Oil & Gas Spring 2021
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Aramco Participates In Collaboration With World-Renowned Financial Institutions Aramco today announced its creation and participation in the launch of Altamayyuz Finance and Accounting Excellence Academy, a first-of-its-kind collaboration between leading accountancy firms and investment banks which establishes a center of excellence for finance and accounting. The academy is the result of a strategic alliance that will provide an exclusive financial and accounting development framework derived from world-class programs and partnerships with leading business schools and companies. It aims to build the capabilities of top finance and accounting graduates in Saudi Arabia, helping to power the growth of financial services in the region and form a highly-skilled talent pool for private and public employers.
ramco has partnered with the Technical & Vocational Training Corporation, Saudi National Bank (SNB), HSBC, Citi Bank, J.P. Morgan, KPMG, Goldman Sachs, Deloitte, EY and Morgan Stanley to launch Altamayyuz Academy. Aramco Chairman, H.E. Yasir Al-Rumayyan, said: “I am pleased to inaugurate Altamayyuz Academy, which is the latest in a long list of distinguished Aramco initiatives serving this ambitious country. The academy will support the advancement of Saudi employees in the financial sector through unique programs offered in coordination with some of the world’s leading financial institutions, providing an opportunity to upgrade both their skills and experience. The inauguration of the academy coincides with the fifth anniversary of Saudi Arabia’s Vision 2030 and it aligns closely with the country’s aspirations for the future. This academy will play an effective role in enriching the financial, investment and accounting sectors, further enabling the economic renaissance currently underway in the Kingdom.” Aramco President & CEO, Amin H. Nasser, said: “Saudi Arabia is witnessing tremendous development, which will be further enhanced through the provision of quality training opportunities for our ambitious young professionals. At Aramco we are dedicated to
equipping future generations with the skills they need to succeed, not only in the energy sector but in other fields where they can make a positive difference, including in the financial services sector. Altamayyuz will harness the expertise of some of the world’s most prestigious international financial and accounting firms, helping develop the skills of young graduates from both the public and private sectors. In doing so it will instill a spirit of excellence in talented young professionals – and help spur the pioneering development underway across the nation in support of Vision 2030.” Khalid H. Al-Dabbagh, Aramco’s Senior Vice President of Finance, Strategy and
Development, said: “Meeting the challenges of tomorrow requires investing in the graduates of today so we stay ahead of the curve. With Altamayyuz Academy, we are creating a valuable source of talent and an active national partner in creating a thriving financial sector in Saudi Arabia. The program will help unlock the full potential of the Kingdom’s human capital by accelerating skills building and knowledge transfer to our top talent. We not only turn great aspirations into reality, but we foster a future proofed sustainable economy.” Atamayuzz Academy offers a worldclass finance program for the Kingdom’s top graduates, which fuses international technical knowledge with market expertise. The program methodology is immersive, interactive, and experiential, with participants continuously networking with experts and industry leaders via seminars, case studies, career counselling, coaching, and mentoring. Participants in the academy’s programs will have the opportunity to study the latest techniques and knowledge in financial accounting, fintech, management accounting, capital markets and Islamic finance, mergers and acquisitions, and financial modeling through an intensive curriculum delivered in collaboration with Spain’s IE University. They will have access to coaching sessions and a fintech immersion week in San Francisco, in partnership with Stanford University. •
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CONTENTS COVER STORIES & SPECIALS German High-Tech Start-up premiso Launches AMBRELLA
Plant operators in the process industry are often faced with the question of how to monitor infrastructure elements that are widely distributed in the field easily and safely. These elements are often difficult to access and exposed to harsh environmental conditions.
Taking the Guesswork Out of Subsea Fault Location
C-Kore Systems, a UK company specialising in the development of innovative subsea testing tools, are seeing exciting results from customers around the world who are using their Subsea TDR technology to precisely locate faults in electrical distribution networks.
WORLD INDUSTRY NEWS Europe MENA South America North America Africa Asia Pacific Russia & CIS
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EXPLORATION & PRODUCTION Hybrid Cable Protection System
VPI’s Cable Protection system, which has been engineered initially for the wind turbine industry, has been developed over the past years by the engineering team into an innovative and multifunctional offshore solution. The cast iron and polyurethane hybrid system is a tailor-made solution for the oil and gas industry.
Try Before You Buy
Petroleum exploration and production are both enterprises that require considerable budget, and with ever-growing complexity, the risks are many. Applying seismic forward modelling can eliminate guesswork, and ultimately help avoid insomnia.
Significant Oil Discovery 6
CONTENTS MIDSTREAM & PIPELINES An Essential Worldwide Network
OGI sits down with Marc de Waele, Managing Director of LPL Projects + Logistics GmbH, to get some expert analysis about the ins and outs of logistical challenges in the oil and gas industry. LPL are experts at moving assets used in oil and gas operations around the world.
Outdated Perceptions to Robotic Tank Cleaning A global survey, commissioned by Re-Gen Robotics and carried out by tankstoragemag.com at the end of 2020, asked engineers, managers and senior executives with responsibility for hazardous area operations, their preferred option for cleaning oil terminal tanks. We have the answers.
Corrosion and Erosion Monitoring
PROCESSING Protect Your Employees Effectively
Increasing construction projects and heavy traffic in inner city areas cause significant and permanent noise pollution for residents. But noise generated during production or manufacturing in the plant itself also affects the well-being of workers.
The Perfect Sensor Solutions
Wherever pressure sensors are needed, a solution can normally be found in the KELLER standard product catalog. However, there are often great benefits to optimising a product specifically for integration and use in existing complete systems.
Schlumberger and Microsoft Expand Partnership
HEALTH SAFETY & ENVIRONMENT A Textile Legacy
For Carrington Textiles and their main production facility in the United Kingdom, Pincroft Dyeing and Printing, celebrating their 130th anniversary this year is a great milestone.
EVENTS CALENDAR 8
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NEWS BRIEF Feasibility Analysis Approved for Soyuz Vostok Gas Pipeline Construction Project
he feasibility analysis regarding the construction project for the Soyuz Vostok gas trunkline was approved today. The analysis was performed by Gazprom within the framework of the comprehensive feasibility analysis regarding the project for pipeline supplies of Russian gas across Mongolia to China. The Soyuz Vostok gas pipeline will become an extension of Russia’s Power of Siberia 2 gas pipeline in Mongolian territory. In the course of the feasibility analysis, the basic technical and technological parameters of the project were established. These include the optimal route for the gas pipeline in Mongolian territory, the pipeline’s length and diameter, the working pressure, and the number of compressor stations. The preliminary indicators reflect the cost effectiveness that needs to be achieved during the implementation of the project. As planned, the feasibility study regarding the construction project for the Soyuz Vostok gas trunkline (including a detailed breakdown of investment and operating costs) will be developed before the end of this year. This is indicated in the action plan of the Joint Working Group of Gazprom and the Government of Mongolia. The feasibility study is being prepared by the Gazoprovod Soyuz Vostok special-purpose vehicle. In December 2019, Gazprom and the Government of Mongolia signed a Memorandum of Understanding. A Joint Working Group was created under the Memorandum. On March 11, 2021, the action plan of the Joint Working Group for 2021–2022 was approved. In early 2021, a special-purpose vehicle named Gazoprovod Soyuz Vostok was registered in Mongolia. The company was established with the purpose of performing design and survey works and conducting a feasibility study regarding the construction project for the Soyuz Vostok gas trunkline. The export capacity of the Power of Siberia 2 gas pipeline might become more than 1.3 times higher than that of Power of Siberia. This will enable exports of large amounts of gas from Western Siberia not only westward but also eastward. •
Lukoil Keeps Investing Into Social Development of the Republic of Komi
UKOIL and the Republic of Komi signed an additional agreement for 2021 in furtherance of the Cooperation Agreement that is already in force. The document provides for investment into the social infrastructure and amenities of the region. Among other things, LUKOIL will aid in expanding an outpatient clinic and completing construction of a day-care centre in the village of Mutny Materik, as well as installing a water treatment and supply system and opening an outpatient clinic in the village of Schelyabozh. The Company will also help to reconstruct buildings of a childcare home in Syktyvkar and a cadet boarding school in the village of Koroviy Ruchei. The additional agreement also provides for construction of apartment blocks in the cities of Usinsk and Yarega, as well as implementation of charity projects in the region. LUKOIL has been supporting the Komi Republic since the very start of its operations in the region. In 2020, in the thick of the pandemic, LUKOIL President Vagit Alekperov donated 50 million roubles of personal funds to outfit the Central District Hospital of Usinsk. These funds were spent to buy up-to-date artificial respiration units, ECG recorders, medical beds, and other equipment needed to treat COVID-19 patients. MORE NEWS.. President of Russia Vladimir Putin signed an Executive Order on granting awards to employees of LUKOIL Group. LUKOIL’s First Executive Vice President Vadim Vorobyov and LUKOIL’s Vice President for Economics and Planning Gennady Fedotov, as well as general directors of several LUKOIL Group organisations – namely Andrei Bogdanov (LUKOIL-Nizhegorodnefteorgsintez LLC), Nikolai Lyashko (LUKOIL-Nizhnevolzhskneft LLC) and Maksim Khitrov (LUKOIL-Severo-Zapadnefteprodukt LLC) – received the Orders of Honour in recognition of their labour achievements and decades-long dedicated work. LUKOIL’s Senior Vice President for Sales and Supplies Oleg Pashaev was awarded the Order of Friendship. Roger Munnings, a member of PJSC LUKOIL Board of Directors and the Chairman of the Russo-British Chamber of Commerce, also received the Order of Friendship for his significant contribution to the development of commercial, economic and cultural cooperation between the Russian Federation and the United Kingdom of Great Britain and Northern Ireland. The award ceremony will take place within the framework of celebrations of LUKOIL’s 30th anniversary. •
German High-Tech Start-up premiso Launches AMBRELLA Asset condition monitoring platform for wide-area industrial plants combined with new NDT sensors. Plant operators in the process industry are often faced with the question of how to monitor infrastructure elements that are widely distributed in the field easily and safely. These elements are often difficult to access and exposed to harsh environmental conditions. In many locations, communication connection and power supply are only available with considerable effort. In an electrolysis plant with high magnetic fields, for example, mobile radio transmission is unthinkable. Despite all this, regular inspection of equipment such as pipelines, pumps and the like is necessary for process optimization and must be carried out at great expense. It usually comes with significant ancillary costs for documentation, scaffolding and testing procedures.
or this reason, the market for various suppliers of field sensor technology is growing very dynamically and will continue to play an important role in the future. If customers wants to use all these new and powerful sensors, they often quickly realize that almost every supplier brings along his own software application. A uniform rights management as well as an overall view and the possibility of correlating data from various sensors is thus rarely possible.
premiso FRP-Monitoring Unit.
Nevertheless demand for innovative solutions is growing daily, and so is the need for higherlevel monitoring systems, but requirements are complex. Due to the increasing shortage of qualified personnel, such a monitoring system must be able to perform measurements validly and autonomously, as well as to provide high quality data on a continuous basis. Furthermore, it is important to combine intelligent monitoring with prediction of future events and to automatically alert the appropriate bodies at an early stage. This will be the only way to cope with the increasing cost pressure and the
associated efforts to extend the service life of infrastructure and equipment. Avoiding unplanned shutdowns and increasing safety within a plant have always been the most prominent goals of plant operators and their partners. All this is only possible with a unified system for monitoring sensors distributed in the field alongside the actual process control system for controlling and maintaining the production process. The German high-tech start-up premiso AG recently presented its AMBRELLA asset condition monitoring platform. The platform combines new, proprietary NDT sensors developed by premiso with the possibility to integrate third party sensors widely distributed in the field, manufacturer-independent. Plant operators in the process industry can use AMBRELLA to automatically monitor the premiso WTM-Monitoring Unit.
current status of their infrastructure elements distributed in the field at any time, regardless of their location. Using intelligent, predefined and customizable alarm functions, plant operators and their partners are able to make operation and maintenance safer and easier to plan, all without manual effort. Sensor parameters are reliably transmitted, analysed and monitored. This creates a new dimension of information regarding operation-critical infrastructure. Simple and efficient management of systems and equipment coupled with extensive options for visualization and evaluation of measured values not only save time and resources, but also offer additional added value for early detection of trends and risks. Existing interfaces and proven data models continue to make it possible to integrate inventory sensors and other IIoT sensors, regardless of manufacturer, at any time. The connection of
a wide variety of transmission technologies such as LoRaWAN®, LTE, 5G, etc. is possible, as is data transfer via predefined interfaces (API) to other cloud platforms and systems. In addition, it is possible to securely transfer the data to process control systems. A consistent security infrastructure in accordance with the highest standards, coupled with uniform rights management, provides a further plus for the use of such a holistic endto-end solution. A single sign-on procedure makes countless separate login procedures and passwords a thing of the past. To compensate for the sometimes poor data situation in the field of non-destructive testing of plants and equipment, the premiso has developed its own high-end sensor technology in addition to the asset condition monitoring platform AMBRELLA. These wireless, batterypowered and modular sensors offer plant operators and their partners the possibility to retrofit existing plants and equipment and, in the future, to cover further use cases through premiso’s own sensor development department. Currently available are sensors for permanent measurement of wall thickness of metallic materials and sensors for monitoring the structural integrity of FRP equipment. Both sensors transfer their data reliably to the AMBRELLA platform via wireless radio transmission using LoRaWAN®, autonomously, battery-powered and immune to interference, even under difficult external conditions such as inside an electrolysis plant or thick walls. With up to three ultrasonic probes per WTM monitoring unit, reductions in the wall thickness
Screenshot AMBRELLA Platform.
A MBRELLA THE FIELD VIEW of metallic materials can be detected at an early stage and automatically trigger an alarm at the appropriate points. Unique feature of this system is the specially developed probe with self-calibration. This makes it possible to operate the system completely selfsufficiently over a long period of time without any additional effort, e.g. by recalibration at regular intervals. This means that even difficult-to-reach areas can be monitored reliably and automatically. An absolute world innovation are the sensors for monitoring the structural integrity of glass fibre reinforced plastic equipment, or FRP for short. The retrofittable, so-called FRP monitoring units provide exact and validated data on the condition of the FRP equipment. This means that a wide range of damage, such as matrix or fibre cracks and other structural deviations, can be reliably detected and evaluated at an early stage. By means of an actuator/sensor system per FRP monitoring unit, the fibre composite material (FRP) is periodically animated and the resonance frequency is determined. Thus, changes in material properties are detected and
transmitted at an early stage. The monitoring unit can be permanently installed on new and used structures. Data transmission via LoRaWAN® ensures the functionality even under difficult conditions. Integrated dynamic analyses in the unit as well as on the AMBRELLA platform provide current overviews and trends of the monitored objects. This allows plant safety to be increased, unplanned outages to be avoided and better planned maintenance. Costly, timeconsuming and resource-intensive inspections using light sources, X-rays or destructive testing can also be avoided. In summary, premiso is the new partner for plant operators and industrial service providers, offering end-to-end solutions from sensor development to platform solutions. Due to its independence from well-known suppliers and its versatile expertise, the company is very well positioned to deliver fast, practicable and custom-fit solutions. • premiso AG www.premiso.de/en
Taking the Guesswork Out of Subsea Fault Location C-Kore Systems, a UK company specialising in the development of innovative subsea testing tools, are seeing exciting results from customers around the world who are using their Subsea TDR technology to precisely locate faults in electrical distribution networks.
he ability to distribute electrical power on the seabed is mission-critical to the production of oil and gas from subsea wells. Without a reliable power supply to Subsea Control Modules on xmas trees and manifolds the operator may be unable to open and close process valves or read-back vital
Figure 1 (Below): C-Kore Subsea TDR For subsea TDR to be of real value it must be capable of distinguishing a fault in an Electrical Flying Lead from the distribution unit to which it is connected. In practice this means that it must have a resolution of a few centimetres whilst having a range of several kilometres. The C-Kore Subsea TDR meets these requirements whilst also having the unique ability to detect anomalies that are very close to it, which is a common blind spot of conventional TDR devices.
instrumentation on pressures, temperatures and flow rates. We all are all aware of the hazard associated with using electrical appliances near water, so it is no surprise that designers of subsea electrical systems, which may be required to operate for 25 years or more, go to great lengths to create robust insulation barriers between the electrical conductors and the seawater. However, experience shows us that at some time, at some point, the insulation defence is going to be breached and that the integrity of the power supply is going to be compromised, putting oil and gas production at risk. For this reason, all subsea production control systems are required to monitor the integrity of the insulation between the live conductors and earth in order to identify if a potentially hazardous fault condition exists. Whilst the Line Insulation Monitor will tell the operator that a fault condition exists on a power channel, it provides no information on where the fault is located. Until the location of the fault can be determined the most appropriate and cost-effective repair solution cannot be identified. In a deep water, long-offset field with
multiple wells and hundreds of connectors identifying the precise location of a fault is a big challenge and a costly one. Time Domain Reflectometry (TDR) is a technique that is widely used to locate faults in onshore electrical systems, such as the buried services that run under our streets, but the challenges of applying the technique to a length of cable that may be in 3000m of water and 20km from the host facility have, until the development of C-Kore’s Subsea TDR tool, limited its value to subsea operators. TDR may be likened to sonar, but instead of using the received echoes of sound waves to create a map of seabed objects, the TDR transmits an electrical pulse into a cable and records the pattern of electrical reflections returned. Such reflections are caused by local differences in the Impedance of the cable that are encountered as the pulse travels along its length and may be due to components such as connectors, splices and nodes as well as to faults such as breaks, shorts, and water ingress. Calibrating the time-of-flight of the pulse to and from an expected reflection, say
Figure 2 (Above): Fault located in subsea UTA This fault would not have been locatable with a traditional TDR from either the host facility or a surface vessel, as the small divergence caused by the seawater fault would have been attenuated and masked. Figure 2 shows the result of the C-Kore software overlaying the responses from a known healthy conductor pair in a 4.9km long umbilical with one with a low Insulation Resistance fault. When the software is used to zoom in on a feature at the near end of the trace a divergence between the faulty and healthy cores is seen at 5 metres; correlating precisely with where a field installable connection has been made between the UTA and the umbilical. from a connector at a known distance from the TDR unit, enables the test engineer to determine the distance to any anomaly observed in the reflection. Successful application of TDR benefits from being able to compare the trace from the faulty conductor pair in a cable with a twin that is known to be healthy (which can be ascertained using an insulation resistance measurement tool, such as the C-Kore Cable Monitor). Conventional TDR also depends heavily on the skill of the operator in applying the optimum pulse width and signal gain to get a clear response, plus their experience in correctly interpreting the complex trace that is returned. This is often an iterative process which can be both very time consuming and costly. TDR testing works best in uninterrupted lengths of cable without nodes and branches, which can result in the pulse being returned as echoes of echoes, each one attenuated in strength and
distorted by its distance of travel, often to the point where no useful information can be derived from the trace. The topology of most electrical power circuits in subsea production control systems, where an umbilical, often many kilometers long, connects the host facility (platform or FPSO) to multiple subsea wells via a daisy chain of cables and splitters, makes successful TDR from the surface problematic. The big reflection from the first subsea connector at the Umbilical Termination Assembly (UTA), the attenuation of the pulse and return signal over the length of the umbilical, and the complex echoes from the branches to individual wells make it extremely difficult to locate any fault or anomaly that lies beyond the UTA. Historically this shortcoming has been partly addressed by performing the TDR from a vessel located above the drill centre, instead of the host facility, thus taking the umbilical attenuation factor out of the equation and enabling the operator to connect into individual sections of the distribution circuit. Unfortunately, whilst TDR from a vessel mitigates some of the problems it introduces other issues associated with the need to deploy a downline cable from the deck of the vessel to the seabed, and these issues significantly reduce its effectiveness. Apart from the costs and risks associated with deploying a downline cable in deep water and harsh environments the effectiveness of the TDR is likely to compromised by the inclusion of several hundred metres of cable with different transmission properties from the circuit that is being tested. Taking the logical step to move the TDR closer to the subsea infrastructure was the challenge that C-Kore took up in developing
“C-Kore tools allows testing to be completed much faster by automating the entire testing process and saving you days of vessel time.” their Subsea TDR tool. Bringing the TDR to the seabed required more than simply marinising the electronics, it demanded full automation of the test process so that all that is required of the diver or ROV is to activate the tool, thus initiating a sweep of tests with different pulse configurations and storing all results to memory. This ensures that whilst the test duration is minimised the operator is assured that the data returned from the seabed will contain all the information required. Operators and subsea contractors using the C-Kore Subsea TDR can now ‘see’ faults and anomalies that would previously have been invisible and can pin-point them to an accuracy that enables intervention with the appropriate repair solution at the minimum cost. They don’t need to guess any more, and they don’t need to risk returning from an expensive subsea intervention with only part of the picture. • If you would like to know more about how C-Kore can help your company and its operations, please contact them at: C-Kore Systems Ltd T: +44 (0)1904 215161 E: firstname.lastname@example.org W: http://www.c-kore.com
NEWS - EUROPE
Court Overturns Previous Ruling In ProsafeWestcon Case A Norwegian Court of Appeal has reversed a decision of a district court in Norway in a case between Prosafe and Westcon regarding the conversion of the Safe Scandinavia unit, ordering Prosafe to pay a total of about $55 million to Westcon. The dispute between Westcon Yards and Prosafe was related to a substantial cost overrun of Westcon’s price estimate for the conversion of Prosafe’s Safe Scandinavia to a tender support vessel.
