines of welding equipment, bending machines and robots, or on chemical dosing skids. AF-E 400 matches the requirements of application areas in heating and cooling/temperature control, machine building of washing or dosing equipment, HVAC, and utilities and industrial automation applications in all process industries. KROHNE has examined issues with products in this segment and developed the cost-effective ultra-compact flowmeter to be best in its class in terms of temperature range, accuracy, pressure drop and flow range: AF-E 400 features a stainless steel housing and is suitable for continuous use at +90°C/ +194°F liquid temperature, allowing for operation in very demanding cooling and hot water applications. The round bore reduction of the sensor makes the flowmeter more resilient in terms of increased pressure, ensuring high accuracy over a wide pressure and temperature range, and a high turndown ratio without risk of cavitation. The integrated temperature measurement eliminates the need for an additional sensor, minimising the intrusion points in the pipe and providing more data from the process. AF-E 400 also features extensive self-diagnostics: the meter continuously monitors several critical aspects including low supply voltage, incorrect parametrisation, flow range exceedance, or short circuit on any of its outputs. Warning messages according to NAMUR NE107 alert the user via the rotatable full colour display or the communication outputs. Due to the special design of its magnetic circuit, field strength and electronics, AF-E 400 is immune to crosstalk caused by magnetic field overlap of adjacent devices, and can be installed in series or in parallel up to a distance of 2 mm/ 0.08” from device to device without interference. Nominal sensor sizes reach from DN6...25/ ¼...1¨ for flow rates up to 150 l/min/ 40 US gpm as standard, up to 500 l/min/ 132 US gpm on request. Output options include 4...20 mA, pulse, frequency, switch, IO–link or Modbus to provide operators with multiple sensor and application data for smarter factory automation. AF-E 400 is sold from stock and shipped within 48 hours. •

Aramco Closes $12.4 Billion Infrastructure Deal

ramco and an international investor consortium, including EIG and Mubadala, today announced the successful closing of the share sale and purchase agreement, in which the consortium has acquired a 49% stake in Aramco Oil Pipelines Company, a subsidiary of Aramco, for $12.4 billion. The consortium consists of a broad cross-section of investors from North America, Asia and the Middle East. This long-term investment by the consortium underscores the compelling investment opportunity presented by Aramco’s globally-significant pipeline assets, the Company’s robust long-term outlook and the attractiveness of the Kingdom of Saudi Arabia to institutional investors. As part of the transaction, first announced in April 2021, Aramco Oil Pipelines Company and Aramco entered into a 25-year lease and leaseback agreement for Aramco’s stabilized crude oil pipelines network. Aramco Oil Pipelines Company will receive a tariff payable by Aramco for stabilized crude oil flows, backed by minimum volume commitments. Aramco continues to hold a 51% majority stake in Aramco Oil Pipelines Company and retains full ownership and operational control of its stabilized crude oil pipeline network. The transaction does not impose any restrictions on Aramco’s actual crude oil production volumes, which are subject to production decisions made by the Kingdom. Aramco President & CEO, Amin H. Nasser, said: “We are pleased to conclude this transaction with the global consortium. The interest we have received from investors shows strong confidence in our operations and the long-term outlook for our business. It is a significant milestone that reflects the value of our assets and paves the way forward for our portfolio optimization strategy. We plan to continue to explore opportunities to capitalize on our industry-leading capabilities and attract the right type of investment to Saudi Arabia.” Abdulaziz M. Al Gudaimi, Aramco Senior Vice President of Corporate Development, said: “The interest we received for this deal is evidence of continued confidence in our Company from institutional investors and sets a new benchmark for infrastructure transactions globally. This transaction utilizes our world-class pipeline infrastructure to create additional value for our shareholders, reinforcing our Company’s resilience and ability to adapt in a rapidly changing business environment.” R. Blair Thomas, EIG’s Chairman & CEO, said: “We believe this is the marquee infrastructure transaction globally and we are pleased to see that so many leading international investors agree with us.” •

ABN 53 137 008 247 Unit 4, 6 Hulberts Road, Toormina NSW 2452, Australia

SEAS Offshore Pty Ltd is a leading provider of state-of-the-art sediment sampling equipment. The company is based in Coffs Harbour, Australia and services clients worldwide. Our vibrocoring equipment was originally developed in the early 1980’s and has been further developed over the years to provide a lightweight, portable and extremely reliable sediment sampling solutions. Solutions for any sediment sampling project can be catered for by the experienced SEAS team. At SEAS we understand that every sampling job is different, so we work with our clients to design each program for best effect to meet our clients’ specific requirements.

Our lightweight and portable equipment enables us to sample in areas that are inaccessible to many other systems, such as shallow lakes, tidal estuaries and near-shore coastal environments. The various SEAS VC models allow sediment types in to be reliably sampled in environments which can be difficult or prohibitive for outer vibrocoring equipment.

