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Autumn 2021

Business Information. Industry Solutions.

SAFE OPERATION OF THE CRITICAL OFFSHORE MACHINERY? ADIPEC SPECIAL

HEAT PIPE AIR PRE-HEATERS: AN ALTERNATE APPROACH INDUSTRY 4.0 SCENARIOS IN THE OIL AND GAS SECTOR

Emery Hill Media Ltd. © 2021



www.oilandgasinnovation.co.uk

Autumn 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 Ashish Jaswal it@oginnovation.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

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CONTENTS COVER STORIES & SPECIALS

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On-Site Oil Analysis

As a rule, the prevailing practice of oil analysis for monitoring the operating condition of the equipment presumes oil sampling every two to three months and using an onshore laboratory for analyzing specific oil parameters.

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Industry 4.0 Scenarios in the Oil and Gas Sector

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Digitalisation and Industry 4.0 have become an increasingly important topic in the oil and gas sector. Due to the fierce competition in the industry, in part, companies can no longer afford downtime of their plants due to malfunctions.

An Alternate Approach

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Combustion air preheating by recovering heat from flue gases is a cost-effective method of increasing the overall thermal efficiency of the refining and petrochemical processes.

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ADIPEC SPECIAL WORLD INDUSTRY NEWS Europe Asia Pacific North America MENA Russia & CIS

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14 22 26 80 84

EXPLORATION & PRODUCTION

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Consolidating Activities on the Global Offshore Market Danish VMS Group is on the verge of a new entry to the global offshore market. With a wide range of service being offered, a long-lasting experience, and a firm strategy, VMS Group will become an even more considerable player in the field of offshore rig, drilling, and service fleet services.

Subseatec Continues Its Journey Towards Increased Sustainability

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CONTENTS EXPLORATION & PRODUCTION

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Disputes Are Inevitable, What Are Your Options?

OGI Magazine sits down with Bernicia Marine Consultants Limited to discuss the evolving nature of mediation and dispute resolution in the offshore and oil & gas sectors. It’s important for readers to understand their options, when they land into disputes in their operations.

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Super Duplex Tubing from Fine Tubes MIDSTREAM & PIPELINES

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More Than Just a Frame System

With TubeLock, Global Gravity are taking care of all handling and transportation of all types of casing, tubing and drill pipe tubing from storage, across the quay to the ship, and onto the drilling rig.

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Oil & Gas Industry Interconnections

Today’s petroleum industry is benefitting significantly with emerging surveillance, sensor and digital data processing technologies. Upstream research and economic analysis used for “next-field” determination, accessibility, and potential harvesting processes require extensive data collection, processing and analysis.

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Expertise in Machinery PROCESSING Future Proof the Process Industry

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OGI sits down with Klippon Engineering for another installment of our interview series. Klippon Engineering is the internationally renowned partner of the Weidmueller Group.

Avoid Downtime, Save Money

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HEALTH, SAFETY & ENVIRONMENT A Unique Rechargeable Floodlight EVENTS CALENDAR

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Keeping water on the outside since 1996

Blanking solutions Miko delivers custom-made blanking solutions for blanking off sea chests, pipe inlets and outlets and all kinds of hull apertures below the waterline. With neutral buoyancy - achieved by blocks of rigid PVC foam mounted externally on the walls - the blanks are easily handled under water by divers or ROV. They are kept firmly in place on the hull by utilizing Miko Anchor Magnets. Miko blanking solution is a safe and reliable option for in-water repair at any depth.

mikomarine.com


COVER STORY

On-Site Oil Analysis for Condition Monitoring of Complex Machinery and Hydraulic Systems of Offshore Oil and Gas Platforms Offshore oil and gas production platforms require reliable condition monitoring programs of lubricants and fluids to provide continuous and safe operation of the critical offshore machinery under harsh environmental conditions. Due to their remote location, oil and gas platforms may not be easily reached by highly trained personnel to make equipment replacement in case of machinery failure. Any major breakdown can substantially hinder the work of a platform or might pose a safety hazard to the operating crew. Moreover, repairs in offshore oil and gas industry can be very expensive and time consuming. In opposite, application of on-site oil analysis program to monitor the condition of essential parameters of lubricating oil and fluids is easy, smart and cost-effective solution which can be adopted as a part of the successful equipment maintenance strategy, i.e. machinery and hydraulic systems required for energy production for offshore oil and gas platforms (e.g. diesel engines, gearboxes, turbines, pumps, compressors etc.).

Alternative Approaches to Oil Analysis for Optimization of Machinery Condition Monitoring As a rule, the prevailing practice of oil analysis for monitoring the operating condition of the equipment presumes oil sampling every two to three months and using an onshore laboratory for analyzing specific oil parameters. However, taking into account offshore and remote location of oil and gas platforms, the laboratory results may not reach the operating personnel and technicians responsible for equipment maintenance for several weeks. Such delays in obtaining oil analysis results may lead to failures in identifying existing maintenance issues at the right time and cause unexpected downtime of the machinery. An alternative approach to oil analysis is the adoption of on-site oil condition monitoring programs through the mechanism of regular or continuous assessment of the critical oil parameters of lubricants and fluids such as water-in-oil, alkalinity reserve, viscosity, acid number, the presence of insoluble and metal particles etc.

Martechnic offers two different oil condition assessment techniques that can be used for maintaining operational equipment of offshore oil and gas platforms: 1.

Regular interval-based determination of lubricants’ condition with the help of portable test devices;

2.

Intelligent monitoring with sensor technology for an unattended machinery space.

The main advantage of these analyses methods is the possibility to provide accurate information on the actual condition of the lubricating or hydraulic oil in use and to detect any occurring irregularities or abnormal processes prior to unexpected catastrophic failures. Portable Testing Equipment: Trend Analysis of Oil Condition Regular oil condition monitoring with portable testing equipment is an easy and Above: Potable Test Kit “LUBE OIL CHECK OS” for on-site trend analysis of crucial parameters of lubricating and hydraulic oil.

quick on-site method which provides almost immediate and high accuracy test results. The operating personnel is able to routinely check crucial parameters of lubricants and hydraulic fluids. When individually establishing monitoring intervals for each oil parameter of interest, technicians collect data for tracking trends in the oil condition to make a prognosis and accordingly to plan efficiently on necessary maintenance time. If an abnormal oil analysis test result is obtained, a repetitive measurement can be conducted by the crew to confirm the accuracy of the measured parameter before a further corrective action should be considered. This can help to reduce expenses and/or predict potential problems or equipment failures prior to their occurrence. The test kit “LUBE OIL CHECK OS” of Martechnic combines portable test devices for five different on-site lube and hydraulic oil


tests that are crucial for condition monitoring and maintenance of the key machinery of oil and gas platforms.

The test device “TWIN CHECK 4.0” for regular on-site measurements of water-in-oil and alkalinity reserve of lubricants.

Water-in-oil and alkalinity reserve of lubricants can be measured with the test device “TWIN CHECK 4.0”. The test device measures automatically and precisely both parameters through the built-in pressure sensor which registers pressure build-up in accordance with the degree of water concentration/ BN value in the oil under examination. The “TWIN CHECK 4.0” is offered in modular design with possibility to replace every single constituent part and has a USB to serial cable connection and memory chip for data storage and trend analysis. Alongside water-in-oil and BN monitoring, the “LUBE OIL CHECK OS” offers a quick “go/ no go” viscosity test to immediately identify any deviation from standard viscosity values. Spot test can help to regularly determine occurring changes in the oil condition and is primarily used for assessing the level of soot contamination of engine lube oil. With respect to hydraulic systems of the oil platforms high operating temperatures or ingress of aerial oxygen can lead to oxidation and nitration of hydraulic fluids and occurrence of acid sludge. Early detection of increased acid value with the test “MT AN CHECK” can help to avoid further degradation and to protect machinery through scheduled maintenance. Intelligent Sensor Technology: ConditionBased Maintenance of Complex Machinery and Hydraulic Systems Remote location of oil and gas platforms and often scarce operating personnel resources for regular oil condition monitoring of complex machinery and hydraulic systems may be the factors to prioritize an installation of permanent oil condition monitoring devices, i.e., intelligent sensor technology. In contrast to portable testing equipment, permanently installed in-line sensors provide continuous 24/7 oil condition assessment, when principal oil parameters are monitored in the real-time mode. Automated alerts with early warning system provide immediate notification of occurring changes of the oil parameters and enable maintenance crew to analyze the

problem and to take necessary maintenance measures at the pre-alarm level during the uninterrupted operation process of machinery. In its turn, equipment maintenance intervals can be optimized and possibly prolonged. Martechnic designed and developed an innovative MT MODULAR MONITORING SYSTEM for comprehensive and continuous oil condition assessment. The principal benefit of the system is its modular design, namely the possibility to customize a version suitable for a specific field of application in accordance with individual requirements and to install the sensors into specific machinery components (generators, gearboxes, mud pump bearings, hydraulic system etc.) Depending on the oil parameters to monitor. Appropriate lubrication is the prerequisite for flawless functioning of machinery components. Due to increased humidity of marine environment, lubrication system may be exposed to moisture condensation and occurrence of water. Continuous measurement of water-in-oil content, for instance in gearboxes, can be made with the infrared AHHOI IR SENSOR. The sensor measures water concentration in

molecular form in the range of up to 10000 ppm / 1.0 vol. % and enables determination of water in all three states: saturated, emulsified and free. The sensor is installed in the bypass and can be equipped with manifold for simultaneous monitoring of up to four different oil systems. HUMIDITY SENSOR can be applied for generators and will enable determination of any unexpected rise in the level of relative humidity of oil in % (ranging from 0 % - no water detected to 100 % - complete saturation/ existence of free water) through continuous measurement of the degree of oil saturation with water. PARTICLE SENSOR is useful for immediate detection of the increased degree of concentration of insoluble particles in oil. FE SENSOR helps to monitor oil system contamination with ferromagnetic particles Simultaneous application of several permanently installed condition monitoring sensors and their connection to the special display unit DATALOGGER for continuous data recording and assessment can offer a reliable and secure solution for conditionbased maintenance of complex machinery and hydraulic systems. Conclusion On-site oil analysis and adoption of oil condition monitoring programs can be considered essential for managing safe, continuous and efficient operation of critical machinery of offshore oil and gas platforms. Implementation of a preventive maintenance strategy with well-planned maintenance intervals may help to optimize the overall performance of the operating equipment and to contribute to providing of uninterrupted production of oil and gas platforms, therefore also effectively protecting the marine environment. For more information on condition monitoring of lubricating and hydraulic oil, please contact Martechnic:

“MT MODULAR MONITORING SYSTEM” offers permanently installed in-line sensors for continuous real-time oil condition monitoring.

Martechnic GmbH Phone: +49-40 853128-0 Fax: +49-40 853128-16 E-mail: info@martechnic.com Web: http://www.martechnic.com


COVER STORY

Intrinsically Safe Mobile Devices for Industry 4.0 Scenarios in the Oil and Gas Sector Digitalisation and Industry 4.0 have become an increasingly important topic in the oil and gas sector. Due to the fierce competition in the industry, in part, companies can no longer afford downtime of their plants due to malfunctions. Through digital transformation and intelligent solutions, problems and malfunctions can be solved quickly or avoided altogether, especially in maintenance and servicing in the upstream and midstream areas. Through maintenance solutions (predictive maintenance), companies gain deep insights into plant behaviour by digitally networking all work areas and continuously analysing data in real time.

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i.safe MOBILE HMT-1Z1 Application Scenario.

he service life of plants and machines can thus be extended, the return on investment maximised and ultimately the profit increased. In order to be able to carry out these highly complex digital processes optimally on the hardware side, extremely robust, highperformance mobile devices with the highest explosion protection are required. In hazardous offshore scenarios simple tasks like taking and processing photos, sending and reading emails, having permanent and secure access to the company cloud for getting any relevant information had often been just a pipe dream in the past. Scenarios in which overloaded workers in hazardous areas had to handle radios, mobile phones and tablets at the same time are becoming rare. This area is very much in flux and there is also a rethink taking place in the individual segments. One example is the switch from conventional radios to smartphone-based push-to-talk communication. This brings many advantages, such as the possibility for group PTT, videobased PTT and the ability to immediately enter images, videos and data of all kinds recorded on site into the company’s own ERP system, e.g., through maintenance solutions. Due to the existing mature technical possibilities - both on the hardware and application side - the trend is clearly towards an all-in-one-device-strategy. This is exactly the mission that the company i.safe MOBILE pursues.

Graphic: Ex Zone Description.

Innovation leader team for explosion-proof mobile devices and solutions As innovation leader in the field of explosionproof mobile devices, i.safe MOBILE, based in Lauda-Koenigshofen (Germany), is always one step ahead with its innovations and offers smartphones, tablets and other mobile devices and accessories with the latest technology for the offshore and onshore sector (1/Cl I Div1). Numerous industry leaders around the world, including Fortune 500 companies, already count on the explosion-proof mobile devices

and solutions of the company and appreciate the company’s reliability, durability and competent support. Through its cooperation with solution partners, i.safe MOBILE is able to offer its customers a wide range of complete solutions, tailored to the respective area and requirements. The company cooperates with AMA (Assisted Reality/Digital Workflow Management), the SAP Gold Partner Evora Solutions (Mobile Maintenance/Mobile Workforce Management), the ICS Group (Supply Chain Digitisation), ProMobi (Mobile Device Management/MDM), Swissphone (Lone Worker Protection Solution), and Tassta (PTT solutions), among others. i.safe MOBILE devices combine a wide range of functions and applications in one single device and thus make working life much easier and secure. High-performance, explosion-proof mobile devices for the hazardous area For both the offshore and onshore sector, i.safe MOBILE offers devices that are Android Enterprise Recommended and can be deployed extremely quickly and easily in fleet operations thanks to zero-touch functionality. The mobile devices are certified according to ATEX and approved for Zone 1 for gases and Zone 21 for dust /21 or CSA Class I, II, III Division 1. In addition, the devices provide other internationally relevant explosion


The i.safe MOBILE IS930.1

protection approvals such as IECEX, CSA, EAC and others. The IS930.1 Industry 4.0 tablet is ideal for maintenance solutions in the IoT environment. The high-performance device has an 8-inch display, two freely programmable buttons, a long-life battery with 8400 mAh and can easily be used and carried thanks to a hand strap and a separate leather bag with a shoulder/ belt/crap system. The amplified loudspeaker guarantees good audio quality even in the noisiest environments. An eye-catching SOS button provides safety for lone workers through a separate LWP-app. The tablet is equipped with various sensors such as accelerometer, gyroscope, magnetic, temperature and humidity, proximity sensors. The flagship of i.safe MOBILE’s industrial smartphone range is the IS530.1, a powerful multifunction device. The Bluetooth 5 smartphone is Android Enterprise Recommended, zero-touch capable, MDM compatible, has a huge 64 GB internal memory and offers the highest camera resolution in its class. Additional accessories such as an RSM, PTT headsets or the IS-TH1 professional barcode scanner can be easily and securely adapted via a 13-pin interface and thus underline even more the multifunctionality of the IS530.1. This smartphone also has an amplified loudspeaker, an SOS button and an acceleration sensor, gyroscope, magnetic, temperature and humidity sensor, proximity sensor. In the hazardous logistics sector of the oil and gas industry, customers can even benefit from the flexible combination of the IS530.x and i.safe MOBILE’s IS-TH1xx.1 high performance scanner for reliable data collection. The highperformance scanner is HID active and captures any 1D or 2D barcode with a range of up to 6 metres or distances of over 15 metres via Zebra OEM Imager Scan Engines. The captured data can be processed directly via the IS530.x

smartphone (connected by the 13-pin interface) and entered into the company’s ERP system - This time and resource-saving solution is ideal for the logistics sector in large refineries and seaports. With the HMT-1Z1, a head-mounted tablet, i.safe MOBILE recently launched a groundbreaking product innovation. This device is the world’s first voice-controlled tablet for hands-free working in hazardous areas 1/21 or CSA Class I, II, III Division 1. The Androidbased HMT has a high-resolution micro display which is well suited also for exterior use. Especially in the most demanding offshore environments customers appreciate the possibility of intuitive voice control and

digital microphones with active noise cancellation. It is compatible for PPE (Personal Protective Equipment) and is perfect for assisted reality scenarios with highly complex remote support applications or remote training sessions. All i.safe MOBILE devices in this category are IP68 dust/waterproof, MIL-STD 810G certified, can be operated from -20 °C to 60 °C even with gloves. i.safe MOBILE GmbH is an international specialist and innovation leader for explosionproof and extremely resilient communication devices. The company develops and markets devices for the oil and gas sector, process industry, chemicals, pharmaceuticals and other industries with highest performance and safety requirements. All devices are safety and quality tested by established approval commitees based on European and worldwide standards. The devices are developed in-house from the ground up in Lauda-Koenigshofen, the company’s headquarters. The company cooperates with reliable partners such as solution providers in the areas of push-to-talk, mobile device management, maintenance software and loneworker, among others, and offers complete solutions from a single source. i.safe MOBILE is represented by a subsidiary in Singapore and Moscow and sales partners in 72 countries in Europe, the USA, Latin America, South Africa, the Middle East, Australia and Asia. For more information please contact: i.safe MOBILE GmbH W: https://www.isafe-mobile.com E: info@isafe-mobile.com

The i.safe MOBILE IS530.1

The i.safe MOBILE IS-TH1xx

T: +49 9343 60148-0

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COVER STORY

Heat Pipe Air Pre-Heaters in Oil Refineries An Alternate Approach Background Combustion air preheating by recovering heat from flue gases is a cost-effective method of increasing the overall thermal efficiency of the refining and petrochemical processes. Consequently, the use of Air PreHeaters (APH) in oil refineries has become well established and widespread in the last 4 decades or so.

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efinery operators have, however, over the years experienced well known problems with conventional APH types, these include: •

Reliability and maintenance.

Premature failure & replacement.

Inability to use in cold weather when internal acid condensation occurs.

Excessive air leakage.

This article describes how Heat Pipe Air PreHeaters (HP-APH) address the limitations of conventional APH types and offer a proven and effective, alternative solution. Conventional APH Technology Many types of APH are utilised within refineries the most common types being plate & frame, DEKA and rotary wheel. Operators have reported a range of problems with APH equipment primarily caused by flue gas acid condensation which leads to premature equipment failure and air leakage. The problem

is well understood by operators and equipment vendors who have developed a range of solutions to avoid acid condensation by maintaining minimum metal temperatures above the acid dewpoint of the flue gas. These solutions all require careful operation to avoid the occurrence of “condensation events” in the APH.

Acid Condensation Avoidance Solutions Common acid condensation solutions include: 1.

Cold Air Bypass (CABP) – This involves by-passing part of the cold air stream around the APH to reduce the air volume being heated. This has the effect of elevating the lower air mass to an exit Temp higher than that required and by doing so increasing the minimum metal Temp in the heat exchanger. The bypass damper is controlled to keep the average of the flue gas exit Temp and ambient air Temp above the known acid dew point by a safety margin of 20F – 30F.

2.

Hot Air Recirculation (HAR) – This is often used in conjunction with the CABP and entails recirculating a proportion of the hot air exiting the APH back to the cold air inlet. This has the effect of elevating the temperatures in the APH in an attempt to avoid acid condensation.

The effect of uncontrolled acid-condensation in a conventional APH is profound and usually results in corrosion breakthrough giving rise to leakage and cross contamination requiring service limitation and eventual bypassing. Most conventional APH equipment is notoriously difficult to repair and often follows a path of reducing performance and eventual shut down. The available acid condensation avoidance solutions are however limited in effectiveness and have a number of drawbacks including reduction of the APH performance resulting in lower energy recovery.

avoidance

The above solutions are only moderately effective at acid condensation avoidance but do reduce the overall effectiveness of the APH through reduction of the Log Meant Temperature Difference (LMTD). Furthermore, even with the use of a CABP and/or HAR, most operators lose a number of operational days per year where cold conditions dictate that the APH needs to be fully bypassed to avoid acid condensation damage. The costs of lost days of recovery is often not calculated and comes as an unforeseen additional production cost. Heat Pipe Air Pre-Heater Characteristics Photos: Above Right: This shows a 2019 replacement of a failed DEKA APH with a custom built 15 MBTU HP-APH. The HP-APH in this case features vertically orientated heat pipes with a cross-flow configuration. Above Left: This shows a 2019 replacement of a failed plate & frame APH with a custom build 26 MBTU HP-APH. The HP-APH is configured as 3 identical modules shipped separately to site. The use of horizontally orientated heat pipes enabled the air and flue gas connections to align with the existing locations and minimise changes.

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The HP-APH utilises as its heat transfer mechanism an array of heat pipes arranged in the hot and cold stream flows. Each individual heat pipe within the HPAPH effectively acts as an independent selfcontained heat exchanger in its own right, this characteristic is extremely advantageous in that it creates significant multiple redundancy in the unit and addresses a key vulnerability in conventional APH equipment. The table on the following page outlines the known issues with conventional APH equipment and how they are addressed in the HP-APH:


Conventional Air Pre-Heater

Heat Pipe Air Pre-Heater

Issue

Cause

Differentiator

Beneficial Effect

Acid condensation formation

Acid condensation formation Difficult to achieve even temperature distribution in large APH equipment. This invariably leads to “cold corners” where localised acid condensation can occur.

By the laws of thermodynamics Heat Pipes are inherently Iso-Thermal. This property eliminates the possibility of “cold corners” and hence unexpected acid condensation formation.

By the laws of thermodynamics Heat Pipes are inherently Iso-Thermal. This property eliminates the possibility of “cold corners” and hence unexpected acid condensation formation.

Low minimum metal temperatures

The minimum metal temperatures in the conventional APH are largely a function of the ambient air temperature and the flue gas exit temperature. Whilst this can be calculated in practice because of the uneven temperature distribution throughout the unit it is unlikely to be accurate.

The heat pipe working temperature is not a simple average of ambient temperature and flue gas exit temperature. Through design this can be elevated significantly above the average of ambient and flue gas exit temperatures.

An elevated and known minimum metal temperature is advantageous in avoiding flue gas acid condensation. It also enables increased heat recovery by permitting lower flue gas exit temperatures. Use of CABP can be reduced or even avoided.

Vulnerability

Conventional APH equipment relies on thin metal surfaces to effect good heat transfer. There is an inverse relationship between heat transfer surface thickness and heat transfer coefficient. This creates conflicting requirements in that increased metal thickness is required for corrosion allowance but this has the effect of reducing heat transfer effectiveness.

The heat transfer coefficient of the heat pipe is less affected by the tube wall thickness than in conventional heat transfer.

Generally thicker material thicknesses can be used in the heat pipes Thus providing increased corrosion allowance.

Material Selection

Conventional APH construction does not readily accommodate mixed materials. The option of utilising Stainless Steel in the areas where acid condensation is most likely is generally not available. To build a large APH wholly in stainless steel is cost prohibitive.

As each heat pipe is independent it is possible to utilise SS material in only the colder end of the APH and non alloy steel grades elsewhere.

The mixed material approach combines cost effectiveness and additional protection.

Resilience

A corrosion failure in a conventional APH will result in immediate leakage and eventual withdrawal from service.

Each heat pipe is independent and self-contained. In the event of a pipe wall failure there will be no leakage as the pipe will still remain sealed in the tube plate.

The impact of individual heat pipe failure is minimised.

Maintenance

Conventional APH equipment is notoriously difficult to repair once corrosion damage has occurred. At end of life a whole unit replacement will be required

Heat pipes are individually replaceable.

Heat pipes are individually replaceable. Whole unit replacement is avoided as individual heat pipes can be changed on site without the need to uninstall the unit.

Control

It is not practical to measure the true minimum metal temperature in a conventional APH due to uneven temperature distribution. The protection against acid dew point condensation therefore relies on calculations of ambient air temperature and flue gas exit temperature rather than on real time measurements.

Within the HP-APH the precise locations of coldest spots are known through design. This enables real time temperature measurement of selected heat pipes in the coldest row of the APH.

The coldest pipe real time temperature can be used to control the CABP to ensure that flue gas exit is targeted to minimum acceptable temperature hence maximising heat recovery duty whilst avoiding acid condensation.

By way of simple comparison with conventional APH types it is the case that the HP-APH offers the benefit of REDUCED RISK of failure and REDUCED CONSEQUENCE of failure. Evidence of fully operational HPAPH equipment installed in the 1980’s and 90’s confirm the longevity of the HP-APH in even the most aggressive and demanding conditions. Retro-Fit Flexibility The HP-APH is available in a variety of

configurations and can be custom designed to accommodate minimum ducting changes as a retro-fit replacement for a failed or end of life conventional APH equipment. All units incorporate temperature sensing heat pipes in key locations and also feature up to 4 rows of stainless-steel heat pipes in the cold end of the units to accommodate any transient condensation during start-up and shut down conditions.