he Stavanger District Court on 8 March 2018 issued its judgement in favour of Prosafe in respect of the dispute between Westcon Yards and Prosafe relating to the conversion of Safe Scandinavia into a tender support vessel. The Stavanger District Court decided in 2018 that Westcon must pay Prosafe NOK 344 million ($40.85 million) plus interest and NOK 10.6 million ($1.3 million) in legal costs. Following this decision, Westcon filed an appeal in April 2018 and Prosafe filed a counter appeal in May 2018. The Gulating Court of Appeal on Thursday decided that Prosafe will pay to Westcon NOK 302,510,457 ($35.9 million) plus interest and legal costs, in total about NOK 465 million (about $55.2 million). The judgement implies full payment to Westcon of the amount claimed. Compared to the judgement in the first instance by the Stavanger District Court, the result in the Gulating Court of Appeal is a complete reversal Jesper K. Andresen, CEO of Prosafe, said: “We how two courts can reach such complete of the result, Prosafe explained on Thursday. take note of the extremely disappointing and opposite results”. A judgement from a Court of Appeal is usually surprising judgement from the Gulating Court As a background, Westcon Yards and final, as the possibilities of further appeal are of Appeal. It is difficult to understand Prosafe entered into an EPC contract for the very limited, the company added. conversion of Safe Scandinavia into a tender support vessel in February 2015. The unit arrived at the yard in March 2015 and the plan was for the work to be completed in the first half of 2015. However, the project experienced delays thereby also delaying the contract start with the Norwegian oil company Equinor, then Statoil. Prosafe claimed that the conversion of the vessel had experienced substantial cost overruns compared to the price estimate given by Westcon when the two entered into the contract. Following delays, the unit finally completed its acceptance testing and mobilized to the Oseberg Øst installation in the North Sea to start drilling support operations for Equinor in March 2016. The 1984-built Safe Scandinavia is an anchor moored semi-submersible tender support and accommodation vessel with beds for 309 persons capable of operating worldwide in harsh conditions. •
NEWS - EUROPE Remote-Controlled Fire Monitors for Fixed Firefighting Systems
Duva Project Marks Important Milestone
he requirement for automated firefighting is continuously increasing. Remote-controlled monitors, especially in combination with automated fire detection, allow a targeted but flexible firefighting operation in limited areas. The technical development in drive engineering, sensor technology and control technology offer some great future potential. Automated firefighting systems are well known as sprinkler systems and also spray nozzles. But for several years automated firefighting systems with remote-controlled monitors are used for fire protection of tank farms, petroleum loading terminals, aircraft hangars, thermal power plants, production facilities, recycling plants, waste incineration plants. When using remote-controlled monitors in automated firefighting systems, this requires a consideration of some function-relevant parameters with regard to the design and construction of the monitors. Repetition accuracy, or a return to the exact start point is essential for remote control monitors, otherwise constant recalibration is necessary. In order to achieve the requirements of repetition accuracy for pre-programmed extinguishing operations, zero-clearance bearings and gears are necessary to effectively prevent any tilting of the pivot mounting. The backward forces generated by firing a mass, such as a water jet, can lead to high equipment stresses and power consumption. A design aimed at reducing the repellent forces and decreasing the power needed to swivel the monitor, such as the optimized FireDos octagonal ‘Oval Flat Design’ is essential. We recommend the use of suitable, contact-free and thus wear-free absolute encoders to implement a high repetition accuracy and precise nozzle direction in the case of automated firefighting systems. It is vital to use such sensors to monitor and save movements and positions even when electricity is shut-off. In case of manual manipulation of the monitor by using the fitted hand-wheels, i.e. during maintenance or commissioning, this ensures that no reference adjustment is necessary for recalibration of the programmed automated swivelling movements. In addition, the drives which regulate the spray pattern must be able to be fitted with absolute encoders. Besides the right / left and up /down movements, this provides a third parameter that allows influencing the shape and range of the spray target area. A larger spraying angle also reduces the extinguishing agent jet’s impact forces and thus prevents a fire of bulk materials from spreading. To achieve the necessary degree of freedom, remote-controlled monitors should allow wide swivelling ranges. Preferably, the horizontal swivelling range is 360° and the vertical swivelling range reaches from +90º to -90°. Both swivelling axes should have self-locking worm gears to prevent the monitor from an unintended adjustment by an external force. Additionally self-locking gears help to stop remote-controlled monitors at the desired position without requiring additional brakes. To achieve the corrosion resistance required for a long-term use of the monitor, components made of seawater-resistant cast aluminium and additional special hard anodized coating are used and have proven themselves for many years. Using only cast parts to build monitors eliminates the risk of stress corrosion cracking, which occasionally appears in welded parts. The development process of monitors using cast parts increases the design flexibility and optimization process significantly. The components can be flow-optimized by the use of CFD (Computational Fluid Dynamics) simulation software. Low-pressure loss figures can be achieved even with comparatively compact dimensions. This reduction in pressure loss indicates that the extinguishing water turbulence on the way through the monitor is reduced to a minimum. Flow-optimisation however does not end with the so-called pivot mounting, i.e. the body of the monitor, but also includes the nozzle. A
eptune Energy today announced the safe and successful installation of four Enhanced Horizontal Subsea Tree Systems (EHXT) for the Duva development project in the Norwegian sector of the North Sea. The installation was carried out by a vessel instead of a rig, reducing installation time, costs and operational emissions. The Duva development, on Production Licence 636, is an oil and gas subsea tie-back to the Gjøa semi-submersible facility. Neptune Energy is the operator of both the Duva project and the Gjøa facility. While conventional installation of EHXTs would be carried out with a drilling rig, Neptune, together with its partners and contractors, conducted the installation using the vessel Far Samson, operated by Solstad Offshore. Neptune Energy’s Director of Drilling & Wells in Norway, Thor Løvoll, said: “By introducing the latest available technology combined with quality planning and teamwork, we completed the installation safely, successfully and ahead of schedule. Deploying the subsea trees from a vessel saved about 20 days of rig time, reducing costs, time and emissions.” The 20 days of reduced rig time is equivalent to approximately $12 million savings for the license partners. By using a vessel instead of a rig, emissions were reduced by more than 60% during the installation activities.* It was the first time Neptune Energy has installed EHXTs in a standalone operation with a vessel. They were successfully deployed on the template wellheads over an 18-hour period, with the total installation and subsea system testing completed within eight days. The operation was carried out in close cooperation with TechnipFMC, Ross Offshore, Solstad Offshore, Oceaneering, Fugro, IKM and Tigmek. Neptune Energy’s Head of Gjøa Subsea Development, Crawford Brown, added: “We are progressing with the Duva project at pace and have reached an important milestone. The efficient installation of the subsea trees allows the project more schedule flexibility as we enter the drilling and completion campaign for the Duva production wells. “Duva is an important part of Neptune’s geographically-diverse, gas weighted portfolio of developments, and will both increase production and extend the operational life of our operated Gjøa platform.” The drilling rig Deepsea Yantai, operated by Odfjell Drilling, will drill and complete the remaining sections of the Duva well program during Q2/Q3 2021. The Duva oil and gas field was Neptune’s first discovery in the Norwegian North Sea, a strategically important area supporting the company’s growth. It is located 14 km northeast of the Neptuneoperated Gjøa field, at a water depth of 360 metres. Gross 2P reserves are 88 mmboe (gas 76%). First production from Duva is expected in the third quarter of 2021. Licence partners on Duva, PL 636, are Neptune Energy (Operator, and 30%), Idemitsu Petroleum Norge (30%), PGNiG Upstream Norway (30%), Sval Energi (10%). •
sufficiently long nozzle design reduces the turbulences from the pivot mounting effectively and creates the basis for the long reach of CFD flow-optimized nozzles. As it has already been practised with manual controlled monitors for a long time even nozzles for remote-controlled monitors can optionally be fitted with regulators for the extinguishing agent flow-rate. FireDos monitors offer this option to take place remotecontrolled during operation. The flow can thus be adapted to the actual requirements of firefighting. •
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NEWS - EUROPE New Ultra-Compact Flowmeter for Utilities and Industrial Automation
ROHNE introduces the AF-E 400 ultra-compact electromagnetic flowmeter for utilities and industrial automation applications. It is specially designed to fit in applications with little installation space available, e.g. in cooling lines of welding equipment, bending machines and robots, or on chemical dosing skids. AF-E 400 matches the requirements of application areas in heating and cooling/temperature control, machine building of washing or dosing equipment, HVAC, and utilities and industrial automation applications in all process industries. KROHNE has examined issues with products in this segment and developed the cost-effective ultra-compact flowmeter to be best in its class in terms of temperature range, accuracy, pressure drop and flow range: AF-E 400 features a stainless steel housing and is suitable for continuous use at +90°C/ +194°F liquid temperature, allowing for operation in very demanding cooling and hot water applications. The round bore reduction of the sensor makes the flowmeter more resilient in terms of increased pressure, ensuring high accuracy over a wide pressure and temperature range, and a high turndown ratio without risk of cavitation. The integrated temperature measurement eliminates the need for an additional sensor, minimising the intrusion points in the pipe and providing more data from the process. AF-E 400 also features extensive self-diagnostics: the meter continuously monitors several critical aspects including low supply voltage, incorrect parametrisation, flow range exceedance, or short circuit on any of its outputs. Warning messages according to NAMUR NE107 alert the user via the rotatable full colour display or the communication outputs. Due to the special design of its magnetic circuit, field strength and electronics, AF-E 400 is immune to crosstalk caused by magnetic field overlap of adjacent devices, and can be installed in series or in parallel up to a distance of 2 mm/ 0.08” from device to device without interference. Nominal sensor sizes reach from DN6...25/ ¼...1¨ for flow rates up to 150 l/min/ 40 US gpm as standard, up to 500 l/min/ 132 US gpm on request. Output options include 4...20 mA, pulse, frequency, switch, IO–link or Modbus to provide operators with multiple sensor and application data for smarter factory automation. AF-E 400 is sold from stock and shipped within 48 hours. KROHNE is a global manufacturer and provider of process instrumentation, measurement solutions and services in many industries. Founded in 1921 and headquartered in Duisburg, Germany, KROHNE has over 4,000 employees and offers extensive application knowledge and local contacts for instrumentation projects in over 100 countries. KROHNE stands for innovation and highest product quality and is one of the market leaders in process industry. •
Neptune Energy Awards Borr Drilling Contract
eptune Energy today announced the award of a $21.4m contract to Borr Drilling, consolidating development, exploration and P&A activities in the Dutch and UK sectors of the North Sea, and reducing costs and operational emissions. The activities will be carried out by Borr Drilling’s new Prospector 1 jack-up rig which is equipped with technologies that reduce carbon and nitrogen emissions from its operations by up to 95% . The approach complements Neptune Energy’s commitment to working with supply chain partners to maximise efficiency and reduce operational emissions across its growing portfolio of assets and development projects. Neptune Energy’s Global Head of Drilling & Wells, Brett McIntyre, said: “Previous drilling contracts have traditionally been awarded at a country level, but by consolidating these workscopes we have adopted a more collaborative and efficient approach with Borr Drilling. “We have an exciting programme of activities planned to support the growth of our global business, and this is an excellent example of how E&P companies and supply chain can work together, adopting the latest technologies and commercial models to improve efficiency and reducing emissions across a variety of offshore activities.” The Prospector 1 uses a Selective Catalytic Reduction (SCR) System which reduces emissions of nitrogen (NOx) and carbon (COx). Harvey Snowling, Chief Operating Officer, Borr Drilling, said: “We are delighted to be awarded this work scope and look forward to working with Neptune once again for this upcoming campaign. This contract award demonstrates our focused collaboration to deliver consistently safe, efficient, high quality drilling services to our customer. “We are always looking for ways to improve the efficiency of our operations and to reduce our impact on the environment and the installation of a SCR system on Prospector 1 represents a major step on our sustainability journey.” The contract includes an option for an additional three wells after the initial seven-month drilling campaign is completed. Last week Neptune announced its annual results for 2020, highlighting new projects coming online this year in Norway and Indonesia, as well as longer term prospects in Norway and the UK that will increase production to around 200 kboepd in 2023.•
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NEWS - MENA Suez Canal Unblocked: “We Pulled It Off!”
oskalis announces the successful salvage operation of the grounded 20,000 TEU container vessel Ever Given in the Suez Canal. With a length of 400 meters and a width of nearly 60 meters this giant ship had been wedged in this vital shipping route since 23 March 2021 blocking all shipping traffic ever since. Peter Berdowski, CEO Boskalis: “Shortly following the grounding of the Ever Given we were requested through SMIT Salvage to provide assistance with the salvage operation. I am excited to announce that our team of experts, working in close collaboration with the Suez Canal Authority, successfully refloated the Ever Given on 29 March at 15:05 hrs local time, thereby making free passage through the Suez Canal possible again. I’m extremely proud of the outstanding job done by the team on site as well as the many SMIT Salvage and Boskalis colleagues back home to complete this challenging operation under the watchful eye of the world. The time pressure to complete this operation was evident and unprecedented and the result is a true display of our unique capabilities as a dredging and marine services provider.” For the refloating of the 224,000-ton container vessel approximately 30,000 cubic meters of sand was dredged to help free the vessel and a total of eleven harbor tugs and two powerful seagoing tugs (Alp Guard and Carlo Magna) were deployed. The vessel is towed to a location outside the channel for further inspection. •
Eni and SONATRACH Sign a Series of Agreements
ni’s CEO Claudio Descalzi met today with an Algerian delegation led by SONATRACH CEO Toufik Hakkar further strengthening the partnership between the two companies.