The VC700 4.4Kw system combined with variable frequency control allows the operator to adjust the vibration frequency to suit the sediment type. The ability to vary the frequency provides a range of 5kN – 60kN drive force. In a unit as compact as the VC 700 this is a leader in the field. The VC700 was recently used with reliable success in sampling the dense iron sands offshore northern Luzon, Philippines. The project delivered over 600 core samples to six meters in length with high recovery rates. SEAS also manufacture and operates a number of sediment sampling systems. Box Core systems, Piston core systems and Grab samplers.

The SEAS Large Box core system provides a box sample 50cm x 50cm x 50cm (0.125m³). The Box core samples provide large undisturbed sediment samples suitable for environmental studies, macro benthic fauna analysis and geotechnical analysis. Our deep water vibrocore system pushes the limits of vibrocore sampling to 3000m, well beyond the capabilities of most of our competitors. When coupled with our multicore MPS3000 platform our deep water VC2000T provides a unique opportunity to acquire samples in an efficient and cost-effective manner. The MPS3000 system can collect 10 core samples from one deployment off the vessel. This capability considerably reduces winch time required to and from the sea floor making the equipment very cost effective. The MPS3000 system can host numerous additional sensors to meet client specifications. With real-time video feedback the coring procedure can be closely monitored. The cameras fitted with pan & tilt function can be turned outward to monitor the seafloor surface environment enabling valuable benthic habitat assessment. The MPS3000 has both low light black & white cameras in addition to a colour focus and zoom camera with additional lighting. For further information regarding any of SEAS equipment please contact: info@seasoffshore.com or visit our website: www.seasoffshore.com

NEWS - ASIA PACIFIC Supplying Asia with LNG Got Much Costlier for the US

upplying liquefied natural gas to the growing Asian market has become more expensive for US producers this year, a Rystad Energy report reveals. Even so, US exporters are unlikely to repeat last year’s cost-related shut-ins as global demand has rebounded to strong levels. Instead, US LNG exports climbed to a record monthly high of 6.5 million tonnes in May and may keep rising to new peaks. Rystad Energy estimates that the short-run marginal cost (SRMC) of US LNG exports to the Asian market has risen to about $5.60 per MMBtu as of June 2021, up 65% from $3.4 per MMBtu in mid-2020 and 30% higher than last year’s average of $4.30 per MMBtu. The SRMCs of currently operational liquefaction projects globally have risen this year due to a jump in transportation costs for LNG, driven by higher charter rates and fuel costs. On top of that, costs in the US have also been boosted by a recovery in domestic gas prices. Despite the lower SRMC of LNG to Asia last year, the US was still the most expensive supplier globally. As the TTF gas prices in Europe and Asian spot LNG prices fell below $2 per MMBtu in mid-2020, US exports took the largest hit, resulting in shut-ins as buyers canceled cargoes. Rystad Energy estimates that about 12 Mt of US LNG exports were shut in last year as a result of the market crash. “We do not see any signs of LNG shut-ins in 2021, but we do see a shift in the SRMC of global LNG and in the cost-of-supply curves. Instead, US LNG production will reach 72 Mt in 2021, its highest annual level on record, under an assumption of no shut-ins,” says Sindre Knutsson, vice president on Rystad Energy’s gas markets team. Despite the significant cost increase, the US is not the most expensive supplier to Asia this year, however. The comeback of Egyptian LNG to the market has seen the North African country assume the role as the marginal supplier of LNG, with an SRMC of about $6.30 per MMBtu. Still, the strong demand of 2021 is expected to absorb even these costs, as Asian spot LNG prices are around $12 per MMBtu. Meanwhile, the high transportation costs also affect producers located closer to Asia. For instance, the average cost of transporting Qatari LNG to Tokyo, Japan, has increased to $0.90 per MMBtu in 2021 from about $0.75 per MMBtu in 2020. By comparison, delivery of US LNG to Tokyo has seen an increase in voyage costs to about $1.90 per MMBtu in 2021 from $1.45 last year (already included in the US SRMC). The SRMC of liquefaction projects is not the only important price increase to influence the LNG market of late. If pre-tax liquids revenue is accounted for, many integrated LNG projects have seen improved competitiveness during 2021 thanks to higher oil prices. Pre-tax liquids revenue is calculated as the pre-tax revenue from oil activity for the upstream assets that feed LNG plants, divided by LNG production. In that way, the variable cost of LNG can be offset by oil production revenues. For example, Qatargas 1 LNG Train 1 has an estimated variable cost of LNG production of $1.60 per MMBtu. If the pre-tax liquids revenue from the oil production is considered, the costs are offset by oil revenues of about $2.60 per MMBtu, which brings net costs down to a negative $1 per MMBtu. That way, projects like Qatargas 1 LNG Train 1 would cover their costs even if LNG prices went down to zero. Nevertheless, there are no signs of prices falling to zero this year, or even to levels around the SRMC of Egyptian LNG at $6.30 per MMBtu. The LNG market looks robust in the short term due to the recovery in Asian and European LNG demand, supported by high demand for restocking, high CO2 prices and lower-than-expected Russian pipeline gas exports to Europe. •