For further information or equiries, please contact: Mark Boocock econotherm (UK) Ltd E: mark.boocock@econotherm.co.uk enquiries@econotherm.co.uk W: www.econotherm.co.uk T: +44 (0)1656 658640

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NEWS - EUROPE Siemens Drives Transformation of the Mobility Industry •

Launch of Simulytic, a Siemens venture, accelerates the move to safe, autonomous mobility

World premiere of Siemens Autonomous Charging System

Partnership with Verein Sozialhelden e.V.: Siemens committed to easing use of charging infrastructure by the disabled

Siemens is official charging infrastructure partner for the Blue Lane Road at IAA Mobility 2021

#MoveToTransform campaign in Munich embodies the spirit of the IAA Mobility and shows the faces behind mobility’s transformation

For Siemens, it’s a home game of a special kind: taking as its motto #MoveToTransform, the company is exhibiting at the IAA Mobility 2021, which is being held for the first time in Munich, Bavaria’s capital and Siemens’ hometown. As a focused technology company, Siemens is presenting a holistic look at mobility for today and for the future. The focus is on how the real and digital worlds are combined in technical products and digital solutions to make industry, infrastructure and transportation more intelligent, efficient and sustainable. “The shift to e-mobility is already in full swing – with our knowhow we’re helping the automotive industry accelerate this transformation even further. Our common goal is to get electric cars on the road faster, more efficiently and more sustainably. Only with cuttingedge automation and digitalization solutions can we achieve this goal. Siemens offers a unique portfolio in this regard. I look forward to seeing many electric vehicles at the IAA Mobility that also carry a fair share of the Siemens DNA,” said Cedrik Neike, member of the Managing Board of Siemens AG and CEO of Digital Industries. Electric vehicles are charged worldwide using different, need-adapted Siemens charging solutions. However, high-performance smart grids are also essential for safe, economical and ecofriendly operation. In this regard, Siemens is contributing decades of global experience and expertise. With its diverse solutions for electromobility, the company is a strong partner for OEMs, power utilities, fleet operators, companies, cities and end customers. “Electromobility is one of the most important pillars of the postpandemic green recovery. We’re working with customers, partners and governments to ensure that the necessary charging infrastructure is in place to accelerate its success,” said Matthias Rebellius, member of the Managing Board of Siemens AG and CEO of Smart Infrastructure. “With our comprehensive portfolio, which includes hardware and software, we’re enabling charging to be seamlessly integrated into existing infrastructure. Our portfolio is complemented by our digital solutions that support energy efficiency and decarbonization.” Achieving a sustainable mobility mix is especially important for Siemens, as Karl Blaim, Managing Director of Siemens Mobility, emphasized: “Urbanization is causing the volume of traffic to continue to rise, and at the same time we aim to greatly reduce CO2 emissions. For this reason, it’s important to intelligently connect means of transportation. Road and rail are seamlessly interconnected, and rail, as the most sustainable means of transport, will form the backbone of mobility in the future. Using digital technologies, Siemens Mobility is increasing the capacity, efficiency and comfort of rail, intelligent Mobility-as-a-Service solutions are seamlessly connecting rail services with other means of transport, and hydrogen and battery-powered trains are rounding off carbon-neutral rail transport where electric overhead lines are not viable.” Simulation startup Simulytic opens up new business fields Driven by disruptive technologies, the mobility sector is changing at a faster pace than ever before. Contributing to this trend, the Munichbased technology company is presenting Simulytic, a newly founded Siemens venture, at the IAA Mobility. The in-house startup, headed by

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Andrea Kollmorgen, is focused on accelerating autonomous mobility deployment at scale. Simulytic aims to use simulation to create insight into the impact and safety of autonomous driving. Specifically, the goal is to ensure that transparency is a permanent part of the risk profiles of self-driving vehicles everywhere. Simulytic is already applying Siemens’ expertise here in the simulation of complex, automated systems and in the use of artificial intelligence in safety-critical applications. Its command of the technologies used in autonomous vehicles enables the venture to make competitive, comprehensive and independent assessments of incident probabilities, changing traffic flows and congestion patterns, the effects of weather and road conditions, and many other localized factors. Drawing on this expertise, Simulytic creates added value for customers, such as insurance companies, by helping them understand the risk potentials from increasingly automated road traffic and thus develop the right products, determine fair prices and create effective business strategies for a future with autonomous vehicles. Automation eases access to charging Siemens is developing answers to the many questions raised by the increasing automation of the mobility industry. For example, who will plug in the charger when an autonomous car has found an available space on its own? Along with its comprehensive product portfolio for charging infrastructure, Siemens is also presenting its latest innovations for charging all types of electric vehicles. These innovations include the Siemens Autonomous Charging System, which enables the fully automated charging of electric vehicles from sports cars to long-haul trucks. The prototype being presented for the first time at the IAA Mobility has a charging capacity of up to 300 kW and will be increased to over 1 MW in a further development stage. With this high capacity, electric trucks can be charged during the driver’s mandatory break time. However, the necessary charging cables are too heavy for people to plug in by themselves. To master this challenge as well, a robot designed by Siemens can handle the difficult task of charging heavy-load vehicles. To test the Siemens Autonomous Charging System under real life conditions and complete its development, Siemens is working with Einride AB, a leading developer of autonomous and electric transport systems. As part of this test, an autonomous truck was, for the first time, supplied with power by an autonomous fast-charging system. Other applications for the new charging system are also conceivable: the Siemens Autonomous Charging System can also manage the charging process for people with physical limitations. Siemens drives development of inclusive infrastructures The vision of autonomous and electric driving has great potential for enabling more inclusive mobility. At present, however, there are scarcely any requirements or standards – such as specifications in tenders to expand the charging infrastructure – that would help people with restricted mobility operate and charge electric vehicles. Verein Sozialhelden e.V. (a public-service association) and Siemens are working together on this issue and meeting for a workshop during the IAA. As part of its campaign, Siemens is also cooperating with the prominent activist Raul Krauthausen, who has worked for years with his Verein Sozialhelden e.V. to promote barrier-free mobility. Digital enterprise for the automotive industry Siemens offers a comprehensive portfolio of solutions consisting of industrial software, automation and services adapted to the specific requirements of the automotive industry. This portfolio combines the real and digital worlds. The solutions provide manufacturers with the flexibility and efficiency needed to sustainably meet increasingly diverse customer needs and the growing demand for e-cars. In particular, the creation of digital twins in the automotive industry offers tangible benefits: it can significantly reduce the number of prototypes needed during the development of a car. In addition, the use of production data increases quality by identifying and eliminating potential quality problems at an early stage. •


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NEWS - EUROPE Eni and the IRENA Launch a Partnership to Accelerate the Energy Transition Eni and the International Renewable Energy Agency (IRENA) have entered a three-year partnership agreement to collaborate in the promotion of renewable energy and accelerate the energy transition, particularly in countries that export fossil fuels. The agreement has been signed by Eni’s Chief Executive Officer, Claudio Descalzi, and IRENA’s General Director, Francesco La Camera, at a time when Milan is hosting the “Pre-COP 26” preparatory ministerial meeting. Under the terms of the agreement, Eni and IRENA will work together to foster dialogue and share their experiences on accelerating energy transition and renewable energy development in fossil fuel exporting countries, as well as to identify barriers to private sector investment in renewable energy in countries where Eni operates and promote solutions in coordination with governments. In particular, Eni and IRENA will promote the integration of the African continent into the biofuel value chain through institutional capacity building, agribusiness and industrial development initiatives aimed at the production of advanced biofuels, helping the decarbonization of the transport sector and promoting development opportunities. The partnership builds upon Eni’s commitment to contribute to the decarbonization of African countries’ energy mix, leveraging renewable energy sources to reduce the use of fossil fuels in power generation. Also, it represents an opportunity for Eni to strengthen the dialogue with IRENA, share its expertise and portfolio of technology solutions, enhance its international role as a leader in the energy transition, and actively contribute to the institutional debate on energy policies that the agency promotes. Eni’s Chief Executive Officer, Claudio Descalzi, said: “The agreement with IRENA is a step forward Eni’s pledge to reach net zero by 2050, as it leverages renewables and other technological and industrial solutions to successfully face the energy transition. We have designed Eni’s evolution in the coming years by combining the objectives of a continuous development in a rapidly evolving energy market with a significant reduction in the carbon footprint of our portfolio. Today’s alliance can boost this process, just as we will be able to make our contribution in terms of know-how and commitment.” IRENA’s General Director, Francesco La Camera, said: “We have reached a critical moment in the energy transition, one that requires the commitment and active participation of energy actors from across the spectrum. It is in the interests of big oil companies and fossil fuel exporting nations to embrace the transition and seek a leadership position in it. The partnership between Eni and IRENA will reinforce our common efforts to advance the low-carbon agenda in the decade of action.” •

Subsea 7 Announces Floating Wind Acquisition Subsea 7 announced that it has entered into an agreement to acquire a majority interest in the equity of Nautilus Floating Solutions S.L. a developer of technology for the floating wind market based in Bilbao, Spain. Nautilus has developed a promising concept for a floating wind foundation based on a semi-submersible steel structure that supports a centrally-placed wind turbine. Subsea 7 will provide technical expertise, and engineering and project management capabilities, to support the advancement of this design and it is envisaged that the concept will be included in tenders for demonstrator or pilot projects in 2021 and beyond. Subsea 7 will acquire a controlling interest of 59.12% in Nautilus and will assume four of the seven positions on Nautilus’ Board of Directors. Tecnalia, the leading Research and Technological Development Centre in Europe and Vicinay, a world class design, manufacturer, and supplier of mooring systems for the Oil & Gas and Floating Wind industries, will remain shareholders of Nautilus with equity interests of 29.14% and 11.74% respectively. Nautilus will remain an autonomous company with strong roots in the Basque Country of Spain, teaming with its network of regional, national and international partners. It will benefit from the support of Subsea 7 in various upcoming bids with key clients in the floating wind industry. While actively supporting the further development of the Nautilus concept, Subsea 7 will also continue to engage with other technology providers to support client, regional or supply chain specificities. Subsea 7 and Nautilus will collaborate closely with Seaway 7 ASA (the recently announced combination of Subsea 7’s fixed wind activities and OHT ASA) to ensure aligned client engagement and that the capabilities within the broader group are fully leveraged. John Evans, Chief Executive Officer, Subsea 7 commented: “The agreement with Nautilus represents an exciting opportunity for Subsea 7 to further our involvement in the technology being developed for the floating wind market. Involvement at an early stage allows the development of this concept to benefit from our technical know-how, experience in delivering EPCI projects, and to maximise the value creation opportunity for our clients and shareholders. Following the agreements with OHT ASA in offshore fixed wind, and with Simply Blue Energy in floating wind, this is another step in the realisation of the Group’s strategy to proactively participate in the Energy Transition.” •

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NEWS - EUROPE Neptune Energy Carries Out First Walk to Work Campaign at Cygnus Gas Field Neptune Energy today announced the start of the first Walk to Work (W2W) campaign at its operated Cygnus gas field in the UK Southern North Sea. A programme of brownfield modifications, maintenance and inspection activities will be supported by Bibby Marine’s WaveMaster 1 vessel, reducing time, costs and environmental impacts. The vessel is equipped with a ‘motion-compensated transfer gangway’, enabling crews to safely walk between the vessel and the Cygnus Bravo platform. It is an efficient and less carbon-intensive means of accommodating the 50 personnel carrying out the work, in comparison with carrying out multiple helicopter flights to and from shore. The W2W campaign at Cygnus Bravo, which is usually unmanned, will also increase productive time allowing for additional operations to be undertaken that would have otherwise been scheduled separately. Neptune Energy’s Managing Director for the UK, Alexandra Thomas, said: “Partnering with Bibby Marine on our first W2W campaign, we believe this approach could be very effective for the Cygnus field and provide significant efficiency and environmental benefits. This will enable us to consider alternative execution strategies for extended shutdowns, intensive fabric maintenance or inspection programmes in the future.” Bibby Marine’s Commercial and Client Manager Mark Whitehead said “We have been assisting Neptune Energy with their planning for this project for a number of months and are pleased we have now arrived at the platform and the project has commenced. “Bibby WaveMaster 1 and her crew have extensive experience on campaigns like this, and the vessel itself is very capable of working in this sector of the North Sea across all seasons having completed over 10,000 gangway connections and transferred over 60,000 people. •

Neptune Energy Installs World’s Longest ETH Production Pipeline Neptune Energy announced the safe and successful installation and testing of the world’s longest trace-heated subsea production pipeline at its operated Fenja field in the Norwegian sea. The 37 kilometre electrically trace-heated (ETH) pipe-in-pipe solution will transport oil from the field to the Njord A platform, operated by Equinor. The innovative use of the ETH pipe-in-pipe significantly reduced the potential cost of the development by enabling the field to be tied back to existing infrastructure. Neptune Energy’s Director of Projects and Engineering in Norway, Erik Oppedal, said: “Completing the installation and testing of the ETH pipe is a great technical achievement and a major step forward in the development of the Fenja field. The ETH pipe-in-pipe solution is crucial for extracting the oil, and is a creative, cost-effective approach that permitted us to tie the field back to existing infrastructure. “Norway is an important part of Neptune’s geographically-diverse portfolio and this is an excellent example of the company’s commitment to investing in the region and adopting advanced technologies to overcome challenges.” The ETH pipeline was developed and qualified through a collaborative approach with TechnipFMC. Due to the high wax content of the Fenja field’s oil, the contents of the pipeline must be warmed to a temperature above 28-degrees Celsius before starting the flow after a scheduled shut down or interruption. During normal production, the temperature in the pipeline would be well above this temperature. The offshore installation was carried out across two subsea campaigns in 2020 and 2021 by TechnipFMC’s vessel, approximately 120 kilometres north of Kristiansund, Norway, at a water depth of about 320 metres. •

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Increasing Gas Exports to Supply Tight European Market Equinor and its partners have received permission to increase gas exports from two fields on the the Norwegian continental shelf to supply the tight European market. Production permits for the Oseberg and Troll fields have each been increased by 1 billion cubic meters (bcm) for the gas year starting 1 October. Already in June, Equinor took steps to evaluate and develop concepts for enhancing the production and exports to the European market. This work resulted in enhanced production permits from the Ministry of Petroleum and Energy for the Oseberg and Troll fields. Specifically, Equinor and its partners have received production permits for the gas year 2021 (starting 1 October) which for each is 1 bcm higher than for the current year, i.e. an increase from 5 bcm to 6 bcm for Oseberg and from 36 bcm to 37 bcm for Troll. “The production permits allow us to produce more gas from these two important fields this fall and through the winter. We believe that this is very timely as Europe is facing an unusually tight market for natural gas. At Equinor we are working on measures to increase exports from our fields on the NCS,” says Helge Haugane, senior vice president Gas & Power. Ramping up at Troll After 25 years of significant gas exports from Troll, around 50% of the gas is left in the ground. To further develop the Troll-area and reinforce our ability to secure gas deliveries to Europe in the coming decades, Equinor has recently completed the Troll Phase 3 project. Recoverable volumes from Troll phase 3, which will produce the Troll West gas cap with industry leading low CO2 emissions, are estimated at as much as 347 billion standard cubic metres of gas. Total recoverable gas volume remaining in Troll is estimated to be 715 billion standard cubic metres. “Now we are ramping up production at Troll following the completion of the Phase 3 project, and we expect to reach plateau production from 1 October. We take pride in being a long-term, reliable supplier of energy and we are happy that we have been able to identify ways to export as much as practically possible into this tight market,” says Helge Haugane.•


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EUROPE - NEWS Western Desert Assets in Egypt Sold to Cheiron Petroleum Corporation and Cairn Energy PLC The sale was announced on 9 March 2021 and the transaction’s effective date is 1 January 2020. Completion follows receipt of all necessary regulatory approvals. With this transaction Shell is refocusing its business in Egypt on our existing infrastructure position in the West Delta Deep Marine (WDDM), the Harmattan Deep Project and Exploration acreage in the new seven blocks in the Nile Delta, West Mediterranean and the Red Sea; in Midstream through our Egyptian LNG (ELNG) joint-venture; and in Downstream through Shell Lubricants Egypt (SLE). Shell has been active in Egypt for 110 years and remains a leading player in country.

The Lower-Cost Subsea Development will Supply the Nation’s Gas-Based Industries The lower-cost subsea development will supply the nation’s gas-based industries bp Trinidad and Tobago’s (bpTT) Matapal subsea gas development has safely achieved first gas seven months ahead of schedule and under budget, despite constraints brought about by the COVID-19 pandemic. Initially, Matapal is expected to deliver 250-350 million standard cubic feet per day (mmscfd) into the Trinidad gas market from resources discovered by the Savannah exploration well drilled in 2017. Gas from this project will be pooled with production from other bp fields to be used as feedstock for the country’s ammonia, methanol and LNG plants, as well as for power generation. bpTT president Claire Fitzpatrick said: “Natural gas will play an important role in the energy transition and to the economy of Trinidad and Tobago for decades to come. This is why our team at bpTT has worked diligently to safely start up our Matapal project, which we successfully achieved both under budget and ahead of schedule. We are committed to a strong energy future in Trinidad and Tobago and this project plays a critical role in delivering that.” bpTT’s second subsea development, Matapal is a three-well subsea tieback to  the existing Juniper platform, helping to minimize development costs and the associated carbon footprint. It is located 80km off Trinidad’s south-east coast, 8km east of Juniper, and in a water depth of 163 metres. With 15 offshore production platforms, bpTT is the country’s largest hydrocarbon producer, accounting for about half of the nation’s gas production.

OKEA Awards Integrated EPCI Contract for Hasselmus Field OKEA 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.”

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NEWS - ASIA PACIFIC PETRONAS Signed Two New Small Field Asset (SFA) Production Sharing Contracts (PSCs) PETRONAS has signed two new Small Field Asset (SFA) Production Sharing Contracts (PSCs) with Rex International Holding Limited (Rex) and Duta Marine Sdn Bhd (Duta Marine) for the Rhu-Ara and Diwangsa clusters offshore Peninsular Malaysia. The award of these PSCs marks Rex’s maiden entry into Malaysia’s upstream industry, in partnership with local company Duta Marine. Rex holds 95 per cent participating interest with Duta Marine holding the remaining five per cent in both PSCs. Rex brings to the table significant operating experience and expertise in developing and producing small oil fields in the Middle East as well as participation in joint ventures in the North Sea. The fields were offered during the Malaysia Bid Round 2020 (MBR 2020) based on the SFA fiscal terms introduced in the same year that intensifies PETRONAS’ commitment to monetising small discovered resource opportunities in Malaysian waters. The Rhu-Ara Cluster, consisting of Rhu and Ara fields, lies within the Penyu Basin 150km off the coast of oil centre Kerteh, Terengganu. The Diwangsa Cluster, which lies in the northwestern side of the Malay Basin, comprises Diwangsa, Bubu, Korbu and Lerek fields. These previously discovered fields have total estimated recoverables of 12.7 MMstb for the Rhu-Ara Cluster and 10.7 MMstb for the Diwangsa Cluster. Both clusters are now primed for development under the SFA PSC terms which incorporates a simplified fiscal model and governance process. A virtual ceremony was held to commemorate the signing of the two SFA PSCs. PETRONAS was represented by its Senior Vice President of Malaysia Petroleum Management (MPM), Mohamed Firouz Asnan, while Rex and Duta Marine were represented by their Executive Chairman, Dan Broström and Director, Mahyudden Abdul Wahab, respectively. Mohamed Firouz said, “We believe that Rex’s proven capability in developing small fields abroad could be deployed in the Rhu Ara fields to unlock the potential in the Penyu Basin followed by the development of Diwangsa Cluster. “We welcome new players who can deliver innovative solutions to ensure the lowest total life cycle cost in developing the discovered resources opportunities available in Malaysia waters. We are pleased to see that the SFA terms have become more attractive to the investors, thus validating the efforts taken to turn Malaysia into a growth hub for the investors.” Apart from a host of small fields, a significant potential in the form of large opportunities lies in the shallow and deepwater fields in Malaysia. Potential investors seeking to invest in Malaysia’s E&P sector can participate in the annual Malaysia Bid Rounds. For more information on opportunities in Malaysia, please visit https://www.petronas.com/ mpm/. •

Petroleum Secretary Flags Off Production From ONGC Deepwater Gas Well Secretary, Ministry of Petroleum and Natural Gas (MoPNG), Mr. Tarun Kapoor flagged off maiden production from the deep-water gas well U1B of Oil and Natural Gas Corporation Limited (ONGC). The gas well, located in KG-DWN 98/2 Block Cluster – II, has an estimated peak production of 1.2 million metric standard cubic meters per day (MMSCMD). It is the deepest well of the Cluster. The event was graced by the presence of ONGC CMD Subhash Kumar, Additional Secretary (Exploration) Mr. Amar Nath, Additional Secretary & Financial Advisor Mr. Rajesh Agarwal, ONGC Director (Exploration) Mr. R K Srivastava and ONGC OSD-Offshore Mr. Pankaj Kumar. Dedicating the gas well to the nation, Mr Kapoor congratulated Team ONGC led by the CMD and lauded the dedication of the Energy Maharatna towards production enhancement of Oil and Gas for the nation. He said that the extensive experience of ONGC in Exploration and Production brings confidence in the successful operation of the deep-water gas well. Expressing that there is a lot of production potential in deep-water wells, the Petroleum Secretary said this monetization holds special national significance as the first priority of the government is to ensure enhancement of domestic production and reduction of Oil and Gas imports. Mr Kapoor said that we look forward to production enhancement, especially from ONGC, and expressed hope for monetization of many more such wells in the near future. The ONGC senior officers from Kakinada in Andhra Pradesh presented the technical details of the production from the deep-water well. Speaking on the occasion, Additional Secretary and Financial Advisor Mr. Rajesh Agarwal complimented ONGC for the monetization of the deep-water gas well and said that the dedication of the Energy Soldiers of ONGC has resulted in the achievement. Expressing gratitude for the continued support of senior Ministry officials, ONGC CMD Subhash Kumar thanked the Ministry, who were instrumental in the run up to the nationally important occasion today. •

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NEWS - ASIA PACIFIC Prompt Action by ONGC and Coast Guard Averts Mishap of LPG Tanker A prompt action by Oil and Natural Gas Corporation Limited(ONGC) and Coast Guard averted a possible disaster relating to an empty LPG Tanker ‘Gas Yodla’ on the Arabian Sea. Early morning on that day, the LPG tanker reported engine failure and started drifting in the Sea, around 20 nautical miles (nm) from ONGC’s D1 field. The vessel is owned by M/s Shield Marine, headquartered at Dubai, UAE. The vessel was on its way to Fujairah, UAE from Mongla, Bangladesh. 17 people were onboard the vessel, including eight Indians and nine Ukrainians. After the first information was reported by ODAG, ONGC promptly diverted its Offshore Supply Vessel (OSV) ‘Sagar Pride’ and ODAG mobilized its Vessel ‘P R Nayak’ to support the drifting vessel. The efforts succeeded in assisting the distressed vessel and also helped keeping it away from ONGC’s operational area. ONGC also withdrew one of its Multi Supply Vessel (MSV) ‘Seamec-3’ and tugboat ‘Saroja Blessing’ from assigned duties and diverted those towards the drifting vessel. ‘Water Lilly’ tugboat from DG shipping also joined ONGC’s vessels. The path of the vessel was closely monitored to ensure safety of the passengers onboard and ONGC installations. By 10 PM on that day, the vessel cleared the south of the D1 field at 15 nm, but was still drifting at 1.5-2 nm per hour. ONGC remained in constant coordination with DG Shipping, Coast Guard and ODAG to ensure that the vessel remain at a safe distance from ONGC fields. Coast Guard Ship ‘Sankalp’ approached the adrift vessel by the morning of next day, and took over as on-scene commander – from ODAG Vessel ‘P R Nayak’. The crew then successfully repaired the engine of MV Gas Yodla, and started its emergency generator by early morning next day. MV ‘Garnet’ was then arranged by the owners for bunker support. Subsequent to conversation with the Coast Guard, the captain of the vessel agreed to it being towed. The vessel was secured to DG Shipping Tug ‘Water Lilly’. As the tow line of ‘Water Lilly’ parted, ONGC immediately deployed ‘Sagar Pride’ which towed the vessel to safety. •

PetroChina’s Ethane-to-Ethylene Project put into Operation The Changqing Ethane-to-Ethylene Project undertaken by the PetroChina Lanzhou Petrochemical Company started production, and produced up-to-standard ethylene products. Located in Yulin City, Shaanxi Province, the project comprises an 800Kt/a ethaneethylene cracker, a 400Kt/a high-density polyethylene (HDPE) plant and a 400Kt/a full density polyethylene (FDPE) plant as well as other utilities and supporting auxiliaries. The project will play a positive role in driving regional economic growth and accelerating development in northern Shaanxi. The project highlights green and low-carbon concepts. Novel flue gas denitration technology is adopted, to reduce nitrogen oxides emissions by 70% compared with conventional cracking furnace and achieve ultra-low exhaust gas emissions. Catalytic oxidation is introduced for waste alkali treatment, along with ultrafiltration + reverse osmosis and evaporative crystallization for deep recycling of wastewater, with a reuse rate over 95%. Moreover, by leveraging cutting-edge information technologies such as big data and cloud computing, the project has been built into a “smart factory”, which integrates production scheduling, electromechanical instrument management and control, and emergency command. It is listed by the National Development and Reform Commission (NDRC) and the Ministry of Industry and Information Technology (MIIT) as a national demonstration project for producing ethylene via the cracking of ethane. •

Tarim Oilfield Natural Gas Ethane Recovery Project put into Operation The ethane recovery project from natural gas in PetroChina Tarim Oilfield was successfully put into operation, and yielded qualified ethane products. The natural gas ethane recovery project is designed to process 10 billion cubic meters of natural gas per year, with an annual output of 762,000 tons of ethane, 366,000 tons of LPG and 75,000 tons of stable light hydrocarbons. The project is an expansion to Tarim Oilfield’s on-stream units — deep recovery of light hydrocarbons from condensate gas. The high-quality ethane produced will feed downstream ethylene projects for deep utilization of natural gas resources. •

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NEWS - NORTH AMERICA BOEM Announces Oil and Gas Lease Sale for Gulf of Mexico The Bureau of Ocean Energy Management (BOEM) announced that it will hold an oil and gas lease sale for the Gulf of Mexico, in compliance with an order from a U.S. District Court. The Biden Harris Administration is continuing its comprehensive review of the deficiencies associated with its offshore and onshore oil and gas leasing programs. Lease Sale 257, scheduled to be livestreamed from New Orleans, will be the eighth offshore sale under the 2017-2022 Outer Continental Shelf (OCS) Oil and Gas Leasing Program. Lease Sale 257 will include approximately 15,135 unleased blocks located from 3 to 231 miles offshore in the Gulf of Mexico with water depths ranging from 9 to more than 11,115 feet (3 to 3,400 meters). Among the blocks excluded from the lease sale are the blocks subject to the congressional moratorium established by the Gulf of Mexico Energy Security Act of 2006; blocks adjacent to or beyond the U.S. Exclusive Economic Zone in the area known as the northern portion of the Eastern Gap; and whole blocks and partial blocks within the boundaries of the Flower Garden Banks National Marine Sanctuary as of the July 2008 Memorandum on Withdrawal of Certain Areas of U.S. OCS from Leasing Disposition. The Gulf of Mexico OCS, covering about 160 million acres, is estimated to contain about 48 billion barrels of undiscovered technically recoverable oil and 141 trillion cubic feet of undiscovered technically recoverable gas. BOEM will include lease stipulations to protect biologically sensitive resources, mitigate potential adverse effects on protected species, and avoid potential conflicts between oil and gas development and other activities and users in the Gulf of Mexico. Fiscal terms include a 12.5% royalty rate for leases in less than 200 meters of water depth and a royalty rate of 18.75% for all other leases issued pursuant to the sale. All other terms and conditions are detailed in the Final Notice of Sale (FNOS) information package, which is available at www.boem.gov/sale-257. Of note, BOEM will be accepting bids by mail only for Sale 257. Walk-in delivery of bids will not be permitted for this sale. BOEM reserves the right to reject bids received. The stipulation that was added for Lease Sale 256 last year specifying the time frame for decisions on an Application for Permit to Drill (APD) and an Application for Permit to Modify (APM) is not included for Lease Sale 257 because it is not needed. The Notice of Availability of the FNOS is available for public inspection in the Federal Register. Copies of Sale 257 maps can be obtained by contacting the BOEM Gulf of Mexico Region public information office at 1201 Elmwood Park Blvd. New Orleans, LA 70123-2394 or by calling 1-800-200-GULF. •

STATS Simultaneously Supports Six North Sea Pipeline Shutdown Projects STATS has successfully completed the largest number of simultaneous pipeline isolation projects in its 23 year history. During the 2021 summer shutdown season, STATS supported six separate Tecno Plug isolation deployments in the UK North Sea, on pipelines ranging from 20” to 36” in diameter. The projects were on critical pipeline systems on behalf of multiple clients, with the isolation periods ranging from 10 to 45 days. Isolation activities were carried out on and offshore at various locations and included the use of STATS Remote Monitoring System, which allowed Tecno Plug isolation tools to be monitored continuously via satellite from STATS Remote Monitoring Centre in Kintore, Aberdeenshire. The satellite monitoring technology enables customers to reduce site Personnel on Board (POB) requirements on their oil and gas installations during breaking of containment activities, whilst still ensuring that the isolation status is continually monitored. The majority of Tecno Plugs deployed as part of the shutdown campaigns incorporated Leak Test Modules, which allowed Operators to perform reinstatement testing of new valves and pipework without disturbing the integrity of line isolations. Each isolation scope was carried out with design, manufacturing, testing and project support being provided locally from STATS Group’s Kintore headquarters. Factory Acceptance Testing was also live streamed remotely to clients, ensuring the client had full participation and oversight during the testing phase, despite the logistical restrictions necessitated by the Covid-19 pandemic. The summer shutdown period saw a surge in demand for STATS Process Plant Solutions which supported both North Sea and international clients with the provision of vapour barrier and localised weld testing services, with many requirements being delivered in quick turnaround times, due to the inevitability of unforeseen scopes that appear. In addition, STATS worked closely with multiple North Sea Operators in the manufacture and installation of its Topside Mechanical Pipe Connectors. These units were provided in sizes ranging from 2” to 20” as a safe and permanent cold-work solution, removing the associated risks of welding and were installed on several key platform systems, including instrument air, diesel and the larger of the units on flare systems. STATS Group sales director, Ron James, said: “This has been our busiest period in terms of simultaneous isolation workscopes, but careful planning meant we were able to build and test in advance the necessary tools and equipment, so that everything was in place to be deployed during the optimum shutdown window. “Our Remote Monitoring Centre means we are able to reduce the number of personnel on board an installation during the length of the shutdown - thereby offering cost savings to our clients, while maintaining the highest level of safety monitoring.” •

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EXPLORATION & PRODUCTION

Experienced Danish Worldwide Service Supplier Consolidates Its Activities on the Global Offshore Market Danish VMS Group is on the verge of a new entry to the global offshore market. With a wide range of service being offered, a long-lasting experience, and a firm strategy, VMS Group will become an even more considerable player in the field of offshore rig, drilling, and service fleet services.

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The VMS International Team.

randing itself as “The World’s Best Alternative” VMS Group is well known as an independent service supplier, providing its services to the international maritime and oil and gas industry for two decades. VMS Group has well-equipped and up-to-date workshop facilities in Denmark, Namibia and Brazil. Combined, these facilities form a strong unit offering services no matter where assistance is required. High quality, flexibility and reliability are the keywords under which VMS Group operates. Now, with a consolidation and expansion of their already existing activities, VMS Group is ready to take another step into the global offshore market. Headquartered in Frederikshavn and with subsidiaries in Brazil and Namibia, VMS Group offers highly skilled international teams around the globe, ready to take on the tasks either onsite or at one of the well-equipped workshops owned by VMS Group. VMS Group covers a wide range of competencies, sales, and services within the maritime and offshore industries, all brought together in one complete solution. The core services include: Repair maintenance of gear, propeller, and diesel

and

engines. Repair, maintenance and balancing of turbochargers for marine engines. Sale of spare parts, engines, and gears. Ship design and project management. All engine types With 280 employees worldwide VMS Group has the capacity to always being able to put together an international team of highly skilled staff for any task, regardless when

and where it is needed. From the company’s positions in Brazil, Namibia and Denmark, VMS Group covers the Americas, Africa, and Europe, but beyond that, there is always a team ready to travel to any conceivable destination around the globe. The service engineers from VMS Group are specialized in all engine types, e.g., Himsen, Rolls Royce/Bergen, Caterpillar, Wärtsila, Yanmar, Wabtec and MAN. For every task it is made sure that all of VMS Group’s competencies are drawn upon: Ranging from sales over project planning and design, to engineering services. This ensures that VMS Group has both the skills and the capacity to compete with even the biggest competitors on the market. Recognized service provider For the last couple of years VMS Group has been appointed to carry out the engine service on the rigs of one of the world’s largest offshore drilling contractors, located off the coast of West Africa. Combined with a strong network in the business and a long-lasting experience, VMS Group is already a recognized service provider to the offshore market and has in recent years further consolidated itself in the offshore market as part of the company’s strategy.