Qatar Petroleum to Become 100% Owner of Qatargas in 2022
atar Petroleum has announced that it will not be renewing the Qatargas Liquefied Natural Gas Company Limited (QG1) joint venture upon the expiry of the relevant agreements on 31 December 2021. As a result, Qatar Petroleum will become the sole owner of 100% of the QG1 assets and facilities on 1 January 2022. Commenting on this announcement, His Excellency Mr. Saad Sherida Al-Kaabi, the Minister of State for Energy Affairs, the President and CEO of Qatar Petroleum, said, “The takeover by Qatar Petroleum will conclude more than 25 years of successful operations of QG1, from which the first ever Qatari LNG cargo was exported. This is a momentous event that highlights Qatar Petroleum’s efforts to further enhance the utilization of our natural resources for the benefit of our country and its current and future generations as well as to continue serving the world’s need for cleaner energy.” His Excellency Minister Al-Kaabi added, “I would like to thank our valued partners, Total, ExxonMobil, Marubeni and Mitsui for their efforts in the development and operation of QG1 over the past three decades. Each one of them has played an instrumental role in the success of QG1. In particular, I would like to express my sincere thanks and appreciation to Total, for being a foundation shareholder from inception and for their valuable contributions throughout this journey; to ExxonMobil, for stepping in at a critical juncture of the project and leveraging their experience to help making the project a reality; and to Mitsui and Marubeni for their valuable contributions in securing anchor offtakes for the project and for their great support during the early phases. Thanks, and appreciation are also due to Chubu Electric, QG1’s foundation customer, for their key role in anchoring this project as the primary LNG buyer as well as to the other Japanese buyers and, of course, the country of Japan as a whole. Furthermore, I would also like to sincerely thank QatarGas operating company leadership and employees for their excellent work and dedication that made this company a success over the last 25years”
With a production capacity of approximately 10 million tons per annum of LNG, QG1 facilities will continue to be operated by Qatargas on behalf of Qatar Petroleum and will play an important role in supplying LNG to the world’s markets in a safe and reliable manner. •
San Donato Milanese (Milan, Italy), 25 marzo 2021 – The Chief Executive Officer of Eni, Claudio Descalzi, and the President General Manager of the Algerian state company SONATRACH, Toufik Hakkar, met today at the Eni headquarters in San Donato Milanese to take stock of common activities and sign various agreements in the exploration and production, research and development, decarbonisation and training fields. These agreements mark a further step forward in strengthening the partnership between the two companies. The first of the agreements signed aims to implement an ambitious program for the relaunch of exploration and development activities in the Berkine basin region and provides for the creation of a gas and crude oil development hub through a synergy with existing MLE-CAFC installations. This agreement is part of the process for the finalization of a new hydrocarbon contract in the basin, under the aegis of the new Algerian oil law which came into force in December 2019. Claudio Descalzi and Toufik Hakkar also signed a Memorandum of Understanding for the development of the partnership between Eni and SONATRACH in the new technologies sector, with a focus on renewable energy, biofuels and hydrogen. This agreement aims to strengthen the cooperation already in place between the two companies in the technological field and continue the decarbonization path undertaken to support the transition towards a low carbon future. Eni and SONATRACH have also agreed to collaborate in other sectors such as staff training, through the signing of an agreement that provides for cooperation between Eni Corporate University and the Institut Algerien du Petrole for the implementation of training programs in the Upstream and new technologies related to the energy transition fields. At the end of the meeting, Eni’s CEO thanked the PDG and the members of the SONATRACH delegation for their constant collaboration and relationship: “Today’s agreements represent the commitment made by our companies to strengthen a historic partnership, in compliance with a shared strategy to accelerate the development of decarbonisation projects as part of our commitment of achieving our carbon neutrality goal.” Eni has been present in Algeria since 1981 where is operator in 48 mining permits. With an equity production of 90,000 barrels of oil equivalent per day, Eni is the main international company operating in the country. •
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NEWS - MENA Aramco demonstrating exceptional resilience despite the macroeconomic impact of COVID-19
he Saudi Arabian Oil Company (“Aramco” or “the Company”) today announced its full-year 2020 results, demonstrating exceptional resilience despite the macroeconomic impact of COVID-19 and delivering on its intended dividend payments to shareholders. Commenting on the results, Aramco President & CEO Amin H. Nasser, said: “In one of the most challenging years in recent history, Aramco demonstrated its unique value proposition through its considerable financial and operational agility. Our exceptional performance during such testing times owed much to the unwavering spirit and resilience of our employees, who set operational records and continued to meet the world’s energy needs both safely and reliably. “As the enormous impact of COVID-19 was felt throughout the global economy, we intensified our strong emphasis on capital and operational efficiencies. As a result, our financial position remained robust and we declared a dividend of $75 billion for 2020. “At the same time, the accelerated deployment of digital technologies across the company significantly enhanced our performance and we continued to make progress on breakthrough low-carbon solutions. “Looking ahead, our long-term strategy to optimize our oil and gas portfolio is on track and, as the macro environment improves, we are seeing a pick-up in demand in Asia and also positive signs elsewhere. We remain confident that we will emerge on the other side of this pandemic in a position of strength.” Aramco achieved a net income of $49 billion in 2020, one of the highest earnings of any public company globally. The Company displayed strong financial resilience in one of the most challenging periods for the industry, during which revenues were impacted by lower crude oil prices and volumes sold, and weakened refining and chemicals margins. Aramco declared a dividend of $75 billion for the year, which reflects the outcome of the Company’s strong performance. The Company continues to preserve a strong balance sheet and its gearing ratio at December 31, 2020, was among the lowest in its industry. Meanwhile, its ROACE of 13.2% was the highest in the industry. Through its flexible capital program and prudent financial management, the Company was able to adjust spending and focus on high-return opportunities. Capital expenditure in 2020 was $27 billion due to the implementation of optimization and efficiency programs, representing a significant saving on capital expenditure of $33 billion in 2019. The Company continues to assess its capital expenditure and efficiency programs, and expects capital expenditure for 2021 to be around $35 billion, significantly lower than the previous guidance of $40-$45 billion. Aramco’s international bond issuance in the fourth quarter achieved record demand for a 50-year tranche and was 10 times oversubscribed compared to its initial offering size. This global investor interest demonstrated market confidence in the Company’s long-term strategy and performance outlook. In 2020, Aramco’s average hydrocarbon production was 12.4 million barrels per day of oil equivalent, including 9.2 million barrels per day (mmbpd) of crude oil. In April, Aramco achieved the highest single day crude oil production in its history of 12.1 million barrels per day. The Company achieved another milestone in August, producing a single-day record of 10.7 billion standard cubic feet per day (bscfd) of natural gas from its conventional and unconventional fields. Both records were achieved despite lower capital expenditure in 2020. Aramco continued its strong track record of supply reliability, despite disruptions caused by COVID-19, by delivering crude oil and other products with 99.9% reliability in 2020. Aramco’s ambition to further expand its downstream business took a
significant step forward with the acquisition of a majority stake in SABIC in June, transforming the Company into a major global petrochemical player with operations in more than 50 countries. In 2020, Aramco also announced a Downstream reorganization intended to maximize value from its global network of assets. Technology and innovation are key to delivering more energy with fewer emissions. Aramco continued to make advances in cutting-edge technology and received a company record of 683 U.S. patents in 2020 among the highest in its industry. Aramco maintained one of the lowest upstream carbon footprints in the industry, achieving an estimated upstream carbon intensity of 10.5 Kg of CO2 per barrel of oil equivalent in 2020. The Company’s estimated upstream methane intensity was 0.06%. These accomplishments are the result of the Company’s decades-long reservoir management and production approach, which includes leveraging advanced technologies and minimizing emissions and flaring. The Company is well positioned to capitalize on developments in hydrogen, given the Company’s scale, infrastructure, low costs and low upstream carbon intensity. One promising area is the conversion of hydrocarbons to hydrogen and then to ammonia, while capturing the CO2 created during the process. In August, Aramco exported the world’s first shipment of high-grade blue ammonia to Japan for use in zero-carbon power generation, a significant step towards sustainable hydrogen usage. In January 2020, Aramco joined the Hydrogen Council as a steering member. The organization promotes collaboration between governments, industry and investors to provide guidance on accelerating the deployment of hydrogen solutions globally. COVID-19 Update Throughout the COVID-19 pandemic, Aramco has remained committed to the safety of its people, establishing protocols to monitor and limit the spread of the virus. The Company has assisted its staff and communities around the world through measures such as employee resource programs, medical support services and monetary donations. Beyond its own employees and operations, the Company has supported the healthcare sector, supplying ventilators, air purification devices and protective equipment for health practitioners and patients. An employee donations campaign, “Stay Home, Stay Safe,” directed help toward the most vulnerable, with employees’ donations matched 100% by the Company. Aramco’s regional affiliates donated cash and medical supplies to organizations in Asia, Europe and the United States.•
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NEWS FROM THE EIC Aramco signs US$12.4bn infrastructure investment deal
ramco has signed a deal with a consortium led by EIG Global Energy Partners (EIG), one of the world’s leading energy infrastructure investors, to optimise its assets through a leaseand-lease-back agreement involving its stabilised crude oil pipeline network. On closing, Aramco will receive upfront proceeds of around US$12.4bn (£9.02bn) further strengthening its balance sheet through one of the largest energy infrastructure deals globally. The transaction represents a continuation of Aramco’s strategy to unlock the potential of its asset base and maximise value for its shareholders. As part of the transaction, a newly-formed Aramco subsidiary, Aramco Oil Pipelines Company, will lease usage rights in Aramco’s stabilised crude oil pipelines network for a 25-year period. In return, Aramco Oil Pipelines Company will receive a tariff payable by Aramco for the stabilised crude oil that flows through the network, backed by minimum volume commitments. Aramco will hold a 51% majority stake in the new company and the EIG-led consortium will hold a 49% stake. Aramco will continue to retain full ownership and operational control of its stabilised crude oil pipeline network. The transaction will not impose any restrictions on Aramco’s actual crude oil production volumes that are subject to production decisions issued by the Kingdom. •
Gas Power Project in Uzbekistan
CWA Power, a leading developer, investor and operator of power generation and desalinated water plants in 13 countries, has announced the successful financial closure for the development, construction and operation of the 1,500MW Syrdarya Combined Cycle Gas Turbine (CCGT) power plant in Uzbekistan. A syndicate of seven international lenders will provide US$750m senior debt for the US$1bn project. The mandated lead entities – including the European Bank for Reconstruction and Development (EBRD), German Investment Corporation (DEG), Standard Chartered, Natixis, Société Générale, the OPEC Fund for International Development, and the Bank of China – helped structure the project finance debt. The commercial banks are providing funding on the back of a Multilateral Investment Guarantee Agency four-point cover. The project will provide cleaner, more efficient and cost-competitive gas power that can be utilised across industries in Uzbekistan. On completion, it is expected to meet 15% of power demand in Uzbekistan and comprise eight percent of all installed power capacity. •
Petrobras Increases Investments in the North of Brazil
etrobras has signed agreements with BP Energy do Brasil Ltda (BP) to take over BP’s entire stakes in six blocks, located in ultradeep water in northern Brazil, approximately 120km from the state of Amapá, in a high-potential exploratory frontier on the Brazilian equatorial margin. The six blocks in the agreements are: FZA-M-57, FZA-M-59, FZA-M-86, FZA-M-88, FZA-M-125 and FZA-M-127, which were acquired by the consortia in the 11th Bidding Round of Blocks of the National Agency of Petroleum, Natural Gas and Biofuels (ANP), in 2013. Blocks FZA-M-57, FZA-M-86, FZA-M-88, FZA-M-125 and FZA-M-127 are owned by Petrobras (30%), Total (40%) and BP (30%). Petrobras had already signed an agreement to assume the operation and the totality of Total’s stakes in these contracts, still subject to ANP approval, as disclosed to the market on 28 September 2020. The FZA-M-59 block is owned by a consortium of Petrobras, with a 30% stake and operator, and BP (70%). The agreement with BP will allow Petrobras to hold 100% interest in the six blocks. The completion of the transfer is still subject to regulatory approvals. This transaction is in line with the 2021-2025 strategic plan, which will see new exploratory fronts outside the south eastern basins, and is part of the company’s portfolio management process, prioritising investments in world-class assets in deep and ultra-deep waters, aiming to maximise value for its shareholders. •
NEWS - SOUTH AMERICA ANDRITZ Signs Maintenance Contract With UPM for the Paso de Los Toros Mill in Uruguay
nternational technology Group ANDRITZ has received an order from UPM to provide industrial maintenance services for its new mill in the city of Paso de los Toros, Uruguay. The mill will have an annual production capacity of 2.1 million tons of bleached eucalyptus kraft pulp when it starts up in the second half of 2022. The contract period will be 18 months for maintenance pre-engineering and site implementation and three years of operation including the warranty phase. ANDRITZ maintenance services will cover the entire maintenance of the mill process areas and industrial assets once the mill is in operation as well as the pre-engineering and related activities to set up the maintenance services in Paso de los Toros. The Maintenance Performance team at ANDRITZ Uruguay will support UPM to achieve top-class reliability and availability as well as outstanding performance by the mill on a continuous basis. When it goes into operation, the mill will be self-sufficient in energy and generate a surplus of around one TWh of renewable electricity annually – to be supplied to the Uruguayan power grid. The mill is designed to fully meet strict Uruguayan environmental regulations as well as international standards and recommendations for modern mills, including use of the latest and best available proven technology (BAT). In February 2020, ANDRITZ was selected by UPM to supply energy-efficient and environmentally leading equipment and processes for all main process islands in fiber production and chemical recovery for this mill. This order reinforces ANDRITZ’s leading position as a provider of long-term maintenance services for pulp mills in South America. •
ANDRITZ Signs Industrial Maintenance Contract with LD Celulose S.A.
indus ANDRITZ Ltda., part of international technology Group ANDRITZ, has received an order from LD Celulose S.A. to provide industrial maintenance services for their new mill in the city of Indianópolis, Brazil. The contract has a contract term of approximately six years and covers full maintenance of all mill areas. The Sindus ANDRITZ maintenance team will be responsible for millwide maintenance, including 24h management of industrial assets as well as predictive, preventive, and emergency maintenance activities during routine operation and shutdowns. The ANDRITZ maintenance team will work seamlessly with the operating team, providing advanced maintenance technology and methodology together with pulp and paper machinery expertise to assure high levels of plant reliability, availability and efficiency, thus helping the customer to reach a high level of production at a competitive cost. With this contract, the ANDRITZ Maintenance Performance division is consolidating its strong market position for greenfield pulp and paper plants with outsourced maintenance in South America. LD Celulose S.A. is a joint venture between the Austrian company Lenzing and the Brazilian company Duratex, formed to set up one of the largest plants for soluble cellulose in the world. With an investment of 5.2 billion Brazilian reais, the plant is being built in the Triângulo Mineiro, between the municipalities of Indianópolis and Araguari. When it goes into operation in 2022, the plant will produce 500,000 tons of soluble cellulose per year. •
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Disappointed ExxonMobil Forced to Curb Output on Guyana FPSO
il major ExxonMobil has revealed its disappointment with the performance of the Liza Destiny FPSO, operating on the Liza field off Guyana, following technical issues, which forced it to reduce output to a minimum. Offshore Energy has reported on this issue several times since the problems started in January 2021. The technical issue was related to a seal on the gas compressor on the SBM Offshore-owned FPSO Liza Destiny, prompting ExxonMobil to temporarily increase the flare above pilot levels to maintain safe operations. ExxonMobil, SBM Offshore, and MAN Energy Solutions have been working to fix the problem since then. By the end of March, teams of experts were making final preparations for the start-up of the flash gas compressor on the Liza Destiny FPSO, in order to restore the flare to background levels. But the repairs were still not completed by early April. Instead, the team onboard the FPSO initiated a comprehensive three-phase testing programme. ExxonMobil said that the final stage of testing would take place this week after the removal of temporary instrumentation. In an update on Wednesday, ExxonMobil revealed another problem that had come up: “As we conducted the final testing phase of the reinstalled flash gas compressor and other components of the system on the Liza Destiny FPSO, we encountered an additional problem with the discharge silencer”.
A team from SBM Offshore, MAN Energy Solutions, and ExxonMobil are on site to assess repairs, with support from engineering experts in Europe and the USA. The company added it had reduced production to a minimum level that mitigates the formation of hydrates in subsea systems, maintains gas injection and fuel gas to the power generators, and minimizes flare. Relevant government agencies have been notified and ExxonMobil is continuing to work with officials to determine the next best steps. The company further said: “ExxonMobil Guyana is extremely disappointed by the design issues and continued underperformance of this unit and will be working with the equipment manufacturer MAN Energy Solutions and the vessel’s operator SBM to rectify the situation”. “This performance is below ExxonMobil’s global expectations for reliability”, the oil major concluded. The FPSO Liza Destiny started producing oil from the Liza field in December 2019, less than five years after the first discovery of hydrocarbons. The concept design for the Liza Phase 1 development project features the Liza Destiny FPSO moored 190 kilometres offshore Guyana, and four subsea drill centres supporting 17 wells. •
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NEWS - NORTH AMERICA Chevron Reinforces Plan to Deliver Higher Returns
t its annual investor meeting today, Chevron Corporation announced plans to increase return on capital employed and lower carbon intensity to enable superior distributions to shareholders. “Chevron’s message to investors is summarized in four words – higher returns, lower carbon,” said Michael Wirth, Chevron’s chairman and CEO. “We’re building on our track record of capital and cost discipline to deliver higher returns. And we’re taking action to advance a lower carbon future.” Chevron will continue to drive a disciplined capital and cost program to deliver higher returns for shareholders. In line with this objective, the company announced it has: Reaffirmed its 2021-2025 guidance for organic capital and exploratory expenditures of $14 billion to $16 billion. Doubled its initial estimate of Noble synergies to $600 million, which contributes to an expected reduction in 2021 operating expenses of 10% from 2019. The combination of a more capital efficient investment program and lower costs is expected to result in a doubling of the company’s return on capital employed and 10% CAGR of free cash flow by 2025 at $50 Brent. “The path to increase return on capital employed is straightforward – invest in only the highest-return projects and operate cost efficiently,” said Pierre Breber, Chevron’s CFO. “Capital discipline and cost efficiency always matter. We have the portfolio and investments that position us to increase returns and grow free cash flow.” Over the next five years, as capital is expected to decrease for its major expansion in Kazakhstan, the company expects to increase its investment in a number of Chevron’s attractive assets, including its
world class position in the Permian. “Our Permian Basin asset is advantaged relative to others. The longterm outlook is positive and capital efficiency is improving,” said Jay Johnson, executive vice president, Upstream. “We expect to grow production while generating strong free cash each year along the way.” In Kazakhstan, the FGP-WPMP project is 81% complete and remobilization of project staff continues to progress. “We remain focused on sustaining our pandemic mitigation measures and increasing productivity at Tengiz,” Johnson said. “Executing our 2021 work program, amidst the pandemic, will be an important signpost for the project’s budget and schedule.” The company exceeded its 2023 upstream carbon intensity reduction targets three years ahead of schedule and today announced lower 2028 targets and zero routine flaring by 2030. The new targets align with the second stock-take period under the Paris Agreement and include all of Chevron’s production on an equity-basis: 24 kg CO2e / boe for oil and gas GHG intensity; a combined 35% reduction from 2016 3 kg CO2e / boe for overall flaring intensity; 65% lower than 2016 2 kg CO2e / boe for methane intensity; 50% lower than 2016 “Our energy transition strategy is focused on actions that are good for both society and shareholders,” said Bruce Niemeyer, vice president of Strategy & Sustainability, “Achieving our 2028 goals is expected to keep Chevron a top quartile oil and gas producer in terms of carbon intensity.” In addition, the company updated plans to increase renewable energy and carbon offsets and to invest in low-carbon technologies such as hydrogen and carbon capture, utilization and storage. Over the past several weeks, Chevron launched its second Future Energy Fund with an initial commitment of $300 million and announced a new bioenergy partnership in California with Schlumberger and Microsoft, designed to qualify as carbon negative. •
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“We released our third TCFD-aligned climate report today, which details how Chevron plans to deliver long-term value in a lower carbon future,” Wirth said. “We expect to invest more than $3 billion in the coming years to advance our energy transition strategy.” For more information about Chevron’s approach to the energy transition, please see Chevron’s Climate Change Resilience report found here. With its industry leading balance sheet and flexible capital program, Chevron is positioned to reward investors in any environment. At a Brent oil price average of $60 per barrel, the company expects to earn double-digit return on capital and generate cash, above its dividend and capital spending, greater than $25 billion over the next five years. At a Brent oil price average of $40 per barrel over the next 5 years, the company expects its net debt ratio to peak around 35% while sustaining the dividend. “Even through these challenging times, Chevron maintained its financial strength and capital discipline,” Wirth concluded. “Our strategy positions Chevron to return cash to shareholders today and into the future.” •
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Transaction to Combine Husky and Cenovus Closes
usky Energy is pleased to announce the transaction to strategically combine with Cenovus Energy has closed.
The transaction was completed through a definitive arrangement agreement announced on October 25, 2020 under which Cenovus and Husky agreed to combine in an all-stock transaction. Pursuant to the transaction agreement, Husky common shareholders received 0.7845 of a Cenovus common share and 0.0651 of a Cenovus common share purchase warrant in exchange for each Husky common share. In addition, Husky preferred shareholders exchanged each Husky preferred share for one Cenovus preferred share with substantially identical terms.
The combination creates Canada’s third-largest crude oil and natural gas producer, based on total company production, with about 750,000 barrels of oil equivalent per day of low-cost oil and natural gas production. Cenovus is also now the second-largest Canadianbased refiner and upgrader, with total North American upgrading and refining capacity of approximately 660,000 barrels per day (bbls/day). In addition, the company has access to about 265,000 bbls/day of current takeaway capacity from Alberta on existing major pipelines, 305,000 bbls/day of committed capacity on planned pipelines and 16 million barrels of crude oil storage capacity as well as strategic crude-by-rail assets that provide takeaway optionality. •
Cenovus common shares remain listed on the Toronto Stock Exchange (TSX) and New York Stock Exchange (NYSE) under the ticker symbol CVE. The Cenovus warrants have been listed on the Toronto and New York exchanges under the ticker symbols TSX: CVE.WT and NYSE: CVE WS. The Cenovus preferred shares Series 1, Series 2, Series 3, Series 5 and Series 7 have been listed on the TSX under the ticker symbols CVE.PR.A, CVE.PR.B, CVE.PR.C, CVE.PR.E and CVE.PR.G. The Cenovus warrants and Cenovus preferred shares are expected to commence trading on the TSX at the opening of market on January 6, 2021 and the Cenovus warrants are expected to begin trading on the NYSE at the opening of market on January 6, 2021. The Husky common shares and preferred shares are expected to be delisted by the TSX at the close of market on January 5, 2021.
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NEWS - AFRICA Total and forêt Ressources Management to Plant a 40,000-Hectare Forest
otal and Forêt Ressources Management have signed a partnership agreement with the Republic of the Congo to plant a 40,000-hectare forest on the Batéké Plateaux. The new forest will create a carbon sink that will sequester more than 10 million tons of CO2 over 20 years, to be certified in accordance with the Verified Carbon Standard (VCS) and Climate, Community & Biodiversity (CCB) standards. The project, financed by Total, includes agroforestry practices developed with the local communities for agricultural production and sustainable wood energy. By 2040, responsible management through selective cutting (treatment of forests which aims to imitate nature by mixing together several species of different age) will promote the natural regeneration of local species and provide Brazzaville and Kinshasa with lumber and plywood. “With this project on the Batéké Plateaux, Total is committing to the development of natural carbon sinks in Africa. These activities build on the priority initiatives taken by the Group to avoid and reduce emissions, in line with its ambition to get to net zero by 2050. They will also help to showcase the Congo’s natural potential and to extend our long-term partnership with the country, where we have been present for fifty years, “ said Nicolas Terraz, Senior Vice President Africa, Exploration & Production at Total. We want to develop these projects with recognized partners, such as FRM, who have a great deal to teach us, while concerting with relevant regions to anchor our commitment in the long term and contribute to local development,” added Adrien Henry, Vice President Nature Based Solutions at Total. The project is designed to produce multiple social, economic and environmental benefits. The planting of Acacia mangium and auriculiformis trees on sandy plateaux exposed to recurring bushfires will create a forest environment that will ultimately help broaden the ecosystems’ biodiversity. The project will create employment opportunities, with a positive impact on several thousand people. In addition, a local development fund will support health, nutritional and educational initiatives to benefit neighboring villages. “The more than 10 million hectares of land reserves on the Congo’s Batéké Plateaux offer a fantastic way to combat climate change at the global level and a unique opportunity for sustainable socio-economic development in isolated regions of the country,” noted Bernard Cassagne, Chairman and CEO of Forêt Ressources Management. “This ambitious and exemplary project is part of PRONAR, the national afforestation/reforestation program launched in 2011 to expand the country’s forest cover and increase carbon storage capacity, create new wood-based businesses to diversify the national economy, and foster the emergence of a green economy in the Republic of the Congo,” concluded Rosalie Matondo, Minister of the Forest Economy of the Republic of the Congo. •
Pavilion Imports Singapore’s First Carbon-Neutral LNG Cargo
emasek-owned Pavilion Energy said it has imported a carbonneutral LNG cargo into Singapore. The company said it is a milestone first import of the kind for Pavilion Energy and Singapore. Carbon emissions associated with the LNG cargo from well-to-tank including the extraction, production, transportation, and regasification will be offset by retiring a corresponding amount of high-quality carbon credits sourced from its portfolio of carbon offset projects. The carbon credits used for the offset are from Natural Climate Solutions projects certified under the Verified Carbon Standard (VCS) and Climate, Community and Biodiversity Standard (CCB) – Evio Kuinaji Ese’Eja Cuana in Peru and Liangdu Afforestation in China. Both projects are designed for the protection and restoration of forests, and promote co-benefits through supporting local communities and protecting biodiversity. Frédéric Barnaud, Group CEO of Pavilion Energy, said, “This carbon neutral cargo is another important milestone for Pavilion Energy in our ambition to provide cleaner energy and develop our carbon trading activities. Our aim is to support our customers in their transition towards a lower carbon future with solutions to meet their climate targets and potential regulatory requirements.” •
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EXPLORATION & PRODUCTION
Our Hybrid Cable Protection System Is Now Ready for New Offshore Industries VPI’s Cable Protection system, which has been engineered initially for the wind turbine industry, has been developed over the past years by the engineering team into an innovative and multifunctional offshore solution. The cast iron and polyurethane hybrid system is a tailor-made solution for the oil and gas industry. VPI now using our latest experience from the wind turbine industry to help the electrification of other offshore industries.
ith over 60 years of experience in the offshore business, Vos Prodect Innovations (VPI) can be seen as one of the pioneers in the field of cable protection and cable accessories for the telecom, oil and gas, and from this decade the wind turbine industry. Within the industry, VPI has gained a reputation of quality and has been trusted with over 150 projects, supplying VPI’s cable protection systems across the globe. Over the past years, VPI has been established as market leader in the engineering and supply of cable-hang off systems. VPI continuously invent itself based on market demand, new insights, and trends from the offshore industries. Three generations of the cable protection system have already been established and are now ready for the next step: the electrification of oil and gas platforms.