McDermott Awarded Contract for Bayu-Undan Gas Field

cDermott International, Ltd today announced it has been awarded a Subsea, Engineering, Procurement, Construction and Installation (EPCI) contract from Santos NA (19-12) Pty Ltd for the Bayu-Undan Infill Well Phase 3C Project, in the Timor Sea, located approximately 310 miles (500 kilometers) off the northwest coast of Darwin, Australia, and 124 miles (200 kilometers) off the southeast coast of Timor-Leste. “McDermott has a strong track record of delivering complex subsea projects in Asia Pacific,” said Mahesh Swaminathan, McDermott’s Senior Vice President, Asia Pacific. “We will continue that tradition as we demonstrate our execution expertise and safety excellence throughout this project.” The Bayu-Undan field is one of Timor-Leste’s largest gas fields. Work on the Phase 3C Project commenced in May and, the scope will be managed by McDermott’s office in Perth. The McDermott scope involves a tieback of a single in-field well to existing facilities re-using existing flexible flowline with a new umbilical and certain infrastructure. BHP Awards McDermott Marine Installation Contract for Shenzi Subsea Multiphase Pumping Project McDermott International, Ltd today announced it has been selected by BHP to provide a marine installation campaign for the Shenzi Subsea Multiphase Pumping Project (SSMPP). The project is located approximately 138 miles (222 kilometers) offshore in the Gulf of Mexico at a water depth of 4,400 feet. “We look forward to continuing our partnership with BHP through this latest contract award,” said Mark Coscio, Senior Vice President for McDermott’s North, Central and South America region. “McDermott’s North Ocean 102 vessel is uniquely qualified to transport and install the materials and equipment for the Shenzi project scope—as well as perform pre-commissioning testing and other necessary surveys to safely deliver for the customer.” The scope of the contract includes: project management; detailed design and fabrication for a pump station suction pile; umbilical installation and flexible jumpers and flying leads installation; transport of all materials and equipment; and pre-commissioning services and other necessary testing and surveys. Engineering, procurement and project management services will be led by McDermott’s Houston engineering group. McDermott’s North Ocean 102 vessel—which has a proven track record of safely executing similar projects—will be used for the transport and installation of the material and equipment. The project will commence immediately and is expected to be completed in the summer of 2022. McDermott is currently providing Front-End Engineering Design (FEED) of a Semi-submersible Floating Production Unit (FPU) for the Trion Project in the Gulf of Mexico, another BHP project, in partnership with Pemex. McDermott was previously awarded and completed services under an initial pre-FEED contract for the Trion FPU. •

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NEWS - ASIA PACIFIC Victorian Spot Gas Price Hits 5-Year High

ictorian spot gas price hits 5-year high

The Victorian spot gas price hit $20 per gigajoule (GJ) on Tuesday afternoon, the highest price since 27 June 2016, five years ago. Other east coast prices were also high, $18.20/GJ at the Wallumbilla hub, $15.44/GJ in Sydney, $14.79/GJ in Adelaide and $14.39/GJ in Brisbane. Factors driving the surge in prices include strong winter gas demand, an outage at Longford and a spike in international gas prices, driven by hot weather and re-stocking of storage. Victorian gas demand peaks in winter. Melbourne’s maximum temperature is forecast to be only 13 degrees on Wednesday and total Victorian gas demand is currently over 1,000 TJ/d. However the state’s largest gas plant, the ExxonMobil, Esso-operated Longford plant, has had one processing train out of action since 28 June. In an emailed statement, Esso said: “Esso Longford’s Gas Plant 3 (GP3) experienced an unplanned maintenance event on 28 June 2021. Our team is working to safely resolve this short-term issue as soon as possible and resume full gas production. We anticipate that this will slightly reduce our daily supply into the east coast market. We are working closely with AEMO and our customers to minimise any potential disruptions to their operations as a result of this.” According to the Gas Bulletin Board Longford produced 981 TJ on 27 June but this dropped by over 100 TJ on 28 June to 877 TJ. Shortterm plant capacity is now listed as being 860 TJ/d. This is 10% below production immediately before the outage and 22% below nameplate capacity . Another likely factor influencing east coast gas prices is high international gas prices. Asian spot LNG prices are at an eight-year seasonal high. The Platts JKM Asian LNG spot price was US$14.31/ MMBtu (A$18.00/GJ) on 5 July. After a colder than usual winter, LNG buyers are re-building stocks ahead of next winter while hot summer weather is now driving demand for power generation for air conditioning. US gas prices are at 30-month highs and UK gas prices are the highest since 2008. There is no sign of higher Gladstone shipments in response to higher international prices. LNG exports from Gladstone in June were down slightly on May with 27 cargoes and in the first week of July Gladstone has only shipped four cargoes. However high international prices are likely to be influencing east coast spot prices. Overall east coast domestic gas is suffering a double-whammy of a plant outage and surging international prices in the middle of the peak southern winter demand season. •