Propeller Workshop.


“Expanding our activities in the offshore market is an important part of our strategic objective, not least in these years when the offshore market is facing recovery and new growth. Our aim is to become an even stronger player in the field of service within the global offshore market, where we see a huge potential and already have established contact with the major companies”, says Kristian Kaasing Larsen, CCO of VMS Group. He mentions Aberdeen and Houston as places of particular interest and strategic relevance. “Since we are already located in Rio de Janeiro, Brazil and Frederikshavn, Denmark, our service engineers will have easy access to these locations”, says Kristian Kaasing Larsen. International teams For tasks being performed in North or South America, the team of service engineers will be recruited from the Brazilian subsidiary, VMS do Brasil, situated near the harbour of Niterói in Rio de Janeiro. With a staff of Danish and Brazilian service engineers and project managers, VMS do Brasil offers service, repair and maintenance of offshore installations, power plants and ships in the all-American area. “Our international teams are all highly skilled and highly motivated, with a high level of work ethics, all competencies that are sought-after in the market”, says Kristian Kaasing Larsen. The well-equipped workshop in Brazil holds all the necessary equipment for maintenance of all brands and types of medium and high-speed marine engines. In addition, the necessary equipment for maintenance of all Caterpillar engines is held at the workshop in Rio de Janeiro. “Also, in Brazil we are the only workshop servicing Himsen engines”, says Kristian Kaasing Larsen. Port of the future For tasks being carried out in or around European waters the staff will be recruited from the service base in the port of Frederikshavn

situated in the northern part of Denmark. The port of Frederikshavn One is one of the most important commercial ports in Denmark and the port of the future, undergoing an ongoing expansion over the years with more and deeper harbour basins, more quays, wider entrance, and significant extended hinterland areas, making it possible to strengthen business areas like, for example, the offshore industry. The Port of Frederikshavn offers 11 meters in water depth, prepared for 14 meters, which makes it possible for ships in the Panamax category, as well as both jack-up platforms and semi-submersible platforms to call at the port. Specialized in spare parts At the VMS service base Frederikshavn there is approx. 4,000 m2 under roof, covering a marine workshop, machine workshop and turbo workshop. Storage facilities alone cover

VMS Group offers services within the field of: • Design, engineering, project management. • Diesel engine, turbo, propeller and power maintenance and repair. • Repair and maintenance of thrusters, gears and pumps. • Shaft repair and service. • Machining services. • Propulsion equipment. • Constructions, welding, and steel work. • Hydraulic and mechanical systems. • Test facilities. • Spare parts, original and reconditioned.

approx. 1,000 m2 with a working height of 8 meters and a Paternoster automated storage system to ensure high efficiency. With a global network of manufacturers and traders VMS Group is able to find almost any requested item or spare part and also offers an extensive stock of reconditioned marine parts. “We specialize in supplying original spare parts for diesel engines and strive for excellence with high quality products at competitive prices with reliability of fast delivery. Our dedicated staff has an extensive technical knowledge and many years’ experience in advising on spare parts. Our global network of manufacturers and traders enables us to find almost any requested item, even if your requirement is not a part of our standard product range. As an alternative, we can supply high-quality spare parts from the best OEM makers in Europe with a guarantee”, says Kristian Kaasing Larsen. Among the first-class manufacturers that VMS Group distributes is YANMAR and Wabtec medium-speed and high-speed marine engines and customized gensets. • VMS Group A/S T: +45 9622 1100 E: vms@vms.dk W: https://www.vms.dk

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EXPLORATION & PRODUCTION

Subseatec Continues Its Journey Towards Increased Sustainability Most industries are facing a transition towards more sustainable operations. With our DNA from both the steel and energy industries, Subseatec sees great opportunities in delivering engineering solutions that allows steel to play a bigger role in this change.

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he oil and gas industry has been one of the main drivers to develop and use advanced steel products and has forced the steel industry and product suppliers like Subseatec to challenge what is considered possible.

Photo: Subseatec CWOR joints.

Peter Jansson, Managing Director and head of material and method development at Subseatec.

The recent developments in the High PressureHigh Temperature (HPHT) field are just one example. In this area, Subseatec has been challenged by oil companies and OEMs to develop products with strength, toughness, and corrosion resistance to withstand the extreme environments of HPHT wells. As a result, Subseatec has gained the knowledge and experience to deliver SCR riser parts with 100K strength, excellent toughness, and state-of-the-art surface coatings to support 30 years of operation. This technology will enable the industry to continue the development of fields that was considered impossible just a few decades ago. These advances also make it possible to use steel stress joints in applications where only titanium and flex joints were considered to offer sufficient strength – allowing the utilization of steel’s many excellent properties as construction material. A partner for the green shift The overall global effort to reduce greenhouse gas emissions is now driving investments among the major energy companies to diversify their portfolios, focusing more on renewable energy sources. This transition will force suppliers to the industry to also diversify their offerings. In Subseatec we have already started this

journey, using all the great technical achievements from the oil and gas industry as our steppingstones into a more sustainable era. “With our deep knowledge of how to utilize steel in high-pressure, high-temperature and corrosive environments, we are ready to take on the challenges presented by the green shift. Since 2009 Subseatec has started several development projects, all aiming to make our company a recognized partner and supplier in the energy transition. One promising business area identified is steel components for transportation and storage of green gases – where many of the technical challenges are like the ones found in the subsea HPHT-environments of the oil and gas industry,” Peter Jansson, managing director of Subseatec, says.

Bright future for steel Through the last decade Subseatec has been in the technological front line of the development and control of special processes in steel production and treatment. One example is the clad welding of sealing surfaces of internal bores, where the company today produces weldments close to what is theoretically possible. “The level of welding we do on the products delivered today is an engineering stunt only to be seen in areas like space technology. This is a true testament to our capabilities, reflecting the challenges Subseatec meets as a supplier to the most extreme HPHT-projects,” Jansson says. He is convinced that the continuous development of higher strength steel grades, combined with more efficient manufacturing methods, makes steel an excellent material for the future. “Higher strength grades give the possibility to reduce the weight of existing designs, which again reduce the amount of energy needed to produce parts. This, together with the ongoing transition to carbon free steel production, gives steel a huge potential to be the preferred construction material also for sustainable projects in the green transition,” Jansson underlines. • If you would like to know more about how Subseatec can help your company and its operations, please contact them at:

Subseatec riser in operation.

Subseatec T: +46 (0)70-668 29 21 E: post@subseatec.se W: www.subseatec.se


Solving subsea complexity

RISERS - SCR & TTR

PIPE & FLOW LINES

BODIES

OTHER SUBSEA

subseatec.se


EXPLORATION & PRODUCTION

Onshore Specialist Support From C-Kore Delivers Safety and Environmental Bonus for Subsea Operators Subsea oil fields account for around 30% of the total global oil production but keeping the oil flowing from fields in remote deep-water locations is no small challenge for operators. Teams of engineers both onshore and offshore work around the clock, 365 days a year to maintain the integrity of the subsea infrastructure that our energy-hungry societies depend on. As consumers in the 21st century we rightly expect them to perform all this without harm to people or the environment.

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he modern subsea oil and gas field is a complex array of hardware, often distributed over an area of the seabed larger than the city of London, all connected by electro-hydraulic umbilicals - the lifelines of the operation. Even with dual redundancy built into these systems and the use of state-of-the-art components, materials and construction methods, umbilical failures have a huge impact on production from subsea fields. So, when an electrical fault develops somewhere in the system, the subsea engineers immediately start planning an intervention to answer the questions “Where is the fault?” and “How do we fix it?”. Planning an intervention efficiently and safely is always key to a successful outcome. The first question to be answered is the timeline – when does it have to take place? Some fault-finding operations have the luxury of being planned during annual maintenance schedules a year in

advance, but more often interventions must be undertaken as soon as possible using a vessel of convenience. This can make the sourcing and logistics of equipment and personnel difficult. Specialised equipment may have to be transported from overseas by surface freight, and once in country may need to craned on board the vessel and secured to the deck. Mobilising offshore crews has been made even harder this past year by the Covid-19 pandemic. With every country having their own Covid protocols in response to everchanging threat levels crews may be required to spend several days in quarantine both before and after the mission. This clearly drives up the costs and can limit the pool of qualified personnel willing to be away from home for so long. Early on, C-Kore Systems recognised the

difficulties subsea engineers have in locating electrical faults in their subsea umbilical networks. Their response was to develop a small, hand-held, testing device incorporating a wet-mate connector to test directly into the subsea equipment. This replaces the use of down-lines and topside testing equipment. A down-line is essentially a very long extension cord, hundreds and sometimes thousands of meters long that connects the subsea equipment to the testing equipment located on the deck of the service vessel. Being a small device packaged in a flight case, the C-Kore testing units are very easy to mobilise. They can quickly be sent to any location via airfreight, and can be walked on board the vessel, not requiring any specialised lifting equipment or sea fastening. Due to their size, they can even be helicoptered on board if the urgency of the job dictates. The use of the C-Kore testing tools on offshore operations is allowing operators to complete their missions in less time and come back with better data and a clearer picture of what is happening on the seabed. Earlier this year a major operator in the far east approached C-Kore asking for assistance in locating the source of low insulation resistance (IR) in their subsea electrical network. The low IR was posing a serious threat to the production of oil from the subsea wells. The customer’s previous experience of electrical fault-finding on the seabed had involved the use of a down-line test cable from a surface vessel; a process that requires the mobilisation of a heavy reeler unit and specialist technicians to the intervention vessel. Reliance on downline intervention limits the accuracy of subsea fault-finding due to the distance between the tester and the equipment under test and to the environmental conditions on the deck of the vessel. It also requires the management of safety risks on the back deck and on the seabed associated with cable handling under challenging weather conditions and sea states. The first task was to decide on the best set of tools for the job. Discussing the goals for the operation with the customer and evaluating

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C-Kore’s small flight cases makes mobilisation quick and easy.


the field layout, the C-Kore engineers recommended the Cable Monitor units and Subsea TDR units. The Cable Monitor unit measures the insulation resistance (IR) and continuity of the electrical lines. The unit plugs directly into the equipment subsea to identify which lines have low IR values. Working at a very low voltage, the units safely test directly into Subsea Control Modules containing sensitive electronic equipment without any danger of damage. Divers can also work in proximity to the Cable Monitor during use, and do not have to retreat to the diving bell as they must do with higher voltage testing systems. This saves valuable testing and diving time. The Subsea Time Domain Reflectometer (TDR) tool works like a radar but for electrical lines, sending an electrical pulse down the line and listening for the reflections. By interpreting these reflections the precise locations of faults and anomalies can be determined. Due the age of the subsea hardware the customer’s engineering team did not have access to detailed dimensioned drawings or STEP files of the interface at the umbilical terminations, but a review of the General Arrangement drawings and video files suggested that adjacent steelwork might make the deployment of the standard C-Kore tool too close for comfort. Finding out the hard way that the test tool would not fit was clearly not an option, so C-Kore took advantage of the modular design of the tools to configure the units specifically for the job to avoid any chance of a clash. C-Kore assisted the client in making the subsea fault-finding intervention as efficient as possible by minimising the number of disconnections, the time on the seabed, vessel movement and the period of power isolation. They also preprogrammed the units with a sequence of core to core and core to earth insulation resistance tests before the units left the factory. All the customer’s offshore team needed to do was to connect the tool to the subsea circuit and flash the ROV lights at it to initiate the test. With the test units pre-configured for immediate deployment no specialist offshore personnel

C-Kore’s modular design allows their units to be customised to fit the application.

were required to operate them. Training was delivered via an on-line interactive session, whilst the client’s team were in Covid quarantine, so that they were all fully confident with the tools prior to the mission.

same result using other means would have necessitated mobilising two specialist engineers from the UK (to cover day and night shifts) and adding nearly 30,000 air-miles to the project’s carbon footprint.

As soon as test results were obtained they were relayed to C-Kore’s team in the UK where specialists were on standby on the same shift pattern as the client’s team to analyse the data and support decision making whilst the vessel was still on station. The C-Kore engineers drew on experience from hundreds of similar situations to assist the client in quickly identifying the faulty parts of the circuit. C-Kore has also amassed a wealth of knowledge in interpreting TDR traces to determine the precise location of the fault and whether it is a short circuit, open circuit, or water ingress problem. Working with C-Kore in this way enabled the operator to benefit from access to a team of experts who can peer review each other’s observations and conclusions in step with the offshore operation on the far side of the world. Achieving the

For their customer in the far east the use of C-Kore’s tools and onshore support service resulted in several electrical faults being identified quickly and efficiently. This was achieved with reduced environmental impact and less exposure of personnel to the Covid risk of international travel. Once Covid-19 is a thing of the past the advantages of C-Kore’s easy-to-use tooling, online training, and 24-hour expert support services will still be delivering savings and environmental gains to the subsea industry.

C-Kore units testing subsea umbilical

For further information on C-Kore’s innovative subsea testing technology, please contact them: W: www.c-kore.com E: sales@c-kore.com T: +44 (0)1904 215161

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EXPLORATION & PRODUCTION

Disputes Are Inevitable, What Are Your Options? OGI Magazine sits down with Bernicia Marine Consultants Limited to discuss the evolving nature of mediation and dispute resolution in the offshore and oil & gas sectors. It’s important for readers to understand their options, when they land into disputes in their operations. We are especially discussing the increasingly important role of “ADR” or Alternative Dispute Resolution. More below.

OGI: Could you start by explaining Bernicia Marine Consultants 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? Bernicia: Captain John Owen, who heads up Bernicia Marine is a CEDR accredited mediator and has a strong foundation in shipping and in particular the oil and gas environment; but also in chemical gases and ammonia which is now being considered as a fuel of the future. John also has more than 30 years experience in marine insurance in both the property and liability (P&I) cover provided to traditional blue water merchant ships in worldwide trades. Founded in 2015, Bernicia Marine are also active in the decommissioning, and, with many years of experience in marine salvage and wreck removal, brings a wealth of experience into oil and gas. As the energy sector transitions and limits the extraction of valuable earth’s resources to forms of renewable energy, it is evident that this requires huge investment and a significant amount of planning. This includes, repurposing, remediation or removal of offshore platforms and subsea structures. The tops of platforms are being removed and some consideration is being given to repurposing the jackets to carry wind turbines or high voltage interconnectors to bring the electrical energy generated by a wind farm back to land. Each of these costly projects are ripe for disputes, and so a mechanism needs to be in place to ensure that the transition of the energy sector is not bound up by disputes and lengthy litigation – although it is perhaps inevitable that some matters will end up in the courts. OGI: Could you explain what Alternative Dispute Resolution or “ADR” is and how it relates to the oil and gas sector? Bernicia: Historically, mediation is referred to in the Bible and has been part of society in a great many cultures around the world with elders taking the role of a community mediator. In its modern form, mediation, early intervention and alternative dispute resolution (ADR) are but three of the more commonly used expressions to describe a process that is generally considered to fall outside the ambit of the courts or arbitration.

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Since the 1990’s, ADR or mediation started to get some traction in business and in particular, the building and construction industry. This was because it was considered imperative that disputes and differences did not hold up long and complex projects and that a mechanism was needed to bring parties together in a consensual way to resolve their differences. During the late 1990’s the Woolf Reforms resulted in changes in the Civil Procedure Rules (CPR) used in the English Courts, and mediation was given greater prominence and a leg up in terms of its use in dispute resolution. These reforms resulted in significant efforts to reduce the increasing number and types of cases coming before the courts and the consequential delays in obtaining judgement. Over time, and as ADR evolved, the courts began to impose costs sanctions on those parties who refused to consider mediation as part of the judicial process, even if they won; which might leave a very hollow victory. The courts have even considered the use of mediation in case management and have suggested that, even when proceedings have been issued to preserve the position, the engagement of a trained mediator is more likely to lead to an outcome satisfactory to both parties (in terms of speed, cost, resolution and future relationships) than the pursuit of litigation to trial. In Oliver v Symons [2012]

EWCA Civ 267. There are two main types of ADR in the commercial environment. Facilitative and evaluative. Facilitative is more common, although non-binding-evaluation is occasionally used to help provide disputants get a steer on how a court might see the merits of their case. It is certainly fair to say that ADR does require active buy in from all parties to work towards consensus. It should not be overlooked that a case being presented before a court or in arbitration can only consider the history of events and the applicable law. Whereas, in the ADR world, much greater flexibility is possible, indeed it is actively encouraged and those in dispute are often urged to consider future relationships as part of concluding a deal. This makes it particularly relevant to the energy sector. OGI: What are the types of situations where ADR is preferable to typical litigation processes, and why? Bernicia: ADR is suited to almost all commercial disputes, save, perhaps, those which might impact significantly on a specific point of law or legal precedent. In the energy sector, LOGIC and other established contracts have step clauses which deal with disputes in quite a structured way. High value contentious disputes are likely to


escalate to board level quite quickly, but might still benefit from the intervention of a mediator and input from a neutral who might see the dispute through a different lens. This is not a cliché, and quite recently, boards of directors have taken to using senior business advisors and mediators to provide directors with a different perspective; or indeed if the Board or directors are themselves in dispute. Such intervention may provide a new perspective which might well result in giving the parties a nudge in the right direction; or the starting point for a different discussion about an old or new problem. Given the challenges that are inevitable as the energy markets transition to renewables and the environmental debates – it is self evident that ADR has a place. OGI: Could you talk a bit about the pilot program of meditation that the OGA is running? Bernicia: While the UK OGA has a number of formal powers which can be used to resolve disputes, some matters could be better addressed by the parties themselves through mediation. Although sometimes seen as a de facto mediation service themselves, the UK OGA would like to encourage parties to resolve the dispute by ADR, rather than a decision being handed down by a judge (or indeed the OGA). A mediation could be arranged in a relatively quick time period of perhaps a few weeks, otherwise the dispute could continue for many months (and even years). In February 2000, and prior to the Covid crisis, the UK OGA announced a mediation pilot scheme, developed in collaboration with the Centre for Effective Dispute Resolution (CEDR) in London. That pilot was to be run for a year, but because of the unusual operating conditions caused by the Covid-19 pandemic, the pilot has now been extended until the end of April 2022. It cannot be stressed enough that ADR is not about the mediator telling the parties what the outcome should be as might be the case with a Judge, or indeed the Regulator. Rather it is using the mediator as a third party neutral and puts the parties at the heart of the problem to help them find a commercial remedy. So often each party argues each and every point before a Judge which may be seen as having value to their case. The significant difference in a mediation is that it is more about the listening and parties attempting to better understand a different perspective. This is quite different from legal counsel thrashing out pleadings on every point in court. OGI: Can you talk about the importance of collaboration, and the difference you find in different sectors such as offshore, opposed to shipping and marine? Bernicia: Mediation need not be seen as a position of weakness. To the contrary – it is now actively encouraged in all areas of business and is, in principle, no different offshore than it is in, say, traditional ocean shipping. As mentioned previously, if parties do not consider mediation, unless they feel they have a particularly good reason not to do so, the courts may penalise them with costs against them for not

considering mediation, even if they win in court.

OGI: What does the future look like for ADR, in the oil and gas sector?

Much has, and will continue to be said about communication and collaboration in industry. Safety and compliance offshore makes this much more relevant. Collaboration and best practice in a well regulated industry is an absolute imperative because when things go wrong, they are inevitably very expensive and might have some significant environmental consequences. Competition is of course good for industry and brings innovation and low cost drivers to the sector. Much is being said across the industry and in the environmental lobby that repurposing of some oil and gas infrastructure needs to be given much greater priority. Carbon dioxide recovery, new hydrogen based fuels very much in its infancy with pressure on commercial shipping to commit to methanol, ammonia, LNG and even bio-fuels. Electricity and hydrogen fuel cells may be limited to some very limited short sea or ferry links. But collaboration is going to be fundamental to make any of this work and it cannot be ignored.

Bernicia: Based on experience, the UK OGA have identified that the majority of disputes had generally arisen due to entrenched licensee behaviours or communication breakdowns. They can be costly and time consuming for the companies involved, as well as threatening the delivery of Maximising Economic Recovery (MER). While recent market changes might have become more positive for some in the oil and gas sector, decommissioning is inevitable and needs to be paid for. So disparity and disputes will inevitably arise. OGI: Thank you for your time. • If you would like to know more about how Bernicia Marine & Captain John Owen can help your company and its operations, please contact them at: Bernicia Marine Consultants Limited T: +44 191 645 0298 M: +44 7437 408 663 E: john.owen@berniciamarine.com

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EXPLORATION & PRODUCTION

STEADY FLOW: Ensuring Optimal Performance Through Robust Filtration Making the right choice of process filtration supplier has never been more important given the operational and financial pressures facing today’s oil and gas industry. Producers and their service providers need to find optimal solutions that guarantee a cost-effective use of operating expenditure over a robust, longlasting service life. A knowledgeable supplier that specialises in both the design and manufacture of filters and housings is best placed to deliver on customer specifications. UK specialist Amazon Filters has been working with a growing list of oil and gas customers this year, supporting them through all stages of production. For its most recent industry order, the company has supplied and fitted hundreds of HFCs (high flow cartridges) on a deepsea FPSO. Operational challenges Process engineers at the platform had concerns over the performance of membrane pre-filtration on their onboard SRP (sulphate reduction plant). Filter cartridge change-outs were being done every two to three days, and each housing was taking 24 hours to execute a change of cartridges. Aside from the vast consumables cost, the operational challenges posed by such frequent and lengthy cartridge replacements were significant. Further investigation revealed a number of serious issues. The filter housings were undersized for the task in hand, due almost certainly to an earlier decision to focus on capital rather than lifetime costs. The upshot was a very high flux rate for seawater service which is guaranteed to lead to shorter filter life. The filter internal assemblies did not adequately support the cartridges as they should have done. This was limiting the maximum differential pressure at which the cartridges could be operated even at time of relatively low pressure drops. It was well below their intended dirty

values, resulting in the full dirt holding capacity of the cartridges not being utilised. Due to inadequate internals design, some cartridges would inevitably rupture which necessitated disassembly and manual cleaning out of the broken debris on each change-out.

Amazon Filters’ Project Specialist Padrig O’Hara

Robust replacements The Amazon Filters solution was to supply replacement internal assemblies with metal screen supports that could be bolted in, operate to a higher differential pressure over a longer lifetime and offer greater dirt-holding capacity than the originals. As well as supporting the cartridges properly, the number fitted was increased through better arrangement in the available space, resulting in a 20% increase in filtration area. This has the benefit of reducing the pressure drop and flux rate through each filter which in turn increases service life. Delivered ahead of schedule, the replacement internals were fitted by the customer with no modifications to the filter vessels required. The improvements were dramatic. Cartridge change-out frequency was reduced from two-

to-three days to two weeks, with change-out time itself cut from 24 hours to five hours. Alongside the use of Amazon Filters filter cartridges at a cheaper unit price than the original fitted ones, the solution delivered a 90% reduction in spend on cartridges, paying back the capital investment in under a month. At the same time, maintenance hours were reduced as far as possible given the constraints of the poorly designed original housings. Focus on the long term Commenting on the successful outcome, Amazon Filters’ Project Specialist Padrig O’Hara said: “The headline message for oil and gas producers concerned with cost control right now is to look at the total lifetime costs of their filtration solutions and not to fixate on initial capital costs. In this application simply retrofitting an equivalent filter product would not have solved the problem. You need to work with a supplier that has a proven track record in understanding the application and designing bespoke solutions. We concentrate on adding value, not just retrofitting. In this particular instance, our approach has given our FPSO customer a huge saving in the number of cartridges used annually. That’s on top of all the other complementary benefits of reduced maintenance time and consistent protection of the SRP membrane.” Tackling contamination

HIGH PERFORMANCE. The SupaSep LGP coalescer harnesses highly effective filtration media made of glass microfibre with a drainage layer of polypropylene or polyester. The inner core is stainless steel and the heat-bonded end caps are polypropylene or nylon.

As well as offering bespoke solutions, Amazon Filters has been busy with product


development, launching its latest innovation in meltblown depth filter cartridges in summer 2021. Contour Gas is designed to stop black powder contamination accumulating in upstream pipework and harming downstream equipment and instrumentation. Black powder is mainly composed of fine but hard particles of iron oxide (Fe2O3) and iron sulfide (FeS) in sizes from 100µm down to sub-micron level. Typically caused by corrosion and erosion, these particles are swept along pipework at high speed in the gas flow. Once they reach downstream infrastructure, they can easily cause costly downtime and endanger production safety. Ideal for high-flow, large-diameter applications, Contour Gas cartridges are made in a tightly controlled manufacturing process supported by environmental quality systems. It involves highstrength fibres being blown continuously onto a central mandrel, building into a one-piece, corefree construction resistant to unloading and media shedding. Ahead of launch, efficiency was tested in line with the requirements of major oil and gas companies using specific challenge levels appropriate to real-life installations. Karl Pizzey, Amazon Filters’ Operations Director, said: “Contour Gas provides reliable

and consistent filtration of the dirt particles in gases, with the flexibility to capture sizes from 0.3µm to 100µm and above. It is available in fine and coarse-graded density structures to match process requirements, the degree of distribution of the black powder, and the subsurface elements and 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 for new installations or as a direct retrofit for either core or coreless filters on existing housing designs affected by black powder.” Coalescer technology The launch of Contour Gas followed the release earlier in the year of SupaSep LGP, the latest evolution of Amazon Filters’ liquid-gas coalescers, used extensively in upstream,

midstream and downstream operations. The new filters can be supplied complete in a bespoke housing or as direct retrofits for products such as Pall Seprasol or Parker Peco DynaCeptor. SupaSep LGP incorporates a patented process for both interpleat and meltblown drainage configurations and to combat re-entrainment of fluids in the housing outlet through a robust barrier. This is designed to support the efficiency and drainage performance of highflow filtration and separation processes while protecting essential assets such as gas turbines, natural gas compressors, lube oil recovery equipment and catalyst beds. SupaSep LGP also supports the recovery of fluids involved in the sweetening and dehydration of natural gas. Among the product’s key strengths is the ability to vary filtration efficiency throughout the filter depth and confer additional properties such as oleophilicity and hydrophobicity. The launch of SupaSep LGP follows the completion of a rigorous laboratory testing programme conducted in partnership with the world-renowned Faculty of Chemical and Process Engineering at Warsaw University of Technology. Experts there are at the very forefront of meltblown fibre technology and coalescer research and design. Reflecting on Amazon Filters’ ongoing investment in manufacturing capabilities, Karl Pizzey said: “At this most challenging of times, we are here to provide the oil and gas industry with reliable products and bespoke solutions that drive efficiencies and transform operational performance.” To find out more about Contour Gas, SupaSep LGP and Amazon Filters’ bespoke solutions for oil and gas, visit: Amazon Filters Ltd. T: +44 (0) 1276 670600

PARTNERSHIP. Amazon Filters worked with academics at Warsaw University of Technology to develop SupaSep LGP. Pictured is an early trial installation at a Polish power plant to confirm ‘form and fit’ of the new coalescer range.

W: https://www.amazonfilters.com/industry/ oil-and-gas-filtration

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MIDSTREAM & PIPELINES

Rise of the Robots: Tank Cleaning Dozers and Robots Incorporated in 1995, Tank Farm Services ltd manufacture and operate a range of equipment to enable safe and efficient removal of sludge from confined spaces whilst eliminating or minimising confined space entry. Sludges and silts formed in tanks, lagoons and confined spaces such as pits and interceptors present the industry with significant health safety and environmental issues. TFS excel in providing bespoke equipment solutions to meet the demands of customer specific requirements.

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il and Gas companies demand the use of best available technology. The method of desludging and cleaning has constantly evolved to meet ever changing legislative and regulatory requirements, is it no longer acceptable to allow teams of cleaners into confined spaces. While safety remains the primary focus, industry now demands that: •

Man entry is removed or minimised.