The VPI Cable Protection System consists of two primary products – the VPI CIS (Cast Iron Shell) and VPI HPS (Hybrid Protection Shell). The VPI CIS is utilised for the cable in contact with the seabed and the VPI HPS is utilised for the free span areas leading into the offshore platform. The VPI CIS, also known as articulated pipes, is casted from cast iron half shells whereas the VPI HPS is formed using the cast iron half shells along with an outer polyurethane shell, to provide extra corrosion protection around the free span areas.
“VPI is your preferred partner in the engineering and supply of subsea cable protection systems and cable hang-off systems.’’
The renewed hybrid system reduces installation time by 50% and ensures every cable unharmed and intact on the bottom of the ocean. The conjunction of the polyurethane surface and the cast iron insert provide all the protection when your cable lies on the bottom of the sea. All our products
continuously undergo vigorous quality and conformity checks, and testing is performed extensively. VPI offers preliminary installation support as well as opportunities to attend ‘training days’, to experience first-hand the ease of assembly and installation for the product range.
As the CEO Marc Derks of VPI stated: “Out of experience, I know that you need systems that are easy to install, which saves precious offshore time, or universal systems as we now came up with a self-locking system, so no bolts are needed.” PROTECTION AND STABILISATION SUBSEA CABLES VPI offers a complete system, which includes the Cable Protection System (CPS) and the Hang Off-System (HOS), as a universal package, that has been tested and installed at numerous projects in the middle east. As the CPS serve
to protect and stabilize subsea power cables, the HOS secures the electricity cable during the installation on an offshore platform and securely locks the cable after final installation. Both systems have been tested extensively, and it is a proven solution for offshore projects. Since this is a “one size fits all” system, we can deliver this within 6 weeks. The VPI CPS also provides bend restriction and impact protection. Vos Prodect Innovations, your preferred partner in the electrification of the oil and gas industry. We contribute to a greener world
by investing in a sustainable future. All our systems are certified with the appropriate chemical and mechanical properties which are fully traceable. If you would like to know more about how Vos Prodect Innovations can help your company and its operations, or more about the VPI Cable Protection System, please contact them at: Vos Prodect Innovations B.V. T +31 (0)591 31 56 00 E email@example.com
EXPLORATION & PRODUCTION
We Create the Tools to Get the Job Done - Not Just Report the Problem Together with local and global clients, RoQC aim to strengthen data quality assurance and increase data quality by applying strong domain knowledge and innovative software solutions within Subsurface & Drilling Data Management. The RoQC software suite (RoQC Tools) represents unmatched timesaving and efficiency gains in Data Management. RoQC Tools provide integration, extended and unique functionality and workflows to the Petrel*, Studio*, DELFI*, OSDU*, EDM* and Openworks* subsurface technology environments.
Increased data quality by utilising automatic quality control checks of Well Path data in EDM on transfer to Petrel.
Increased access to data (data liberation and transparency – reducing the dependency of Well Planner to send emails attaching Well Paths outside business hours).
Increased user access (no limitations, unlimited user access).
Reduction of decision risk by having exactly the same data on both systems, distributed immediately when requested.
RoQC LogQA RoQC Sync for Well Planning RoQC Sync enables integration between both Halliburton Landmark´s EDM-EDT and Oliasoft WellDesign, to the geological targets in Petrel. A Drilling Manager in a major O&G company was frustrated by their current Well Planning process. He noticed that after a planning session in Halliburton Landmark’s EDT (Engineers Desktop) the Drilling Engineer used email to share the planned well trajectory with the Geoscientist, who was responsible for the Geomodel used for identifying geological targets. The Geoscientist had to manually load the trajectory data to Petrel and did not have any supportive CRS information, nor the well name or which version it was. Problem statement: Well Engineering is not well integrated with Geology and Geophysics. After multiple emails back and forth the well and trajectory was finally loaded to the G&G interpretation system, Petrel. The whole planning exercise took multiple days and it repeated itself each time a new well trajectory was planned. Today the drilling manager can do more iterations and reduce the planning time just by using RoQC Sync. It simplifies the workflow tremendously and enables a closer integration between Petrel and EDM.
RoQC Sync can be used for the following workflows: •
Sync well, wellbore, trajectory and casing data from EDM to Petrel.
Sync well, wellbore, directional survey, position logs, casing/liner, anti-collision and tool uncertainty factor from EDM to Oliasoft WellDesign.
Sync well, wellbore, directional survey, position logs, casing/liner, anti-collision and tool uncertainty factor from Oliasoft WellDesign to Petrel.
Sync well, wellbore, directional survey, position logs, casing/liner and picks from OpenWorks to Petrel.
Immediate benefits of use: •
Reduction of time spent on data export of Well Paths from EDM (Well Planner).
Reduction of time spent of data import of Well Paths to Petrel (Geoscientist).
Reduction in cycle time for Well Paths revisions (Geoscientist - Well Planner).
Reduction of time spent on finding the most recent Well Paths (Well Planning Team).
Eliminating the chance for errors in data export and data import, human errors (this is done by the application in a strict rule-based process).
Enables ingestion from multiple data sources and performs error detection based on deterministic classification rules, advanced ML Processing Results, Smart Visual Analysis and Bulk Correction Capabilities. A Petrophysicist in a major O&G company was working on a large data set of well logs, stored in LAS format files on disk. The Petrophysicist wanted to populate their current interpretation project with more log data to complete the existing wells and to populate with additional wells and associated log data. The challenge was thousands of LAS files that had to be loaded and verified. They initiated a project to automatically batch load multiple LAS format files to a staging project prior to being distributed to the interpretation project. Based on past experience they knew that they would encounter LAS file duplications, errors and various issues with the curve data stored. In order to improve quality of work, save time for the Petrophysicist, and minimise man hours for Data Management, it was decided to use the RoQC LogQA tool in a data quality verification stage before the batch loading was initiated. RoQC LogQA was used to ingest all the thousands of LAS format files and to automatically perform an advanced ML analysis to classify LAS file errors, to store and display log curve data quality results, and to improve data quality.
The Petrophysicist used the tool to: •
Screen large numbers of files quickly and efficiently, sorting out files that need to be corrected before batch loading.
Provide a quick way to check the actual values of logs, either with statistical analysis (dashboard) or graphical (chart) representation. This way, log channels with wrong values can easily be found, as can curves with only one values, mislabeled curves, curves with no samples, etc.
Correct identified issue(s)
RoQC Tools for Petrel and Studio plug-ins Native plug-ins that truly extends the Data Management footprint in Petrel and Studio. They provide efficient error detection and bulk correction tools for your important data that resides in Petrel projects and Studio repositories. One of our clients wanted to have an overview of all Petrel projects that were stored on their file systems. They also wanted to know the status of each project from a data quality point of view. The purpose for acquiring this information was to gain knowledge of erroneous, faulty and nonstandard data. This was then used as a guide for the data management department to use its resources more efficiently. This client reduced its volumes of Petrel projects by 60% by focusing on; •
Cleaning up and correcting critical errors in projects used for decision making.
Referential data projects.
Archival and deletion of projects that had no or little value in terms of data quality.
The discovery of duplicate projects and duplicate data types within projects reduced file
storage significantly. Today they monitor the Petrel project environment using the Audit Report and Studio Indexer. This gives them insight into all projects and the project’s data quality over time. The RoQC Audit Report runs data quality queries on Petrel projects, Studio Repositories and OpenWorks Projects. Currently, there are 50 different data quality queries used to interrogate a Petrel project. The result is presented in an intuitive user interface with a status bar for each data type and the identified error. This reports not only the errors and potential errors, but also generates metrics – simple data compliance percentages for multiple data types, e.g CRS, Well, Well Logs, GWLs, Well Tops, CheckShots. When run with Studio Indexer, audit report extends the Studio Find/Indexer attributes so that the results of the Audit Report can be stored. With this integration you can monitor the current state of your data in all Petrel projects. With the other RoQC Tools installed you are presented with a contiguous workflow
with direct links to the tools that are used to fix the identified data problems. RoQC Tools KPI Dashboard The KPI Dashboard WebApp presents aggregated information from data quality audits generated by the RoQC Audit Report for Petrel and Studio. A business unit manager in a one of the largest O&G companies in Norway was concerned about the lack of transparency and the level of quality of the company´s subsurface data. The manager wanted to have an overview of the subsurface data that the geoscientists were using in their interpretation environment and not only the number of projects, sizes and users but more importantly the level of quality that existed within these projects. Specific data types that are vital to the geoscientist are monitored. Being able to measure quality on a project level and data type level over time is crucial for increasing quality, reducing uncertainty and improving the decisionmaking process. Defining Key Performance Indicators and presenting results in a Data Quality KPI Dashboard enables transparency, data governance and audit-ability for management. The Audit Report enables data quality interrogation and monitoring in an automated and very efficient way. All results from the quality audits are presented as graphical elements, charts, spider plots, text and numbers, allowing the user to view, drill down, analyse the data and see trends from a subsurface data quality perspective. • If you would like to know more about how RoQC can help your company and its operations, please contact them at: RoQC Data Management AS T: +47 47454650 E: firstname.lastname@example.org W: https://www.roqc.no
* Petrel, Studio, DELFI are the mark of Schlumberger * EDM, EDT, OpenWorks are the mark of Halliburton Landmark
* OSDU is the mark of Open Group * Oliasoft WellDesign is the mark of Oliasoft
EXPLORATION & PRODUCTION
SchuF Worldwide Group SchuF is an industry-renowned valve supplier with over 100 years experience designing and manufacturing application-specific valve solutions. SchuF has developed over 20,000 control valve variations in its hundred-year history. Each has its own specific characteristics tailored to the process control elements that are most important for it – pressure, level, flow or temperature.
chuF has the capability to ship our unique and highly-praised valve solutions worldwide from design and production facilities located in Germany, India, Ireland, Italy, the United Kingdom and the United States, where SchuF´s skilled team of engineers and product specialists design each valve from the ground up to meet specific application requirements and provide optimal service life and performance. As well as a complete range of globe control valve designs, SchuF also supplies a wide range of other bespoke valve types, as well as both pneumatic diaphragm and pneumatic piston spring-return actuators. The SchuF range of Control Valves have been designed to meet the ever increasing demands of modern processing requirements in the Oil & Gas, Power, Petrochemical, Chemical and general industries. SchuF valves include a wide range of trim designs, from simple contoured plugs or single-stage multi-hole cages through to the multi-stage labyrinth disc-stack designs, which will meet the requirements of both standard and critical and demanding severe service applications.
An 8” ASME 600 control valve under pressure test at SchuF’s modern testing facilitates.
SchuF Globe Control Valve Products
SchuF Globe Valves are ideal for severe operating conditions with high flow rates, high pressure or temperature drops, corrosive & erosive substances, vibrations. SchuF has developed specialist solutions to many associated design challenges across numerous globe control valve applications.
ASME B16.5 (Pipe Flanges)
ASME B16.25 (Butt Weld End)
ASME I & VIII
Each design has its own specific characteristics tailored to the process control elements that are most critical.
Bonnet Designs: •
ASME CL150 to ASME CL4500
BS EN 1092-1 PN16 to PN 300
Body Size: • 25 mm to 600 mm • 1 in to 24 in
End Connections: •
Butt weld end
A 2” ASME 600 Cryogenic control valve.
This trim would be used for low pressure drop applications .This is a plug with a profiled face to give the required flow characteristic. Spline Trim This trim would be used for low flow conditions. This trim has a Cv range from 5
A 14” ASME 150 control valve with jacketing.
down to 0.01. Both single and multistep designs are available. Cage Guided Single and Multi-Stage Trim This is a Cage Guided Trim and has low pressure recovery which means it can handle much higher pressure-drops than the Contour Trim before cavitation occurs. The standard trim design ranges from a single-stage cage design, through to a 5-stage design, for higher pressure drops, controlling velocity and noise. Stacker Trim or Multi-Stage Spindle (dirty applications) For the more severe service applications, the Stacker Trim (see below picture), which is a multi-stage labyrinth-type trim design with up to 36 turns (stages of pressure drop), may be required. For those applications with large particles and high pressure drops we supply our multi-stage spindle (see below picture). Body Materials SchuF control valves can be manufactured in most forms of castable alloy, such as; •
Carbon Steel (WCB, WCC, LCC)
Stainless Steel (CF8M, CF3M, etc.)
Chrome Moly (WC6, WC9, C12A)
Duplex St.St. (A995 4A / 5A /6A)
High Nickel - Monel®, Alloy 625
Inconel Alloy 740H (UNS N07740)
Trim Materials Trim material selected will be compatible with the specified body material. In addition to the base trim materials, Gr. 6 Stellite® / Ultimet® overlays and solid tungsten carbide inserts may also be specified in order to prevent erosion damage on contaminated services.
Typical Applications Oil & Gas: CO2 carbon capture flow control,
Trim design for contaminated fluids with solid particles with protective sleeve and bespoke plug design. MOL pump pressure control, MOL Pump minimum flow re-cycle, Overboard dump valve, High-pressure seawater injection control systems, Minimum-flow pump recycle, Separator level control, Compressor recycle / Anti-surge valves, Gas pressure control & Gas blow-down. Power: Boiler feedwater pressure/flow control valve, Condensate minimum-flow recycle, Emergency drain valve, High-pressure steam blowdown, Spray-water control, Steam Turbine Bypass & start-up valves.
Design Integrity •
Clamped cage for positive guiding on severe service applications.
High integrity plug guiding system.
Low emission packings i.e. API 522.
ASME VIII Body/Bonnet bolting.
A Disk Stack Trim (right) and a Silencer (left).
A multi-stage spindle trim for dirty applications.
Quality-Assured Manufacturing •
Rigorously tested to ensure specified performance on site.
Quality assurance systems in accordance with ISO 9001:2015. LRQ4005817
Optional full ISO 15156 / NACE MR-0175 certification.
If you would like to know more about how SchuF can help your company and its operations, please contact them at: SchuF Armaturen und Apparatebau GmbH T: +49 6198 571 100 E: email@example.com W: https://www.schuf.de
innovative valves, precision engineering
16” ASME 600 Control valve with piston actuator and manual handwheel.
EXPLORATION & PRODUCTION
Try Before You Buy – Benefits of Seismic Forward Modelling Mitigating risk is always a focus within our industry but it becomes even more crucial in these times with an ongoing pandemic and ensuing low oil price. Petroleum exploration and production are both enterprises that require considerable budget, and with ever-growing complexity, the risks are many. Applying seismic forward modelling can eliminate guesswork, and ultimately help avoid insomnia when commencing cost and time intensive operations like seismic surveying, processing, interpretation, and ultimately drilling based on potentially equivocal information. In short, performing a modelling study first, is significantly cheaper than failing in the field.
here are different concepts of seismic forward modelling that are tenaciously misunderstood as being competitive when they are complementary. The various applications of the different concepts, and the problems they aim to resolve can be somewhat obscure, and the ranges in cost and efficiency are vast. In practice, the different approaches are intended for different objectives, even though seemingly similar products (like synthetic seismic records) can be generated by all of them.
Below: A single shot gather for similar model and survey, using FD modelling (A), Kirchhoff modelling (B), and ray tracing (C). FD modelling generates most comprehensive results but also is most time consuming. Kirchhoff modelling can be limited to P-P reflections from the target zone and is good for migration and velocity sensitivity tests as diffractions are included. Ray tracing is most efficient and dedicated to event identification, as the part of the wavefield to be modelled can be pre-selected.
To simplify, one can distinguish between two major concepts, i.e., full wavefield modelling and ray tracing. Full wavefield modelling (which often is referred to as FD modelling) is known as the most comprehensive way to simulate seismic data and has been undisputedly successful for decades. Processing tests are among its major applications, as these typically require complete synthetic records, ideally containing primaries, multiples, converted waves, or different types of noise. However, when generating these for field-size surveys, or higher frequency signals, reconstructing the full wavefield can be prohibitively expensive, and remains computationally demanding, even in the era of ever-growing computer clusters. Luckily, the modelling effort can be significantly reduced if only selected parts of the wavefield are required. In such cases, ray tracing (or ray-based modelling) would be a far less expensive and time-consuming approach lowering the threshold for usage. Ray tracing not only has advantages in cost, speed, and flexibility but also provides information that would not (or not as easily) be available from full wavefield modelling. E.g., reflection points are known for all modelled rays, which makes illumination studies a core application. In contrast to just calculating nominal fold, which is fully defined by the survey parameters, ray tracing allows for generating attribute maps right on the target area of interest. This allows for
identifying shadow zones and low-fold areas, doing infill analysis, and estimating the expected signal to noise ratio. In addition, reflection events can be migrated on the fly, quickly simulating expected relative amplitude distribution along a target. Other common mapping attributes are travel time (indicating required listening time), the lateral distance between common mid-point and common reflection point (indicating required migration aperture) and the relationship between offset, incident angle, and azimuth (indicating suitability for dedicated amplitude studies or determining anisotropy from seismic data). In principle, all parameters that are stored along the rays can also be filtered, sub-selected, and mapped, which provides a great deal of flexibility.