PETRONAS and CNOOC Sign 10-Year LNG Supply Agreement

ETRONAS LNG Ltd. (PLL), a subsidiary of PETRONAS, has secured a 10-year term deal to supply liquefied natural gas (LNG) to CNOOC Gas and Power Trading & Marketing Limited, a subsidiary of China National Offshore Oil Corporation (CNOOC). This long-term supply agreement also includes supply from LNG Canada when the facility commences its operations by middle of the decade. The deal is for 2.2 million tonnes per annum (MTPA) for a 10-year period, indexed to a combination of the Brent and Alberta Energy Company (AECO) indices. The term deal between PETRONAS and CNOOC is valued at approximately USD 7 billion over ten years. “PETRONAS is proud to strengthen our decade long relationship with CNOOC through this term LNG supply. Importantly, it reflects the markets’ receptiveness and recognition of AECO indexed LNG into the world’s largest LNG market; as we seek to grow the use of LNG as a cleaner and cost effective form of energy,” said PETRONAS Vice President of LNG Marketing & Trading, Shamsairi M. Ibrahim. The AECO index, housed on the ICE NGX commodity exchange platform, is one of the most liquid spot and forward energy markets in North America. It is the leading price marker for natural gas in Canada similar to the United States’ Henry Hub, which is the benchmark for natural gas prices used as an indexation to LNG prices. PETRONAS introduced the AECO index to its customers in May this year following the sale of a spot cargo from Bintulu, Malaysia, to a buyer in the Far East. The agreement with CNOOC, China’s largest LNG importer, reflects PETRONAS’ commitment to ensure security of supply through an established transparent and stable price index such as AECO in the LNG market, while providing additional pricing options for its customers. Once ready for operations, the LNG Canada project paves the way for PETRONAS to supply low greenhouse gas (GHG) emission LNG to the key demand markets in Asia. The deal also further strengthens the ongoing relationship established since 2006 and reflects PETRONAS’ commitment in supporting the endeavor of CNOOC and its associated companies to meet the fastgrowing demand for cleaner energy and support China’s national aspiration of peak emissions and carbon neutrality. •

NEWS - SOUTH AMERICA An Expected Surge In FPSO Τhe FPSO market is booming this year, with more contracts awarded in the second quarter of 2021 than during the full year 2020. Rystad Energy expects FPSO awards to reach a total of 10 units in 2021, with another 10 following next year, creating a very healthy project line-up for contractors, effectively doubling their pipeline. Four FPSOs were awarded in the second quarter and we believe another four will be awarded before the end of the year. Including the two awards from the first quarter, this will bring the total tally up to 10 FPSO contract awards in 2021 – more than triple the three awards from 2020 – signaling a rapid comeback in FPSO contracting activity, despite the Covid-19 pandemic. The four FPSO contracts expected to be awarded before the end of the year include the Mero 4 and Parque das Baleias in Brazil, Limbayong in Malaysia, Liuhua 11-1 in China. “It’s not that contractors were out of business, there are currently over twenty FPSOs under construction, one of which is likely to startup already this year. But after a weak 2020, the recent awards and the expected ones are doubling the pipeline, ensuring manufacturers will keep busy in the years ahead,” says Aleksander Erstad, energy service research analyst at Rystad Energy. Petrobras is currently evaluating bids for the two Brazilian FPSOs, Mero 4 and Parque das Baleias. The Brazilian giant only received bids from one supplier for each of the FPSOs. For the larger unit, Mero 4, SBM Offshore was the sole bidder, while Yinson was the only player to bid for the smaller Parque das Baleias FPSO. The muted interest comes as the FPSO supply chain is nearing full capacity with several supplier unable to take on new projects. In Malaysia, Petronas is evaluating bids for the Limbayong FPSO with a contract award expected to be handed out before the end of the year. Contractors involved in the bidding process are Yinson, MISC, Sabah International Petroleum, and a consortium comprising Bumi Armada, MTC and Shapoorji Pallonji. China’s CNOOC is looking for a cylindrical FPSO to redevelop the Liuhua 11-1 and Liuhua 1-4 fields in the South China Sea. The FPSO will be built in China and is likely to involve COOEC, Cosco and CIMC Raffles. Another 10 projects are likely to be awarded in 2022, with the year expected to match 2021 in terms of FPSO awards. Most of the FPSO awards come from Latin America with four units bound for Brazil and one for Guyana. Angola and the UK are likely to see two awards each, and one is lined up for Australia. A joint venture between Saipem and Daewoo Shipbuilding and Marine Engineering (DSME) won a contract to supply the P-79 FPSO to be deployed at the Buzios field in Brazil. The contract is valued at $2.3 billion with Saipem’s share at $1.3 billion and DSME’s share accounting for the rest of the total value. DSME will build the hull and living quarters while Saipem will cover the topsides. The FPSO will be a newbuild with oil processing capacity of 180,000 barrels of oil per day (bpd), gas processing of 254 million cubic feet per day, and storage of 2 million barrels. The project will also give a boost to domestic Brazilian fabrication activity as Petrobras requires a 25% local content share. The contract for Equinor’s Bacalhau FPSO was also finalized in the second quarter. On 1 June, Equinor reached a final investment decision for the field development, triggering the full engineering, procurement, construction, and installation scope, which will be executed by Modec. Modec will also operate the FPSO for the first year. The company has conducted the front-end-engineering-design and pre-investment on the FPSO under a contract signed with Equinor in early 2020, and the FPSO hull is already under construction by Dalian Shipbuilding Industry Company in China. Once completed, the FPSO will be one of the largest in the world with oil processing capacity of 220,000 bpd, gas injection of 530 million cubic feet per day, water injection of 200,000 bpd, and 2 million barrels of storage capacity.