Waste streams are reduced, recycled or reclaimed.

Tank, vessel or equipment outages are reduced or eliminated.

Survey A topographic survey is designed to accurately locate and quantify sludge, by identifying the location, height and volume of the sludge. Tank owners can then assess how the tank clean is approached and whether it is advantageous to carry out no entry desludging or progress straight to robotic cleaning. On line desludging For significant tank bottom sludge accumulations contained in bulk storage tank, the use of Jet Mixing Cannons will have a dramatic effect scale of the tank clean, up to 95% of the accumulated tank bottom sludge comprises of hydrocarbon which can be recovered by the cannon process. Closed loop cannon systems are installed while the tank remains fully in service, once installed crude oil is pumped from the tank and recirculated back through the cannon nozzle which directs a submerged jet of oil across the tank floor, this action rehomogenises and resuspends the accumulated hydrocarbons into overhead product. Final clean Tank cleaning dozers are not new technology in fact mini tracked “Dozers” or “Hydrodozers” have been used extensively throughout the industry in various guises since the mid eighties for desludging bulk storage tanks and “TFS excel in providing bespoke equipment solutions to meet the demands of customer specific requirements.”


confined spaces. Dozers are internationally recognised as a major contributor to safety, reducing the risk exposure and the physical demands imposed on a manual cleaning operatives while increasing the efficiency of the clean. Able to operate in zone 1 classified areas, dozers are hydraulically powered with hydraulic umbilical lines extending from the rear of the dozer and connected to a hydraulic powerpack that’s located in either a zone 2 classified area or safe area. Traditionally dozers are “ride on”, supplied as fixed frame units or in component form for insertion through a tank or vessel manway. Ride on dozer are controlled and manoeuvred around the tank by its operative, if operated in harmful or oxygen deficient atmospheres breathing apparatus must be worn. Breathing air lines are provided within the hydraulic umbilical lines and routed to a breathing air supply outside the tank, more commonly breathing air is supplied from an “Air Barrel” mounted on the rear of the dozer, removing the requirement for trailing BA lines. Dozers have the option of being supplied with a variety of front end attachments which can be quickly interchanged to suit the tank or confined space being desludged. Attachments include rubber dozer blade, rubber dozer blade with suction point, auger with suction point, rotary tiller, clam shell bucket, rotary sweeping brush or bespoke to suit customers requirements. Remote controlled dozers or robots do not require man entry and are increasing employed for desludging and cleaning activities. Remote controlled dozers are either craned into pits or driven directly into tanks through an open manway, a door or through a shell of the tank where a section has been cold cut away, the latter is normally employed where the accumulated sludge volume is significant and opening the manway door cannot be carried out safely. The main difference between ride on and remote dozers is the operator remains outside the confined space, controlling the dozer from a safe area. Remote dozers are particularly suited

to pit desludging, being able to operate fully submerged allowing the desludging to take place while the clients plant remains fully operational. Desludging is affected either by means of front end auger attachment coupled via pipeline to a vacuum tanker, or an onboard hydraulic operated submersible pump, the pumped products are directed to either centrifuge, belt press or dewatering box for further processing. Without question remote Zone 1 dozers and Zone 0 robots are the future of tank cleaning, Remote desludging and cleaning tanks can in many cases be carried out without man entry,

however the type of tank, its design and the standard of cleaning required will ultimately dictate this. Robot operators may claim that their “process” is 100% no man entry, and while their “process” maybe 100% no man entry it does not mean that tanks are 100% clean and sludge free and man entry won’t be required. Finished product tanks that do not contain internal obstacles such as roof legs and contain minimal volumes of sludge are obviously easier to desludge than a crude oil tank containing over 200 legs to manoeuvre around. Although the bulk of desludge / cleaning maybe achievable man entry is still required for final cleaning to hot work and removal of any entrapped sludge e.g. contained inside roof legs seal removal etc. Tanks containing coils are also problematical, especially in cases the coils are mounted low to the tank floor and have multiple floor clamps to manoeuvre around. Ultimately any sludge or cleaning that can be carried out remotely is a step in the right direction however tank owners should taper their expectations accordingly as man entry will ultimately be required. • If you would like to know more about how Tank Farm Services Ltd can help your company and its operations, please contact them at: Tank Farm Services Ltd T: +44 0115 976 1123 E: info@tankfarmservices.co.uk W: https://www.tankfarmservices.co.uk

Providing innovative equipment and services to the bulk storage tank, petrochemical and oil refining sectors.

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Super Duplex Tubing from Fine Tubes Now Available with Enhanced Strength and Improved Corrosion Resistance for Oil and Gas and Chemical Process Applications

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ine Tubes is pleased to announce that specialist metal tubing product, Super Duplex, is now available. Demonstrated capabilities include high strength and corrosion resistance for demanding applications. The tubing is NORSOK M-650 approved and made to order in specialist non-standard sizes for bespoke orders in the oil and gas and chemical process sectors. This enables it to meet very precise customer specifications, as well as offer high-quality, extremely reliable product performance. The Super Duplex tubing can be produced with very short lead times and in small batch sizes for optimum versatility. It is available in straight lengths that can be seamless cold redrawn and annealed to suit customer specifications. Typical tubing sizes range from 3mm (0.040 inches) to 31mm (1.25 inches) outer diameter in seamless form. Hostile working environments require optimum operating efficiency, excellent strength and corrosion resistant properties and complete product reliability. Super Duplex from Fine Tubes is ideal for use across multiple critical applications in the oil and gas and chemical process sectors. These applications include heat

exchangers, flow meters, downhole pressure housings and smart wells, subsea Xmas trees and manifolds, injection and ballast water, and other critical subsea, downhole, and offshore oil and gas instrumentation. Nick Head, Tube Product Manager at Fine Tubes says of the product: “We have a proven track record of supplying key tubing products like Super Duplex that meet the strict requirements of the oil and gas and chemical process sectors. Smaller batch capabilities ensure flexibility in the range of volumes we can produce. The ability to manufacture Super Duplex in non-standard sizes also enables us to meet the very precise requirements of our customers.” Fine Tubes has a long and successful history of operating in the oil and gas and chemical process sectors. The company delivers a wide range of precision tubes that deliver extended product life, as well as reducing downtime and maintenance costs. Tubing products from Fine Tubes are made from high pressure stainless steel and nickel alloys. The highquality materials used enable the tubes to perform without failure, time and time again, for maximum corrosion and pressure

resistance up to 100,000psi. The company is one of five business units that make up AMETEK Specialty Metal Products (SMP), alongside Hamilton Precision Metals, Superior Tube, AMETEK Eighty Four and AMETEK Wallingford. Each of these business units manufacture metal products for the oil and gas and chemical process industries. These other products include hard-facing powder coatings used in thermal spray, spray and fuse applications, plus metal strip and engineered components for drill bits and shaped charges for well perforations. In addition, clad metal plate products are used for pressure vessels and transition plates. Operating out of Plymouth in the UK, Fine Tubes manufactures precision metal tubing products in a range of specialty alloys at its highly integrated tubing mill. As well as the chemical process and oil and gas and industrial sectors, tubes produced by Fine Tubes are used in numerous critical applications across many global sectors, including energy, medical, aerospace and defence. • www.finetubes.com

Tackle corrosion.

With Super Duplex tubes. NORSOK approved Super Duplex tubes deliver greater corrosion resistance than standard Duplex grades - engineered for hostile high chloride environments. Short lead times • Small batch sizes

Scan for more information

Contact: sales.finetubes@ametek.com

www.finetubes.com


BUXTON SPECIAL ALLOYS LTD. Your Partner in Steel

Buxton Special Alloys Ltd. is one of the largest stockholders of stainless steel, Duplex and Super Duplex materials in Europe. Our market sectors include Oil and Gas, Petrochemical, general machining, marine, Automotive and Nuclear where we supply our products to a range of companies producing Valves, Pumps, Seal Rings, Flanges and many more. BSA hold a stock of over 800tonnes of bar from 25mm OD to 630mm OD across a range of grades, stocked at our 2 sites in Rotherham and Sheffield. We have 9 saws at these sites enabling us to cut 24 hours a day 7 days a week, giving us the ability to deliver express jobs within 24 hours. We have strong partnerships with a number of mills, and have sole exclusivity for supply of Stavanger Steels AS (Former Scana) products into the U.K. and the U.S.A. Material is Norsok approved through the ruling section, and 3.2 witnessed and certified material can be supplied quickly taking advantage of the in-house ISO17025 registered laboratory. We offer Re-Forging Billet, Round Bar, Square Bar, cut pieces, rings, hollow bars, tubes, flanges and individual forgings. We also offer specialised machined parts to customer drawings working closely with long established local machine shops. B.S.A. has just won a prestigious contract for the supply of Alloy 625 forgings for the Marjan Oil Field Development Project, which is owned by Saudi Aramco and as our Forge Partner have already been awarded Saudi Aramco approval the customer knows they are in proven reliable hands. Our recent success stories have included 80% supply of parts for construction of the new Tintagel Bridge project. We have also supplied a contract worth over £1million for supply of parts for installation within the nuclear island at a U.K. nuclear power station. Last year we won our largest order so far for proof machined seal rings for Thai Oil, the project sale value for B.S.A. was in excess of £1.8million.

Contact information: Jane Robinson, General Sales Manager

jrobinson@bsa-ltd.com

Tel : 07786180053


MIDSTREAM & PIPELINES

Whether Sampling Road Tankers or Oil Terminals, UK Sampling Gauges Ltd Has Just the Kit! The analysis can only ever be as good as the sample; with this in mind UK Sampling Gauges Ltd have developed various kits to suit any sampling application.

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ur closed sampling systems featuring the MK 7, MK 10 and MK 14 are ATEX & IECEx approved. Whilst meeting industry requirements they also benefit from UKSGL unique design features:

• •

Incredible reliability and accuracy.

Highly secure and safe sampler tape connection.

Environmentally friendly – a must, given current climate issues!

Operator friendly ergonomic winding system for ease of use.

The ‘fall out’ cannot enter the sampler during retrieval process.

Samples that are taken can be very easily transferred through the spout without contamination. Mechanical counter enabling a constant reading of sampler depth. Strong stainless steel tape that’s tested up to 220kgs! The MK 10 and MK 14 can use samplers that accommodate bottles for sampling (these bottle type samplers are ideal for RVP sampling).

The MK 7 kit is ideal for taking representative samples under closed conditions, fitting directly onto a 2-inch vapour control valve and can take samples up to 500ml.

The MK 10 kit connects directly on to 4-inch valves and can take samples of 1L capacity. With this kit there is the option also to take samples directly into bottles (500ml capacity) using our ALSB-V 502 sampler capable of taking running, spot and all-level samples. The MK 14 connects on to 6-inch valves and uses the ALSB-V 1002 sampler which accommodates 1L capacity bottles. To add to our sampling range we also offer two restricted kits, the MK 2 system (up to 500ml capacity) and the MK 2/2 system (up to 1L capacity) and our exclusive RVP (Reid Vapour Pressure) sampling kit. The RVP kits can be used with either the MK

MK 7 Winder in operation.

ALSBV taken onsite in Rotterdam.

A selection of winders and samplers.


7 winder or the MK 2 winder so is suitble for use under both closed and restricted sampling conditions.

Conventional Running Sampler Results

We also offer a very comprehensive range of samplers to suit any operation (spot, universal / alllevel, bottom, running) and open sampling winders including the ATEX and IECEx approved MK 1A winder suitable for use with a range of UKSGL samplers including the ALBTMS – a spot and bottom sampler that’s uniquely designed to sample oil water interface at the bottom of the tank. In addition our portfolio also offers a range of sampling accessories – water finding rules for black fuels, sounding rods, gas caps, adaptors and back packs. Testing and Data Furthermore, not only can we say UKSGL equipment gives the most accurate and reliable samples, we can confidently say the equipment is not affected by outside pressure and we have the data to prove it! UKSGL type running and all level sampler (RNS and ALSB-V) operate on a one key principle – the inlet probe is not affected by the outside pressure during descent. To prove this, UKSGL manufactured an inhouse testing station that is able to simulate depth with pressure. The initial tests were carried out using conventional sampling equipment – testing with one hole and then with two holes. UKSGL then tested the RNS / ALSB-V (running and all level) sampler.

The graphs show the results of both sets of tests – the results are outstanding! Result analysis indicate the following: •

UKSGL RNS (running) sampler / ALSB-V (all-level) bottle sampler shows a constant filling rate irrespective of depth.

The conventional type running sampler does not show the same. The results are very sporadic and the sampler fills quickly at the top level of the tank and does not evenly fill giving incorrect samples.

This data puts these UKSGL samplers in a league of their own! They are the only samplers that are proven to be unaffected by outside pressure and therefore are the only samplers that can take true representative samples time after time irrespective of depth. About UKSGL UK Sampling Gauges Ltd, founded in 1986, are specialists in the design, development and manufacture of accurate manual sampling equipment for liquids to meet 21st Century oil industry requirements and ever changing industry standards. All of the UKSGL sampling equipment comply with EN ISO 3170:2004, ASTMD 4057:2000, ISO 5555:2001 and have been tried and tested by inspection and oil companies world wide. The unique design of our equipment ensures representative samples are taken time after time. Reliability is a key feature of equipment that helps to avoid repetitive sampling, saving time and money. UK Sampling Gauges Ltd are also fully equipped for video conference calling and also virtual demonstrations using their in-house testing station. For further details download our App, available for free download, to gain access to our training videos, brochures and product / UKSGL updates. • Contact Details: T: +44(0)1778 392818 E: sales@samplinggauges.com W: www.samplinggauges.com


MIDSTREAM & PIPELINES

More Than Just a Frame System Global Gravity was established in Esbjerg in 2011, and specialises in transporting casing, tubing, and drill pipes for the oil industry. The company is the inventor of the patented TubeLock system, which is the world’s first “Tubular Transport Running System” (TTRS).

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ith TubeLock, Global Gravity are taking care of all handling and transportation of all types of casing, tubing and drill pipe tubing from storage, across the quay to the ship, and onto the drilling rig. TubeLock improve safety and efficiency significantly for the offshore operators. Pipe handling can be quite a dangerous job if it is not carried out correctly and because of threats from the outside. Every day, the crew work in harsh conditions, exposed to wind, cold and noise in a very challenging working space. There is a great risk of injury to people and damage to equipment. It is not far from the walkway to the edge, and bulldog clamps and tools have been dropped on several occasions. With traditional wire slings heavy loads of pipes are rolled out, stacked and bundled with 10- to 12-metre-long steel wires, causing danger to the people working when unloading and dangerous stored energy released when the slings are removed from the bundled pipes. TubeLock reduce these risks as the pipes are stored and transported in a safer manner and are stacked according to all safety criteria. With TubeLock there are less manual handling and most preparations can be done onshore. Furthermore, surveys show that customers reduce time spent on the overall handling process by 50% compared to the traditional solutions. At the same time, TubeLock requires 50% less space and halves the amount of handling out on the drilling rig. Using the TTRS Systems you can run the tubulars directly out of the TTRS frames as they are all measured and numbered. You can run the pipes directly into the wellbore from the TubeLock system, therefore there are no requirements for the rig crew to unload the frames and lay the tubulars out on the pipe deck reducing the handling of tubulars on the Rig and supply boat by 50%.

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It is a documented fact that our operators save 50% of the time normally used moving pipe from supply boat to cantilever deck on the drilling rig ready to be run in hole. The time saved offloading boats free the deck crew and cranes for more important tasks related to the drilling operation. And saves both fuel on cranes and supply vessels during the operation.


As pipes does not have to be laid out upon arrival on the rig, handling is reduced by at least 50% thereby reducing risk of dropped objects and injury to personnel. TubeLock is certified as an offshore lifting appliance under DNV ST-0378 and Norsok R02 and is in compliance with ILO and LOLER recommendations. TubeLock is manufactured from Aluminum to ensure it is easy to handle and no single part weight more than 15 kilos. The aluminum base product also ensure there is no galvanic corrosion between TubeLock and chrome alloy tubes. Sand-Screens is yet another product that we have successfully transported, saving the operators time and space by not having to use large transport baskets which take up cumbersome space on the supply vessel even when returned empty. The cost of chrome and super chrome tubulars are some of the highest costs when drilling and completing wells and there is a high risk of damaging these tubulars when bundling and slinging Chrome Tubulars. When these tubulars are transported in the TTRS frames they are protected and cannot be damaged. A work group set up by UK Oil and Gas and Step Change to review lifting incidents, has highlighted the practice of bundling and slinging tubulars to be a high risk process and that we should work to eliminate that process within a timeframe agreed by all industry participants.

Our Track record is as follows:

“We believe that TubeLock® TTRS will be the future for all involved with pipe transport, storage, inspection and drilling.”

UK Operations – 3-1/2” to 9-5/8” (Equinor – 13 wells)

Qatar Operations – 3-1/2” to 13-3/8” (North Oil Company – 5 year contract 4 No. rigs )

Denmark Operations – 3-1/2” to 13-3/8” (TOTAL – 5 Year Contract)

Australia Operations – 4-1/2” & 7” (Santos)

Trinidad Operations – 5-1/2” Bakers Sand Screens (BHP)

Norway Operations – 4-1/2”, 5-7/8” & 7” ( Var Energi, AKER BP & Neptune) • Holland Operations – 4-1/2” to 9-5/8” (Tulip Oil, Wintershall Noorzdee BV, NAM) • Germany Operations – 2-7/8” to 9-5/8” ( Wintershall DEA – 5 Year Contract) Global Gravity supply the world´s first Tubular Transport Running System (TTRS). TubeLock® provides optimization of all processes for pipe handling within all types of well interventions and drilling operations around the world. Giving our global customers great cost savings in combination with the safest and most effective TTRS for all types of pipes used by drilling rigs. If you would like to know more about how Global Gravity can help your company and its operations, please contact them at: Global Gravity ApS T: +45 71 99 20 10 E: support@globalgravity.dk W: https://www.globalgravity.dk

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MIDSTREAM & PIPELINES

“THIS IS WHAT I ALWAYS WANTED” The VTTI/ETT storage tanks in Rotterdam (The Netherlands) are in always in use. “This is an extra reason for us to ensure that the inspection of our tanks takes as little time as possible”, explains Ralph van Dijk of the company. The use of drones by Terra Inspectioneering offers a solution. Thanks to this technology the inspection duration has been shortened from two weeks to two days. The story of a customer from the very beginning.

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he Euro Tank Terminal (ETT, part of the VTTI group) located in Europoort, Rotterdam has 36 storage tanks for the storage of fuel oil, jet fuel, methanol and gasoil. Next year, ETT will start using six new storage tanks on the site for the storage of fuel oil. “Apparently the market for fuel oil is still good,” explains maintenance engineer Ralph van Dijk of the tank storage company for the expansion. FIRST MEETING He says he is approached almost daily by parties who claim to have invented something very beautiful. “Nine times out of ten it turns out to be an empty shell,” he says. Terra Inspectioneering – formerly called RoNik Inspectioneering – was one of many companies that contacted ETT 5 years ago. “The company was still in its infancy”, says founder and commercial director Marien van den Hoek of Terra Inspectioneering. “We had just decided to focus on the inspection of confined spaces with drones. We had completed a pilot with Oiltanking in Terneuzen and because I knew the maintenance manager of ETT, we also knocked on this door.” Van den Hoek offered ETT to carry out the visual inspection of storage tanks using drones. An offer that Van Dijk heard with interest, but which he did not yet accept at the time. Van Dijk: “I said: ‘We

only really benefit if the steel thickness can be measured.’ Otherwise I would still have to send people up into the tank.” ADDED VALUE A year and a half later, Van den Hoek reported again, this time with a drone that can perform both visual inspection and UT thickness measurements. This time, Van Dijk agreed: “As soon as we tried it out for the first

time, I could already see that this way of inspecting offered added value. The problem with fuel oil storage tanks is that it is a heated product. The tank has PUF insulation, which you prefer not to remove. However, the heated fuel oil creates internal condensation, which increases the risk of corrosion. We’ve been running into this problem for several years now. We have had people measure the roof construction and walls using rope access, but that takes two weeks. You can also use crawlers, but for that the walls have to be cleaned thoroughly and you have to make holes in the roof because otherwise the equipment might fall and it must therefore be secured. That while the inspection by Terra Inspectioneering is completed within two days. That is why I welcomed them with open arms.” VIDEO, FILM AND 3D MODELS The fact that ETT’s storage tanks are full as standard is an important factor, according to Van Dijk. “At other storage terminals, there is often an empty tank, which makes it easier to take another tank out of operation. Then you move the contents from one storage tank to another. But we don’t have that luxury. If a tank has to be taken out of service for inspection, we always get in the way of the customer. They know that too, but apparently they find this a pleasant terminal, because we are always full. That is why it is very important for us to take storage tanks out of service for as short a time

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as possible. We use a pit-stop strategy for such situations, in which we prepare for worst-case scenarios. For example, we make agreements with contractors that they prepare their tools in advance. This is how we prepare for what we can reasonably expect. So you understand that it doesn’t make us very happy if we have to take a storage tank out of operation for two weeks for rope access. The time saved by using Terra Inspectioneering is therefore a major advantage. In addition, I can verify the data from the drones. The drones film and take pictures. The software can also create 3d models. Unlike the photos that rope access employees often take, the photo and video images from the drones are fantastic in quality.” WALL, ROOF SHEETS ÁND CONSTRUCTION TRUSSES During one of the first test flights of a drone in a storage tank, Van Dijk had an eye-opener. “The drone was measuring in the tank, but got damaged. I thought this was a big deal, but the people at Terra said they could come back the next day. That evening, new parts of the drone would be 3D-printed.” This turned out to be possible because Terra designs the drones itself and also makes them with 3D printers. Initially, Terra’s drones only inspected the tank walls. Partly at the request of Van Dijk, Terra also started inspecting roof structures. So these are complex IPE or UNP rafters that have to be measured completely. “At first they only did the bottom flange, but Terra can now measure the entire profile. All standard sizes are measured, so that we have a good idea of the corrosion formation. Did this give me new insights? Not directly, but this is the realization of what I have always wanted. There can be problem areas in roof constructions, but they are difficult to reach. I now have a better view of the risks”, says Van Dijk.

POSSIBLE SOLUTION FOR CORROSION UNDER INSULATION Terra Inspectioneering is one of a select group of suppliers with whom Ralph van Dijk of ETT likes to exchange ideas about ‘issues’. “They work with the content and come up with solutions. That is why I like to invest my time and energy here.” One of the topics that Ralph van Dijk and Marien van den Hoek of Terra Inspectioneering are studying is corrosion under insulation. “Certainly with our PUFsprayed storage tanks, this is a difficult problem to detect. It is a local problem that you usually do not pick up with internal measurements, but can have major

consequences. In the worst case, you have a leak in a tank wall.” It is possible to visually inspect a tank wall with the aid of an aerial platform for defects that indicate corrosion. Insulation must then be removed in these places to check whether there are actually problems underneath. This is expensive and there is also a chance that places will be overlooked during visual inspection. The use of the latest thermal imaging cameras on drones may offer a solution in combination with the latest AI (artificial intelligence) technology. ETT is discussing this with Terra Inspectioneering. “Thermal image makes temperature differences visible. Thermography allows you to detect wet insulation. However, temperature differences can also be caused by irregularities in the PUF insulation. In the past we have tested with thermography, but that turned out to be a problem and the results were therefore not reliable. We have developed new ideas with Terra Inspectioneering. How soon are we going to start testing? As far as I’m concerned, as soon as possible!” In addition, Terra Inspectioneering will carry out another pilot at ETT: visually inspecting pipe racks at height using drones. van Dijk: “We are going to see how it works, what it yields and what the reports look like. UT measurements are also a concrete option. If the test is successful, I would like to request the NL-CBI supervisor whether Terra Inspectioneering can carry out the inspection in this way on our pipelines that are subject to inspection. I expect this will not be a problem.” Terra Inspectioneering B.V. Voltaweg 11a 4382NG Vlissingen The Netherlands https://www.terra-inspectioneering.com Phone: +31-85-3010095 Sales: +31-6-44557462 info@terra-inspectioneering.com

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MIDSTREAM & PIPELINES

Oil & Gas Industry Interconnections for Sensing and System Digitization Bob Stanton Director of Technology, Omnetics

Today’s petroleum industry is benefitting significantly with emerging surveillance, sensor and digital data processing technologies. Upstream research and economic analysis used for “next-field” determination, accessibility, and potential harvesting processes require extensive data collection, processing and analysis. Communication systems and data transfer is being accomplished using digital processors, and computers with extensive capability.

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uring exploration, for example, orbiting satellites using FLIR and Multispectral imaging analysis are sending data to surface level systems for mapping to help select new petroleum sites. High speed Gallium based sensor chips in the surveillance systems transfer information like, precision geophysical positioning, depth, chemical distribution data and even variations in density of materials of interest in the images. Throughout the petroleum sequence, high-speed electronics are changing system control methods from “Upstream” to “Processing”. The combination of using new sensor designs and actuators attached with miniature connector wiring is adding constant data saving time and money. New CMOS, sensors provide high-speed, low current and low voltage digital signals that are easy to transmit from down-hole or on-line processors to overall control centers. Sensors and miniature circuit boards must often be squeezed into rugged and tight fitting positions and will be exposed to constant use in rugged environments. When simultaneous logging data and drilling, (LWD), is used to

control bit direction and depth, the circuitry is housed immediately behind the bit for analyzes mud slurry and position. Immediate

data is critical and is transferred up to controllers at the surface. Micro and Nano connectors and wiring routes massive amounts of data from deep inside the bit casing to give the operator above more accurate and timely data. Nano-sized connectors and cable have become critical elements in interconnecting these sensors based monitoring systems. Benefits range from their rugged performance capabilities while reducing size and being rapidly adapted in contact format and shapes to match new designs. These connectors have years of proven down-hole performance and offer continuous data transmission integrity in operations up in the 200 degree centigrade range-of-use. Petroleum electronic applications requiring in-line signal routing,

Photos: Left: Micro + Nano Sensor Connectors. Above: Oil Platform Control Room.

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right-angle cable plugs and panel-mounted systems are environmentally sealed when necessary. Direct board mount connectors mating to in-line cable systems also help reduce space requirements while maintaining high reliability. Additional focus on materials and design methods are often required. The main challenge is in size reduction of connector systems while maintaining the rugged requirements necessary for this industry. Connector contact design is a key element in vibration and electrical performance assurance. The spring pin and socket connector system has proven reliability over wide ranges of shock, vibration and thermal changes. Made of BeCu, (beryllium copper), with high tensile strength, at 17,200ksi, they easily withstand the rigors of use and abuse that is often experienced in the oil and gas work. The connector pin and socket elements are plated to Mil. B488-type II, Code C class 1.27. This requires a strong nickel plate barrier that is then plated with 50 micro-inches of gold. Then, the connector pin and socket elements are crimped to high temperature, (if required), Teflon® insulated wiring that is carefully laser stripped to avoid nicking miniature wiring without the need for solder. This provides the highest thermal performance. The wired elements are then inserted into miniature insulator housings of LCP, (liquid crystal polymer), and sealed in place with High Temperature epoxy when required. Additional metal shells are often added to support the structure to the cable, when needed to insure cyber and EMI protection shielding is added.

Photos: Above: Std. Nano-D on Steering Devices. Right: Micro and Nano Metal Hi-Temp Connectors. Below: Micro Metal Circular Connector. Miniature connector and cables are helping to add data and high-density interconnections to the increasing use of high-speed digital data from sensors and machine monitoring devices. Monitors for device position, to temperature, pressure and even chemical detection are offering data for automatic control with precision processing. A wide range of standard design high temperature connectors exist today. Many sizes and shapes

have already been designed and tested to meet needs in oil and gas technology. When a new size or shape is needed, Omnetics offers fast-turn solid-modeling, 3-D fabrication equipment, and direct-linked CNC machinery that can speed things up significantly. Designers can begin by selecting the proven and established pin to socket elements used in today’s connectors or begin working directly on line with a solid modeling engineer to quickly layout a new model, size and shape to fit his equipment. When the design looks good, a 3-D model or a CNC device is made and sent to the designer to insure fit within his equipment. This method assures that new designs and assemblies can be completed very quickly and at significantly lower cost than before. Omnetics and other connector companies are staffing rapid-turn prototype laboratories with technical specialists to leverage these new capabilities and satisfy these new interconnect challenges. The sequence for new designs are straight forward. A. See standard that are available today and ask for samples. B. If needed, call and talk with sales or engineers about your unique needs. C. Build a solid model on line with the connector supplier. D. Make a quality and testing assurance list. E. Work with a qualified supplier from your industry. For more info, see: www.omnetics.com Or call your local representative.