Most ray tracing studies are carried out for either survey planning or survey evaluation. Survey planning would focus on finding the required survey parameters to sufficiently illuminate a specified target area or volume of interest. This does not necessarily provide final shot and receiver spacing, but macroscopic parameters like required offset, most efficient survey azimuth, most efficient locations of shots and receivers, and – of course – the required size of the survey, all of which has significant impact on acquisition costs and quality. On the other hand, survey evaluation indicates whether a given survey is fit for purpose or help understanding why it was not, after field operations completed - such as when evaluating multi-client data. “Fit for purpose” in this context means that the survey will result in seismic data that contain all required information to carry out needed analysis. Thus, survey evaluation either intends to ensure that appropriate acquisition parameters were used, or provide guidance for both processing and interpretation – making sure that one is getting the most out of the collected data. This methodology could also be used to determine possible uplift before procuring additional seismic data. Often a point of confusion is the generation of synthetic gathers, which typically is considered a task for full wavefield modelling, but can be based on ray tracing as well. Being aware of the differences between approaches will help to decide which application is best suited for the task at hand. Ray tracing requires to pre-select parts of the wavefield to be modelled (e.g., certain primary reflections, specific multiples, or P-S converted components). It is possible to combine many different parts within a single modelling run. This is the ray tracing advantage – first because it inherently leads to the efficiency of ray-based modelling, secondly because any part of the wavefield that can be separated can also be identified in field data. As such, event identification is a task that ray-based modelling is ideal for, e.g., distinguishing between
primaries and multiples when doing processing tests. Ray tracing could even be required for understanding full wavefield modelling results, which makes both modelling approaches highly complementary. It is also worth pointing out that ray tracing requires slightly different models to work than those required for full wavefield modelling. While the latter can use gridded elastic property fields at various levels of detail, albeit more computer intensive. Ray tracing requires smooth macro models that typically are horizon based. As several ten meters of wavelength are assumed for seismic signals, the smoothness requirement is no principle drawback. However, ray tracing models need to be built carefully, require representation of sharp impedance contrasts through interfaces, and are often optimized for a dedicated task. If both ray tracing and full wavefield modellingare combined in an complementary approach, it typically is recommended to build a ray tracing model first, that later can be easily gridded into elastic property cubes (including attenuation and anisotropy if needed). As ray tracing is so quick, one could be tempted to combine the most important parts of the wavefield to carry out processing tests without spending the time and computer resources on full wavefield modelling. Clearly it is possible to migrate ray-based modelling data, but typically caustics and triplications are not well represented, and amplitudes may be artificially boosted close to critical angles. Depending on the model, migrated ray tracing data may therefore suffer from systematic artefacts that sometimes are tolerable and sometimes not. However, advanced ray modelling packages have managed to overcome this limitation by way of Kirchhoff modelling, intended to combine the best of both worlds. Kirchhoff modelling is typically not applied to a full section but rather a selected reservoir model at depth, and
Below: Comparison between 1D convolution and 3D convolution as based on the same wavelet and reflectivity grid. 3D convolution takes both illumination and resolution into account. The 3D convolution operator is generated from overburden, survey and wavelet using ray-based modelling. It is also referred to as a point-spread function, providing a direct measure of both lateral and vertical resolution.
is often limited to primary P-wave reflections for simplicity and efficiency. As such, the process is quicker than full wavefield modelling but focusses on ray-based generation of diffractions that later can be migrated. Typical applications include velocity sensitivity tests, as seismic migration – like pre-stack modelling – requires a velocity field. Using the same velocity field that initially was used for generating pre-stack data would provide a perfectly migrated image. However, using deviations from the “perfect” model for migrating the same pre-stack data will indicate how velocity perturbations affect the final image. Kirchhoff modelling therefore is a powerful tool for evaluating velocity. Similar approaches are used for doing even quicker simulations of depth migrated sections. Ray-based modelling can simulate point-spread functions that are subsequently used as 3D convolution wavelets, integrating both illumination and resolution effects. That way, classic seismic processing is completely avoided, as depth migrated sections can be directly estimated from a given reservoir model. Naturally, this cannot entirely replace full wavefield modelling and imaging but is useful in cases that require many different seismic simulations within a short timeframe. Typical applications would be resolution studies using the point spread function, and time-lapse feasibility modelling, where the focus is on production related changes between a base case and a monitor case, where processing effects are considered static between the different time steps. In summary, before investing in seismic operations that are both time consuming and costly it could be pertinent to investigate the potential of forward modeling. Furthermore, full wavefield modelling although most comprehensive is also the most expensive and time consuming. Ray based methods have a much lower threshold precipitating its use in a range of applications. Depending on the task at hand, ray-based methods may in many cases provide equally useful and much more efficient alternative. • NORSAR Innovation T: +47 63 80 59 00 E: firstname.lastname@example.org W: https://www.norsarinnovation.com
EXPLORATION & PRODUCTION
Significant Oil Discovery Close to the Fram Field in the North Sea Equinor and partners Vår Energi, Idemitsu Petroleum and Neptune Energy have made the biggest discovery so far this year on the Norwegian continental shelf (NCS). Preliminary estimates place the size of the discovery between 12 and 19 million standard cubic metres of recoverable oil equivalent, corresponding to 75-120 million barrels of recoverable oil equivalent. “The discovery revitalises one of the most mature areas on the NCS. With discoveries in four of four prospects in the Fram area during the past 18 months, we have proven volumes that in total will create considerable value for society,” says Nick Ashton, Equinor’s senior vice president for exploration in Norway.
xploration wells 31/2-22 S and 31/2-22 A in the Blasto prospect of production licences 090, 090 I and 090 E were drilled about 3 kilometres southwest of the Fram field, 11 kilometres northwest of the Troll field and 120 kilometres northwest of Bergen. Based on the quality of the resources and the proximity to existing infrastructure the discoveries can be developed and produced in line with Equinor’s climate goals. The company’s ambition is to reduce greenhouse gas emissions from operated fields and onshore plants in Norway by 40% by 2030, compared to 2018. “Equinor is already an industry leader in lowcarbon production. The discoveries in the Fram area will help us reach our goal of a further 40% reduction by 2030 while maintaining the current production level,” says Ashton. Exploration well 31/2-22 S struck a total oil column of around 30 metres in the upper part of the Sognefjord formation and an oil column of around 50 metres in the lower part of the Sognefjord formation. The oil-water contacts were proven at 1860 and 1960 metres respectively.
Exploration well 31/2-22 A struck high-quality sandstone in the Sognefjord formation, but the reservoir is filled with water and the well is classified as dry. Regarding the discovery to be commercially viable, the licensees will consider tying it to other discoveries and existing infrastructure in the area. The wells were not formation tested, but extensive data acquisition and sampling have been carried out. These are the first and second exploration wells in production licence 090 I. The licence was awarded in the 2017 awards in predefined areas (APA 2017) licencing round. Well 31/2-22 S was drilled to a vertical depth of 2282 metres below sea level and a measured depth of 2379 metres below sea level. Well 31/2-22 A was drilled to a vertical depth of 2035 metres below sea level and a measured depth of 2207 metres below sea level. Water depth in the area is 349 metres. The wells have been permanently plugged and abandoned. The wells were drilled by the West Hercules drilling rig, which is proceeding to drill exploration 34/6-5 S in production licence 554 in the northern North Sea sector. •
EXPLORATION & PRODUCTION
Highlighting a Cost Efficient EOR Technique Reducing the carbon footprint and GHG emission of oil production with a simple approach using polymer flooding and modular skids The Covid-19 crisis has led to an unprecedented situation in the oil industry, with severe oil price depreciation due to sudden demand reduction and failed production cut agreements. On top of that, all operating companies have subscribed to net zero and are managing energy and CO2 reduction. So, oil companies have been forced to reduce their budgets, and oil exploration has been cut or reduced. Soon, more oil production and reserves bookings will be required from the existing wells.
n this context, quickly and easily maximizing production and of existing assets in a costefficient way is paramount. Polymer flooding can enable increasing the recovery factor (RF) over water flooding by up to 20% at only 3 – 6 $/bbl extra. At the same time, societal pressure is growing for to reach net zero production emission target by 2050. Polymer flooding can enable meeting that target by reducing CO2 emissions by 3 – 6 time due to a reduction in water-cut in the same order of magnitude. Currently, 60% of global brown field production is from water injection, delivering recovery factors from 20 to 40% depending. Polymer flooding is proven from more than 300 projects worldwide. These projects recover more oil, in a shorter time-frame and at a reduced environmental footprint compared to waterflooding projects. This EOR technique has been economically successful in India (Mangala), Canada (Pelican lake, Suffield, Medecine Hat,), Argentina (Diadema, Grimbeek), China (Daqing, Shengli, Dagang, etc), and the Middle East and Eastern Europe (Patos Marinza, Marmul, Kazakhstan fields). In the 1990’s, SNF partnered with China in the Daqing EOR project. There, SNF built and commissioned the worlds’s first captive polymer production plant for polymer EOR. Since then,
many EOR projects have been documented. These projects have shown that polymer flooding increases RF by 15 - 20%[ref] over water flooding. Furthermore, these projects report an average utility factor (UF) of 1,7 kg of polymer per incremental barrel of oil, or 80 tons of additional oil per ton of polymer injected. This UF is attractive considering that polymer costs less than 2.5 $/kg. Thus, polymer flooding can generate significant additional short-term production with a low incremental OPEX of 2.5 to 5 $/bbl. In addition, SNF has developed surface facilities which are integrated into sea containers, easily transported to onshore or offshore sites and connected to existing water lines. This approach accelerates polymer injection. In turn, this modular approach offers operators flexibility by enabling incremental deployment from pilot to potential full field development, as well as simple facility relocation to another part of the field, if needed. Thus, CAPEX is phased with the different project phases, helping to maximize profits. In addition, rental options are possible. Maintaining OPEX and CAPEX at 3 to 6 $/bbl allows polymer flooding to be economically attractive, even in a low oil price environment, while adding proven reserves
and accelerating oil recovery. Polymer EOR has additional benefits: it also reduces water use and lowers GHG emissions. Operators report significant water cut (WC) reduction with increased oil production. The literature shows that mature fields can demonstrate a WC reduction from 98% to 90% at constant production rate. For less mature fields, WC reduction from 65% to 40% is reported. Also, due to acceleration, several years of water and related energy consumption are avoided. Ultimately, water production can be reduced by a 3 to 6 times with a proportional CO2/bbl emission reduction. Thus, the carbon intensity of crude oil is reduced from pumping and lifting savings, since less fluid volume is injected generating less produced water. Unquantified additional savings have been observed from downhole drag reduction due to friction reduction from the polymer in the wellbore. New oil and water separation techniques also enable reduced fresh polymer consumption by up to 45% after polymer breakthrough by recycling the produced polymer. Furthermore, oil field chemical consumption can also be reduced, immediately resulting in a chemical cost savings and GHG reduction associated with the production of those chemicals. In these difficult times, this is the opportunity to innovate. Deployment of polymer flooding is a proven cost-effective approach to maximize productivity of your current assets while preserving our environment by reducing water use and cutting energy demand and GHG emissions. SNF is the global leader for EOR polymer manufacturing with more than 20 local production plants near oil production areas combined with a unique logistic and engineering service to bring the polymer from the plant to the reservoir in a simple way. • SNF www.snf.com email@example.com
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EXPLORATION & PRODUCTION
Disruptive Times in Maritime Training By Peter Björkroth, Senior Lecturer, Novia UAS, Technology and Seafaring, Aboa Mare.
Disruptive events bring possibilities with them. It is up to us all to turn Threats in a SWOT analysis into Opportunities. There are many sad examples in history when opportunity knocked, but no one answered the door. Kodak is of course one infamous example. My favorite Kodak-moment though, is the physician Ignaz Semmelweis (1818 – 1865). Semmelweis introduced the, at the time, revolutionary and outrageous idea that doctors should wash their hands. Between doing autopsies and assisting women give birth! Semmelweis’ idea was tested, proven to be effective, but nevertheless rejected! Semmelweis died before his idea was accepted by the larger medical community.
During the 2020’s no one would protest against washing their hands, but there might have been other solutions to problems that have been rejected. No doubt the offshore industry has struggled with a new kind of challenges. Just like ship crews all around the globe, the platforms have struggled with the logistics of crew changes. Passing borders, different regulations in different areas and lack of flights have no doubt called for creativity among the crewing departments – not all have been able to meet the challenge. Albeit the grade of seriousness is lower, also training facilities, such as Aboa Mare, have faced challenges during the last year. How have we then tried to turn the threat into an opportunity? How have we been able to take advantage of the disruption at hand? When physical contact is to be avoided, thoughts automatically go to remote operations, e-learning, virtual reality and so on. We have all seen futuristic images of people wearing helmets that provide the virtual environment and authentic experience for the person wearing it. No doubt such a helmet can create an environment that gives the person a learning experience that is as close to reality as possible – the person is totally immersed in the virtual setting, for example on a navigating bridge. In the future participation in this kind of fullyimmersive simulations at Aboa Mare will maybe be done from homes or even vessels, by seafarers who are wearing virtual reality helmets connected to the Aboa Mare simulator environment. Maneuvering will be conducted with for example a virtual tablet. VR-helmets might be the goal, but we are not there yet. So far, we have worked with what is plausible for the time being. The pandemic has forced people entering a country to stay in quarantine. Aboa Mare, together with ABB Marine & Ports, succeeded in making the most of that time. Remote simulations were used to enable efficient usage of the time in quarantine. The course participants could e.g. familiarize themselves with, and practice using, the equipment relevant for vessels operating with Azipod® propulsion, already before coming to the simulation center. For example, virtual
Sebastian Roschier, Navigational Specialist at ABB doing a maneuvering test during an ABB Azipod® propulsion H883 course.
levers as well as ECDIS-displays and visuals were streamed from Aboa Mare to the hotels. The familiarization with the equipment is a must and has so far been done on site. Remote simulations thus reduce the time course participants must be present in the simulation center, and can reduce time spent away from either home or vessel. Shorter time away reduces the costs for training.
propulsion vessel operation in ice - course, and finally the basic level Polar Code training could all be certified to successful participants. By staying a few extra days, also the Polar Code Advanced could have been completed, adding a fourth competence to the same training period. Further onboard experience is of course needed for the Advanced Polar Code certificate.
The varying needs of our customers both require and enable different ways of realizing training. In the above-mentioned example with “training at the hotel”, three courses – all important for the customer – were realized during one two-week period, only partly at the training center. The H883-Azipod®propulsion vessel operation course, the H938- Azipod®
Another smaller-scale example of using VR is the virtual emergency steering simulator. The bridge team can be navigating on a bridge simulator, but the actual steering is conducted by a person operating the simulated, or virtual, emergency steering. The person operating the steering uses virtual instruments and tools, such as pliers, to carry out the orders from the
VR emergency steering (BRM & ERM course).
bridge. Eventually the steering will be possible to conduct from outside the center, also fully immersed and not only with PCs like today. The emergency steering room can be at Aboa Mare or maybe even onboard! The benefit of this may seem negligible, but it is nevertheless important to practice these procedures. With more functions like the one in the example possible to be remotely simulated, in an environment as close to the real experience as possible, the list of people who needs to gather in the same facilities at the same time gets shorter. All small improvements add to cost-efficient and efficient training. These developments also support maritime
training on the whole. In Finland maritime students can get a portion of their onboard training covered by simulations. Aboa Mare can also provide simulator training that gives the 30 required days onboard-experience for the Advanced IGF certificate. As the only provider in the world. Some might argue that simulations are not “the real thing”, but it is also a fact that an OOW gets to experience a lot more e.g. traffic situations in a planned simulated 1-hour scenario than during a 4-hour watch on for example the Atlantic Ocean. And it is not possible to provide navigating in ice, in real ice, for everyone who needs the experience.
Port manoeuvre during an ABB Azipod® propulsion H938 course.
Simulations are a safe and efficient alternative. At Aboa Mare we all feel that virtually anything is possible in virtual training (pun intended). We can not do everything at the same time, but every journey begins with a single … simulation? The journey has begun and Aboa Mare wishes you warmly welcome to icy conditions and other challenging maritime experiences! Aboa Mare - Maritime Academy and Training Center www.aboamare.fi email@example.com
EXPLORATION & PRODUCTION
High-Quality Vibrocoring Systems 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.
ur 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. The SEAS Piston Coring System has proved reliable in collecting quality core samples to
compliment pipeline and cable route surveys. The system when combined with SEAS Vibrocoring equipment provided core sampling options for a variety of sediment types 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 costeffective manner. The MPS3000 system can collect 10 core samples from one deployment off the vessel. 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: firstname.lastname@example.org or visit our website: www.seasoffshore.com
ABN 53 137 008 247 Unit 4, 6 Hulberts Road, Toormina NSW 2452, Australia
SEAS Offshore Pty Ltd is a leading provider of state-of-the-art sediment sampling equipment. The company is based in Coffs Harbour, Australia and services clients worldwide. Our vibrocoring equipment was originally developed in the early 1980’s and has been further developed over the years to provide a lightweight, portable and extremely reliable sediment sampling solutions. Solutions for any sediment sampling project can be catered for by the experienced SEAS team. At SEAS we understand that every sampling job is different, so we work with our clients to design each program for best effect to meet our clients’ specific requirements.
Our lightweight and portable equipment enables us to sample in areas that are inaccessible to many other systems, such as shallow lakes, tidal estuaries and near-shore coastal environments. The various SEAS VC models allow sediment types in to be reliably sampled in environments which can be difficult or prohibitive for outer vibrocoring equipment.
The VC700 4.4Kw system combined with variable frequency control allows the operator to adjust the vibration frequency to suit the sediment type. The ability to vary the frequency provides a range of 5kN – 60kN drive force. In a unit as compact as the VC 700 this is a leader in the field. The VC700 was recently used with reliable success in sampling the dense iron sands offshore northern Luzon, Philippines. The project delivered over 600 core samples to six meters in length with high recovery rates. SEAS also manufacture and operates a number of sediment sampling systems. Box Core systems, Piston core systems and Grab samplers.
The SEAS Large Box core system provides a box sample 50cm x 50cm x 50cm (0.125m³). The Box core samples provide large undisturbed sediment samples suitable for environmental studies, macro benthic fauna analysis and geotechnical analysis. Our deep water vibrocore system pushes the limits of vibrocore sampling to 3000m, well beyond the capabilities of most of our competitors. When coupled with our multicore MPS3000 platform our deep water VC2000T provides a unique opportunity to acquire samples in an efficient and cost-effective manner. The MPS3000 system can collect 10 core samples from one deployment off the vessel. This capability considerably reduces winch time required to and from the sea floor making the equipment very cost effective. The MPS3000 system can host numerous additional sensors to meet client specifications. With real-time video feedback the coring procedure can be closely monitored. The cameras fitted with pan & tilt function can be turned outward to monitor the seafloor surface environment enabling valuable benthic habitat assessment. The MPS3000 has both low light black & white cameras in addition to a colour focus and zoom camera with additional lighting. For further information regarding any of SEAS equipment please contact: email@example.com or visit our website: www.seasoffshore.com
Maersk Drilling Confirms Long-Term Drillship Contract Based on the previously announced Conditional Letter of Award, Maersk Drilling has been awarded a contract from Tullow Ghana Ltd. for the provision of the ultra-deepwater drillship Maersk Venturer and additional services for a development drilling campaign at the TEN and Jubilee fields offshore Ghana. The contract commenced in April 2021, with an estimated duration of around four years. The estimated contract value is approximately USD 370m, excluding additional services provided and potential performance bonuses.
he contract has a progressive day rate structure for the full duration. However, the contract contains certain provisions which, after an initial period of 18 months, permit a shift to a market-linked day rate structure and early termination for convenience by Tullow Ghana Ltd. “We’re thrilled to have firmed up this longterm contract for Maersk Venturer, bringing it back to a basin where the rig and its crew previously performed stable and highly efficient operations for Tullow. We’re delighted to have started up operations again in Ghana where we will continue our work with the Ghanaian community, our partner Rigworld and other local suppliers who have contributed to our successful operations in the region,” says CEO Jørn Madsen of Maersk Drilling. Maersk Venturer is a high-specification 7th generation drillship which was delivered in 2014. It is currently operating at the Jubilee field offshore Ghana. • Maersk Drilling awarded four-well drillship contract with Shell in Malaysia Maersk Drilling has secured a contract with Shell Malaysia for the 7th generation drillship Maersk Viking to drill four development wells at the Gumusut-Kakap project offshore Malaysia. The contract is expected to commence in December
2021, with an estimated duration of 150 days. The firm contract value is approximately USD 34m, including a mobilisation fee. The contract includes five additional onewell options for work offshore Malaysia, the Philippines, and Brunei Darussalam. “We’re delighted to confirm that Maersk Viking will return to Shell Malaysia for work on the Gumusut-Kakap project. In this way, we will be able to build further on the great collaboration that the rig’s highly capable crew has established during its current campaign with Brunei Shell Petroleum,” says COO
Morten Kelstrup of Maersk Drilling. Maersk Viking is a high-spec ultra-deepwater drillship which was delivered in 2013. It is currently operating offshore Brunei Darussalam. • Maersk Drilling Contract
Maersk Reacher is contracted under the terms of the frame agreement that Maersk Drilling and Aker BP entered into in 2017. Maersk Reacher will be reactivated with reduced drilling equipment and a specific focus on delivering the most efficient well intervention and stimulation set-up including a reduced crew level compared to standard drilling mode. “We’re delighted to get this contract which will see Maersk Reacher return to Valhall where it was last in service as an accommodation rig. This new contract to assist with well intervention, stimulation and accommodation will not utilise the full drilling capabilities of the rig, but we’re confident that we can build on our experience with the Aker BP Jackup Alliance and work to deliver increased efficiency also in this context,” says COO Morten Kelstrup of Maersk Drilling. •
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EXPLORATION & PRODUCTION
Robots Could Replace Hundreds of Thousands of Oil and Gas Jobs - Rystad Even with the Covid-19 downturn finally past us, operators will have to continue exploring new avenues for cost reductions to be better equipped to withstand future market declines. In a report that looked into the adoption of robotics across the petroleum industry, Rystad Energy found that existing solutions could replace hundreds of thousands of oil and gas jobs globally and reduce drilling labor costs by several billion dollars by 2030, if there is an industry push for such a transition.