In China, SK Innovation handed out a lease and operate contract to CenerTech for an FPSO to be deployed in the Lufeng 12-3 field. CenerTech will build the FPSO, then lease and operate it for a fixed period of 10 years. The contract is valued at RMB 4.43 billion ($684 million) with FPSO capital expenditure incurred by CenerTech estimated at RMB 2.41 billion ($372 million). Petrobras contracted two FPSOs during the second quarter. In addition to P-79, the P-78 FPSO was contracted earlier in May. The P-78 was awarded to Keppel Shipyard under a turnkey contract valued at $2.3 billion. Keppel subcontracted the hull and living quarter scopes to Hyundai Heavy Industries for $762 million. The FPSO will have identical specifications as P-79. Keppel will use its Brazilian shipyard BrasFELS on parts of the fabrication scope to fulfill the 25% local content requirement. The P-78 and P-79 FPSOs represent a change in Petrobras’ contracting strategy. Petrobras had been contracting all FPSOs under lease and operate agreements. The switch to turnkey contracting, however, opens up to a wider set of potential suppliers, and Petrobras made the move as the leasing market for very large FPSOs is nearing full capacity. •

NEWS Eni Through Vår Energi Announces a New Significant Oil & Gas Discovery Offshore Norway

ni through Vår Energi, jointly owned by Eni (69,85%) and by HitecVision (30,15%), announces a new significant oil and gas discovery in production license PL027 in the Southern North Sea, with the dual branch exploration wildcat Prince 25/8-20 S, King 25/8-20 B and the appraisal side-track 25/8-20 C in the King Paleogene prospect. Vår Energi (operator) holds a 90% stake of the license and Mime Petroleum is partner with 10%. The exploration well is located in direct reach of existing infrastructure, approximately 6 kilometers north of the Balder field and 3 kilometers west of the Ringhorne platform in a water depth of 128 meters and is considered as commercial discovery. The Prince wildcat well-branch reached a vertical depth of 2,374 meters below sea level and encountered an oil column of about 35 meters in the Triassic Skagerrak formation within good to moderate reservoir sandstones. Wildcat well-branch King reached a vertical depth of 2,353 meters and discovered a gas column of about 30 meters and a light oil column of about 55 meters with some thick Paleogene injectite sandstone with excellent reservoir properties. Deepening of the well indicated further the lateral continuity of the Triassic Prince Skagerrak discovery in an adjacent fault block towards the Ringhorne Platform. An additional King appraisal side/track further confirmed the lateral extend and connectivity of the Paleogene reservoir sands and proofed a gas column of about 40 meters and an oil column of about 55 meters in injectite sandstones, of which about 35 meters are formed by thick and massive oil bearing sandstone with excellent reservoir quality.

The well was not formation tested, but extensive data collection and sampling has been performed which indicates a production potential of approximately 10000 boepd per well. Preliminary estimates place the size of the discovery between 220 and 360 Mboe hydrocarbon in place (60-135 million barrels of recoverable oil equivalents), split among 140 and 250 Mboe in the Paleogene reservoir and between 80 and 110 Mboe in the Triassic Skagerrak reservoir with significant further upside potential in both discoveries to be verified with further exploration/appraisal activity. Vår Energi is evaluating a rapid tie-in to the existing infrastructure of the Balder Ringhorne area to accelerate the exploitation of the Paleogene resources. After the recently announced Isflak discovery in the Barents Sea and the Blasto and Garatiana West discoveries in the Northern North Sea, King/Prince further validates Vår Energi’s successful Infrastructure Led exploration strategy also in the Southern North Sea by proofing additional high value resources in the Balder Ringhorne Area that can potentially be exploited with a fast track solution. Vår Energi has ownership in 137 licenses and oil and gas production from 35 fields. Vår Energi operates over the whole Norwegian continental shelf; the Goliat field in the Barents Sea, the Marulk field in the Norwegian Sea and the Balder and Ringhorne fields in the North Sea. The company has an organization with 900 employees with more than 50 years’ experience on the Norwegian continental shelf, built on the previous companies’ heritage offshore Norway. Vår Energi’s current production stands at approximately 280,000 boepd. •