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MIDSTREAM & PIPELINES

Expertise in Machinery for Industrial Pipe Preparations Copier Machinery: Manufacturer of pipe preparation machines is based in Giessen, the Netherlands, and has a sales office with warehousing in Tulsa, Oklahoma. Formed in 1997 by Jan Copier, the company offers a full range of pipe preparation machines that includes cutting, beveling, threading, welding, and roll grooving.

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opier Machinery prides themselves on manufacturing state-of-the-art machines and providing accurate and rapid service compliant with the wishes and needs of their customers. The company is active in several industries including fire sprinklers, automotive, marine & offshore, and the oil and gas industry. Copier is committed to helping their customers with almost every pipe-end preparing issue they are facing. Through their market knowledge, experience, customer-centric approach, and resources they have successfully engineered, manufactured, and delivered over 400 pipe preparation machinery to more than 40 countries.

The Beaver CNC.

Development of the Beaver CNC Copier Machinery started with manufacturing end-working machines that use form tools. A form tool is a kind of cutting tool having one or more cutting edges with a defined profile or contour. That profile or contour is reproduced as the needed form on the workpiece surface. In 2012, Copier responded to the increasing demand for using CNC-controlled machinery in end-working. CNC is single point machining; it refers to a cutting tool with a single sharp edge that removes material from the workpiece. There was a demand for CNC machining since it became more complex to work with form tools with larger wall thicknesses. Also, more complex materials like high alloys with higher strengths

The Beaver CNC.

are easier to machine by CNC-controlled machinery. The CNC machine can prepare pipes with higher wall thicknesses without changing tools during the machining process. Furthermore, a CNC controlled machine is easier to control in automation without needing human force; it is more flexible to control by sending production data only. In addition, more complex materials require a stable machine; materials such as duplex and super duplex. The demand for CNC machining also increased due to the

flexibility of the machine. It is easy to control automatically since it can create all kinds of bevels with the same tool; less tooling and less change-over time is required. Copier Machinery responded to this demand by developing its own CNC machine. The machines already existed within the highend industries, but not within the industries in which Copier Machinery is active. Three different applications can be performed with the machine: beveling, cut grooving, and threading. These are three preparations that are often applied in the oil and gas industry. The machine is completely pre-programmed for standard bevels and can be extended upon special requests. Only the basic metrics such as pipe diameter, wall thickness, and type of application have to be filled in. The machines are built according to the latest technology; they can be accessed remotely. This allows Copier Machinery to connect to the machine remotely to update software or support with operating in it. The machines are prepared to log data and to connect to the factory where the other machines operate. With this capability, the factory can track production volume, efficiency, and maintenance requirements. Thanks to its stable, robust, and state-ofthe-art design; the CNC machine requires minimum maintenance. The company provides training that includes basic maintenance.


How it works On a rotating tool lathe, the X-axes of the machine are mounted on the chuck. That means, the tool, mounted on the X-axes, will move on the rotating chuck to get the correct profile. This can be done by the CNC controls like Fanuc. In this part of the industry, there is not much knowledge of CNC programming (with G-codes), therefore, it is mandatory to have a good interface between machine and operator. That is why you should have a program between operator and CNC, that only requires to give basic metrics like diameter, wall thickness, type of preparation, and material. With these data, the machine should be able to run. Safety Safety is always an important condition when operating machinery, especially when it is automatically controlled. The process itself must also prevent as many safety problems as possible. Changing from one machining situation to another requires at least 50% less human work on tooling, which decreases change over time between batches, decreases human errors with tooling, and eliminates safety issues as well. Success story Heinz Gothe is a company specialized in processing different kinds of steel. In 1920, the company was founded as a Coppersmith in Düren, Germany. The company is, among other industries, active within the oil and gas industry.

Gothe was looking for a new pipe finishing machine to improve their production efficiency with a new, fast and safe solution. They were working with large-sized pipes on a traditional lathe, where the pipe is turning and the tool is fixed. This was causing danger for the operator due to the lack of control and safety of the cycle. The batch specifications differ in terms of material, pipe size, wall thickness, and Photos: Above: The Copier Machinery Team. Below: The Beaver CNC.

required bevel shape. Therefore, adjustment of the old turning lathe is required per batch. Bringing and positioning the pipe, adjusting the tooling, and completing the entire beveling cycle with their outdated beveling machine took too much time. At the time, the solutions available on the market were limited and did not fully meet Gothe’s production requirements. Copier Machinery came up with the Beaver 24 CNC as a solution for Gothe. The CNC machine operates oppositely compared to the traditional tool lathes: the workpiece is fixed by clamping safely and the tool is rotating. This made the production process safer for the operators of Gothe. The most important advantage of Beaver CNC is that there is no need to change tools per bevel shape or bevel angle. The radial and axial feeding can perform the preset shapes automatically and precisely which is speeding up the production cycle by four times. The solution Copier Machinery provided to Heinz Gothe facilitated their production in terms of speed and safety. The beveling process is four times faster since the new machines are operating in their fabrication shop. • If you would like to know more about how Copier Machinery can help your company and its operations, please contact them at: Copier Machinery

W: https://www.copiermachinery.com E: sales@copierbv.com T: +31 (0)183 44 1313


MIDSTREAM & PIPELINES

What Can Digitalisation & Transparency Deliver for Project Logistics? XELLZ, a company in-the-know when it comes to using digital solutions to optimise logistics and operations, has much to share on the subject of digitalisation and transparency including the limitations of technology and the value of the human factor.

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espite the lack of standardisation and the complexity of transport logistics, there is an abundance of new ideas, technologies and platforms that can significantly enhance operational efficiency within the project cargo industry. XELLZ believes that all the systems they have created, technological or otherwise, have one basic common drive, “to make things easier for us, our customers, and for the projects we control,” says Peter Bouwhuis, CEO, XELLZ. Project cargo logistics is a very different animal to other logistics. Every shipment is different, with hundreds of varying factors and to digitalise the process completely is difficult. What cannot be digitalised, can be monitored digitally. “For instance, cargo handling and seafastening can be monitored using a tool such as SurveyCam. This innovative tool takes video evidence for inspection reporting, checklists and uploads all the data to the cloud for customer, insurance company, contractor to see,” says Bouwhuis. SurveyCam provides online tools for the maritime logistics industry to record logistics operations, route surveys, and any damages. XELLZ uses this tool daily to gather data from their field managers on site. They say that RVI (Remote Video Inspection) is ideal for staff who are present at a job site or even the job site staff

themselves that need to perform an inspection or survey. The tool produces an instant report that is sharable online with customers, the project team, or anybody that needs to have the information. Project Data All data is checked and verified before going into the system. “Information is power, but you need the right valuable data.” XELLZ developed an in-house platform called ProjeXsmart to handle all the data. The platform has its own database and manages links to other databases rather than duplicating the work. ProjeXsmart is a platform where all project documentation,

The Project Logistics Control Centre (PLCC) is essentially the “mission control” hub.

communication, data, pricing and scheduling is stored and shared. Photographs and videos can also be uploaded to the platform. The platform virtually controls the project, manages the team tasks, sends notifications for upcoming tasks and identifies potential delays for the project as well as keeping everything on a tight schedule and on budget. “The online platform is our backbone where we can manage any task in the project and keep you alerted automatically so that nothing is left to chance. This technology generates transparency and gives clarity to all parties involved,” says Amanda Labee, Assistant VicePresident XELLZ.


Peter Bouwhuis, CEO, XELLZ.

Mission Control The Project Logistics Control Centre (PLCC) is essentially the “mission control” hub. The centre brings all information and communication together into one online location and creates a single point of collaboration eliminating duplication of work. It is a critical environment operated by a team of people with 100% control, productivity, transparency, and efficiency to ensure the success of projects for multidisciplined organisations. PLCCs are the perfect fit to see the big picture through all lenses of the project and leave nothing in the shadows. This enables a safe and timely risk-analysis which is a major factor in getting the “element of surprise” under control. Peter Bouwhuis says, “One of the main advantages of our PLCCs is the ability to bring many different disciplines together and establish connections between them. That way, project logistics managers can be in control of all different sources at the same time. Without these logistics control centres, every discipline would need a different source to try and collaborate with each other, resulting in a significant loss of time and high costs.” PLCCs direct ships, trucks, aircrafts and any other transport or element that is needed for the project as well as other relevant resources to reach the job site on time. During crisis situations such as natural disasters, coordination between the project logistics centres can potentially prevent project failure and save significant financial loss. Transcending Transparency Transparency is not just about the project plans or how project cargo freight is transported. Transparency is about the whole chain of events and the entire pricing and rate structure. XELLZ has a policy that is conducive to complete open communication before, during, and after the project. Starting with the preplanning where all technical and possible

solutions are shared, all pricing and cost options and models are communicated, and negotiations with (sub)-contractors are carried out in the open with the customer to ensure the best and optimum cost solution is chosen.

projects. The logistics is too complex and subject to constant change and outside influences that would easily disrupt a more manual process. A digitalised Project Logistics Control Centre operated by a team is the best approach.

Using ProjeXsmart, XELLZ says they can lower the total cost of project logistics by over 25 percent as well as offering 100 percent transparency across the entire project lifetime.

Technology helps improve the project focus and control in many ways, but it should never be forgotten that this cannot be achieved without human intelligence. When it comes to developing beneficial PLCCs, there is a fine balance that must be found between human and technological factors. We should think twice about eliminating manpower from complex processes to rely solely on technology.

Results Results show that control and focus are heightened, and any action taken by the team in charge is proactive instead of reactive. As is the case in most projects, being proactive mitigates risk and avoids a crisis. “Getting a project finished in time and within budget has always and still is the goal that we all strive for, so let’s look at technology as an aid to logistics control and not to automate the control.” Technology is needed and digitalisation is essential when operating offshore or onshore

Team of Xellers XELLZ are tackling new challenges and transitioning project logistics into a smart sector the “XELLZ way” with transparency, trust and technology. Headquartered near Amsterdam, XELLZ provides worldwide project logistics management from their offices in the Netherlands, the U.S., Ireland, Nigeria and Germany. The XELLZ team are currently busy with four upcoming ‘Energy Transition’ projects in Germany and the US, the largest of their kind in these countries. XELLZ is also making headlines with their early involvement in offshore wind farms off the coast of Ireland, where 24shore (a division of XELLZ) has secured over 300.000m2 of land at the port of Rosslare. XELLZ Ireland Ltd. is in discussions with energy companies and others interested in the installation of these offshore wind farms. 24shore will also develop the European Business Park (EBP) on the land connected to the port area with direct access to the quay and will be used for offshore supply base operations including pre-installation assembly and mobilisation. The area also offers SME’s a space to locate their business during and after the construction and maintenance & repair. • XELLZ B.V. T: +31.20.808.3128 E: info@xellz.com W: https://www.xellz.com

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PROCESSING

Mixability of Different Hydraulic Fluids Why mixing of different bio hydraulic fluids is not recommended by any manufacturer The difference between mixability and compatibility, as well as the long-term negative impact that incompatibility can have on your equipment: These are topics that often don’t get the attention they deserve.

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ou can mix different Environmentally Acceptable Hydraulic Fluids, but the question remains: Do these different fluids work together efficiently without negative impact on components of the hydraulic system? The answer is no. The variety of base oils (esters) classified as «HEES» When it comes to bio oils (Environmentally / Acceptable Hydraulic Fluids), competitors often claim mixability and full compatibility by stating that they use HEES/synthetic esters as base oils, just like PANOLIN does. What they don’t mention in this context is that there are thousands of different HEES/synthetic esters and that just because the terminology sounds similar, it doesn’t mean you get the same performance. Otherwise, why would PANOLIN be the benchmark for high-performance hydraulic fluids and why are other fluids not able to perform to such high levels? When you see a reference to base-oil specifications according to ISO - which in the case of ester-based lubricants falls under the group category «HEES» - bear in mind that this group covers both unsaturated and saturated synthetic esters. This is just one reason why performance levels differ. It is not just about the base oils, but the additive systems as well Most of the arguments competitors make when they compare themselves to PANOLIN have to do with the base oils but they do not consider

the additive systems. Have you considered the role of additive systems? They come in many different qualities and can be mixed into the base oil in many ways. PANOLIN additive technologies are based on more than 35 years of experience and are combined from many different individual components. This is a rarity in the marketplace as it is obviously less cost-effective than purchasing a readymade additive package from a major chemical company and mixing it into the base oil to come up with a finished product. Different additive systems are not detectable by routine chemical analysis. The picture on the following page shows the catastrophic impact on bronze material in a hydraulic piston pump caused by the non-compatibility of additive systems in two different hydraulic fluids. Failures are expensive Almost any liquid can be mixed, but that doesn’t necessarily mean it is compatible. The crucial point is whether the base oils and additives of the two fluids are compatible. To justify this, the composition of the fluids has to be known, but PANOLIN does not share this information. The serious negative effects on your equipment will not show immediately, but the degradation sets in gradually until the damage is irreversible. The cost for repair can be many times what an initial investment in the best possible and OEM-approved fluid for your machine would have cost.

Summary •

Mixability is not the same as compatibility: Only compatibility guarantees the functionality of hydraulic systems without problems or failures.

Not all esters are the same.

HEES covers two different ester types: saturated and unsaturated, which are not the same.

The additive systems must be compatible otherwise a negative impact on the equipment cannot be avoided.

Contact us to get free advice and education on environmentally friendly lubricants from the PANOLIN TecCenter.

Conclusion •

PANOLIN technology is committed to high performance and environmental compatibility, based on more than 35 years of experience.

Unfortunately, competitors make claims that have a negative impact on costs and expenses for the end user.

Leading official equipment and component manufacturers will tell you not to mix hydraulic fluids as it has a negative impact on the performance and compatibility of the system and materials.

PANOLIN is concerned about the negative impact on your business arising from false information issued by other lubricant manufacturers.



PROCESSING

Future Proof the Process Industry OGI sits down with Klippon Engineering for another installment of our interview series. Klippon Engineering is the internationally renowned partner of the Weidmueller Group in the field of process engineering. They combine over 60 years of engineering expertise with the knowledge and experience of their specialists and strategic partnerships, in the process industry. We delve into a fascinating case study involving Exolum and Weidmueller’s remote I/O technology. More below.

OGI: Could you talk about Klippon Engineering and the work they do? Klippon: Klippon Engineering is headquartered in the UK. This is where we started producing the first fully certified terminal blocks and enclosures more than 60 years ago. Today, our offering ranges from connectivity solutions, power and signal protection products and systems, to complete solutions and technologies for communications, retrofit & migration, automation, translation, IoT and data acquisition/analysis. Klippon Engineering aims to provide you with a customised system or solution suiting your industry or application. We identify connectivity as the key to meeting the industrial needs of the present and the future. That’s why our “Best in Market” solutions from the well-known Klippon® brand have a close connection to all areas of the process industry. Whether green energy i.e., Hydrogen, oil & gas, chemicals & pharmaceuticals, water treatment, heavy industry, glass, or paper production: we are at the side of all branches of industry as a partner with our global Klippon Engineering expert network. Let’s connect – and face the future together. OGI: What is PROtop and could you talk a bit about it? Klippon: PROtop is a superior, future-proof, and sustainable high-end power supply created for the highest demands of Industry 4.0.

Installations need a reliable power supply that can withstand harsh environmental conditions 24/7, condition monitoring for targeted, preventive maintenance is becoming important. PROtop combines the highest efficiency and compact housings with high durability and direct parallel connection, without diode modules; this reduces costs and creates space in the control cabinet. Due to the powerful DCL technology, even difficult loads - motors, for instance - are operated smoothly, while circuit breakers are triggered reliably.

This excellent communication capability allows permanent condition monitoring and full integration with control systems. OGI: What are the main advantages of using Klippon Engineering’s enclosure systems? Klippon: Klippon Engineering’s ranges of enclosures are of proven premium quality, comprehensively certified for all global regions and can be equipped with all the necessary electronic components, buttons, connection solutions, etc. for specific applications. These junction boxes can be configured and ordered directly in the Weidmüller Configurator. Our worldwide assembly locations ensure fast delivery service. Klippon Engineering’s umbrella certification process allows fast economic certification of new applications and this is coupled with Weidmuller’s accredited laboratories offering the ability to perform application-specific tests and issue accredited test lab reports to support each project. OGI: Can you talk about the importance of protection, safety, and reliability when choosing a partner for automation? Klippon: With ever-increasing safety demands along with the need to increase product life and reduce the cost of plant ownership within the process sector, any selected partner must have an outstanding safety record and a proven track record for quality and service.

“We identify connectivity as the key to meeting the industrial needs of the present and the future.”


Klippon Engineering with its many years of personal expertise in certification and product design can support a challenging market. Weidmuller’s latest products have extended MTBF increased efficiency and reliability whilst ensuring all required regulations and safety standards are achieved. OGI: Is it possible to outfit / retrofit processing plants without extended downtime, and if so, how does that work? Klippon: The need for ever-increasingly complex machines and systems and with many systems globally coming to the end of their useful life make the rewiring of controls, sensors, or actuators a challenge. However, it is possible - Klippon Engineering uses migration and retrofit solutions to speed up installation and avoid wiring errors. This saves time and money. We offer PLC/DCS interface boards, front connectors, interfaces and assembled cables for all commercially available control systems. And if required, we also supply you with an individual PLC/DCS migration solution including approval. OGI: Finally, could you enlighten our readers of a case study where you helped a client with your solutions? Klippon: A good example is the retrofit of Weidmüllers remote I/O at our customer Exolum. Exolum manages Europe’s largest network of refined products and is ranked second in Europe in terms of storage capacity and seventh in the world. The site in Amsterdam is offering storage and logistics services for different types of fuels. In 2018 the old DCS was replaced with a new one. Due to the size of the project, it was decided to leave the existing remote I/O in place and only the CPU modules and communication modules were replaced. The selected DCS – System exists of two redundant CPU’s and communication modules for the radar level measurement, 8 block & bleed loops, remote I/O (Profibus based) and several sub systems. After completion of the DCS replacement, Exolum started the next phase in the project being the replacement of the remote I/O.

The key features they were looking for were cost efficiency and reliability. They first had the idea to stay with their existing automation supplier, but it turned out that their remote I/O was very costly and needed space which was not available. Exolum found u-remote on our website. At the same time, they visited the Hannover fair and used this opportunity to have a short introduction of u-remote at the Weidmüller booth. After the fair, this visit was followed up and an appointment was made for an in-depth discussion and a demonstration of U-remote at Exolum. Klaas Wijbenga (Automation sales engineer) and John van Leeuwen Business development manager - process at Klippon Engineering) introduced the Weidmüller portfolio and demonstrated u-remote. It was advised to use the TCP/IP communication instead of the Profibus. At the same time, Exolum had a small project on hand which was not critical and for which they needed control. In this project, they have used u-remote to test the system. This application was the control of a heat tracing on pipes, using an electrical heating

system which should be controlled by one controller per string. In total there are 13 strings. On each string, there are two Pt100 temperature sensors and the highest value is leading for the control. After a test of half a year without any failures and excellent support from Weidmüller, the choice was made to use u-remote for their remote I/O requirements. They did realise that support is always required when you select something new and it is necessary to find out how it works but their experience with other suppliers was not always as positive as they experienced with Klippon Engineering. A second project in the boiler room, where during normal operation a complete system was exchanged without interruption of the daily operation, was proof for them that they made the right choice. “The personal involvement and friendly relationship that was created from the first minute has given us trust in selecting Weidmüller as a partner for our automation solutions” explains René van Oostrom of Exolum. “Besides the u-remote including the control functionality, they help us with the complete solution for the 24Vdc power solution, the Ethernet based infrastructure and the marshalling concept including signal conditioners, surge protection and junction boxes”. The next step in our fruitful co-operation will be a pilot project for Industrial Analytics. As on most sites also at Exolum there are several “simple” rotation equipment is operational, and these are not monitored other than through visual inspection. With this pilot project, u-sense vibrations sensors will be installed on a few pumps and with the Auto ML software, we will create a predictive maintenance tool. If this industrial IoT solution is successful, this solution will be extended for all critical pumps. OGI: Thank you for your time. • Klippon Engineering UK Ltd. T: +44 1162 823470 W: https://www.klippon-engineering.com

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PROCESSING

RETROFITTABLE VIBRATION SENSORS LoRaWAN is setting the future strategy for Condition-based Asset Monitoring For Rotterdam based I-IoT experts TWTG, 31st August 2021 is a milestone in this pioneering technology company’s moderately short, but colourful history. On that day, the team announced they had won a tender to supply Shell’s Pernis Refinery with their NEON Vibration Sensors.

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or oil and gas operators, the ambition to increase the digitalisation of facilities has become increasingly prevalent. And also for Shell, the future of asset performance management is changing. Becoming ever more digitised, with data collected from Industrial IoT sensors providing increased insight and knowledge. This project will help demonstrate the benefits that condition-based asset monitoring can bring to any industrial facility. The Vibration Sensors work by detecting bearing faults on pumps, motors or other rotating equipment early, allowing operators to act swiftly before any serious issues arise, so by reducing downtime and eliminating potentially hazardous situations. The Vibration Sensor is designed to be retrofitted to existing machinery and enable previously-passive objects to achieve ‘smart’ abilities and accordingly, contribute data. Data enables engineers to learn about the wellbeing of a facility and make proactive decisions concerning maintenance or replacement of equipment. Over time, harvested data will enable engineers to analyse historical data, look for clues, anomalies, or sequences of events that occurred as precursors to an incident and start to learn the, sometimes seemingly unconnected, tell-tale markers to avoid recurrences.

Beautifully designed, robust devices, NEON products are built with the quality components and materials necessary to meet the stringent levels essential for use in the oil and gas environments. A crucial feature of the Vibration Sensor is its ability to transmit frequency spectrum via LoRaWAN. This functionality is a game-changer, eagerly

demanded and awaited for by engineers - a feat never achieved before by a LoRaWAN sensor. Felix Fikke, Instrumentation Project Engineer at Shell Pernis, was excited about having NEON Vibration Sensor on site: “These devices will change the way that we monitor our pumps and allow us to react faster. We can measure root-mean-square (RMS) velocity as well as Fast Fourier Transform (FFT), and all this is possible with a LoRaWAN sensor which is fantastic!” For TWTG, to win the Shell tender is a significant moment and one they do not take lightly. John Tillema, Co-founder and CTO at TWTG, is understandably enthusiastic. “We are delighted Shell placed their trust in TWTG for the delivery of our products, and we will work tirelessly to demonstrate that we should be the supplier of choice for any other LoRaWAN devices in the future.” And for TWTG, this is incredibly personal. Shell’s actions validate their decision to keep their development firmly concentrated on LoRaWAN based products. Tillema explains, “It wasn’t a quick decision to base our future development on LoRaWAN. Over the last few years, the industry has debated which protocol is the perfect wireless backhaul to establish tomorrow’s I-IoT

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solutions. Bluetooth, 5G, Wifi, to name a few and of course LoRaWAN. We didn’t ignore these discussions - in fact, we listened hard. We didn’t bury our heads in the sand and continue development regardless. We continually assessed our strategy and reviewed the technological landscape. And always we came to the same conclusion - That LoRaWAN was the right strategy. It’s the only protocol to tick all the boxes Affordability, scalability, reliability, versatility. LoRaWAN devices use very little power - The lack of hardwiring meant that devices could be fitted anywhere, installed and calibrated in only a few minutes. And probably the last determinator - these devices were retrofittable. This means oil and gas companies can enable existing facilities to become ‘Smart’ without the need to replace what is otherwise perfectly functional equipment. We have worked hard for this moment; it’s a big moment for TWTG. But for me, this moment is about our team. I am proud of every member of our team we have assembled to get this far. It’s their endless resilience, aptitude, and enthusiasm that drives us to achieve, well, almost anything.” Partners Report Reveal Impressive Results from TWTG Devices Shells’ recent announcement coincides with a new report released in August that compares measurements from NEON Vibration Sensors with established portable vibration testing equipment. These tests were conducted under the watchful eye of external testing engineers and involved testing seven different machines at two locations. TWTG’s R&D lead, Thijs Buuron, explained the principle behind the report. “We set out to prove the accuracy and adaptability of our NEON Vibration Sensor, which is designed to be retrofitted onto any pump or motor in the field. Scrutinised by test partners, we performed a series of tests, first with our own Vibration Sensor and then with the certified test equipment.

We used two different solutions for the test equipment, and these are generally accepted to be the best available on the market, and notably, each cost approximately 30 times the price of a single NEON vibration device.” Before the test, KPIs were agreed upon that would define a successful result. The goal was to achieve comparable results to the test apparatus in terms of RMS velocity. For TWTG, the results were fantastic. The NEON devices demonstrated the KPIs agreed and provided close to the given measurements of the extremely precise manual vibration measurement instruments used as the control tools. Buuron revealed, ”All in all, we are excited with the results, and they absolutely verify the accuracy of the LoRaWAN sensors. In general, the test demonstrates that our numbers match very closely with the reference numbers. They represent an opportunity for engineers to achieve near real-time measurements and enjoy a far better insight into trend information. This is powerful data that allows companies to benefit from early warnings and eventually avoid unscheduled downtime altogether.” Buuron is a testament to Tillema’s belief in the team TWTG have built over the past few years. In 2018, after graduating from Rotterdam University of Applied Sciences, Buuron joined TWTG and quickly established himself as a key member of the development team. If his work wasn’t busy enough already, Buuron is always keen to expand his knowledge and TWTG encourages this by freeing up his schedule to study remotely at the University of Boulder, Colorado, for a Masters in Electrical Engineering. In his spare time, Buuron relaxes by creating his own personal electrical engineering projects. Currently, he’s tracking his friends and colleagues and then applying some

advanced machine learning techniques, aiming to perfect his Nerf Gun gameplay. A New Landscape TWTG’s recent successes represent a new mindset for the oil and gas industry. As an industry, it has been slow to adopt new technology - not just today, in digital terms - but also in bygone years with mechanical innovations, it is an industry that invests in terms of generations, not years. Traditionally, there has always been time to think about change and a cushion of money on which to take that time to decide. But now, things are different. The technological wave is so rapid, it changes and evolves at a totally different pace. You can’t plan a technological solution that will be in place for a generation. However, oil and gas companies have understood the value of technology and recognise it will make them more profitable and allow them to differentiate in terms of safety and efficiency in a hypercompetitive environment. What is needed is technological solutions that work with existing infrastructure. Not wholesale replacement of what is still good machinery to achieve a digital overview. The last word is with the co- Founder, Tillema. “With the Shell announcement and the release of the report that confirms the viability of the Vibration Sensor, it has been a big couple of weeks for TWTG, but we are confident this is only the beginning of a new period of digitisation within the industry. Like an oil tanker, the oil and gas industry has been slow to turn, but now the ship has begun to turn, we are heading into a new technological era. Oil and gas companies are seeing the benefits of utilising data to increase efficiency, safety, and ultimately profitability.” • TWTG W: www.TWTG.io/industry E: mail@TWTG.io T: +31 10 203 7905

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PROCESSING

Avoid Downtime, Save Money: Choose the Right Partner OGI sits down with Hetraco B.V. to learn more about the work they do for the petrochemical, offshore, maritime, and building industries. Hetraco B.V. is a manufacturer of special fasteners with rolled thread. Particularly in the petrochemical industry, things can change very quickly and Hetraco helps us understand why it is so important to be able to act and react quickly, which helps their clients avoid costly downtime. Many companies don’t realize that when you buy high quality and reliable assets, you must use high quality and reliable fasteners as well. We learn more below.

OGI: Could you start by explaining Hetraco B.V.’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? Hetraco: Hetraco B.V. was founded in 1972 by Herman Hendriksen. The name Hetraco B.V. is an abbreviation of Hendriksen Trading Company. Hendriksen started selling turned, die-cast and bended products to industry and machine manufacturing companies from his home. In 1982, Kees Eindhoven took over Hetraco B.V. and the company shifted its activities more towards the chemical industry and offshore, sectors which require fast delivery of special bolts, nuts and studs. To meet this need, Mark Eindhoven started his own production company, under the name Dutch Bolting Company B.V. (DBC). In 2004, Hetraco B.V. was also acquired by Mark Eindhoven. This resulted in the ideal combination of an organization both purchasing and selling all types of fasteners materials available in the market, with the addition of the in-house production of ‘specials’. 2021 Hetraco has experienced enormous growth and presented it’s new strategic plan 2021-2025 together with a change of the board.

Nowadays we’re manufacturer of special fasteners with rolled thread. We deliver these products globally to a couple (focus) market segments like petrochemical, offshore, maritime and heavy industry building.