ne of the segments with much to gain from the adoption of robotics is drilling, as it is highly cost-intensive and involves carrying out dangerous tasks in challenging environments. Robotic solutions have already been introduced successfully in drilling operations, with companies such as Nabors at the development forefront. Applying current supplier specs, which suggest that robotic drilling systems can potentially reduce the number of roughnecks required on a drilling rig by 20% to 30%, Rystad Energy estimates that such a reduction in both offshore and onshore drilling crews can bring cost savings of more than $7 billion in wages in the US alone, based on present wage levels. Inspection, maintenance and repair (IMR) operations are also ideal for robotic operations and is the segment where adoption of robotics has gained the most traction among operators in recent years. This has so far mainly been limited to subsea IMR activities, but we are now starting to see IMR robotics solutions also being used for topsides. Overall, Rystad Energy believes that at least 20% of the jobs in segments such as drilling, operational support, and maintenance could in theory get automated in the next 10 years. Looking at the current staffing headcount of some key oil and gas producing countries, the US could reduce its staffing needs by over 140,000 employees and Russia by over 200,000 personnel. Canada, the UK, and Norway could shed between 20,000 and 30,000 jobs each. “Despite the huge potential of robotics, operators should be aware that these savings will be partially offset by the considerable investments required for the adoption of these solutions, which may vary depending on the cost structure and whether the robots are owned or leased,” says Sumit Yadav, energy service analyst at Rystad Energy. Nevertheless, the next generation of robotics solutions is already emerging within subsea IMR in the form of perpetually underwater robotics solutions that offer significantly lower costs and better reach than a conventional remotely operated vehicle (ROV). While a conventional
ROV needs to be sent down from the surface, these new systems can stay underwater permanently and easily access places that are difficult to reach for conventional ROVs, irrespective of the weather conditions. A notable example is the self-propelled robotics arms unit Eelume, developed by Kongsberg Maritime and used by Norwegian operator Equinor. Owing to their snake-like design, the robotic arms have the flexibility and agility to transit over long distances and carry out subsea IMR activities such as visual inspection, cleaning, and operating valves and chokes in highly confined spaces. Not all digitization and robotization translates into a reduction in manpower, however. For instance, Transocean has introduced wearable safety technology that alarms a crew member if they come too close to the drilling equipment. If the crew member still doesn’t maintain a safe distance, the alarm will shut down the equipment. Similarly, Diamond Offshore has launched the industry’s first cybernetic blow-out preventer (BOP) service. The service named Sim-Stack makes a virtual replica of the BOP hydraulically and electrically to assess its overall health and regulatory compliance. The system provides much faster information on
component failures, reducing downtime and improving safety, and can also be used to train personnel, according to the rig operator. While the emergence of robotics in the oil and gas industry seems inevitable, we believe that full-scale adoption is still a few years away as the long-term reliability of robotics in complex 3D environments such as those found on offshore platforms is yet to be tested. Another challenge in the implementation of robotics is limited communication capabilities, especially between robotics units. If robots are to fully replace humans, it is imperative that these systems communicate seamlessly to unlock true value. The implementation of such communication systems is both complex and costly. Finally, job cuts due to robotics are likely to be met with some resistance from labor organizations, and robotized work processes may also need to pass regulatory hurdles as authorities seek to ensure that the operational changes brought on by the new technology satisfy safety and environmental standards. For more analysis, insights and reports, clients and non-clients can apply for access to Rystad Energy’s Free Solutions and get a taste of our data and analytics universe. • https://www.rystadenergy.com
INTERNATIONAL SCIENTIFIC & EXPERT
MEETING OF GAS PROFESSIONALS OPATIJA, CROATIA, 16 - 18 JUNE 2021
JOIN THE LARGEST INTERNATIONAL GAS CONFERENCE & EXHIBITION IN SOUTHEAST EUROPE! 60 speakers/hundreds of high ranking gas and energy experts, managers and decision makers /20+ partners / 30+ exhibitors
„Natural Gas – its Role in the Energy Mix and Contribution to the Energy Transition“
2. Introductory Presentations and Panel Discussion: • „Natural Gas Exploration and Production Projects“ • „Current Situation and Trends on the Natural Gas Market and Future Expectations“ • „Development of Sustainable Transport Powered by CNG, LNG and LPG“ 3. Development of Strategic Gas Infrastructure in Europe for Secure Gas Supply 4. Smart Technologies, Innovations and Transfer of Technologies
7. Issues Related to the Transport, Distribution, Storage and Consumption of Natural Gas in Terms of Efficiency and Safety 8. Legislation, Technical Regulations, Rules of the Profession and Consumer Rights in the Gas Sector 9. Poster Session: Issues Related to the Gas and Energy Industry Confirmed key speakers:
5. Development Potentials of LNG Terminals and their Role in the Future European Infrastructure
Andrea Stegher, IGU Vice President, elected as IGU President for 2025-2028
6. The Contribution of Biogas for the Decarbonisation of the Economy
Ariel Cohen, PhD, Senior Felow at Atlantic Council, Senior Felow at ITIC
Pre-event matchmaking tools and on-site social events will help delegates to network and meet international delegates and key speakers. CHECK OUT THE CUTTING EDGE PROGRAM: https://susret.hsup.hr/en/ programme/
REGISTER HERE: https://susret.hsup.hr/en/ registration-of-participants/
Croatian Gas Center Ltd., Heinzelova 9/II, 10000 Zagreb, Croatia phone: +385 (0)1 6189 590, e-mail: firstname.lastname@example.org
MIDSTREAM & PIPELINES
NH Towage - A Towing Company Working Across Europe The key to success of the Danish family-owned company are towages of objects
Complicated operations. Over the years NH Towage has been involved with the towages of ships from Black Sea region to Scandinavia for the past 15 years and have during these years performed more than fifty tows with success. The duration of the voyages is approximately 20 to 22 days and requires an excellent crew. Niels Henriksen, Master Mariner, Owner and CEO of NH Towage adds, “In fact, our 42 ts BP Hunter just left Turkey with a unfinished ship for a Norwegian shipyard and are expected in Norway Mid May. The ship will be made ready for delivery to the client at the shipyard taking a good part of a year”.
nother recent job was the “Raouff R” being towed from Beirut to a scrap yard in Turkey. The “Raouff R” was damaged during the explosion in Beirut and as a part of the clean up process in Beirut a towage was needed to the nearest scrap yard being in Turkey. NH Towage has also performed many quite challenging tows with ships to be scrapped in, for example, Denmark and Turkey, which are the leading countries with scrap facilities. The ship has been towed from distances such as Rio in South America, and from Greenland, to be towed over the Atlantic to Europe. Niels Henriksen explains “We are pleased to assist with these often-challenging towages and hold the expertise though more than 30 years for carrying them out successfully. It is also very important from an environmental perspective that old, discarded ships can be scrapped and eventually made into new ships” All kinds of offshore works Another part of the business is to assist with surveys in connection with pre-planning of
offshore windmill parks as well as bridge projects. The smaller tugs in the fleet with low draft, crane and space for survey equipment
and accommodation for the technician are very suitable for these types of jobs both locally and abroad. One of the latest jobs, among others, survey for the new Fehmarn Bridge as well as pre-surveys for locations for offshore windmill parks in the Baltic Sea. Working abroad is a big part of the business. The service area of the tugs is mostly Europe, however the company have also performed many towages crossing the polar circle including trips to Canada, Greenland, Svalbard. We have gone as far as pipe laying projects in Yara Sea and towage to and from Novy Port in Northern Russia. Passing the polar circle around the year requires a lot of knowledge and familiarization with the various weather situations occurring during these voyages. In recent jobs, there have been quite a few towages of fishing vessels from Newfoundland, Greenland, and Iceland to Spain. The trawlers will be upgraded in Spain and after an extensive makeover will be part of the fishing industry in Africa. Niels Henriksen adds “An excellent example that scrapping of vessels is not the only option, but also older
vessels can be upgraded and get a second era” The family-owned firm have also worked on some of the biggest and most challenging construction projects such as the Great Belt Bridge connecting the islands of Zealand and Funen, the 16 km bridge from Denmark to Sweden and recently the Crown Princess Mary Bridge connecting important infrastructure north of Copenhagen. But also working outside Denmark is a large part of the business with large scale projects in Germany, United Kingdom and as far away as Yara Sea, Northern Russia where the tugs worked with installation of a gas pipeline. A long way with plastic pipes Another special trade is towage of large pipes to various destinations in both Europe, Africa and
also as far as the Caribbean Sea. The pipes are made of PPE and with a diameter up to 2m and with a length of up to a kilometer, they require much attention by the crew during the voyage with constant focus on waves and wind as they are not so easily towed. The latest a towage of 6 pipes with length of 800 m from Norway to Tunisia was performed with delivery by New Years Eve. Strong traditional values NH Towage upholds traditional Danish values such as delivering on time and at the right price and with a great success. Mr. Henriksen, being a master mariner himself, explains “We are determined to innovate when required and we can change or adapt quickly to any situation needed”.
As well as bridges, NH Towage also works on the assembly of wind turbines, piers, jetties, and harbour extensions. Other services they offer include heavy lifting transportation, assisting dredgers, cable-laying operations and providing support to diving teams, and always with an emphasis on quality, safety, and reliability. And with a broad base of partner companies on board, NH Towage can also deliver on large-scale projects that exceed their own capacity of tugboats. Henriksen enthuses: “We are proud of flying the Danish flag and all our vessels and equipment is classed with DNV – a highly recommended class society within the towing industry. My father founded the company in 1977, and I have been on board since 1986.” About: NH Towage NH Towage is based in Svendborg, Denmark and specialises in short and long-distance towage as well as all kinds of offshore building projects including towages of barges, pipes, surveys and works on the assembly of wind turbines, piers, jetties and harbour extensions. Other services they offer include heavy lifting transportation, assisting dredgers, cablelaying operations and providing support to diving teams. and always with an emphasis on quality, safety, and reliability. The fleet includes six tugboats, three barges and one crew transfer vessel – all with Danish Flags and classed in DNV. If you would like to know more about how NH Towage can help your company and its operations, please contact them at: NH Towage T: +45 62222911 E: email@example.com W: https://www.nhtowage.dk
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.
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: firstname.lastname@example.org W: www.samplinggauges.com
MIDSTREAM & PIPELINES
An Essential Worldwide Network OGI sits down with Marc de Waele, Managing Director of LPL Projects + Logistics GmbH, to get some expert analysis about the ins and outs of logistical challenges in the oil and gas industry. LPL are experts at moving assets used in oil and gas operations around the world. With many projects, building materials or vital assets to an operation have to not only be delivered in a timely fashion, but in many instances, “just in time” to avoid downtime or make sure the recipients are ready to receive such a large order. Mr de Waele explains how this all works below.
OGI: Could you start by explaining LPL Projects & Logistics’ 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? de Waele: LPL Projects + Logistics GmbH is an international logistics provider, specialized in projects for the complete logistics of industrial plants. In this field of business we are active for more than 50 years. The roots of the company going back to the foundation in 1872 in Germany. Historically, we were responsible for the complete logistics chain for many plants in the oil and gas industry. We are active with our own international offices and a wide partner network which we build up during the last decades. All our offices and partners have a wide knowledge of the products in the oil and gas Industry. Nowadays we are active in more than 70 countries worldwide to serve the needs of our valued clients. OGI: Could you talk a bit about the work that you do in the oil and gas industry? de Waele: Beside complete refineries, gas fired power plants and other chemical plants we are partners for many suppliers in the oil and gas industry, such as suppliers of pipes, oil racks etc. For example, LPL Spain had been entrusted
with the transport of several offshore anchor piles from Tarragona (Spain) to Mobile, Alabama. The piles are destined for an offshore oilfield project in the Gulf of Mexico.
Marc de Waele, Managing Director of LPL Projects + Logistics GmbH
It is a deep-water field in a water depth ranging from approximately 1,370m - 2,200m. New oil reserves have been discovered within an existing field, but these are outside the reach of the existing drilling rig and therefore new subsea and surface facilities are required to exploit the new reserves. The EPC contractor received the piles for further works at their terminal in Theodore (Mobile), AL. The units had to be transported within a very tight time frame and had to arrive “just in time” for further modifications before final installation in the Gulf of Mexico. The shipment was not only approved by our customer being the manufacturer of the anchor piles but also by the receivers as well as the end customer through their appointed Marine Warranty Surveyors. The overall operation was carefully planned in advance and executed by our own staff together with the Supercargo that was appointed by the shipping line. OGI: What is the scope of your services? de Waele: We are organizing the complete scope of logistics services from the supplier(s) premises up to the final destination. This includes all local services in the country of
origin and country of destination, like assistance for export declaration, packing, transports to the (air)port and handling at the (air)port. We are evaluating the best possibility in regard to prices and/or timeline to serve the needs of our clients. We treat ourselves as partners and not only suppliers. In addition to the “pure transport handling” we are supporting our clients already at the calculation stage with information and possible savings in the complete chain.
With our own technical department and experienced staff, we are organizing route surveys in many countries of destination. This surveys include the possibilities of transport, but also contact to the authorities to check the way of applications and national laws and regulations. OGI: How important is it to have logistics partner with a worldwide network and why is it so important? de Waele: A worldwide network in our field of business is essential. Mainly we are in charge for the complete scope of services, including local transports and other services like customs clearance or setting heavy lift items onto foundation. For this worldwide service, partners or own office with knowledge in the field of Heavy Lift operations are needed. With most of our partners we have a longlasting and trustful cooperation for all project logistic services. In addition, our own international staff is supervising critical cargo (in regards to weight, sensitivity or value) the intersections together with our partners. OGI: Could you talk a bit about the work you do with breakbulk cargo, as it pertains to the marine, shipping, oil and gas industries? de Waele: Besides the very special Project
Logistics work, we are very active in the field of Break Bulk cargo, too.
the right partner and the confidence must be mutual.
With our own charter department in Germany we are in close contact with all major vessel owners on direct basis.
OGI: Finally, could you enlighten our readers of a case study where you helped a client with your solutions?
We are combining volume from our own offices and partner network, which gives us more possibilities in the market.
de Waele: In the beginning of 2016, one of our major clients during the last 20 years entrusted us with the handling of the biggest project ever performed through them.
OGI: Does LPL Projects & Logistics have anything new or exciting to talk about this year? de Waele: Digitalization and visibility of the services getting more and more important, also in our field of service. We are using our own Information System for Project Logistics, called “LPConnect”. This tool allows our clients to check all details of the performed, but also planned transport for their project. With the connection to the IT-tools from our clients we are exchanging data vice versa. We are permanently upgrading this system to meet the needs of our clients. Information, communication and visibility of information is essential in our field of business, as our clients trusting us in handing over very sensitive and high values or cargo with construction times up to one year. So our clients must be sure to have chosen
We were in charge for the complete logistic services of 2 x 4,6GW combined cycle Power Plants to two different locations in Egypt. During the last 4 years, we have handled more than one million freight tons, including more than 500 Heavy Lift transports (pieces above 50 tons). Our scope of services included the transport via air, sea or land from 5 continents, 32 countries & 73 places as well as the complete local handling in Egypt. In addition we were in charge to set 16 turbines and 16 generators onto foundation. This components with a weight of around 500 tons per piece needed very specialized transport handling. For more information you are invited to watch our video under: https://www.lplog.com/en/lpl-group/downloads--media
OGI: Thank you for your time. •
MIDSTREAM & PIPELINES
Re-Gen Robotics Confronts Outdated Perceptions to Robotic Tank Cleaning A global survey, commissioned by Re-Gen Robotics and carried out by tankstoragemag.com at the end of 2020, asked engineers, managers and senior executives with responsibility for hazardous area operations, their preferred option for cleaning oil terminal tanks. While an overwhelming 86 per cent of survey respondents, expressed a preference for 100% ‘no man entry’ tank cleaning at their terminal, the survey also provided a troublesome insight from a third of companies surveyed, who said that they had used some form of robotic cleaning in the past.
ust under two thirds (64%) of the companies that had used robotic cleaning, reported that the tank clean was unsuccessful. The main reasons given included, lack of skill and incompetency of the tank cleaning company, that the robotic tank cleaning involved at least 60% manned entry and that the contract was not fulfilled to agreed standards. Commenting on the survey findings, Fintan Duffy, Managing Director of Re-Gen Robotics said; “Most tanks owners have used some form of ‘robotic’ tank cleaning but invariably at points during the cleaning process, personnel have had to enter the tank to fix ramps and complete the wash out of the tank manually with a lance, as previous machines were not equipped with integrated augers or jetting systems. In reality, the robots until now, have not been fit for purpose. “While some systems have reduced the amount of time staff will spend in the tank, by up to 40 per cent, compared to manual cleaning, this has not eliminated the significant HSE and commercial risks tank owners are exposed to. And one would argue that it has presented
Fintan Duffy, Managing Director of Re-Gen Robotics.
genuine, 100% no man entry, robotic tank cleaning with a challenge. One of course, that Re-Gen Robotics is more than happy to address. “Applying fully integrated, 100% no man entry, closed loop, robotic cleaning technology is where a monumental difference can be made to safety in oil tank industry. Our state-of-the-art tank cleaning system is eradicating industry fatalities and hugely decreasing all risk categories, by eliminating human exposure to confined spaces. “At no time during the Re-Gen Robotics cleaning process is there a need for human presence in the confined storage
Re-Gen Robotics Control Room.
container. Our technical operator remains a safe distance away in the Zone 1 control unit, where they can monitor activity and progress through a series of ATEX cameras fixed to the robot. “There is no human exposure to sludge or waste materials during the cleaning process and once cleaning is complete, the robot safely exits the container via its hydraulic ramp and is returned to the control unit.” A follow up poll, taken during the online Terminal of the Future Conference in March ’21 asked attendees; ‘Would you like to see ‘No Man Entry Robotic Tank Cleaning’ at your Terminal in place of Confined Space Entry Tank Cleaning?’ A massive 88% per cent of respondents, said yes, indicating that the oil industry is acutely keen to commit to enhancing safety in their operations, by completely eradicating manned entry cleaning. For more information visit: www.regenrobotics.com Re-Gen Robotics Ltd.
A Re-Gen Robotics Robot.
10 Reasons Why Oil Companies Don’t Utilise Robotic Tank Cleaning and Why They Should! 1. It’s never 100% ‘no man entry’ Our process is strictly 100% no man entry. The protection of personnel is the cornerstone of our business. Our technical operator remains in the Zone 1 control unit where activity is monitored through a series of ATEX cameras fixed to the robot inside the tank. Our second crew member remains in the jet/vac tanker, to operate the access cranes via remote control, and to control the suction and jetting pressures feeding the robotic equipment. The robotic system takes too long to set up. Not true, from arrival onsite, to the robot entering the tank is approximately four hours. 2. The robot can’t clean a floating roof tank Our specialised equipment is designed to navigate around tank legs and furniture. With forward and rear facing ATEX cameras and lighting, out technical operator can see the location of any obstacles. A 360-degree jet head ensures even the tank roof is thoroughly cleaned. 3. The robot can’t clean around heating coils It can. Our offset suction head reaches under water suction pipes around the external diameter of tanks. The offset suction head is a low-profile tool, to access under pipes and has the ability to remove waste from below floor level. It can operate offset on the left, right and straight-ahead positions. This tool alone can
decrease tank cleaning time by 10-12%. 5. The robot can’t remove heavy oil fuel It can. Our Robots have an auger system located at the front which breaks down heavy sludge, without the requirement to use water, thereby generating less waste. The sludge is then extracted by an ADR certified jet/vac tanker with a 4,800 C/ m3 per hour vacuum capacity. 6. The robot not submersible The robot is powered via hydraulics and can work if fully submerged in sludge. The ATEX cameras rise to a maximum height of 1.5m and are equipped with water nozzles to clean camera lenses when dirty.