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NEWS - AFRICA Eni Announces a Significant Oil Discovery Offshore Ghana OPEC Participates in Nigeria Oil and Gas Conference and Exhibition 2021

he Organization of the Petroleum Exporting Countries (OPEC) took part in the 20th edition of the Nigeria Oil and Gas Conference and Exhibition. At the Opening Ceremony, OPEC Secretary General, HE Mohammad Sanusi Barkindo, delivered a keynote address on the theme: ‘Global oil market dynamics in a decarbonizing world’. The Secretary General, in his recorded remarks as Honourary Conference Chairman, thanked the leadership of Nigeria for its unwavering commitment and continuous support of OPEC over its fivedecades of Membership. He lauded Nigeria’s contributions to promoting sustainable stability in the global oil market and its influential role in the OPEC and non-OPEC Declaration of Cooperation (DoC). “OPEC is deeply indebted to HE Muhammadu Buhari, President of Nigeria, for the leading role he has played and continues to play in support of the Declaration of Cooperation process. This historic achievement has ushered in a new era in global energy cooperation,” Barkindo stated. He added: “Over the last five decades, OPEC and Nigeria have sown the seeds of friendship to build a highly fruitful and mutually beneficial relationship, forging strong ties that will last forever.” In underscoring Nigeria’s contribution to the Organization, he noted that over its 50 years of Membership, the country has provided OPEC with 23 Heads of Delegation, six of whom served as President of the Conference. Nigeria has also proffered the Organization with four Secretaries General. Barkindo stressed the importance of the event, which he noted has risen in stature over the years to become a leading industry event. He also recalled the two industry pioneers whose visionary leadership were responsible for its founding – Dr. Rilwanu Lukman of Nigeria and Dr. Alirio Parra of Venezuela. On the Conference’s theme, the Secretary General pointed out that all forms of energy will be required to meet current and future energy demands, and that recent calls for oil and gas industry divestment are irresponsible and unrealistic. In this context, the Secretary General underlined the key role of innovation, technology and science in the energy industry, which has resulted in cutting-edge solutions such as carbon capture, utilization and storage (CCUS), as well as hydrogen. These will be viable options for reducing the global carbon footprint, he added. On energy poverty, Barkindo underscored the need to ensure energy access for all around the world as part of a fair, inclusive and equitable energy transition. The Secretary General stated OPEC’s intention to return to its birthplace in Baghdad, Iraq, in September of this year to celebrate the Organization’s Diamond Anniversary. This landmark occasion will celebrate OPEC’s six decades of supporting stability in the global oil market, in the interest of consumers, producers and the global economy. The OPEC Secretariat takes part in this leading energy event on an annual basis. This year’s edition saw the Secretariat participating through hosting a booth, where the Organization’s history and achievements were presented, along with its flagship publications, the World Oil Outlook, the Annual Statistical Bulletin and the OPEC Bulletin. Nigeria will mark its 50 years of Membership in OPEC on 12 July. For this special occasion, the OPEC Secretariat has produced a special issue of the OPEC Bulletin, which takes a retrospective look at Nigeria’s journey as an OPEC Member from 1971 until today. The Secretariat has also produced a documentary film to mark the occasion. •

ni announces a significant oil discovery on the Eban exploration prospect in CTP Block 4, offshore Ghana. The Eban - 1X well is the second well drilled in CTP Block 4, following the Akoma discovery. Preliminary estimates place the potential of the Eban–Akoma complex between 500 and 700 Mboe in place. The Eban - 1X well is located approximately 50 kilometers off the coast and about 8 kilometers Northwest of Sankofa Hub, where the John Agyekum Kufuor FPSO is located. It was drilled by the Saipem 10000 drilling ship in a water depth of 545 meters and reached a total depth of 4179 meters (measured depth). Eban - 1X proved a single light oil column of approximately 80m in a thick sandstone reservoir interval of Cenomanian age with hydrocarbons encountered down to 3949m (true vertical depth). The new discovery has been assessed following comprehensive analysis of extensive 3D seismic datasets and well data acquisition including pressure measurements, fluid sampling and intelligent formation testing with state-of-the-art technology. The acquired pressure and fluid data (oil density and Gas-to-Oil Ratio) and reservoir properties are consistent with the previous discovery of Akoma and nearby Sankofa field. The production testing data show a well deliverability potential estimated at 5000 bopd, similar to the wells already in production from Sankofa Field. The estimated hydrocarbon in place between the Sankofa field and the Eban-Akoma complex is now in excess of 1.1 Bboe and further oil in place upside could be confirmed with an additional appraisal well. Due to its proximity to existing infrastructures, the new discovery can be fast-tracked to production with a subsea tie-in to the John Agyekum Kufuor FPSO, with the aim to extend its production plateau and increase production. The Eban discovery is a testimony to the success of the infrastructure-led exploration strategy that Eni is carrying out in its core assets worldwide. •