In the future, Hetraco wants to continue growing, creating a stronger and even more solid organization.

We always attempt to offer products to our customers with their requested delivery times. We have a high service grade, customer focus and deliver products with high quality are important for us. Also our flexible delivery times are one of the reasons why customers keep coming back.

Hetraco: We produce all kind of fasteners like bolts, nuts, studs and products according to drawings. Our specialism is “thread rolling” in all kinds of types, like Metric, UNC, UNF, 8-UN, BSW, etc. The dimensions we’re able to produce are from M5 – till M200.

OGI: Could you talk about the work you do with fasteners manufacturing?

Our production starts with searching the correct raw material according to the requested specifications. We have a large stock by ourselves with EU-materials, from standard steel, high temperature, stainless, Duplex and the Nickel Alloys. The next phase is the production on our CNC-machines with turning & milling and final phase is thread rolling. Recently we have invested in a Doosan Puma 700XLY which is capable of bars up to 5 meters between the centers. This machine is supported by 6 hydraulic steady rest for stable running. OGI: Could you talk about the work you do in the offshore sector? Hetraco: Currently we have been seeing a lot of changes within the offshore industry, nowadays the focus becomes more and more

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Rolled Thread, the Hetraco Specialty.

to the wind industry. At this moment we are building reliable and long-term partnerships with companies who are investing in this industry. You can think about Crane building, Gang-way production and all service-related companies. We’re also very proud of a being a partner from Allseas and that we could deliver several projects for the Pioneering Spirit. This is a very positive reference for us to promote our business. OGI: Could you talk about the work you do in the petrochemical sector? Hetraco: Our experience in the petrochemical industry is already more than 30 years. This started with a couple refineries in The Netherlands where we delivered our special fasteners. Because we’ve expanded the capabilities of our own production facilities, we currently deliver our products on refineries through all Europe. In this sector it is very important that you are able to act & react very fast. During a TA (turnaround) there will be around 2000-3000 people working on a plant. It is very important to get the downtime as short as possible. Because of these extreme challenges we have created extra production capacities for our partners during these turnarounds. In preparation of the turnaround we have meetings what they expect from us. On this basis we can retain production time and people available even on the weekends if necessary. OGI: Why is it so important to have the right partner in relation to fasteners? Hetraco: I think that it is always (and for every part) important to have the right partner. Regarding the fasteners, these will usually be used at the end-phase, during the assembly or during the change when the turnaround already is started. These fasteners are often forgotten or ordered too late. Purchase departments sometimes thinks too easy about this and talk about special fasteners if you can pick them from stock.

When you expect a high quality and reliable product you also need to buy high quality fasteners. Build a good relationship with a manufacturer and give them also in an early stage the information about your expectations. If you can manage this together the manufacturer has also the time to buy the correct raw material with the correct specifications. He will be able to manufacture fasteners on the requested delivery dates and is also able to produce the urgent unexpected deliveries during the turnaround. OGI: What are the various products that you offer the oil and gas industries? Hetraco: We are able to manufacture thread related special fasteners like bolts, nuts, studbolts and products according to drawings. The dimensions we are able to produce are from M5 till M200 and other types of thread like UNC, 8-UN, UNF, BSW, BSF, BSP, G, Metric Fine & customer specific.

Rolled Thread > that is our specialty! In our production facility we have 6 thread roll machines; this is including our latest investment of the PR-100 which is a 100Tons machine. Our staff has more than 20year experience and we have a very good mix of personal for sharing knowledge and continue the future business. We are unique in the Benelux with this machine park and the capabilities we are able to offer. OGI: Finally, could you enlighten our readers of a case study where you helped a client with your solutions? Hetraco: We are not an engineering company who is able to develop new solutions or make calculations for projects. We are able to deliver to customer specifications and produce the products with the correct raw material, 98% from EU material. If the customer has additional request like a surface treatment, Magnetic Particle Inspection, third party inspection or something else we are able to arrange this. We would like to unburden the customer and along to simplify the process so that costs can be saved. You can think about a yearly based contract with raw material directly from mill manufacturer till simplify packaging or arrange weekly transport by ourselves. We have several examples which are customer specific based, and we can tell you that we have saved thousands of euros together. It starts with a good inventory based on the wishes of the customer. We look forward to get in contact with you! OGI: Thank you for your time. • If you would like to know more about how Hetraco B.V. can help your company and its operations, please contact them at: Hetraco B.V. T: +31 55 303 21 80 E: sales@hetraco.com W: https://www.hetraco.com

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PROCESSING

Clean Gas? Are You Sure? New technology is reducing the risk of compressor and other plant failures. National Grid in the UK has recently published its findings on testing a camera-based system to detect liquid and solid contamination in gas flows. LineVu provides live video streams that show activity in high pressure pipelines for both gas processors and gas networks. This information provides an extra dimension in understanding and allows actionable insights to be made for process control and gas quality.

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as/liquid separators are not 100% efficient 100% of the time. In fact, their performance is one of the most common causes of problems and capacity constraints. Foaming, flow surges, start-up, shutdown, and flow ramping are all common causes of liquid carry-over. Liquids in a gas network collect at low points that cause corrosion, compressor failures, or even explosions. Undetected liquids cost the industry $Millions every year in damage, lost revenue and labour costs. While dewpoint meters and gas chromatographs monitor gas quality, amine and glycol are most likely to carry over into the sales gas lines when separator performance is compromised, and these liquids are not currently monitored. Within a plant, poor separator performance can be a real problem. When a dew pointing system is fitted to remove condensate, glycol carry-over can freeze and cause blockages. Molecular sieves and mercury absorber beds can be destroyed by liquid carry-over. More importantly, their life is insidiously reduced by small, constant, undetectable liquid carry-over. Compressor Failures The lack of liquid carry-over monitoring frequently means that liquid contamination is not known until it is too late and a compressor fails. Dry Gas Seals (DGS) within gas compressors rely on a supply of clean process gas to ensure lift-off between static and rotating

components. When liquids enter the gap between the rotating seat and stationary face, high shearing forces generate heat. The generated heat leads to gap instability, causing contact between the rotating seat and stationary face, damaging the seal faces and resulting in a seal failure. In a survey of 71 compressor failures, 100% of failures reported liquid ingress to the DGS. The health and safety report went on to state that: “DGS failures are not normally directly hazardous but have the potential for escalation. Resulting in an uncontrolled excessive release

of hydrocarbon gas.” Gas Safety Management Regulations (GS(M) R) in the UK and Federal Energy Resource Council (FERC) in the USA require that gas in transmission networks should not contain liquids or solids. This is impossible to determine with current technology at custody transfer at the gas entry points to a network. Ensuring a contaminant free gas in networks also extends the asset life by reducing the threat of corrosion. When liquids are present in a network, they pool at low points and corrode the pipeline to the point of rupture, as at Carlsbad, New Mexico. Fiscal Measurements When contamination occurs in dry gas flows, orifice plate and ultrasonic flow meters overread, significantly increasing the uncertainty from <0.5% to around 2%. As calorific value and hydrocarbon dewpoint measurements are taken from the gas phase only, any liquids at the bottom of the pipe are not included in these measurements. A New Understanding

Figure 1. The LineVu Camera Can.

Figure 2. Mobile phone app.

As more systems are installed worldwide, data from this patented technology is bringing a better understanding of how gas and contamination interact within a pipeline. Much of the real-world data gathered from large diameter pipelines do not agree with


established fluid dynamic models. While most CFD models treat liquids in a pipeline as homogenous, separation of different density liquid flows has been observed at high pressure, and lighter end liquids have been seen being drawn off of a stationary mass of contamination, leaving a dry material behind. LineVu brings a new approach to monitoring liquid carryover that provides certainty about gas pipeline contamination levels. When liquid flows occur, they are often not one flat stream but, depending on their density, could be a worm-like shape or many small streams. Operators are provided with a live view of pipeline activity, and image processing is used to alarm if contamination is present. Implementing this technology enables compliance with regulations, improves process safety, and has several financial benefits. LineVu’s “Camera Can” is certified for use in hazardous areas and normally mounted vertically on a standard tapping point and views down to the pipe floor below reporting activity on the pipe floor and in the gas flow between the camera and the pipe floor. By continuously monitoring the effectiveness of gas/liquid separators, more effective maintenance is possible, and the threats posed by contamination are decreased. The National Grid trial effectively validated the video detection system, and LineVu is now providing video-based liquid detection systems for in-pipe monitoring. The camera and illumination system is configured to take video and images of the pipeline through the isolation valve. With a live link to the control room, operators better understand gas quality and the impact of process changes. The standard flange is a Class 900 3” RTJ. The Camera Can (Figure 3) has a secondary containment vessel to prevent loss of containment upon a window or seal failure. The secondary containment vessel is constantly monitored for pressure and temperature. The SIM card in the interface unit allows connection to the mobile phone network via a secure link to

Figure 3. Camera Can.

enable technical support, including:

configured for notification via:

Relay activation.

Email notification – with still shots.

Text notification – with still shots.

Push notification – with still shots.

Remote system commissioning, setting camera and illumination for optimum results.

Continuous health checks.

Upload of software updates.

Fault diagnosis.

Remote technical resources able to view live data to aid operational decisions.

Data monitoring.

Greater process confidence is gained when operators can see events in highpressure systems. When the alarm is raised, LineVu automatically starts recording data. It continues to record until no further contamination is detected. The interface unit and LineVu controller are mounted in a safe area, with an ethernet connection between them. All data is saved on-site with sufficient space in the LineVu Controller to save up to a year of data. The system has proved to be highly sensitive to mist flows and liquid streams in a pipe with alarm thresholds set at a high sensitivity level with notification emails set up. In addition to the alarm function, LineVu provides extra functionality beyond the detection of contamination. In normal operation, LineVu is set to store a still shot once a minute. It automatically compiles these shots into a time-lapse video which can be downloaded every 24 hours. Replaying these videos at 1500x speed highlights and reveals low-level contamination (under alarm threshold) for further investigation. Threshold alarms and system alarms can be

As the system has access to the mobile phone network, cybersecurity has been considered in its design. There are several levels of security. The systems can operate independently of the operational or data networks operated by the end-user; all connections are via a secure link, and all data uses high-level encryption. In addition to alarm notification, each system provides a web interface (Figure 5) that can be accessed with the correct credentials and user authentication. Users can: •

View live video

View historical video

Export sections of footage

Export snapshots and PDF reports

A mobile phone app (Figure 2) is also available via a secure and authenticated link. Conclusion With a LineVu system installed, threats to asset integrity such as compressors, and corrosion can be better managed; sources of contamination can be better understood and therefore reduced. Uncertainties on fiscal measurements of both flow and calorific value can be better managed. Clean-up costs after a contamination event can be correctly allocated to the source. • Process Vision Ltd. W: www. processvision.com E: info@processvision.com

Figure 3 The LineVu System.


ADIPEC 2021 to Welcome Back the Global Energy Sector in Person • •

The world’s most influential meeting place for energy companies and professionals will once again convene in-person – safely and securely – in Abu Dhabi New market dynamics, the energy transition, technical innovation and hydrogen’s potential will be high on the agenda of the four-day event – the industry’s first chance to meet following COP26

A

DIPEC will return in person this year to the Abu Dhabi National Exhibition Centre, bringing together experts from across the sector and giving visitors the chance to shape the future of the energy landscape. ADIPEC 2021 will convene energy professionals on both the production and consumer ends of the value chain to network in a safe and secure way; to unlock millions of dollars’ worth of new business; and to discover the range of products, solutions and technologies at the cutting-edge of the industry. As the first opportunity to reflect on the outcomes of the UN Climate Change Conference (COP26), this year’s edition will offer: • An Exhibition showcasing the expertise of more than 2,000 companies, where over 51 national oil companies, international oil companies and international energy companies – along with 26 international country pavilions – will outline the best of the global energy sector, as well as providing visitors first-hand experience of the application of digitalisation. • High-level Leadership Roundtables, convening executives and government ministers in the exclusive Middle East Energy Club to discuss and debate the strategic challenges and opportunities facing the energy sector.

A Strategic Conference on the new market dynamics and innovations that are changing the energy sector, the potential of hydrogen to support the energy transition, how to unlock new value in the Offshore and Marine sector in an age of decarbonisation, and the scope for smart manufacturing.

ADIPEC’s flagship Forum for Diversity, Equity and Inclusion, where thought leaders will offer insights on how to build the future energy workforce.A comprehensive Technical Conference welcoming engineers from around the world, who will share best practice and discuss everything from geosciences and the application of artificial intelligence to maintaining operational excellence in the field.

The 11th edition of the prestigious ADIPEC Awards, honouring those innovators, projects, companies, and individuals exploring possibilities that can reshape the energy world.


Christopher Hudson, President of dmg events, organisers of ADIPEC, comments “There is a great amount to discuss this year for energy companies, governments, and stakeholders across the value chain, from the challenges posed by new emissions targets to the possibilities opened up by the world’s ongoing economic recovery. The opportunity for these discussions will be at ADIPEC 2021, the first major energy exhibition and conference taking place after COP26, where CEOs, government ministers from around the world and energy experts will set out the future of the sector.” He added: “After over a year of lockdowns, restrictions and virtual sessions, the message we have received from the industry is clear: it is eager to again meet in person, share best practice, and find new opportunities that simply could not happen virtually. As we look forward to returning in person to Abu Dhabi, 2021’s edition is set to be the most important yet.” •

Christopher Hudson, President of dmg events.


ADIPEC SPECIAL Natural Gas to Play Pivotal Role in Powering the UAE’s Economic Growth for the Next 50 Years In the opening address of Gastech, Minister of Industry and Advanced Technology H.E. Dr. Al Jaber explains how the UAE is strengthening its position as a regional leader in natural gas and the emerging blue Hydrogen market. Balancing economic growth with environmental protection was the impetus for the UAE’s gas industry and it turned an environmental liability into a commercial opportunity H.E. Dr. Al Jaber notes LNG and broader gas markets globally are tightening, with demand outpacing supply. Building strong partnerships is at the center of the UAE’s approach to growth and it invites new and existing partners to take advantage of opportunities in its gas businesses. ADNOC is on track to enable gas self-sufficiency for the UAE and is progressing major gas projects. Natural gas is set to play a pivotal role in powering economic growth in the United Arab Emirates (UAE) over the next 50 years, according to His Excellency Dr. Sultan Ahmed Al Jaber, UAE Minister of Industry and Advanced Technology and Managing Director and Group CEO of the Abu Dhabi National Oil Company (ADNOC). Delivering the opening address of Gastech 2021, H.E. Dr. Al Jaber highlighted the United Arab Emirate’s (UAE) leadership in natural gas and said natural gas will support the nation’s vision for economic growth as set out by the Leadership in the ‘Principles of the Fifty’. “The ‘Principles of the Fifty’ is a mandate for progress driven by 10 guiding principles aimed at making the UAE the most dynamic economy in the world. Gas will play a pivotal role in this blueprint for growth, as the essential fuel stock for our downstream hub in Ruwais and our industrial joint venture, TA’ZIZ,” H.E. Dr. Al Jaber said. Speaking virtually, His Excellency explained that the UAE is strengthening its position as a regional leader in natural gas and the emerging blue Hydrogen market. He attributed this leadership position to the foresight of the Founding Founder of the UAE, the late Sheikh Zayed, who recognized the enormous potential natural gas offered and the need to balance economic growth with environmental protection. “Our Founding Father Sheikh Zayed’s commitment to the environment and truly sustainable development was the key driver. In 1973, at his direction, ADNOC stopped burning the associated gas from all its operations, and instead captured it and shipped it. “In short,” H.E. Dr. Al Jaber added, “we turned an environmental liability into a commercial opportunity. From that moment, when it came to gas, we never looked back. For almost fifty years the UAE has viewed gas in all its forms as one big opportunity, and we’ve built our gas business on a number of firsts.” d use it in enhanced oil recovery (EOR) to liberate more gas.

H.E. Dr. Al Jaber pointed out that the country was the first in the region to stop flaring and find economic uses for gas, the first to build a liquefied natural gas (LNG) plant, the first to produce ultra-sour gas at an industrial scale, and the first to store carbon dioxide (CO2) and use it in enhanced oil recovery (EOR) to liberate more gas. The UAE is on track to achieve gas self-sufficiency as ADNOC leverages advanced technologies to expand into unconventional gas, tap into gas caps and unlock new reservoirs, as part of the company’s integrated gas strategy launched in 2018. “At the heart of this goal, is the expansion of our producing assets, like Shah and the development of new ones, like the unique Umm Shaif gas cap and the Hail, Ghasha and Dalma project,” H.E. Dr. Al Jaber said, as he provided an update on ADNOC’s progress. “Construction of artificial islands is underway and we are leveraging our experience in world-class developments to ensure costs are minimized and commercial benefits maximized for all our partners. Together, these projects will deliver over 3 billion standard cubic feet of gas per day, enough to power several million homes.” His Excellency went on to share his perspectives on natural gas markets and the role natural gas will play in the energy transition. “As the world consolidates its recovery from the Covid-19 pandemic, LNG and broader gas markets globally are tightening, with demand outpacing supply. Longer-term, the outlook is also robust, driven particularly by markets in Asia. Gas provides almost one-quarter of the world’s energy supply and will continue to play a critical role in the global energy system. No other fuel source can reliably supply the baseload power to heat and cool homes, drive heavy industry and expand economies, all while keeping emissions at a minimum.” His Excellency added that as innovations are helping to make gas even cleaner and more sustainable, the UAE is applying technology to create zero-carbon fuels from gas such as Hydrogen. “Already at ADNOC, we produce about 300,000 tons of hydrogen a year. By leveraging our existing gas infrastructure and commercial-scale CCUS capabilities, the UAE can and will become a major player in the emerging blue hydrogen market.” Concluding his remarks, H.E. Dr. Al Jaber extended an open invitation for partnership in the UAE’s gas industry, noting that building strong partnerships across the world is one of the key principles for the UAE’s economic vision. “This has always been at the center of our approach to growth and it will remain the key to the future.” Gastech is the world’s foremost gas, LNG, hydrogen, and energy event. The 2021 edition is taking place in Dubai under the patronage of His Highness Sheikh Mohammed Bin Rashid Al Maktoum, Vice President and Prime Minister of the UAE and Ruler of Dubai. •

New Well to be Drilled at South Pars

TEHRAN (NIOC) _ Pars Oil and Gas Company is planning to drill a new well at South Pars offshore gas field in order to preserve the field’s output. The Director of Oil and Gas Engineering of Pars Oil and Gas Company said measures are being taken to maintain production from the South Pars gas field including drilling a new well in the northern part of this joint field. According to Pars Oil and Gas Company, Ali Akbar Majed said preliminary processes for drilling a descriptive well in the northern part of the field have started and drilling operations are expected to begin by late September. He also announced planning to identify new gas reserves in South Pars. •

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ADIPEC SPECIAL ADNOC Invests Over $750 Million in Drilling Services to Support Production Capacity Growth The Abu Dhabi National Oil Company (ADNOC) announced an investment of $763.7 million (AED2.8 billion) in integrated rigless services across six of its artificial islands in the Upper Zakum and Satah Al Razboot (SARB) fields to support its production capacity expansion to 5 million barrels per day (mmbpd) by 2030. The investment is in the form of three contracts awarded by ADNOC Offshore to Schlumberger, ADNOC Drilling, and Halliburton after a competitive tender process. Schlumberger’s share of the award is valued at $381.18 million (AED1.4 billion); ADNOC Drilling’s share is valued at $228.71 million (AED839.58 million), and Halliburton’s share is valued at $153.87 million (AED564.85 million). Over 80% of the total award value will flow back into the United Arab Emirate’s (UAE) economy under ADNOC’s In-Country Value (ICV) program over the 5-year duration of the contracts, reinforcing ADNOC’s commitment to ensuring more economic value remains in the country from the contracts it awards. Yaser Saeed Almazrouei, ADNOC Upstream Executive Director, said: “These important awards for integrated rigless services will drive efficiencies of drilling and related services, and optimize costs in our Offshore operations as we ramp up our drilling activities to increase our production capacity and enable gas self-sufficiency for the UAE. The contractors bring best-in-class expertise and technologies with a proven track record in the industry and ADNOC Drilling’s scope reflects its expanded service profile following its successful transformation into a fully integrated drilling services (IDS) company, enabling it to offer its clients start-to-finish well drilling and construction services. Importantly, the high In-Country Value generated from the awards will stimulate new business opportunities for the private sector and support the UAE’s post-Covid economic growth.” The scope of the contracts includes coiled tubing services with thrutubing downhole tools, stimulation services, including equipment and chemicals/fluid systems, surface well testing services, wireline, and production logging services and tools, saturation monitoring, and well integrity. Previously, ADNOC Offshore’s rigless services were provided through several discrete service-specific contracts. Unifying the scope through integrated service contracts, underpins ADNOC’s smart approach to procurement and provides ADNOC Offshore with operational flexibility while enabling cost efficiencies and single point responsibility by the contractors. Ahmad Saqer Al-Suwaidi, CEO of ADNOC Offshore, said: “These contracts are an important contributor to ADNOC Offshore’s plans to build our production capacity to over 2 million barrels a day in the coming years to support the ADNOC Group’s smart growth strategy. The award follows a highly competitive bid process, which included a rigorous assessment of how much of the contract value would support the growth and diversification of the UAE’s economy through ADNOC’s In-Country Value Program.” The six artificial islands covered by the awards are Asseifiya, Ettouk, Al Ghallan, and Umm Al Anbar in the Upper Zakum field and Al Qatia

and Bu Sikeen in the SARB field. Artificial islands provide significant cost and environmental benefits, particularly in shallow water, by enabling the use of lower-cost land-drilling rigs instead of higher-cost offshore jack-up drilling rigs. ADNOC has a proven record of developing artificial islands and drilling the Middle-East’s longest wells, as part of its continued commitment to protecting the UAE’s marine environment while enabling greater operational efficiencies and safety. ADNOC Drilling’s transformation into a fully integrated drilling services provider followed the award to Baker Hughes of a 5% share in the company, which is now capable of delivering start-to-finish drilling and well-construction services onshore and offshore with proven efficiency gains. As of May 2021, ADNOC Drilling has delivered over 180 IDS wells since 2018, achieving an efficiency improvement of close to 50%, which resulted in over $210 million (AED767 million) savings. As an integral part of its 2030 strategy, ADNOC is optimizing its procurement strategy to reflect market dynamics, focusing on longterm contracts with a reduced number of suppliers that provide stable and reliable delivery at highly competitive rates. This smart approach is enabling ADNOC to create more value, drive efficiencies, and ensure that strategic materials and components are available on time while achieving substantial efficiency gains as it increases overall procurement spend.

First Train of South Pars Phase 14 Refinery Online in Winter: Min. TEHRAN (NIOC) – Iranian Minister of Petroleum Javad Owji said the first train of the phase 14 refinery of the South Pars gas field would come on stream in the winter this year. Speaking to reporters during a visit to Assaluyeh, Mr. Owji said, “I thank God that I succeeded in making my first business trip to Assaluyeh region as the Iranian Minister of Petroleum; over the course of this trip I visited gas refineries, petrochemical complexes and platforms of South Pars.” He considered the supply of winter fuel as one of the most important concerns of the Ministry of Petroleum at present, and added: “More than 700 million cubic meters or in other words 70% of the country’s gas consumption is supplied from Bushehr Province and the South Pars refineries.” The Minister of Petroleum noted last night’s meeting with the managers of the oil industry in the Pars Special Economic Energy Zone and positively evaluated the meeting, saying the latest state of the refineries and ongoing projects in the region were the focus of the meeting. Owji expressed hope that with the decisions taken this year, the maximum production and recovery of gas from the South Pars joint field will be achieved. He underlined the South Pars Refinery Phase 14 as the last refinery to come on stream, and added: “Our comrades have promised that the first gas sweetening train South Pars Refinery Phase 14 will be put into operation this winter and will help the country’s gas network.” The Minister of Petroleum arrived in Assaluyeh on his first business visit in his new post, and after attending the tomb of the anonymous martyrs of Assaluyeh, examined the gas and petrochemical projects based in the area in a meeting with the relevant managers in the Pars Energy Special Economic Zone.

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ADIPEC SPECIAL

Smart Pipe-Shop Automation Solutions Pipes and piping systems are the backbone of our modern society, and there are few places where this becomes more apparent than in the oil and gas industry. Besides the thousands of miles of pipelines worldwide that bring the crude oil, natural gas, or other products from one place to the other, pipes are also crucial components of oil rigs, the tankers, the refineries, and a wide variety of other installations. Because just like a body cannot function without veins and arteries, industrial installations cannot function without a multitude of piping systems.

Concept visualization of the transport system.

Since it is impractical, time-consuming, expensive and dangerous to weld every single pipe joint on site, large segments of the pipe systems are usually pre-fabricated in pipe-shops, often including sophisticated CNC machines for a number of special tasks. These pipeshops allow for fabrication of large quantities of segments, or spools, which can be prepared cheaper and more easily inside the shop, and can then be installed on-site faster and with less hot work. However, in order for a pipe-shop to be as efficient as possible, it needs to be planned and operated smartly, especially if there are special requirements, or uses CNC-machines for processes like plasma-cutting or bending. In fact, the best and most powerful machine will not live up to its full potential, if it takes too long to bring new material, remove finished material, and calculate the required data for its operation. Upon closer examination transport and idle times are usually the biggest cost factors in pipe-shop operation, and they can often be traced either to a bad arrangement of machines / systems, or to bad process planning and organization. Mistakes here can have repercussions that may only be felt at later stages in the fabrication cycle, so attempts to make improvements at those stages do not address the actual problem. As an example, if a fitter takes 18 minutes to prepare a joint for welding, but it takes 20 minutes to deliver the pipe and

fitting to him, then the problem is not on the fitter’s side, and improving his performance to 15 minutes per joint will only increase his waiting time, not his productivity. But since the fitters and welders are usually the final step in the prefabrication chain, it is here that the effects of any other, earlier bottleneck becomes visible. And thus fitting and welding is where most pipe-shop owners or managers focus their attention when it comes to improvements, often overlooking other problems in their fabrication cycle that need addressing.

3R solutions from Germany is a consultant and systems integrator who specializes in improving pipe-shop operations, through a mix of process automation, software integration, and optimized flow of material. Founded in the early 1980s the company can draw on many years of experience, as well as an extensive network of partner companies, who are leaders in their respective field. In addition to designing the pipe-shop, 3R solutions can also manage the entire project, selecting and procuring the machines, arranging transport and installation, and coordinating the different machine manufacturers on behalf of the client. By looking at all aspects of the fabrication cycle, 3R solutions can identify the bottlenecks and challenges, and create a concept for a streamlined and optimized workflow inside the shop. Since each client has different requirements and specifications, the first step in any project has to be an in-depth analysis and evaluation, in order to determine the optimal machines and arrangements. Depending on the pipe materials and dimensions, as well as standards and regulations, certain processes may not be suitable or even permitted, or certain machines may be more efficient than others. An expert like 3R solutions can help here, because they can determine whether a machine is viable or not, or if there is a better alternative more

Actual installation of transport system.


Buffer tables in front of stations allow for continuous process flow.

suitable for the individual client’s needs. Another important factor is the level of automation in general. Unlike the automotive industry, where the same spool geometry is fabricated thousands, or even tens of thousands of times, the oil and gas industry generally requires a wide variety of geometries, which are then fabricated in small batches, or even individual units. Because of this a lot of pipeshop owners in this industry shy away from automation, thinking that their specific requirements mean that it is not possible to automate fabrication. However, while the spool geometries are much more diverse than in the automotive industry, the core processes remain comparable: handling, cutting, edge preparation, fit-up and welding. So even if automating the entire fabrication cycle may not be possible or economically viable, it is still possible to streamline and partially automate certain aspects of fabrication. And by optimizing the general flow of material and information inside the shop, the individual machines’ capacities can be utilized to a greater extent. The machines for the workshop itself are generally selected based on performance and reliability, and are modified from their standard versions, in order to be included in an automated line. This modification can include certain interfaces to the machine control (in order to transfer certain parameters or data), or minor adjustments to the machine itself (for physical integration into the whole system, including emergency stop and safety processes). Machines are fabricated by leading manufacturers, many of whom have cooperated with 3R solutions for many years, on multiple projects. This long-term cooperation with customers and partners is a mainstay of 3R’s corporate philosophy. The idea is to involve the client in the planning process, in order to ensure that their requests and wishes are listened to, and implemented as much as

possible. This includes not only the owners and managers, but also the operators and maintenance personnel, who will later have to work / service the equipment. They not only may offer valuable suggestions or input, but involving them in the planning process will help lower potential initial resentment against the idea of automation, and spark enthusiasm about the project as a whole. The heart of 3R solutions’ system, however, is the planning and monitoring software, which has been continuously developed, expanded and improved in the past 40 years. It is not only applied in the workshop itself, where it

provides work orders and tracks the fabrication status of each piece of pipe, but also in work preparation and process planning. The software is used to import the 3D model from 3rd party CAD platforms, and turns it into isometric drawings, which are then automatically split into spools for fabrication based on customizable parameters. For each spool the software can generate documentation such as part lists, cutting lists, welding information or work sheets, as well as CNC data for various processing machines such as plasma-cutting or pipe-bending machines. By interfacing with material management and scheduling systems, it is possible to generate optimized work packages, with all relevant data already prepared in digital format, for paperless fabrication. Cutting lists are nested for reduction of scrap, and workloads are balanced between work stations / machines, in order to best utilize individual capacities. All processes are not only tracked, but documented, allowing for the creation of extensive reports for quality control, internal record keeping, and reporting to the end customer / buyer of the spools. It is this combination of software and machines, proper planning and tracking, that helped 3R’s customers achieve significant improvements in their productivity, and build pipe-shops that became showcases for automation and process innovation. • If you would like to know more about how 3R solutions GmbH can help your company and its operations, please contact them at: 3R solutions GmbH T: +49 2381 / 9724 – 710 E: info@3-r.de

Visualization of data flow from Engineering to Fabrication.