7. You can’t get the robot out of a tank remotely, if it breaks down You can. In the event of a mechanical failure, our robots can be retrieved via their umbilical cords, using our self-contained cranage system 8. The ramps for the robot can’t be placed inside the tanks without manned entry The system comes with a hydraulic ramp which we set up outside the manhole. A hydraulic pump sets the ramp section in place for the inside of the tank, with no fuss or requirement for manned entry. 9. We’ll have to provide scaffolding, cranage and a safety rescue team anyway Re-Gen Robotics supplies the complete system to clean your tank. We operate a fully contained system so no scaffolding, cranage or vacuum jetting is required. Because the service in 100% no man entry, standby rescue teams are not required. 10. It’s more expensive and time consuming It’s really not. The robot has proven to reduce time of tank cleaning by 45%, this translates to cost saving in production uptime and job man-hours.
Self Contained Craneage System.
On average we allow two/three days to clean a 30m diameter white oil tank. As there is no requirement for human presence in the oil tank, ReGen Robotics is classed as a medium risk contractor. This reduces paperwork and permits, there is no requirement for capital outlay, standby rescue teams, spading of tanks or inhouse robot operators. •
MIDSTREAM & PIPELINES
Corrosion and Erosion Monitoring Made Easy Sensorlink deliver high precision wall thickness monitoring equipment to the international oil and gas industry. Through decades of experience Sensorlink have fine-tuned the technology to deliver unparalleled repeatability, enabling clients world-wide to make quick and accurate decisions based on accurate data and integrate this into their integrity management systems.
n the oil and gas sector corrosion and erosion are serious problems. Internal corrosion in pipelines in the oil and gas industry is generally caused by water, carbon dioxide (CO2) and hydrogen sulfide (H2S). Corrosion can also be aggravated by microbiological activity. Erosion is generally caused by particles in the flow causing wear and tear on the inner pipe-wall. This internal corrosion and erosion need to be controlled and monitored. Sensorlink provides tools that will be useful in these operations. All Sensorlink’s corrosion and erosion monitoring systems are based on ultrasonic pulse-echo method. Ultrasonic pulse-echo measurement is a well-established method for measuring wall thickness and detecting defects in the oil and gas industry. The technology is well known and this makes the measured values from Sensorlink’s systems easy to verify by the client. When it comes to erosion and corrosion monitoring, ultrasound has distinct advantages compared to other available techniques. It is non-intrusive and measures the metal thickness directly and is not dependent on indicators like for example probes and coupons. Special processing methods have been developed for such instrumentation giving high resolution and accuracy measurements for monitoring wall loss. Our careful and committed technology development has resulted in Sensorlink
PipeMonit® Swarm for topside applications and Sensorlink UltraMonit® for subsea applications – giving you the best wall thickness monitoring option both under and over water. Both the topside systems, PipeMonit® Swarm, and subsea system, UltraMonit® are non- intrusive, meaning that the integrity of the pressure system in maintained
The Sensorlink technology is capable of measuring changes in the wall thickness with greater accuracy, thus avoiding the uncertainty caused by inadequate instruments or unskilled operators. Wall thickness can be measured to a very high accuracy by repeating measurements at the same spot over time with permanently installed instrumentation. The main considerations when planning to install a corrosion monitoring tool are related to the physical factors concerning the pipe and the pipe condition. The current technology allows for normal homogeneous coatings to be left on, typically one may leave FBE and 3LPE/LPP coatings on. When planning an installation of a monitoring tool, data management and usage should be addressed. The amount of data that can be pulled out of a monitoring tool is large and an application process should be in place to maximise the benefit of the information gained from monitoring.
Benefits of retrofit UT monitoring tools. The general benefit of monitoring vs inspecting is that one can observe changes in wall loss or corrosion rate more accurate. Not only can one determine the actual corrosion rate much faster, but with a historical trend of the corrosion rate one can correlate the corrosion rate with other operational parameters like flow temperature, flow rate, chemical composition etc. This gives rise to much more insight into how the process parameters influence the corrosion rate and how the degradation of an asset develops over time. This is very valuable information to be used in life-time assessment of an asset. Improving decisions related to safe operational life and major maintenance or modification actions. This is particularly relevant for pipelines close to the well, as the well chemistry varies substantially over the life of the well, and often rather quickly as well. Sensorlink’s retrofittable tools are flexible in the sense that they can be installed at most locations on a pipe including installation in bends in addition to straight pipe. The fact that a retrofit tool also can be moved between different monitoring locations adds to the flexibility of these tools. This can be effective in situations where one does not observe corrosion in the location one first thought was critical. One may then move the tools to another location. In this case the first location will be rated as not critical and the corrosion model may be updated to reflect this new knowledge. Users tend to have some main drivers to
install monitoring tools. One strong driver is to validate the effect of chemical inhibitors. With the performance of the current technology this is feasible as the response time is in matter of days and weeks. One of the other main drivers is to follow the development of known defects or critical areas. More generally one wants to validate the corrosion rate, and the estimated wall loss from manual inspection. Monitoring as part of an asset integrity strategy Monitoring should be part of a well-balanced asset management strategy. In general, an asset management framework will contain a risk assessment, determining which are part of the pipe that has the highest potential for integrity fails. Based on this, an inspection strategy and frequency are put in place to
validate the risk assessment and to follow the development of the degradation. Depending on the degradation phenomena one can enhance the inspection strategy through monitoring. The valuable aspect of using nonintrusive approach to monitoring is that if the risk assessment change over the life of the asset one may relocate the monitoring. With intrusive techniques like coupons, probes, ring pair and FSM this is not feasible. If the asset degradation is influenced by variations in process parameters, the asset management strategy should move to more monitoring rather than solely rely on inspection.This is purely due to the more accurate data available in a monitoring regime than a pure inspection regime. If the corrosion/erosion phenomena are very localised and unevenly distributed along the pipe one may apply monitoring of these known defects. This will determine any change in the development of these defects, and thus make it possible to adjust the inspection frequency, being it ILI or manual. Throughout the history of Sensorlink we have delivered more than 200 systems for topside monitoring and over 35 systems for subsea monitoring. Permanent monitoring of corrosion and erosion will be a valuable addition to your integrity management. • If you would like to know more about how Sensorlink AS can help your company and its operations with corrosion and erosion monitoring, please contact them at: Sensorlink AS W: www.sensorlink.no E: email@example.com T: +47 735 38 050
MIDSTREAM & PIPELINES
Oceanteam ASA Announces Potential Combination With PASSER Group AS Oceanteam Bourbon 4 AS, a joint venture owned 50/50 by Oceanteam ASA and Bourbon Offshore Norway AS, has entered into a Memorandum of Agreement regarding the sale of the vessel CSV Southern Ocean the “Vessel Transaction”. The sale is made subject to customary conditions and is expected to be completed in April 2021. After debt service, the sale of the vessel will generate a positive cashflow for the joint venture Oceanteam Bourbon 4 AS.
s disclosed earlier, Oceanteam intends to bring focus to its strategy going forward: focussing on a growing renewable – and energy transition market. In that respect a significant first step is being taken as described below. In addition, the Company has entered into a term sheet with Corinvest B.V., Stichting Value Partners Family Office (together the “OTS Majority Shareholders”), Farvatn Private Equity AS (“Farvatn”), and Melesio Invest AS (“Melesio”) (and together with the Company, the OTS Majority Shareholders, Farvatn and Melesio, the “Parties”) regarding the Parties’ intention to pursue a combination of PASSER Group AS (“PASSER”) and the Company, whereby all the shares in PASSER are transferred to OTS against consideration shares in OTS (the “Transaction”). The Parties envisage that the Transaction will comprise the following main steps: Combination of OTS and PASSER OTS and PASSER will combine their activities in a transaction where OTS acquires 100% of the shares in PASSER against 71,428,000 consideration shares in OTS (the “Consideration Shares”) to be issued at NOK 3.00 per share or equal to the subscription price in the Private Placement (as defined and described below). The number of Consideration Shares assumes that PASSER as of 31 December 2020 had a normal level of working capital and a net debt level of around zero (+/- MNOK 5), all of which to be confirmed in the due diligence to be conducted in connection with the Transaction. If the actual working capital and/or net debt levels deviates
from these assumptions, the Parties shall discuss and agree appropriate adjustments to the number of Consideration Shares. As the nominal value of the shares in OTS are higher than the subscription price set out above, the nominal value of the shares must be reduced through a share capital decrease prior to (or simultaneous with) the issuance of the Consideration Shares to the shareholders in PASSER. PASSER is a leading provider of turnkey cable handling solutions used in the production, transportation, laying and storage of large offshore cables, serving some of the leading cable manufacturers and installation contractors in the world, and also has a growing business within cryogenic insulation solutions for sustainable shipping. Farvatn currently owns 85.43% of the shares in PASSER. The remaining shares in PASSER are owned by board members, employees of PASSER and employees of Farvatn.
Rapid electrification will transform the energy mix by 2050 and drive significant investments in offshore connectivity infrastructure. The combination of Oceanteam and PASSER will create a leading provider of mission-critical solutions for handling of large offshore cables with a strong value proposition to clients and an attractive platform for further growth. The combined company will have 1) a comprehensive offering covering all phases of the offshore cable lifecycle 2) attractive size, scale and diversification 3) a fully integrated value chain 4) strong and recurring client base with an offshore renewable focus and 5) attractive organic and strategic growth prospects. The overall strategy of the combined company will be to continue its successful transition from fossil to renewable with a strategic focus on the high-growth offshore renewable market. Further, the combined company expects to drive industry consolidation in combination with accelerated international growth with focus on Europe, Asia and the US. On behalf of the entire Board of Oceanteam Mr. Keesjan Cordia (as Chairman) and the Chairman of PASSER Mr. Tore Hopen express their strong commitment and enthusiasm to the transaction that will position the combined company well into the offshore renewable and clean energy megatrend: “we are both very excited on writing this new chapter in both our companies’ history in a changing world”. •
MIDSTREAM & PIPELINES
Reducing Risks in Oil and Gas Transportation The oil and gas sector, like many industries, relies heavily on transportation to move crude oil from wellheads to refineries or refined products from refineries to their final destination, using tankers at sea and pipelines, railroads and trucks on land. Natural gas is mostly transported by pipelines and liquefied natural gas tankers.
afety on tankers
Safety is of the utmost importance when transportation is involved. Whatever their size – from the smaller general-purpose tankers for refined products, to the super tankers that transport crude oil – tankers face a huge number of hazards at all times. Some examples include: Cargo, which is flammable in nature, and bound to release some types of gases. Equipment carried by seafarers, such as torches, mobile phones or cameras, may pose potential fire/explosion risks, especially if they are not intrinsically safe. Only explosion-proof equipment should be used aboard such vessels. All electrical equipment in general, such as power tools, used in daily operations and for repairs. Lightning or electrical storms, Cigarettes, which have caused fires in the past and led to a general smoking ban on deck and in prohibited areas. Tanker design Tanker architecture is extremely important. Older tankers, built as single-hulled vessels, are expected to be phased out by 2026, in accordance with the International Convention for the Prevention of Pollution from Ships (MARPOL 73/78). Most newer tankers are double-hulled, allowing an extra space between the hull and the storage tanks. It is worth noting that, since the 1970s, the
number of spills has gone down drastically. According to the International Tankers Owners Pollution Federation (ITOPF), the average number was 79 in the 1970s and decreased by over 90% to 6 in the 2010s.
liquid moving forward and backward. The shape of the tank also plays a role and makes for safer transportation: oval for diesel and gasoline, circular for LNG.
Modern tankers are said to be safer when grounding incidents occur, but still can be breached in case of hull or equipment failure, fire/explosion, or collision with another vessel.
Historically, railroads were the primary means of oil transportation. Today, they are in competition with pipelines, but because they offer more flexible routes, they are still a viable alternative.
When dealing with oil or gas transport on land, the choice is between trucks, railroads and pipelines.
All means of transportation have their advantages, disadvantages and common points: the need for ongoing maintenance, repair and overhaul, the use of Ex-proof equipment when applicable, as well as extensive safety measures for those operating the vessels or vehicles.
Road safety measures for tanker trucks go further than just speed limits. Trucks are airtight and a system of dividers stops the
Operators must establish measures to ensure that corrosion, leaks and failures never stay unnoticed and are seen to as soon as possible, to avoid human casualties and environmental damage. Automation and smart technologies are increasingly used in the oil and gas industry sector. In addition to all technological advances that make vehicles safer, such as automatic braking systems, adaptive cruise control, sensors and alerting systems, transportation management systems provide valuable assistance in monitoring supply chains and identifying how, when and where to move products safely. Sensors also help to monitor corrosion, cracks and anything out of the ordinary in tanks and pipelines. •
MIDSTREAM & PIPELINES
Parliamentarians Affirm Importance of Line 5 Pipeline for Canada and U.S. & Call For Urgent Executive Action A multi-party Canadian House of Commons Special Committee report released today affirms the economic importance of the Line 5 pipeline to both Canada and the U.S. and recommends urgent, binational executive action to resolve the dispute between the State of Michigan and Enbridge over the Straits of Mackinac crossing.
ine 5 “is a significant aspect of Canada’s economic relationship with the United States and contributes to secure energy supplies in both countries,” the report states. “Its shutdown could have many implications, including reduced safety, shortages of various energy products on both sides of the Canada–U.S. border, transportation bottlenecks for Alberta’s crude oil, and job losses for Canadian and American workers. In this context, the Special Committee believes that the Government of Canada’s efforts designed to ensure that Line 5 remains in operation are vital.” Since the beginning of 2021, governments, local communities, labor groups, chambers of commerce, business councils, industry associations and thousands of citizens in Canada and the U.S. have been vocal in stressing the importance of keeping Line 5 operating without interruption until Enbridge can complete its Great Lakes Tunnel Project. The Special Committee’s report on Line 5 follows parliamentary hearings in March that featured testimony from labor and business groups like Canada’s Building Trades Unions, the Laborers’ International Union of North America, and the Canadian Chamber of
Commerce. The Energy Ministers from Ontario, Alberta and Saskatchewan also testified to the importance of Line 5. Many organizations provided written input to the committee. “Enbridge is grateful for the tremendous outpouring of support for the uninterrupted operation of Line 5, including Parliamentarians across all party lines who’ve come together on
this important cross-border issue,” said Vern Yu, Executive Vice President and President, Liquids Pipelines. “We concur fully with the findings of the report, most importantly on the need to resolve the current dispute through executive action and state-to-state negotiation. As the report makes abundantly clear, it’s in the best interests of both Canada and the United States to agree on a plan to keep the Line open and get the new proposed tunnel built in a timely manner. “The stakes could not be higher,” Yu said. “Line 5 is not just a pipeline—it’s an economic lifeline in Canada and the United States.” Enbridge Inc. is a leading North American energy infrastructure company. We safely and reliably deliver the energy people need and want to fuel quality of life. Our core businesses include Liquids Pipelines, which transports approximately 25 percent of the crude oil produced in North America; Gas Transmission and Midstream, which transports approximately 20 percent of the natural gas consumed in the U.S.; Gas Distribution and Storage, which serves approximately 3.8 million retail customers in Ontario and Quebec; and Renewable Power Generation, which generates approximately 1,750 MW of net renewable power in North America and Europe. •
THE USE OF LNG IS GROWING. DO YOU NEED TO KNOW MORE?
DEVELOP AND STRENGTHEN YOUR LNG KNOWLEDGE AND EXPERTISE GTT Training can provide training in all aspects of LNG operations for ships and terminals, in almost any location, worldwide. Our training portfolio includes approved STCW, introductory and operations courses for LNG Carriers, LNG Bunker vessels and vessels using LNG as marine fuel, along with a range of courses covering FSRUs and LNG terminal personnel. GTT Training uses its own, in-house developed, Liquid Gas Handling Simulator, G-Sim. G-Sim is a simulation platform that allows operators to be trained in all aspects of handling Liquid Gas on board LNG Carriers, LNG Fuelled Vessels and within shore facilities. Approved by DNV GL, G-Sim is also available for purchase by clients for use in delivering their own training programs either ‘Online’ or in their training facilities. GTT Training can also provide support for course development, course delivery and the training of instructors.
Learn more on www.gtt-training.co.uk
MIDSTREAM & PIPELINES
Total Partners With Siemens Energy to Reduce LNG Related Emissions Total and Siemens Energy signed a Technical Collaboration Agreement to study sustainable solutions for CO2 emissions reduction. The collaboration will focus on natural gas liquefaction facilities and associated power generation. Each partner will bring together their best-in-class technologies and combine their know-how to deliver industrial-stage solutions such as combustion of clean hydrogen in gas turbines, competitive allelectrical liquefaction, optimized power generation, the integration of renewable energy in liquefaction plants’ power system and their efficiency enhancement.
his collaboration with Siemens Energy, a major player in the energy technology sector, brings many opportunities to further reduce the carbon footprint of our activities, especially in our strategic LNG business,” said Arnaud Breuillac, President Exploration & Production at Total. “The development of lowcarbon LNG will contribute to meet the growth in global energy demand whilst reducing the carbon intensity of the energy products consumed. Reducing its carbon footprint is essential for LNG to play its role fully in the energy transition. “We are pleased to partner with Total as one of the main players in the LNG value chain to explore how we can competitively reduce the carbon footprint of brownfield and greenfield LNG projects,” said Thorbjörn Fors, Executive Vice President of the Industrial Applications Division at Siemens Energy. “The agreement is a next step, following our announcement last June to collaborate together and conduct studies exploring possible liquefaction and power generation plant designs to help decarbonize the production of LNG.” Total is the world’s second largest privately owned LNG player, with a global portfolio of
nearly 50 Mtpa by 2025 and a global market share of around 10%. The Group benefits from strong and diversified positions throughout the LNG value chain: gas production and liquefaction, LNG transportation and trading, and contribution to the development of the
LNG industry for maritime transport. Through its interests in liquefaction plants in Qatar, Nigeria, Russia, Norway, Oman, Egypt, the United Arab Emirates, the United States, Australia and Angola, the Company markets LNG on all world markets. Total is a broad energy company that produces and markets fuels, natural gas and electricity. Our 100,000 employees are committed to better energy that is more affordable, more reliable, cleaner and accessible to as many people as possible. Active in more than 130 countries, our ambition is to become the responsible energy major. Siemens Energy is one of the world’s leading energy technology companies. The company works with its customers and partners on energy systems for the future, thus supporting the transition to a more sustainable world. With its portfolio of products, solutions and services, Siemens Energy covers almost the entire energy value chain – from power generation and transmission to storage. The portfolio includes conventional and renewable energy technology, such as gas and steam turbines, hybrid power plants operated with hydrogen, and power generators and transformers. •
Custom Solutions for Harsh Environments
Innovative customized solutions made of PTFE and other high-performance plastics capable of performing in the harshest of sub-sea and surface environments that are designed to minimize downtime and maximize production. As a technology leader with our own process know-how we offer unique technical solutions for rotating and dynamic equipment including pumps, compressor systems, valves and FPSO swivel stacks. We manufacture parts with dimensions up to 3.000 mm made of NORSOK approved material.
Visit us at SPE Offshore, Aberdeen UK www.ek-kt.de/oilandgas firstname.lastname@example.org Phone +49 7142 583-0
MIDSTREAM & PIPELINES
Historic Moment for ADNOC The Abu Dhabi National Oil Company (ADNOC) and Intercontinental Exchange (ICE) today, officially celebrated the start of trading of the United Arab Emirate’s (UAE) flagship crude oil, Murban, as a Futures contract on the new ICE Futures Abu Dhabi (IFAD) commodities exchange. During a high-profile launch event at Abu Dhabi Global Market (ADGM), attended by H.H. Sheikh Mansour bin Zayed Al Nahyan, Deputy Prime Minister and Minister of Presidential Affairs, ICE, ADNOC and the partners in ICE Futures Abu Dhabi, marked the start of trading for ADNOC’s Murban crude oil on ICE Futures Abu Dhabi, a significant milestone for Abu Dhabi and the UAE in its jubilee year. The introduction of the world’s first Murban Futures contract is the latest step in ADNOC’s ongoing transformation into a more market and customer centric organisation. By making Murban a freely traded crude, similar to Brent or WTI, customers have better price transparency, flexibility to hedge and manage risks and increased access to Murban crude. For ADNOC, its flagship crude grade becomes more available to a broader set of market participants around the world. Alongside ICE and ADNOC, nine of the world’s largest energy companies and traders are joining IFAD as founding partners. This includes BP, GS Caltex, INPEX, ENEOS, PetroChina, PTT, Shell, Total and Vitol. Representatives from the partner companies joined today’s launch event at ADGM, many participating virtually from around the world. In attendance also were Suhail bin Mohammed Al Mazrouei, Cabinet Member and Minister of Energy and Infrastructure, Khaldoon Khalifa Al Mubarak, Group CEO and Managing Director of Mubadala Investment Company, Jassim Mohammed Buatabh Al Zaabi, Chairman of the Department of Finance, Awaidha Murshed Ali Al Marar, Chairman of the Abu Dhabi Department of Energy, Khalifa Al Suwaidi, Chairman of ICE Futures Abu Dhabi (IFAD), in addition to representatives of partner companies.