Eni: Meeting Between the CEO of Sonatrach, Toufik Hakkar, and the General Manager of Eni

he two companies to accelerate collaboration in the technological field, in particular in the hydrogen sector, towards a shared goal of reducing the carbon footprint of their activities. The CEO of Sonatrach, Toufik Hakkar, and the General Manager of Eni - Natural Resources, Alessandro Puliti, met today in Algiers to review the progress of Eni’s activities in the country. Sonatrach and Eni agreed to accelerate cooperation in the technological field, building on the Memorandum of Understanding the two companies signed last March in Milan, with specific focus on hydrogen production. A road map was outlined for the joint assessment of the technical and commercial feasibility of a pilot project to produce hydrogen using electricity generated from renewable sources (solar and wind). In addition, in order to preserve the country’s water resources, the use of water produced by oil fields will be evaluated for the electrolysis processes necessary for the production of hydrogen, appropriately treated through dedicated plants. The two companies reiterated their intention to accelerate cooperation for the common goal of reducing the carbon footprint of their respective activities. The ongoing projects are aimed at improving the energy efficiency of the processes, the electrification of treatment plants, the abatement of fugitive methane emissions and the parallel development of projects dedicated to new zero-emission energy solutions. Eni has been present in Algeria since 1981. With an equity production of 90,000 barrels of oil equivalent per day, Eni is the leading international company in the country. •

NEWS OKEA Awards Integrated EPCI Contract for Hasselmus Field

KEA awards Subsea Integration Alliance a contract for the Hasselmus field development located seven kilometres northwest of the Draugen platform, in the southern Norwegian Sea.The Hasselmus project is the first engineering, procurement, construction, and installation (EPCI) contract awarded under the scope of the frame agreement awarded in 2017. The project work scope covers the EPCI of the subsea production systems (SPS) and subsea pipelines (SURF) for a single subsea well with direct tie-back to the Draugen production platform. The development concept will benefit from the OneSubsea configurable vertical tree platform, which leverages a uniquely adaptable product architecture to address the dynamic conditions throughout the basin life cycle. It starts with a standard and robust core and adapts to well and basin requirements with numerous fit-for-purpose functional modules that address technical challenges without affecting the core performance. The platform enables flexibility in dynamic field conditions and contributes to reliable project delivery with budget certainty while minimising total cost of ownership for the life of the field. The SPS scope also includes the installation of a subsea wellhead, subsea controls, completions installation system and OneSubsea’s innovative completion installation tooling—independent of rig selection. OneSubsea’s tooling platform eliminates the need to purchase tooling for projects, even for instances that have historically needed it. It employs a universal suspension tooling suite that includes a common set of tools, regardless of the downhole line configuration

and type of tree being deployed, making smaller well-count projects more economically viable. And through the industry’s first rentalmodel enabled means of tubing hanger in wellhead installation and orientation, OneSubsea’s proprietary Tubing Hanger Orientation Spool (THOS) system decouples tooling design from rig-specific interfaces, removing historical interdependencies, enabling quicker first oil. The SURF scope comprises approximately nine kilometres of pipein-pipe flowline with mechanically lined BuBi® pipe, a highly costefficient alternative to metallurgically clad pipe for corrosion-resistant applications, and associated structures. The flowline will be pulled into the Draugen platform via a j-tube and routed to the Hasselmus field at approximately 250 metres water depth. Stuart Fitzgerald, CEO Subsea Integration Alliance LLC said: “This award to Subsea Integration Alliance supports our strategy for early engagement, full subsea system delivery, and our track record with OKEA. Working in partnership with OKEA has supported optimised solutions, early decision making and shortened delivery time, ultimately improving cost efficiency throughout the entire field lifecycle. We look forward to continuing to support this objective for the Hasselmus project.” Steve Tate, Deputy CEO, Subsea Integration Alliance LLC said: “Delivering with certainty will be key to help OKEA start up production by 2023. The OneSubsea configurable vertical tree platform will be a key enabler to provide greater schedule assurance and reduce overall project risks by providing a standard design with plug-and-play capability. Coupled with our integrated project delivery model, we are committed to support OKEA’s objective.” Hasselmus is OKEA’s first operated field development project adding more than 4,400 boe/d of production at peak. Production start-up is estimated to be in Q4 2023. •

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Under the Patronage of His Highness Sheikh Mohammed Bin Rashid Al Maktoum, Vice President and Prime Minister of the United Arab Emirates and Ruler of Dubai Supported By

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21-23 September 2021 Dubai World Trade Centre United Arab Emirates

The First Major Energy Event to Take Place Live & In-Person this Year!