W: https://www.3-r.de

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ADIPEC SPECIAL West Karoun Oil Fields under Development TEHRAN (NIOC) _ West Karoun is home to a cluster of oil fields Iran shares with neighboring Iraq. This area in western Iran is set to form a new oil civilization in Iran. There are 11 oil fields in West Karoun. Iran Plans to develop them to increase its oil output by 1 mb/d by developing these fields. Arvand and Phase 3 of Darquain are among these projects. Darquain field will have a 200,000 b/d share in the above figure. Darquain which lies in Khuzestan Province is 45 kilometers north of the city of Khorramshahr and 100 kilometers south of the oil-rich city of Ahvaz. The field is expected to see its output exceed 220,000 b/d once phase 3 developments are fulfilled. Darquain is one of the 49 oil fields introduced for investment under the Iran Petroleum Contract (IPC) model. Darquain which was discovered in 1964 following drilling one exploration well, holds over 5 billion barrels of oil in place, 1.3 billion barrels of which is recoverable. Darquain’s oil is light with an API gravity of 39. The oil produced at this field is delivered to the AhvazAbadan oil pipeline. According to estimates, the investment required for the development of Darquain-3 amounts to $1.5 billion. Darquain-3 envisages operating the Ilam and Sarvak reservoirs, as well as the untapped part of Fahlyan. To that end, water and gas would be injected into the Sarvak reservoir and gas would be injected into the Fahlyan reservoir. Furthermore, 31 oil wells, 6 gas injection wells, crude oil processing facilities including pipelines, processing installations, gas compressors, infrastructure including crude oil storage tanks and roads are among other activities under way at Darquain-3. In phases 1 and 2, oil was recovered from Fahlyan formation. In phase 3, oil recovery from the Ilam and Sarvak layers will be done, as well. Darquain-1 came online in 2005. Darquain-2 required $1.3 billion in investment and demining 7.5 million square meters. Darquain-2 came online in February 2011. Darquain-3 was expected to become operational within five years. Three years have since passed and the field is still far from startup. According to plans, in the first stage, 14,000 b/d of light crude and in the second stage, 46,000 b/d of heavy crude will be extracted from Ilam and Sarvak layers. Darquain-3 targets the heavy crude layers of Ilam and Sarvak and the undeveloped part of Fahlyan. Eni completed feasibility studies on this project and submitted its results. The findings of Eni studies indicate that the heavy crude in Ilam and Sarvak layers were recoverable. Due to the heavy crude oil content, the third phase is totally different from the first and second phases.

Arvand Awaiting Investment Until a couple of years ago, development of the oil and gas fields that Iran shares with neighboring countries had been slowed due to financial and technical impediments in Iran, thereby helping neighboring nations make big gains. Iran has shifted its focus on the development of joint oil and gas fields located mainly in South Pars and West Karoun. In the West Karoun area, Iran shares oil fields with Iraq. Three West Karoun oil fields recently started production. The fields shared with Iraq have been proposed to foreign investors for future cooperation. Foreign companies may sign agreement with Iran based on the content of IPC. Arvand oil field which is located 50 kilometers south of Abadan in Khuzestan Province is one of these fields in question. The field lies at the entry of Arvandroud River and is 42 kilometers long and 13 kilometers wide. Arvand is estimated to contain one billion barrels of oil in place with a recovery rate of 15%. Arvand also holds over 14 bcm of dry gas and 55 million barrels of gas condensate. Discovered in 2008, the Arvand field lies along Iran-Iraq border. Drilling had started in Arvand in 2006 for the purpose of estimating the hydrocarbon potential of the formations in the Khami and Bangestan centers. Four well logging operations were carried out in Fahlyan formation to prove the existence of oil and gas in that formation. The Fahlyan formation holds light crude oil with API gravity at about 44. Arvand oil field is administered by Arvandan Oil and Gas Production Company (AOGPC) whose production is estimated to reach 1.4 mb/d by 2025. AOGPC is estimated to have the highest oil and gas production rate in the coming decade. A major facility inside this field is a 165,000-barrelper-day processing unit. This treatment unit was built by National Iranian Oil Company during years when Iran was under sanctions. A variety of crude oil may be processed at this facility. Thanks to the existence of this treatment facility, the return of investment will be fast. Any investment in the development of Arvand oil field will have a good rate of return. The short distance between the Arvand field and the treatment facility is an indicator of the fast development of the oil field. Several years ago, an agreement was signed between AOGPC and the Iranian Offshore Engineering and Construction Company (IOEC) for the development of the Arvand oil field, but the agreement was never implemented due to financial and other problems. The Arvand oil field is expected to produce 5,000 b/d of oil in the first phase, which would reach 20,000 b/d in the final phase. The investment needed for the development of this field stands at $135 million, which is likely to increase. The API gravity of oil in Arvand varies between 39 and 43. •


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HEALTH, SAFETY & ENVIRONMENT

Atexindustries Developed a Unique Rechargeable Floodlight A

texindustries is located in the Netherlands as part of the Optilight Group: Various companies specialised in ATEX certified lighting and peripherals with a strong position in Europe, North Africa and the Middle East. Since the early nineties the Optilight Group has been located in Woudrichem, near Rotterdam, Antwerp and the German banks of the Rhine. “We supply a wide range of industries, such as the aircraft industry, shipbuilding, food & beverage processing and the petrochemical industry” explains Jean Paul Minczeles of Atexindustries. “Thanks to our range, we can offer a total solution for any unique and specific situation. From the plug that connects the

The Ultra2 portable work light with wide beam. Its maintenance free batteries provide an operating time of eight hours at full power of 3200 lumen. It weighs only 5,5 kg.

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equipment to the power supply to where the portable lamps are used. We can supply everything: connectors, transformers, cable reels, extension cables and finally the portable lamps”. A few years ago, Atexindustries took the initiative to develop a revolutionary product: a powerful and easily portable, ATEX certified, and rechargeable floodlight. The reason was obvious: power supply for work lights, often temporary installations, can be quite a challenge, both with or without ATEX requirements. Cable length limitations, different voltages, different types of connectors, mismatching sockets can make

Jean Paul Minczeles, Atexindustries. installation work difficult and expensive. And since requirements vary from country to country this is certainly a nightmare for internationally operating companies. The length of the power cable can be one of the biggest problems. With a safe voltage of 24 V. and a cable length of 25m. many items like catalytic cracking units of 70 meters high, storage tanks of 60 meters, airplane fuselages with wingspan and length of 50 meters cannot be reached for good quality illumination. Minczeles: “We worked together with Artidor, the only company that turned out to be able to develop a lightweight rechargeable lamp with revolutionary properties: A minimum of 3000 lumens for eight hours. Within a year our vision became reality: the required light output, at least 3000 lumens, the operating time of eight hours and yet a magical weight of less than 6 Kg. (12 pounds): The Ultra2 was born.”


Lamp properties The requirements of the various industries have been taken into account in the design of this lamp. Of course: At ATEX zones, we quickly think of the petrochemical industry. But, as it weighs less than 6 Kg, it is perfect for transport to and use at offshore locations, to be used on hard-to-reach places or in circumstances where floating can be lifesaving: Sewers or pump houses, engine rooms. Certification allows it to be used with hydrogen pipelines and installations. The design has rounded corners and the elastic polypropylene housing causes minimal damage in the event of a fall. A must in the aviation industry where fuselage protection is paramount. The special features make the Ultra2 not only an extremely safe lamp, but also the most efficient and cost-effective ATEX solution. With a portable rechargeable lamp, expensive ATEX items such as plugs, reels, transformers and extension cables are no longer necessary. Installation work by a certified professional has also become superfluous, an additional time and money saver. The eight-hour operating

time make the floodlight clearly suitable for installation, repair & maintenance work and, due to its versatility, also for emergency situations. Last but not least: The Ultra2 is a good solution for the rental industry. No discussions with the end user about the correct voltage, 230 V or 24 V or about cable length, no necessary training about transformers and matching connectors. The use of the lamp is simple and Above: Traditional power supply for work lights are often temporary installations. Cable length limitations, different voltages, different types of connectors, mismatching sockets can make installation work difficult and expensive. Below: The requirements of the various industries have been taken into account. The design has rounded corners and the elastic polypropylene housing. It floats in water and is easily stackable and spacesaving.

uncomplicated, ideal for rental. The maintenance-free housing, antistatic to the core, is smooth and easy to clean. The batteries are also maintenance-free and come with a four-year warranty. The design is easily stackable and space-saving. “Indeed, since the introduction in the spring of 2019, we have seen more and more different types of customers switching to a rechargeable way of working,” concludes Jean Paul Minczeles with satisfaction. “And a professional network of distributors certainly helps,” he adds.

Atexindustries BV Tel: +31 (0)183-309333 https://atexindustries.com info@atexindustries.com Woudrichem, The Netherlands

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HEALTH, SAFETY & ENVIRONMENT

Global Leader in the Oil and Gas, Environmental and Remediation Markets With a global focus on the environment, water and soil contaminated by petroleum hydrocarbons has been a hot topic for a long time. This heavily regulated industry requires laboratory analysis be performed, which takes time, often days or weeks to get test results. The use of portable test equipment, capable of getting accurate, reliable data is in high demand to improve monitoring, treatment and remediation efforts. In 2020, a partnership between two U.S. companies and a company from Denmark, collaborated together to provide innovative solutions to this market.

T

he heart in the set-up is the Sitelab UVF500D analyzer, a rugged, handheld, batteryoperated instrument used for testing oil in water and oil in soil on-site or in the laboratory. It’s made for Sitelab Corporation in the U.S. by Turner Designs, Inc. and is a direct replacement for the previous version called the TD-500D, long used in the oil and gas market all over the world. The analyzer is ideal for all types of crude oils and heavy fuel oils. Samples only take a few minutes to analyze, useful for making quick field decisions. The equipment is easy to operate and no training is needed. Most importantly, results correlate well to certified laboratory methods. The UVF-500D is sold online and distributed worldwide by Obstitech ApS in Denmark. A full line of test supplies and accessories are also available. Turner Designs, Inc. has been the industry leader manufacturing fluorescence-based instruments for over 45 years. All that knowledge is incorporated into the UVF-500D to have the lowest cost, most user friendly,

ruggedized, accurate, and repeatable oil in water and oil in soil analyzer on the market. For over 20 years, Sitelab, located in Massachusetts, USA, has been the industry leader in providing portable hydrocarbon field analysers to the petroleum, environmental and soil remediation markets. Sitelab is a

small business focused on hydrocarbon analysis using UVF technology. Sitelab’s laboratory develops methods, improves products and services the UVF-500D. Each analyzer is calibrated and tested for quality control. Test kits and other supplies available used with the equipment ensures customers get accurate, reliable test results. Obstitech

has

more than 35 years’ experience in both the on and offshore oil and gas market and related industries. Obstitech is located in Esbjerg, Denmark and is a flexible, dynamic company with focus on the customer’s needs and satisfaction. Obstitech’s strong team understand the customer’s applications, problems and solutions for monitoring petroleum hydrocarbons in water and soil. Technology The UVF-500D analyzer is based on using ultraviolet fluorescence technology which is the most accurate and reliable

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UVF-500D handheld.

method to quantify hydrocarbons. When exposed to UV light, polycyclic aromatic hydrocarbons (PAHs) excite and emit energy or “fluoresce”, which is measured by the detector. The amount of fluorescence is then quantitated using an oil calibration standard with a known concentration. Readings only take a few seconds and concentrations are displayed in “PPM” units. Simple in a way, but a highly effective technology. The analyzer uses hexane and methanol solvents to prepare water and soil samples for analysis. The UVF-500D can be used for a wide range of applications. Use it to detect oil in seawater, fresh water, produced water, discharge water, bilge water, wastewater, groundwater, stormwater, soil, sediment, sand, drill cuttings, asphalt, bitumen and oil on metal. A case involving the use of a UVF-500D for oil in water application - Decommissioning Offshore Oil Platforms in California Coal Oil Point in Santa Barbara, CA is a popular spot for surfers with Platform Holly looming in the distance. This and a network of other oil platforms were permanently closed down after the 2015 pipeline spill at Refugio State Beach. A contractor is using the UVF-500D to test oil in water on-site for plugging and abandonment operations. These huge structures contain miles of pipe, which must be cleaned out to remove any residual oils. The California State Lands Commission requires the water to be tested and treated prior to disposal. The UVF-500D uses fluorescence to detect concentrations of total petroleum hydrocarbons (TPH) in water. The analyzer is very sensitive to all types of crude oils. Samples are extracted

in hexane solvent for analysis. This is the same solvent used by EPA Method 1664 performed off-site by the certified lab for confirmation. The analyzer arrives factory calibrated to TPH from zero to 100 ppm. Most oils can be detected to <1 ppm. There is no upper limit; highly contaminated sample extracts can be diluted further in solvent for analysis.

A case involving the use of a UVF-500D for oil in soil application - Soil Remediation Projects in Kuwait from 1991 Iraq War Photo from the U.S. Space Shuttle (credit: nasa.gov), show oil wells set on fire along the Persian Gulf in June 1991. Hundreds of wells burned, some up to ten months. An estimated 1 to 1.5 billion barrels of crude oil was released, leaving behind hundreds of lakes of oil and “tarcrete” soot across 5% of Kuwait’s landscape. Today, Kuwait has big plans to finish remediating the contamination. Field screening samples using a handheld device has been specified. The UVF-500D analyzer is ideal for this application. Field screening TPH in soil takes only minutes, useful for making real time sampling decisions, site characterization, excavation and treatment verifications. Sitelab’s UVF instruments have been used in Kuwait on previous projects with great success. Accuracy was good over a wide range of concentrations compared to certified laboratory results. Hundreds of soils were tested. Facts The UVF-500D is the most robust, lowest cost, easiest to use, most accurate oil in water oil in soil analyzer on the market. Obstitech, Sitelab and Turner Designs (together) are 100% committed and take great pride in providing the customers with the best products and support possible. • Obstitech ApS Guldagervej 56, 6710 Esbjerg V, DK Phone: +45 7020 5771 E-mail: info@obstitech.dk

Platform Holly, California.

Web: https://www.uvf-500d.com

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HEALTH, SAFETY & ENVIRONMENT

Supply Chain Boost at Carrington Textiles to Meet Changing Customer Demand Across Europe The global textile manufacturer restructured its supply chain to adapt to global market conditions. After 18 months of global supply chain disruption, workwear fabric manufacturer Carrington Textiles, revealed the company’s challenges during this period and the growth its supply chain team has been through to be able to maintain the company’s high levels of service.

S

ince early 2020, the COVID-19 pandemic caused a whole new set of challenges for Carrington Textiles, ranging from the team having to adapt to a new dynamic way of doing things remotely, to lockdowns and positive cases around the world impacting the availability of raw materials and freight.

With the rollout of the vaccine programme and the coronavirus pandemic restrictions gradually easing in many countries around the world, Carrington Textiles saw a considerable increase in demand from the beginning of 2021, a situation to which it had to respond quickly to meet customers’ expectations.

Brexit was another big task for Carrington Textiles, as the company had to find ways for establishing new procedures that adhered to the Trade Cooperation Agreement (TCA) with the European Union to ensure products could still be shipped to customers without unnecessary delays

Supply Chain Director for Carrington Textiles, Stuart Pritchard, explains: “We have seen in 2021 extraordinarily high levels of demand in comparison to 2020, which were higher than we could have predicted. We worked in collaboration with our internal teams to understand where we produce fabrics, ensuring we have the right raw materials in the right place, at the right time. With a multisite operation in the UK, Portugal for EU origin fabrics and Pakistan, these challenges were complex.”

Additionally, the Suez Canal blockage which lasted six days, had a severe impact on the supply chain, generating even further delays on blank sailings, loops changing and unforeseen transhipments.

Stuart Pritchard, Supply Chain Director (Credit Carrington Textiles).

The supply chain boost Stuart outlines what has changed in Carrington Textiles’ supply chain and how is this benefiting not only customers but the environment. “We have introduced a new warehouse in Portugal with a bespoke management tool written by our own IT team, so we have full control on the system and its features. “We’ve also had to restructure the entire supply chain team by adding 50% more talent in order to ensure we have the right competence operating at the right level to meet our customers’ needs. We looked outside the textile industry to find the best people with a wide range of experience and ideas that can improve our service to customers. “With this growth, the team is not only able to implement new customs procedures and documentation, but also to spend more time analysing and improving processes, stock performance, global production capacity utilisation and ensuring our worldwide raw material needs are fit for purpose. “Because it’s important for us to have access to the right data at the right time and in the right format we have also invested in a demand planning tool that will produce forward sales, production and stock projections and help manage our business in order to meet that all our customers’ expectations. This will no doubt enable us to be more agile and predict where we need to focus our efforts to ensure smooth operations through what’s been a very tough couple of years for supply chains. “This new technology will also make our supply chain a lot more sustainable and environmentally friendly, as it will help us ensure we are not purchasing and shipping more product than needed. I believe in managing our capacity needs and production facilities ahead, so we utilise our assets efficiently and don’t waste energy”. • www.carrington.co.uk

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Risk Prevention in the Ex Sector

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owadays, workplace safety is of major importance, regardless of business size or type of activity. Many countries around the world have put in place strict health and safety rules and regulations to protect their working populations. The risks vary, the measures don’t Risks are not the same in an office or on the floor of an industrial plant and a risk-free workplace doesn’t exist. Office workers may slip, trip and fall due to wet floors, frayed carpets or unsecured electric and phone cords. They may also suffer from ergonomic injuries and eye strain due to long hours spent sitting at the computer. All managers responsible for health and safety, whatever the work environment, should: •

identify and monitor potential health and safety hazards

offer ongoing training for employees to avoid/minimize any risks

comply with up-to-date health and safety legislation

carry out safety inspections

apply safety policies and best practices

run through emergency procedures and drills for the personnel

This is unfortunately not the case everywhere – sweatshops and child labour still exist in places where protective safety measures are minimal or non-existent. Organizations such as the International Labour Organization (ILO), the United Nations, the UN Economic Commission for Europe (UNECE) and many non-governmental organizations (NGOs) develop programmes – in particular through the UN Sustainable Developments Goals (SDGs) – to raise awareness and encourage countries and business owners to consider the introduction of such measures. The Ex factor In one industrial area, explosive (Ex) atmospheres, the risks are omnipresent and workers often operate in difficult conditions, for instance oil, gas and mining. In addition to oil refineries, rigs and processing plants, gas pipelines and distribution centres, or underground coal mines, Ex areas can be found in a great number of industry sectors. Risk prevention The United Nations, through UNECE, has endorsed IECEx, the IEC System for Certification to Standards Relating to Equipment for Use in Explosive Atmospheres, as the international certification system for the assessment of conformity in Ex areas, to help address risk prevention. The UNECE Working Party on Regulatory Cooperation and Standardization Policies (WP.6) worked in close cooperation with IEC and IECEx to develop a model for legislation in the sector of equipment used in environments with an explosive atmosphere. The model was adopted by the WP.6 in November 2010. It provides for adequate risk mitigation, without creating excessive costs or red tape for business. Any member state that has no regulatory framework in the explosive equipment sector can use the model as a blueprint for legislation. If countries already have such a framework, they could consider gradually converging towards this international model. Once the model has been adopted as national legislation, the sector will operate under a single common regulatory framework in all participating countries. IECEx helps ensure highest level of safety UNECE has drawn on IECEx experience to build its model. Since 1996, IECEx has been the only truly international conformity assessment system that provides testing and certification for all items of Ex equipment – electrical and non-electrical – and installation, maintenance and repair of equipment and systems. •


MENA - NEWS Abu Dhabi Offshore Exploration Block Awarded to a Consortium led by Pakistan Petroleum Limited First-time Pakistani companies will invest in and explore for oil and gas in an Abu Dhabi concession. Award builds on the deep-rooted bilateral ties between the UAE and Pakistan. Pakistan Petroleum Limited led consortium awarded concession for Offshore Block 5 and will invest $304.7 million (AED1.12 billion) during the exploration phase. Award underscores ADNOC’s expanded approach to strategic partnerships and concludes Abu Dhabi’s second competitive block bid round. The Abu Dhabi National Oil Company (ADNOC) announced the signing of a historic exploration concession agreement, awarding the exploration rights for Abu Dhabi’s Offshore Block 5 to a consortium of four Pakistani companies – Pakistan Petroleum Limited (PPL), Mari Petroleum Company Limited (MPCL), Oil and Gas Development Company Limited (OGDCL), and Government Holdings (Private) Limited (GHPL) – in Abu Dhabi’s second competitive block bid round. The consortium is led by PPL. The award marks the first time Pakistani companies invest in and explore for oil and gas in an Abu Dhabi concession as well as the first time ADNOC partners with Pakistani energy companies. The historic agreement builds on the deep-rooted bilateral relationship between the United Arab Emirates (UAE) and the Islamic Republic of Pakistan and underscores ADNOC’s expanded approach to strategic partnerships, including those who can provide access to key growth markets for the company’s crude oil and products. The exploration concession agreement was signed by His Excellency Dr. Sultan Ahmed Al Jaber, UAE Minister of Industry and Advanced Technology and Managing Director and Group CEO of ADNOC, and Moin Raza Khan, Managing Director and CEO of PPL. H.E. Dr. Al Jaber said: “This historic exploration concession award marks a new chapter of energy cooperation in the 50-year old UAEPakistan relationship. It represents an important platform upon which we can drive win-win opportunities to support Pakistan’s energy security and further strengthen the strategic and economic ties between our two countries. We are delighted to partner with Pakistan Petroleum Limited and the other members of the consortium on Offshore Block 5. “The consortium was selected as part of Abu Dhabi’s block bid round where we have once again reinforced our approach to strategic partnerships that contribute the right combination of market access, capital, best-in-class expertise or advanced technology. We are very optimistic about the potential to unlock significant value with all our partners in this second competitive block bid round as we continue to accelerate the exploration and development of Abu Dhabi’s untapped resources, in line with the Leadership’s wise directives.” Under the terms of the agreement, the consortium will hold a 100% stake in the exploration phase, investing up to $304.7 million (AED1.12 billion) towards exploration and appraisal drilling, including a participation fee, to explore for and appraise oil and gas opportunities in the block that covers an offshore area of 6,223 square kilometers and is located 100 kilometers north east of Abu Dhabi city. Khan said: “The PPL-led consortium is delighted to be selected for the concession award of Abu Dhabi’s Offshore Block-5. This award is not only a watershed moment for Pakistan and the Emirate of Abu Dhabi towards bilateral energy cooperation and economic links but also offers an opportunity to strengthen strategic cooperation with ADNOC to share technical know-how and expertise. “We are particularly excited that this consortium comprises the ‘big four’ national exploration and production companies that are fully geared to support ADNOC and the Emirate of Abu Dhabi in reinforcing its leading position in the global energy sector.” Following a successful commercial discovery during the exploration

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phase, the consortium will have the right to a production concession to develop and produce such commercial discoveries. ADNOC has the option to hold a 60% stake in the production phase of the concession. The term of the production phase is 35 years from the commencement of the exploration phase and the block offers the potential to create significant in-country value for the UAE over the lifetime of the concession. In addition to drilling exploration and appraisal wells, the exploration phase will see the consortium leverage and contribute financially and technically to ADNOC’s mega seismic survey, which is acquiring 3D seismic data within the block area. The data already acquired over a large part of the block combined with its proximity to existing oil and gas fields, suggests the concession area has promising potential. ADNOC launched Abu Dhabi’s second competitive block bid round in 2019, offering a set of major onshore and offshore blocks, on behalf of the Government of Abu Dhabi. The award of Offshore Block 5 to the Pakistani consortium concludes this second block bid round, which has seen very competitive proposals submitted for the geographical areas offered. Following ADNOC’s recent discoveries of 22 billion stock tank barrels (STB) of recoverable unconventional oil resources and 160 trillion standard cubic feet (SCF) of recoverable unconventional gas resources, it was decided not to award an exploration license for Onshore Block 2. ADNOC intends to engage with potential partners for unconventional resource licensing opportunities around this geographical area. This area contains some of the unconventional resources discovered that have production potential ranking alongside the most prolific North American shale oil plays. As part of Abu Dhabi’s second block bid round, ADNOC awarded Offshore Block 4 to a wholly-owned subsidiary of Cosmo Energy Holdings Co., Ltd.; Offshore Block 3 to a consortium led by whollyowned subsidiaries of Eni and PTT Exploration and Production Public Company Limited (PTTEP); and Onshore Block 5 to Occidental. Based on existing data from detailed petroleum system studies, seismic surveys, exploration, and appraisal wells data, estimates suggest the blocks in this second bid round hold multiple billion barrels of oil and multiple trillion cubic feet of natural gas. PPL operates 15 producing fields across Pakistan and contributes over 20% of the country’s total natural gas supplies.


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MENA - NEWS Qatar Petroleum Commences LNG Ship Orders for the North Field Expansion Projects

Helmerich & Payne Makes Cornerstone Investment in ADNOC Drilling IPO

​Qatar Petroleum announced that it has ordered four new LNG carriers from Hudong-Zhonghua Shipbuilding Group Co. Ltd. (Hudong), a wholly owned subsidiary of China State Shipbuilding Corporation Limited (CSSC).

The Abu Dhabi National Oil Company (ADNOC) and its subsidiary ADNOC Drilling Company (“ADNOC Drilling”) and Helmerich & Payne, Inc. (NYSE: HP) (“H&P”), a global leader in rig technologies and drilling solutions, jointly announced a strategic alliance, that will see ADNOC Drilling acquire eight FlexRig® land rigs from H&P for $86.5 million. Following this transaction, H&P will make a $100 million cornerstone investment into ADNOC Drilling’s recently announced Initial Public Offering (“IPO”).

These four carriers are the first batch of orders in Qatar Petroleum’s massive LNG shipbuilding program, which will cater for future LNG fleet requirements for the North Field expansion projects as well as for existing vessel replacement requirements. This order is also the first ever placed by Qatar Petroleum or any of its affiliates with a Chinese shipyard for LNG ships, and the first with Hudong in connection with the agreement to reserve ship construction capacity that was executed in April 2020. His Excellency Mr. Saad Sherida Al-Kaabi, the Minister of State for Energy Affairs, the President and CEO of Qatar Petroleum, commented on this occasion and said, “We continue to push forward with our LNG expansion projects, and this announcement is yet another step in our journey. I am especially pleased with the signing of this order as it marks our first ever new LNG carrier to be built in the People’s Republic of China.” His Excellency Minister Al-Kaabi added, “We are proud to contribute to the success story of the LNG ship construction industry in China. We are also confident in Hudong’s capabilities to execute this order, worth in excess of 2.8 billion Qatari Riyals, to the highest safety and technical standards and to deliver top quality LNG carriers that will facilitate continued safe and reliable delivery of LNG to the world.” “I would like to take this opportunity to thank Hudong’s team for all the hard work to bring this order to fruition during these challenging times. I would also like to thank the leadership of our esteemed partner, CSSC, for their valuable support to this effort in line with our mutual desire to further strengthen the excellent relations between China and Qatar. I am very grateful to the Qatar Petroleum and Qatargas teams, whose dedicated efforts were instrumental in reaching this milestone,” His Excellency Minister Al-Kaabi concluded. The North Field expansion projects will increase Qatar’s LNG production capacity from 77 million tons per annum to 126 million tons per annum. Qatar Petroleum’s LNG carrier fleet program is the largest of its kind in the history of the LNG industry and will play a pivotal role in meeting the shipping requirements of Qatar Petroleum’s local and international LNG projects, as well as replacing some of Qatar’s existing LNG fleet.

The strategic alliance and rig acquisition will support ADNOC’s target of reaching 5 million barrels per day (mbpd) production capacity and gas self-sufficiency for the UAE by 2030, along with plans to unlock its unconventional oil and gas resources. These agreements will further drive ADNOC Drilling’s growth and expansion as well as enhance its rig-based operational performance by providing access to the worldclass H&P FlexRig® land rig fleet and leveraging H&P’s expertise and technologies. In addition, the alliance will support ADNOC Drilling in further driving operational excellence through maintenance efficiencies, supplementing supply-chain capabilities, and adding engineering and rig design competencies. The alliance will also deliver more competitive well completion times, greater drilling efficiencies and improved well economics. For H&P, these agreements help facilitate its goal of allocating capital internationally, particularly in the MENA region, by accelerating its access into the attractive and fast-growing Abu Dhabi market as a key platform for further regional expansion. H&P’s cornerstone investment in the upcoming ADNOC Drilling IPO also highlights its confidence in the attractiveness and long-term value creation potential of ADNOC’s unique energy assets to leading international market participants. His Excellency Dr. Sultan Ahmed Al Jaber, UAE Minister of Industry and Advanced Technology and ADNOC Managing Director and Group CEO, said: “I am pleased to announce a strategic alliance with Helmerich & Payne, a globally renowned drilling solutions provider. This exciting alliance and value creation opportunity will provide ADNOC Drilling with access to new world-class rigs and services, enabling it to continue to support ADNOC in our ambitious production capacity expansion plans. “H&P’s cornerstone investment in our planned ADNOC Drilling IPO further reinforces ADNOC’s continued success as a primary catalyst in attracting leading global investors and industry partners into Abu Dhabi and the UAE.” ADNOC announced its intention to float a 7.5 percent minority stake of ADNOC Drilling on the Abu Dhabi Securities Exchange (“ADX”) through an IPO, demonstrating the continued growth, strength and prominence of Abu Dhabi’s financial marketplace. Both ADNOC and H&P will remain committed, long-term shareholders in ADNOC Drilling. John Lindsay, H&P’s President and CEO commented: “We are excited to enter into this strategic alliance with ADNOC Drilling and the value this alliance can create for both companies and stakeholders. Our investment in ADNOC Drilling is an additional step in the execution of our international growth strategy to allocate additional capital outside the U.S. and serves as a testament of our belief in what ADNOC Drilling and H&P can achieve together. We look forward to partnering with ADNOC and ADNOC Drilling to help create a similar value proposition that we have for customers in the U.S. and other international locations.” H&P’s cornerstone investment will be at the IPO price and is subject to a three-year lock-up. As stated in the ADNOC Drilling Prospectus, like other shareholders, H&P expects to benefit from ADNOC Drilling’s commitment to a robust dividend policy. The rigs are expected to be delivered and commissioned in stages over a twelve-month period subject to acceptance upon successful completion of a final inspection on customary terms and conditions.

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RUSSIA - NEWS NOVATEK Obtains the Arkticheskoye and Neytinskoye Fields

LUKOIL and Gazprom to Develop Large Oil and Gas Cluster in Yamal-Nenets Region

Moscow, PAO NOVATEK (“NOVATEK” and/or the “Company”) announced that the Company’s wholly owned subsidiary, Yamal LNG Resource, won the auctions for geological survey, exploration, and production licenses for two subsoil license areas, which includes the Arkticheskoye and Neytinskoye fields on the Yamal Peninsula in the Yamal-Nenets Autonomous Region.

​Saint Petersburg, PJSC LUKOIL and PJSC Gazprom Neft concluded an agreement on creating a joint venture to develop a major oil and gas cluster in the Nadym-Pur-Tazovsky area of the Yamal-Nenets Autonomous District. The document was signed by Vagit Alekperov, President of LUKOIL, and Alexander Dyukov, CEO of Gazprom Neft PJSC, in presence of Alexey Miller, Chairman of the Management Committee of Gazprom PJSC. ​

The Arkticheskoye and Neytinskoye fields have combined estimated hydrocarbon reserves of 2.9 billion barrels of oil equivalent (boe), including 413 billion cubic meters (bcm) of natural gas and 28 million tons of liquids, according to the Russian hydrocarbon classification system. The license terms are for 27 years and resulted in cumulative one-time payments for the subsoil use of RR 13,154.85 million. The new license areas are located in close proximity to NOVATEK’s existing assets on the Yamal Peninsula and expand the Company’s resource base for implementing LNG projects. •

NOVATEK Creates a Subsidiary to Develop Domestic LNG Fuel Market The Board of Directors of PAO NOVATEK (“NOVATEK” and/or the “Company”) resolved to create a subsidiary called NOVATEK – LNG Fuel, which will construct small-scale LNG plants, facilitate LNG wholesale markets and develop a retail network for LNG as a motor fuel, as well as provide LNG as part of the autonomous gasification program in the Russian domestic market. NOVATEK has been actively developing the production and sales of LNG as a motor fuel. In 2020, the Company launched a small-scale LNG plant in Magnitogorsk, Chelyabinsk Region with a capacity of 40 thousand tons per annum. Presently, the Company owns 12 LNG fueling stations in Russia and plans to further expand the production and distribution networks for clean-burning fuels for transport. “We are creating a dedicated subsidiary to develop the domestic LNG fuel market as part of our commercial marketing strategy,” noted Leonid Mikhelson, NOVATEK’s Chairman of the Management Board. “The use of LNG as a motor fuel can reduce carbon emissions compared to diesel or other petrol products, as well as significantly reduce harmful particles emitted into the atmosphere, which contributes to the decarbonization of the transport industry and the protection of the environment.” •

The joint venture will be based at Meretoyakhaneftegaz LLC, a Gazprom Neft subsidiary. The Tazovskoye oil and gas condensate field, which was put on-stream this June, will be at heart of the new production area. The venture is also to develop the Severo-Samburgskoye and Meretoyakhinskoye fields, as well as two Zapadno-Yubileiny license blocks. These areas currently undergo additional appraisal and pilot works, on which basis a development strategy for the cluster will be developed. Total reserves initially in place at this new cluster stand at over a billion tonnes of oil and about 500 bcm of gas. A considerable proportion of the reserves initially in place lie within the Achimov Formation and are categorised as hard-to-recover reserves. Meretoyakhaneftegaz is the first asset to be managed by LUKOIL and Gazprom Neft on a parity (50:50) basis. Over the next few months, the parties plan to prepare detailed binding documents on establishing the joint venture, as well to secure all necessary corporate and regulatory approvals. The companies will also look into further opportunities to expand their cooperation on several lucrative projects in their regions of operation in Russia. “LUKOIL has always been putting a premium on homeland projects; we see great prospects for them. The Company is interested in increasing its investment both into upstream and downstream projects in our country. We are actively developing new fields in West Siberia, Timan-Pechora, the Caspian and Baltic Seas, as well as in other Russian regions. We also keep implementing selective deep conversion projects at our refineries in Russia. Gazprom and Gazprom Neft has been our strategic partners for many years. Together, we can combine the best Russian technologies to develop this new massive hydrocarbon cluster in the region we consider strategic – the Yamal-Nenets region. Its development will ensure additional hydrocarbons output, extra tax revenues to Russian budget, and have a multiplier effect for related industries,” said Vagit Alekperov, President of LUKOIL PJSC. “Inviting a partner to develop an asset in polar regions, which is important for Gazprom Group, falls in line with Gazprom Neft’s strategy, aimed, among other things, at further growth in the Arctic and efficient introduction of complex geology fields. A collaborative development of solutions to the challenges posed by hard-to-recover reserves is an essential task for oil and gas companies. Its accomplishment will significantly increase the resource potential of the industry. This deal supports further evolution of our strategic partnership with LUKOIL,” said Alexey Miller, Chairman of the Management Committee, Gazprom PJSC. “Developing those fields covered by our joint venture with LUKOIL is a critical task – for our entire industry. This joint venture, bringing together our financial and technological resources, will see us working on developing hard-to-recover reserves, including producing oil from Achimovsky strata. This, in turn, will create new jobs – and extra tax revenues – at every level, as well as facilitating further technological development, for both our company and the entire wider ecosystem of contractors and equipment producers,” noted Alexander Dyukov, CEO, Gazprom Neft PJSC. •

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NEWS - RUSSIA Gazprom and LUKOIL Creating Joint Venture to Develop Major Oil-and-Gas Cluster in YaNAA A working meeting between Alexey Miller, Chairman of the Gazprom Management Committee, Alexander Dyukov, Director General of Gazprom Neft, and Vagit Alekperov, President of LUKOIL, took place today in St. Petersburg. The parties discussed the state and prospects of strategic interaction between the Gazprom Group and LUKOIL aimed at, inter alia, implementing joint projects for the exploration, production, transportation and processing of hydrocarbon feedstock. As part of the meeting, Alexander Dyukov and Vagit Alekperov signed an agreement to create a joint venture (JV) for the development of a major oil-and-gas cluster in the Nadym-Pur-Taz region of the YamalNenets Autonomous Area The JV is being set up via Meretoyakhaneftegaz, a subsidiary of Gazprom Neft. The new production center will have at its core the Tazovskoye field, which was put into production in June 2021. In addition, the JV’s activities will cover the development of the SeveroSamburgskoye and Meretoyakhinskoye fields, as well as two ZapadnoYubileyny licensed blocks. The aggregate geological reserves of the new cluster amount to more than 1 billion tons of oil and about 500 billion cubic meters of gas. Meretoyakhaneftegaz is the first asset to be managed by Gazprom Neft and LUKOIL on a parity basis. A considerable part of the company’s geological reserves is located in the Achimov sequence and belongs to the hard-to-recover category. Over the next few months, the parties plan to prepare detailed binding documentation pertaining to the establishment of the JV, as well as obtain the requisite corporate and regulatory permits.

Furthermore, the two companies will continue to explore additional opportunities for expanding their cooperation on a number of promising projects in their regions of activity across Russia. “Our task is to effectively bring into development the hydrocarbon reserves with complex geology that are located beyond the Arctic Circle. The joint efforts of the two companies will allow us to deploy the best technological solutions there. It should also be noted that the creation of the JV is facilitating further advancement of the strategic partnership between the Gazprom Group and LUKOIL,” said Alexey Miller. “Development of the fields that are covered by our joint venture with LUKOIL is an important task at the level of the entire industry. In the joint venture, with our financial and technological resources united, we will work on the development of hard-to-recover reserves, including the production of oil from the Achimov sequence. In its turn, this will create new jobs and generate additional tax payments to budgets of all levels, and will also facilitate further technological development of our companies and the entire ecosystem of contractors and equipment manufacturers,” said Alexander Dyukov. •

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25-Year Anniversary of Russian Gas Supplies to Greece Over the past quarter of a century, Gazprom has exported upwards of 54 billion cubic meters of gas to this country. The annual amount of supplies has grown by more than 15 times. All these years, the cooperation has relied on a long-term contract with the Greek corporation DEPA. The contract, which was signed in 1988, is still in effect. In 2020, another long-term contract was signed with Mytilineos. Gazprom continues to provide Greece with reliable gas supplies. Over nine months of 2021, they grew by 10.8% to 2.5 billion cubic meters. Gas from Russia is delivered via the TurkStream gas pipeline and the national gas transmission system of Bulgaria. • “Projects in Russia have always been and remain the top priority for LUKOIL, and we see a huge potential for this. The company is interested in increasing the amounts of investments both in hydrocarbon production and processing in our country. We actively develop new fields in Western Siberia, the Timano-Pechorskaya oil & gas province, the Caspian Sea, the Baltic Sea, and other Russian regions, and continue implementing targeted projects for advanced processing of oil at Russian refineries. Gazprom and Gazprom Neft have been our strategic partners for many years, and in cooperation with them we are able to bring together the best domestic technologies for the development of a new large-scale hydrocarbon production cluster in a region that is of key importance to us, i.e. in the Yamal-Nenets Autonomous Area. The development of the cluster will bring additional production of hydrocarbons along with tax revenues for the budget of Russia, a multiplicative effect for related industries,” said Vagit Alekperov. •

Gazprom and Shell Review Current Issues of Joint Activities A working meeting between Alexey Miller, Chairman of the Gazprom Management Committee, and Ben van Beurden, Chief Executive Officer of Royal Dutch Shell, took place via a video link. The parties reviewed current issues pertaining to their joint activities, including the Sakhalin II project and the efforts being undertaken by the two companies to reduce their carbon footprint across the natural gas value chain. Alexey Miller and Ben van Beurden paid particular attention to the situation in the European gas market. •

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NEWS - RUSSIA Conditions for Connecting Consumers to Gas in 156 Localities Created by Gazprom since Early 2021

Board of Directors Discusses Prospects for Gas Supply and Gas Infrastructure Expansion in Russia

The Gazprom Board of Directors took note of the information on the implementation of a socially-oriented and cost-effective system of gas infrastructure expansion and gas supplies to serve the needs of the population.

The Gazprom Board of Directors took note of the information about the prospects for the expansion of the gas supply and gas infrastructure network in Russian regions through 2030.

It was noted that gas infrastructure expansion is the most ambitious socially significant project of Gazprom. The Company continues to implement the instructions of Vladimir Putin, President of the Russian Federation, for expediting additional gas grid expansion in the localities that are already provided with gas, as well as achieving the stepwise completion of gas infrastructure expansion in Russia. The meeting reviewed the preliminary results of the work undertaken to that end in 2021. Gazprom is actively implementing the programs for gas supply and gas infrastructure expansion in Russian regions for 2021–2025. Since the start of 2021, the Company has built 78 gas pipelines stretching for about 1,400 kilometers and created the conditions to bring gas to households, apartments and boiler houses in 156 localities. In September 2021, the Russian Government approved the regulatory acts pertaining to additional gas grid expansion. The documents outline, inter alia, the rules for connecting households to gas distribution networks as part of additional gas grid expansion efforts, the procedure for consumer engagement, and the timelines of this program. The appropriate legislative changes were developed taking into account the proposals put forward by Gazprom. Currently, Gazprom and the constituent entities of the Russian Federation continue collecting applications for gas connections in the localities that are already provided with gas. As of today, more than 350,000 applications have been received from across the country. Consumers can apply for a gas connection via several channels: for instance, via the client centers of the Gazprom Mezhregiongaz Group and the multifunctional centers, via the federal or regional portals of government services, or the special-purpose website of the single operator of gas infrastructure expansion in the Russian Federation https://connectgas.ru/. The platforms of the Gazprom Mezhregiongaz Group and the single operator of gas infrastructure expansion are functioning in a single-window format. In addition to filing applications, they allow the users to, inter alia, make a preliminary calculation of how much it will cost to build the networks within the boundaries of a land plot, buy gas-using equipment (boilers, gas stoves, gas meters) and make an order for its installation. Based on consumer applications, proposals from the single and regional operators of gas infrastructure expansion, technical capabilities of the gas transmission infrastructure and other parameters, the constituent entities of the Russian Federation have drawn up and are finishing the asset-by-asset plans of additional gas grid expansion. The Russian Government recommended that the regions approve these documents before 2021 end.

It was noted that Gazprom, being a socially-oriented company, has for many years pursued the creation of conditions for connecting residential and industrial consumers to gas as one of its key activities. As per the list of instructions of Vladimir Putin, President of the Russian Federation, dated May 31, 2020, gas infrastructure expansion in Russia is to be completed in a stage-wise manner by 2024 and 2030, and residential consumers must not bear any expenses for the connections to gas distribution networks. Gazprom carries out comprehensive work to reach the goals set by the Russian Government. In 2020, the Company and 67 Russian regions signed gas supply and gas infrastructure expansion programs for a new five-year period, i.e. for 2021–2025. The amount of financing channeled by Gazprom is 2.9 times higher than that in 2016–2020. Over two-thirds of the investments will be provided to rural areas. By 2026, gas grid expansion will be completed to the fullest extent possible in 35 regions of Russia. The implementation of the programs is well underway in strict compliance with the schedules. Each of the 67 Russian regions has in place joint task forces which include representatives of Gazprom and regional authorities. They coordinate the efforts of the parties so as to make the gas infrastructure expansion operations as timely and efficient as possible. On April 30, 2021, the Russian Government, in line with the instructions of the country’s leadership, approved the Action plan (roadmap) for the implementation of a socially-oriented and cost-effective system of gas infrastructure expansion and gas supplies to serve the needs of the constituent entities of the Russian Federation. Among the significant novelties provided for by the document is the introduction of the role of a “single operator of gas infrastructure expansion.” In June 2021, a number of important amendments were introduced into Federal Law No. 69-FZ on Gas Supplies in the Russian Federation. In particular, the concepts of a single operator of gas infrastructure expansion and a regional one were established in said document. The Russian Government was vested with the authority of designating the single operator of gas infrastructure expansion, schemes of cooperation between the parties to gas grid expansion activities, and oversight schemes for the works. In July 2021, the Russian Government appointed Gazprom Gazifikatsiya (established by Gazprom Mezhregiongaz and Gazprom Gazoraspredeleniye) as the single operator of gas infrastructure expansion and approved the list of territories falling under the purview of said single operator, which includes 66 constituent entities of the Russian Federation and the Sirius federal territory. The single operator will build gas pipeline branches, gas distribution stations, inter-settlement gas pipelines, and gas distribution networks up to the boundaries of land plots, thus making it possible to synchronize to a great extent the construction of gas infrastructure expansion facilities, achieve a considerable optimization of the construction costs, and significantly reduce the time required for connecting consumers to gas supply networks. Gazprom, jointly with the administrations of the constituent entities of the Russian Federation and the Russian Ministry of Energy, has completed the consolidation of data on the number of households that are not connected to gas in the area of presence of the Gazprom Group’s gas distribution entities. A preliminary procedure of application submission for gas grid connections from potential consumers is in progress. •

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RUSSIA - NEWS Supplies of Russian Gas to Hungary and Croatia via New Route Commence Hungary and Croatia started receiving Russian natural gas via a new route: the gas is supplied by the TurkStream gas pipeline and further across the national gas transmission systems of Bulgaria, Serbia, and Hungary. Supplies via this route were made possible thanks to a new gas trunkline built in Hungary by FGSZ Ltd., as well as the completion of expansion of the national gas transmission systems in Bulgaria and Serbia where operators Bulgartransgaz EAD and GASTRANS d.o.o. Novi Sad had brought compressor stations onstream. •

Gazprom Ramps Up Gas Production and Supplies Over 8.5 Months of 2021 Gazprom ramped up its domestic supplies from the gas transmission system by 14.8 per cent (or by 21.3 billion cubic meters) over said period of 2021. As many as 25 Russian regions are already receiving heat supplies, almost a week earlier than last year. The Company increased its gas exports to the countries beyond the FSU to 138.6 billion cubic meters. Gazprom continues to keep the amounts of its gas supplies near the all-time high level (141.3 billion cubic meters for the same period of 2018). This is higher than the figure for the same period of 2020 by 17.4 per cent (or by 20.6 billion cubic meters). Specifically, Gazprom increased gas supplies to Turkey (+157.7 per cent), Germany (+35.8 per cent), Italy (+15 per cent), Romania (+347.6 per cent), Serbia (+125.9 per cent), Poland (+11.4 per cent), Bulgaria (+52.3 per cent), Greece (+12.8 per cent), and Finland (+19 per cent). Gas supplies to China via the Power of Siberia pipeline continue growing and are regularly exceeding the daily contractual obligations of Gazprom. According to Gas Infrastructure Europe, the level of reserves in European underground gas storage facilities remained the lowest in many years as of September 13, 2021. The negative difference between the current inventories and last year’s level is 22.8 billion cubic meters of gas. Only 62 per cent of the total amount of gas that was withdrawn in the last heating season has been replenished. As for Ukraine’s UGS facilities, the negative difference versus last year is 30.6 per cent (or 8.2 billion cubic meters of gas). Gazprom is actively injecting gas into Russian UGS facilities. The daily average indicator for the first half of September is 325 million cubic meters. •

Contractual Documents Signed to Implement Project for Gas Processing Complex near Ust-Luga A number of contractual documents relating to the implementation of the construction project for the Gas Processing Complex near Ust-Luga (GPC of CPECG, forms part of the Complex for processing ethanecontaining gas (CPECG)) were signed at St. Petersburg International Gas Forum 2021. A license agreement was signed, ensuring the provision of rights for the use of the natural gas liquefaction technology by Gazprom and Linde to the operator of the GPC of CPECG – RusKhimAlyans (joint venture of Gazprom and RusGazDobycha). The technology is patented in Russia, with Gazprom and Linde as the patent holders. Gazprom, Linde, and RusKhimAlyans signed a Memorandum of Intent. The parties plan to assess the possibility of building an additional – the third one – production train at the LNG production plant as part of the GPC of CPECG. The camp is intended for the workers, engineers and technicians engaged in the construction of a storage facility for raw materials & marketable products and a marine shipment terminal that form part of the GPC of CPECG. The camp will have housing facilities, canteens, medical stations, leisure areas, infrastructure facilities, and utilities. It is planned to implement a wide range of measures to combat the spread of COVID-19 in the camp. Such measures, for instance, include building a housing facility serving as an observation area to quarantine newly-arrived workers. The camp will have its own fire station to ensure fire safety, as well as a security post with a police station to maintain public order. Velesstroy will be responsible for the development of design and working documentation, supply of materials & equipment, as well as construction & installation works and start-up & commissioning activities. The shift camp is due to be completed by late 2022. •

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NEWS - RUSSIA LUKOIL AND Tatarstan Develop Cooperation Vagit Alekperov, President of PJSC LUKOIL, and Rustam Minnikhanov, President of the Republic of Tatarstan, signed a cooperation agreement in Moscow. The parties intend to jointly develop upstream and downstream projects, production infrastructure, and public amenities. The agreement aims at increasing the efficiency of Tatarstan fuel and energy complex, improving investment environment in the region, expanding its mineral resources base, promoting stability and environmental improvement. LUKOIL, as ever, puts a premium on the social development of the region. Under the previous cooperation agreement, concluded by the Company and Tatarstan government in June 2010, LUKOIL took an active part in the revival and development of the region’s spiritual culture, as well as restoration of world-famous relics. The Company supported orphanages and performance groups, payed attention to the development of sports and social infrastructure. The Sarsak-Omga autoroute was reconstructed and the road system was constructed in Bolshaya Shilna village of Tukayevsky municipality. Since 2010, under the aegis of the republic’s president Rustam ​ Minnikhanov, Tatarstan has been one of the regions where the annual LUKOIL Social and Culture Projects Competition takes place. Over the years, over 7.5 thousand applications were submitted, out of which over 1.5 thousands became winners. •

SOCAR Increased Oil Production by 10% and Gas Production by 9%

NOVATEK Holds Arctic LNG Projects Shipowners Conference

SOCAR achieved growth in drilling and production in the third quarter of 2021. The company conducted more than 20,000 meters of drilling, which is 82% more than the same period last year.

PAO NOVATEK (“NOVATEK” and/or the “Company”) held the Company’s first Arctic LNG Projects Shipowners Conference in Moscow. Top management of the world’s major shipping companies, leading manufacturers of marine equipment and developers of state-ofthe-art IT solutions for the marine industry took part in the Conference.

Oil and gas production of SOCAR amounted to 2 million tons and 2 billion cubic metres, respectively. Thus, the Company achieved 10%-growth in oil production and 9% - in gas production compared to the same period last year. The comprehensive action plan to maintain stable production levels in the oil and gas fields operated by the company has been consistently implemented.

The participants paid a particular attention to environment protection, promotion of green shipping and introduction of sustainable technical solutions with the view to reducing the carbon footprint during marine operations in the Arctic. The Conference also looked into year-round navigation along the eastern route and crew training for Arctic vessels operations, including the cooperation between shipowners and Russia’s dedicated Arctic navigation training centers. “This conference offered all stakeholders in Russian Arctic shipping a unique opportunity to engage in a direct dialog on the topical issues of shipping in the region, including matters pertaining to organizing safe year-round navigation in the eastern sector of the Northern Sea Route, as well as to obtain first-hand updates on most recent developments allowing to improve the vessels’ energy efficiency and make them more environmentally friendly,” said Leonid Mikhelson, NOVATEK’s Chairman of the Management Board. “The created infrastructure and the accumulated unique experience in complex Arctic projects implementation, including hydrocarbons shipping, allow the Company to achieve in the near future a significant increase in its LNG production, and subsequently the shipping volumes”. •

In Q3 2021, oil and gas output of the country totalled to 8.7 million tons and more than 11.3 billion cubic metres, respectively. This means a 6% increase in oil production and a 38.6% increase in gas production compared to the same period last year. The increase in oil output was mainly due to the gradual easing of production cuts under the OPEC+ deal. SOCAR’s export performance for the third quarter was also satisfactory. The Company exported 4.5 million tons of oil, which is 22% higher than the same period last year. That includes both the crude sales of SOCAR and the crude, exported on behalf of the state of Azerbaijan. The country’s natural gas exports increased by 48% to 4.4 billion cubic metres. During the reporting period, 2.4 billion cubic metres of gas was consumed in the country, which is 8% more than the same period last year. In July-September 2021, SOCAR refined 1.8 million tons of oil, which is 46.5% more than in the same period last year. This sharp increase is related to the periodic maintenance carried out at the Heydar Aliyev Oil Refinery in the third quarter of last year. However, the plant did not stop its operations for periodic maintenance in Q3 this year. During the quarter, SOCAR’s Gas Processing Plant processed 812 million cubic metres of gas. The export volume of oil and gas refining and petrochemical products exported by the company increased significantly in the third quarter. SOCAR exported 1.1 million tons of petrochemical and refined petroleum products, an 88% increase compared to the same period last year. Of course, the above-mentioned reason played an important role in production increase at the refinery. At the same time, exports of chemical products such as high-pressure polyethylene, absolute isopropyl alcohol and carbamide showed a significant growth. •

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Host Organisation:

SPE Eastern Europe Subsurface Conference Unlocking New Resource Potential of Eastern Europe and the Black Sea

23–24 November 2021

Hilton Kyiv, Ukraine

go.spe.org/east_europe

Register Now: go.spe.org/east_europe Confirmed Leading Industry Figures Include: SPE President Kamel Ben-Naceur Franck Neel, OMV Petrom Oleg Neplyakh, KPMG Roman Opimakh, Ukrainian Geological Survey Robert Perkowski, PGNiG Artem Petrenko, AGPU Oleksandr Romanyuk, Naftogaz Yuriy Vitrenko, Naftogaz


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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


2021

IMPORTANT EVENTS CALENDER

October 2021

Downstream USA 2021 Dates: 12.10.2021 - 22.10.2021 Venue: NRG Center, Houston Website: www.reutersevents.com/events/downstream

November 2021 ADIPEC 2021

Dates: 08.11.2021 - 11.11.2021 Venue: Abu Dhabi, UAE Website: www.adipec.com Telephone: +971 2 444 4909

SPE Eastern Europe Subsurface Conference Dates: 23.11.2021 - 24.11.2021 Venue: Kyiv, Ukraine Website:https://www.spe.org/events

December 2021

23rd World Petroleum Conference Dates: 05.12.2021 - 08.12.2021 Venue: Houston Website: www.23wpchouston.com/

AntwerpXL 2021 Dates: 07.12.2021 - 09.12.2021 Venue: Antwerp, Belgium Website: www.antwerpxl.com

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Energy Transition Europe 22 - 23 November 2021 Online & On Demand

Setting the European Net Zero Agenda

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Kadri Simson Commissioner for Energy, European Commission

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Philippe Ducom President, Europe ExxonMobil

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2022

IMPORTANT EVENTS CALENDER

February 2022

SPE Offshore Europe 2021 Dates: 01.02.2022 - 04.02.2022 Venue: Aberdeen UK Website: www.offshore-europe.co.uk/

April 2022

SPE Norway Subsurface Conference Date: 27.04.2022 Venue: Quality Hotel Edvard Grieg Bergen, Norway Website: www.spe.org/events

June 2022

Global Energy Show 2022 Dates: 07.06.2022 - 09.06.2022 Venue: BMO Centre at Stampede Park Calgary, Canada Website: www.globalenergyshow.com

August 2022

ONS | Offshore Northern Seas 2022 Dates: 29.08.2022 - 01.09.2022 Venue: Stavanger, Norway Website: www.neventum.com/tradeshows

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