2,500+

300+

70+

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H.E. Suhail Mohamed Al Mazrouei Minister of Energy & Infrastructure United Arab Emirates

H.E. Chief Timipre Sylva Honourable Minister of State- Petroleum Resources Federal Republic of Nigeria

H.E. João Galamba Secretary of Energy Portugal

H.E. Dharmendra Pradhan Honourable Minister of Petroleum & Natural Gas India

Patrick Pouyanné Chairman & Chief Executive Officer TotalEnergies

Klaus-Dieter Maubach CEO Uniper SE

Dev Sanyal Executive Vice President Gas & Low Carbon BP

Peter Clarke Senior Vice President ExxonMobil Upstream Oil & Gas Company

Jillian Evanko CEO Chart Industries

Joseph McMonigle Secretary General IEF

Harald Link Chairman & President B.Grimm Power

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PetroChina Annual General Meeting 2020 held in Beijing Under the Patronage of His Highness Sheikh Mohammed Bin Rashid Al Maktoum, Vice President and Prime Minister of the United Arab Emirates and Ruler of Dubai

n July 10, PetroChina Annual General Meeting 2020 was held in Beijing. Presided over by Dai Houliang, Chairman of PetroChina (hereinafter, “the Company”), the meeting deliberated on and approved a number of proposals including PetroChina 2020 Annual Report of the Board of Directors, PetroChina 2020 Annual Report of the Board of Supervisors, PetroChina 2020 Annual Financial Statements, and PetroChina 2020 Annual Profit Distribution Plan. At the meeting, Dai Houliang and the Company’s directors and top management responded to questions from shareholders and shareholder representatives such as changes and prospects of the oil and gas market, the Company’s green and low-carbon transition, and its natural gas and refined products business development.

21-23 September 2021 Dubai World Trade Centre United Arab Emirates

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Shareholders, shareholder representatives, directors, supervisors and the board secretary of the Company attended the meeting. Top management of the Company and heads of relevant departments attended the meeting as non-voting delegates. •

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The First Major Energy Event to Take Place Live & In-Person this Year! The Gastech 2021 Conference will convene the full energy value chain as the industry moves to decarbonise and transition to a more sustainable future. Hear from over 300 policymakers, industry leaders, and disrupters as they present new business models, strategies, and innovations that will be instrumental in addressing growing energy demand and tackling climate change obligations.

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Lukoil Team Wins a Contest for Best Qualification Assessment Tools

joint team of experts from LUKOIL-Technologies and LUKOIL-Permnefteorgsintez (wholly-owned subsidiaries of PJSC LUKOIL) won the first prize in the National Competition for the Best Qualification Assessment Tools in the personnel competency assessment category. The LUKOIL team has presented a set of theoretical and practical tests for professional exams designed for oil and gas pump operators (level 4 qualification). The contest was organized by the National Qualification Development Agency with support of the Ministry of Labor and Social Protection of the Russian Federation to identify and promote best practices in applying tools of the national qualification system. Qualification assessment tools presented by the participants were appraised from the point of view of testology and qualification assessment methodology. The winner was selected based on consideration of such aspects as variety of test types, creative wording, unconventional approach (use of case reviews, video and audio materials, infographics, etc). •

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AUVSI XPONENTIAL 16.08.2021 - 19.08.2021 Georgia World Congress Center https://www.xponential.org/xponential2021/public/enter.aspx 2021 IPF 24.08.2021 - 26.08.2021 Richmond, VA https://www.offshorewindus.org/2021ipf/ The 18th Asian Oil, Gas & Petrochemical Engineering Exhibition 08.06.2021 - 10.06.2021 Kuala Lumpur Convention Centre https://www.oilandgas-asia.com/ SPE Offshore Europe 2021 Virtual 07.09.2021 - 10.09.2021 ADIPEC 2021 08.11.2021 - 11.11.2021 Abu Dhabi, UAE https://www.adipec.com/ Gastech Exhibition & Conference 2021 Dubai World Trade Centre https://bit.ly/3iEbHfH +44 (0) 203 615 5916 AntwerpXL 2021 07.12.2021 - 09.12.2021 Antwerp, BELGIUM http://www.antwerpxl.com 23rd World Petroleum Congress Dec 5-9th 2021 Houston, Texas, USA https://www.23wpchouston.com/ Offshore Technology Conference 16-19 Aug 2021 Houston, Texas, USA http://2020.otcnet.org/ The 28th World Gas Conference (WGC 2021) 21.06.2021 - 25.06.2021 130 Gongpyeong-dong, Jung-gu, Daegu, South Korea https://www.wgc2021.org/