Commending the landmark launch of Murban Futures Contracts, H.H. Sheikh Mansour said: ‘’This historic decision falls within the strategy of the UAE and the vision of the wise leadership, which aims to increase the economic achievements and consolidate the honorable position of the UAE and its leadership on the global competitiveness map, and in support of its leading role internationally in the oil market, as a basic resource, in order to ensure the continuation of distinguished development successes.’’ H.H. affirmed that the state is keen to keeppace with the changes and developments of the energy sectors, based on forward-looking plans that are capable of achieving prosperity, progress and the development of national wealth, in the service of the people of the UAE and opening promising horizons for them.
Commemorating the new Murban Futures contract, Dr. Sultan Al Jaber, UAE Minister of Industry and Advanced Technology and ADNOC Managing Director and Group CEO, said: “This is a historic moment for ADNOC, Abu Dhabi, and the UAE as we celebrate the launch of the IFAD exchange with ICE and, with our partners, capitalize on the growing demand for high-quality Murban crude oil, particularly from markets in Asia. This achievement is testament to the vision and foresight of our wise leadership, who have supported this progressive step that makes Murban crude a freely traded commodity that is more widely available to buyers and traders around the world.” “The launch of the world’s first Murban Futures contract makes our largest crude grade even more attractive to the global market, enabling ADNOC’s customers and market participants to better price, manage and trade their purchases of Murban. Murban Crude is recognized the world over for its intrinsic chemical qualities, consistent and stable production volumes, large number of international buyers, and numerous longterm concession and production partners. In making Murban a freely traded global commodity, it becomes even more attractive to market participants and will deliver greater value to ADNOC and its partners. This historic and strategic milestone reinforces the UAE and Abu Dhabi’s status as a leading global energy hub and underscores ADNOC’s central role as a catalyst to empower the UAE’s economic ambitions.” •
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Calenberg OIL-EX Absorption Mat – Perfectly Suits the Needs of the Oil and Gas Industry Calenberg elastomer solution for a clean environment ensures sustainable environmental protection for transport and industrial areas. Due to its special material matrix, the OIL-EX absorption mat prevents leaks of hazardous substances such as oil or other hydrocarbon compounds.
IL-EX consists of elastomeric materials, an absorption layer of bound pelleted rubber and a high proportion of recycled material. An impermeable barrier layer on the underside of the mat prevents contamination of the substrate. OIL-EX absorbs liquid hydrocarbons such as oils, low-viscosity lubricants, fuels, and organic solvents and selectively binds the hydrocarbons from emulsions. The liquids are distributed on the surface of the mat by the shaping of the absorption layer and are subsequently bound in the material matrix. The absorbed liquids remain in the mat and cannot be squeezed or rinsed out. Surface water, however, is not bound and drains off. Drainage is facilitated by longitudinal and transverse profile grooves. As a result of the absorption of the materials, the mat material swells and consequently reduces the width of the grooves. If the absorption capacity of the mat is exhausted, this is indicated by completely ›closed‹ grooves. Characteristics • •
Easy handling (installation, cutting to size) Suitable for mobile use.
Shock absorbing effect.
Noise and thermal insulation.
High proportion of recycled raw material.
Long service life.
Protection of the substrate in a wide range of applications OIL-EX protects the substrate from contact with harmful substances. The mat is suitable for mobile and stationary use wherever uncontrolled oil losses and leaks can occur. It is recommended to use the mat in mechanical engineering, equipment, and vehicleconstruction areas, e.g., for maintenance, repair, and cleaning purposes. Outside use on unpaved surfaces has also proven to be particularly effective. Fields of application •
Absorption effect independent of weather • and temperature. • Short absorption time.
Full pedestrian access and restricted • vehicular access.
Absorbed media cannot be extruded or • flushed out. • Can be used on unpaved surfaces.
Cisilent® Room Partitions.
Maintenance and parking areas for road Reference project: Oil-Ex absorption mat reand rail vehicles. laid in Hamburg port Storage and temporary storage for Locomotive stabling points with OIL-EX machines. absorption mats have been reconditioned and re-laid over a large area in the Port of Hamburg Protection of hydraulic equipment. to prevent contaminants entering the subsoil. Storage and transport securing of hydrocarbon-filled drums, tanks, and Calenberg’s Oil-Ex absorption mats have been used in the diesel locomotive stabling containers. points for many years to prevent damage to Filling stations. the environment. Easy to install, the mats bind Loading areas etc. any liquids leaking out into their absorption layer, particularly oil and diesel, so that these liquids do not penetrate the ground. The mats in the Port of Hamburg now need replacement after some eight years of use. More than 1200 m2 of new Oil-Ex mats were laid in spring 2020. Each old mat was removed before installation and then taken away for correct disposal. The new mat was then rolled out immediately, ready cut to a suitable width by Calenberg. Suitable OIL-EX profiles connect the joins between the individual mat strips, sealing them tightly. • Calenberg Ingenieure GmbH T: +49 5153–9400-0 E: firstname.lastname@example.org W: www.calenberg-ingenieure.com
Oil-Ex, Hamburg Port.
Protect Your Employees Effectively From Machine Noise and Ensure Full Productivity With Cisilent© Type E
ncreasing construction projects and heavy traffic in inner city areas cause significant and permanent noise pollution for residents. But noise generated during production or manufacturing in the plant itself also affects the well-being of workers.
Cisilent® Machine Enclosure. Picture ©Schubarth + Co AG .
Calenberg has developed a lightweight flexible sound insulation system to protect the environment from intrusive air-borne noise and meet requirements for an increased need for rest. The systems are quick and flexible in their use (for corner cut-outs and pipe penetrations, for example) to provide different noise control measures and can also be optimally integrated into the surrounding area, even where there is little space. Cisilent® Type E can be purchased or rented. Structure The textile structure made of high-strength polyester fabric features three layers interconnected in such a way that they form pockets to hold the filling medium. These pockets are offset from one another at the sides on the front and rear, thus offering unique flexibility in the panels. Their surfaces are resistant to water, ozone, UV radiation, dirt, and micro-organisms. Filling the chambers with non-flammable insulation rock wool potentially increases the sound reduction index up to 53 dB. There are no standard sizes as all elements are manufactured to client specifications. Only the length parallel to the chambers is limited to 4 m for production reasons. Noise control indoors Effective protection against noisy machines and other sources of intrusive noise The Cisilent® Type E’s low mass per unit area provides bespoke noise control in both production and administration areas. Customised solutions and measures are developed to protect those affected from noise and maintain productivity. Our comprehensive sound insulation includes reduction of sound
transmission from one room to another in the building interior and prevents sound transmission in the event of loud noise emission inside the building. Temporary sources of noise can be sealed off acoustically. Clamping strips, bayonet connectors or castors in rails can be used to fasten the system in such cases. Cisilent® Type E is used, for example, in a curtain system, in soundproof booths or mounted on a frame to provide acoustic separation in workplaces. Noise control outdoors- Minimising noise exposure Cisilent® Type E’s absorption effect is often sufficient to provide effective noise control. In such cases, Cisilent® panels can often be attached quickly and easily to existing structures thanks to flexible manufacturing options, such as angled cuts or pipe penetrations. If this is not possible, simple supporting structures are often adequate to ensure effective noise control for the long term. The options for using Cisilent® Type E range from machine enclosures and installation on construction scaffolding through to permanent sound insulation surfaces. Advantages Highly sound-absorbing; low weight of around 5.5 kg/m²; flexible use in terms of place, subsurface, installation length and similar; easy to install/dismantle; can be moved; easy to transport; long service life; heat-, -ozone and weather-resistant; sturdy panel structure; resource-efficient thanks to reusability; quickly available; sound reduction index of Rw = 21 dB
Cisilent® Machine Enclosure.
Reference project: Maintenance hangar, Sandweiler, Luxembourg The opening to a space in the maintenance hangar needs to be closed off to protect employees in the rest of the hangar against noisy work within the space. The system enclosure needs to be easy to remove to provide access through the opening width. Cisilent® Type E features as a curtain system to enclose the entrances to the space on both sides. Each curtain is split into two parts on either side to make it easy to evacuate the area in an emergency. The panels are fastened to guide rails that form a dual rail system, along which the suspended Cisilent® Type E panels are pulled over one another. Systematic overlapping of the panels ensures effective noise reduction when the panels are closed. Reference project: Drilling site in Bözberg, Switzerland Deep drilling is being carried out to create geological deep deposits in the Jura East region. To ensure drilling operations with two triplex pumps as part of a tower drilling site, a noise reduction of +10 dB was required. The mobile noise barriers Cisilent® type E was fixed to a scaffolding as sound insulation for the pumps. The enormous absorption capacity of the sound-absorbing side of Cisilent® was facing the pumps. This prevented reflection going over the shielding and reduced noise pollution for the workers working on the pumps. The subsequent measurements carried out by the authorities showed that the required noise reduction was also met as a result. Our partner Schubarth advised and supervised the project and used Cisilent® Type E as a rental system for sound and noise reduction. •
CUSTOM SOLUTIONS Wherever pressure sensors are needed, a solution can normally be found in the KELLER standard product catalog. However, there are often great benefits to optimising a product specifically for integration and use in existing complete systems. In addition to outwardly identifiable components such as housing parts or plugs, this also includes the inner workings of the sensor. We produce a large number of individual parts in-house and establish close working relationships with our suppliers, enabling us to make a wide variety of modifications with ease.
Shared expertise for the perfect sensor solutions Our customers are specialists in their field: they know the requirements and operating conditions best. Since 1974, KELLER has been harnessing the potential of piezoresistive sensor technology to see numerous challenging projects through to completion. In all of these projects, a mutual exchange of expertise was essential to their success. Sharing our knowledge is what enables us to find the best sensor solution. Even applications that may appear trivial at first glance can prove highly complex upon closer analysis. By taking the actual usage conditions of the sensor into consideration right from the outset, we can achieve major improvements in effectiveness and durability. And this holds true whatever the application – from fill level sensors in rainwater tanks to ultra-precise laboratory instruments, and even rocket science. No matter the task at hand, the expert advice from our sales engineers and developers is a vital piece of the puzzle. Whether an existing product can be used – possibly with suitable modifications – or a new development is needed depends entirely on the customer‘s project. Together, we look at the requirements to determine the properties needed for flawless measurement. Armed with many years of experience, we take a close look at all the factors involved and their various interdependencies.
Thanks to our technological expertise, longstanding experience and mastery of the many processes involved in manufacturing pressure sensors, coupled with a high level of vertical integration, we can make even the impossible possible.» Bernhard Vetterli, Technical Director
output signal. Products with a digital signal output have additional factors that also need to be determined, such as sampling rate or signal resolution. The values defined at this stage form the starting point for selecting components.
Measuring ranges & performance
Another crucial requirement is taking the ambient conditions into consideration. Not only does this increase the service life of the sensor, it is also an essential prerequisite for correct measurements. If the pressurised system operates with a large overpressure or with dynamic loads, the sensor design must be optimised for these particular demands. With some applications or neighbouring system parts, there is a risk of signal distortion or component failure due to vibration or shock. Temperature also has a major impact on all materials and their resistance. Complications can be caused not just by extreme temperature values but also by rapid changes in temperature. Another equally important factor is chemical resistance. The materials used for housings and seals must be carefully selected, otherwise they risk being damaged by aggressive measuring media. External factors such as petrol fumes, UV radiation, salt water or even microorganisms can also cause problems. It is therefore essential that all relevant factors be considered. Of course,
First of all, we define the basic sensor specifications such as overall measuring range, accuracy, calibration to specific measuring points and units of pressure, or scaling of the
Perfectly tuned to the ambient conditions
even finely tuned designs still have limits, and additional protective measures may be needed. Our experience has taught us that material and physics hardly know any limits when it comes to creating new challenges for us to solve.» Stefan Fehr, Head of Quality Assurance.
“Our experience has taught us that material and physics hardly know any limits when it comes to creating new challenges for us to solve.” Stefan Fehr, Head of Quality Assurance.
Mechanical design When designing a sensor, all the above points must be taken into consideration. A device‘s performance is heavily influenced by the sensor design, from the choice of sensor chip and coupling medium through to the materials and production techniques used. In addition, customers may have particular requests concerning shape and size, pressure connections and so on. And of course, any specific requirements pertaining to the area of application must be complied with, along with all the applicable legal regulations and standards. Electronics & configuration The main function of the electronics is to prepare the measurement signal, as well as possibly to save it and output it via a suitable interface. Customers can also request that applicationspecific calculations be integrated in the firmware, or ask for special device and software configurations. Once again, there are other requirements that depend on the environment, such as extended lightning protection, EMC or explosion protection. Intrinsically safe products can also be specially configured to match the parameters of the customer‘s overall system. Electrical interfaces & connections Digital interfaces can be configured for specific communication protocols, or modified to suit the customer‘s needs. Meanwhile, analog interfaces also continue to play a vital role in sensor technology. KELLER is highly experienced in developing application-specific solutions based on both of these principles,
including devices with light wave and frequency outputs. For electrical connections, the necessary plugs can be integrated into the design, while cable outlets can be specified by the customer. Labelling In addition to customer logos, it is also possible to have functional markings applied to the product, either by means of laser inscription or by printing information on labels. These may include part codes, serial numbers, data matrix codes or guide marks. Customers can also specify a colour-coding scheme for the connecting wires. For consumer products
such as manometers, a personalised design that includes the customer‘s logo can be applied to the front panel. • If you would like to know more about how KELLER AG für Druckmesstechnik can help your company and its operations, please contact them at: KELLER AG für Druckmesstechnik T: +41 52 235 25 25 E: email@example.com W: https://keller-druck.com/en
“Thanks to our technological expertise, longstanding experience and mastery of the many processes involved in manufacturing pressure sensors, coupled with a high level of vertical integration, we can make even the impossible possible.” Bernhard Vetterli, Technical Director
Electrical interfaces & Connections
The perfect sensor solutions.
ADNOC Commits to ‘Make It in the Emirates’ The Abu Dhabi National Oil Company (ADNOC) today reiterated its commitment to drive industrial growth and diversification through its ambitious downstream and industry growth program, supporting the Ministry of Industry and Advanced Technology’s (MoIAT) ‘Make it in the Emirates’ strategy. Petrochemical, refining and gas growth projects are currently under construction, with a number of projects also recently completed across the Downstream and industry portfolio. ADNOC is gearing up for growth with TA’ZIZ, the world-scale chemicals production hub and industrial ecosystem based in Ruwais, with investment in excess of AED 18 billion and a number of further growth projects in the Downstream and industry sector.
n addition, a blue hydrogen and ammonia business is under development to capture the emerging global demand for low carbon fuels. The commitment builds on ADNOC’s flagship In County-Value (ICV) program, which has driven in excess of AED 76 billion back into the UAE economy. ADNOC’s renewed commitment in driving industrial growth in the UAE comes as the Front End Engineering and Design (FEED) tenders for TA’ZIZ, the world-scale chemicals production hub and industrial ecosystem based in Ruwais, have been issued. Mr. Khaled Salmeen, Executive Director of ADNOC’s Downstream, Industry, Marketing & Trading Directorate, said: “ADNOC’s downstream and industry operations are a critical engine of industrial growth in the UAE. Our operations provide competitive fuels and feedstocks to enable the Nation’s industries and manufacturing supply chains. With our ambitious growth plans, ADNOC is proud to support the Ministry of Industry and Advanced Technology’s ‘Make it in Emirates’ strategy, creating new opportunities for companies to grow, develop and to thrive in the UAE”. ADNOC currently supplies over two-thirds of the UAE’s industrial energy needs, supporting and enabling the growth of local industries. The company’s focus on driving industrial growth through its downstream business will see significant investments across its chemical, polyolefin, refining and hydrogen portfolios. Within TA’ZIZ’s Industrial Chemicals Zone, total investment will be in excess of AED 18 billion, with the chemicals produced enabling new industries in the UAE, across a wide range of light industries and industrial services. Examples of new products which can be produced in the UAE include disinfectants, plastics, construction materials and pharmaceuticals. Opportunities are available for local and international investors to participate across the value chain. “We are truly looking forward to continuing the fantastic work we have already produced together.” Since the launch of TA’ZIZ, joint venture partners ADNOC and ADQ have received
significant interest from investors, with partners for key anchor projects set to be announced in the coming months. TA’ZIZ is also a vehicle to enable local private sector investment in the UAE’s downstream industry. Following the mandate from the Supreme Petroleum Council in November 2020, to explore potential opportunities in hydrogen with the ambition to position the UAE as a hydrogen leader, the company is exploring the potential to help meet the emerging global demand for blue hydrogen and blue ammonia derived from natural gas. ADNOC will build on its advantaged position as a major natural gas reserves holder and producer, with existing infrastructure and strong partnerships. ADNOC continues to develop its Ruwais refinery, the world’s fourth largest, to enhance the flexibility and resilience of operations including the AED 13 billion ‘Crude Flexibility Project’ and AED 2 billion ‘Waste Heat Recovery’ project, which are both under construction. By investing in these capital projects, ADNOC will continue to ensure the provision of secure and competitive fuels and feedstock to local industries. Expansion of the World-scale polyolefin production at Borouge continues, with the fifth polypropylene unit now more than 90% complete. The unit will have the capacity to make polypropylene for approximately
600,000 kilometres of polypropylene pipes per annum, enough to circle the Earth 15 times. Since 2018, ADNOC has attracted significant foreign direct investment from international partners in the downstream business including refining, fertilizers and gas pipelines. ADNOC’s downstream growth plans are in line with its 2030 strategy of a more profitable upstream, more valuable and resilient downstream and sustainable, economic gas supply, underpinned by more proactive and adaptive marketing and trading. ADNOC’s existing and sizeable downstream portfolio comprises eight companies with capacity to process 10.5 billion standard cubic feet (scf) of gas per day, and 922,000 barrels per day (bpd) of condensate and crude. They produce up to 40 million tons per year (mtpa) of refined products, and a range of other products, including granulated urea, liquefied petroleum gas (LPG), naphtha, gasoline, jet fuel, gas oil and base oils, and other petrochemical feedstock and specialty products. •
Dow Launches Blockchain Pilot for Mattress Recycling Program Testing will demonstrate ability to trace circular polyurethane flexible foam composition and strengthen value-chain transparency. Dow Polyurethanes, a business division of Dow (NYSE: DOW), has launched a blockchain pilot project to test the technology’s suitability for supporting flexible foam circularity. The pilot uses a blockchain platform developed by ChemChain to transfer verified product information securely within the RENUVA™ mattress recycling program.
hat if we could ensure transparency in a circular product without compromising confidentiality? Our engagement with recyclers and customers on circular solutions has led us to pose this crucial question. Ensuring that the necessary compositional information can be shared at every step in the value chain is critical to enable circularity at the end of product life”, said Jihane Ball, director of global product safety and compliance at Dow. “Through our pilot, we are testing the transfer of product information in a controlled way and applying it to the circular RENUVA™ mattress recycling program. Existing chemical industry information exchange systems are unable to meet the demands for prompt responses, consistency, disclosure of information about formulations, and trust along the entire supply chain. The advent of circular products is driving the need for efficient and reliable information sharing along the supply chain. Blockchain technology can speed up information exchange, providing quick access to verified data on a need-to-know basis, and enabling traceability. Using the ChemChain platform developed for the chemical industry, Dow will generate digital assets containing key encrypted information on the chemical composition of its solutions. These assets can be integrated into the final polyurethane-based products ensuring contents can be identified at every stage in a products’ lifecycle. Recyclers can then easily access this information and identify the most appropriate action for the disposal or recycling of end-of-life mattresses. ChemChain is a blockchain platform designed for use by the chemical industry to transfer information on chemicals in products along the value chain, from chemical manufacturers to consumers, recyclers, and waste operators. The platform is the result of the ChemChain European project. The RENUVA™ mattress recycling program is part of Dow’s RENUVA™ circular economy program which aims to advance the recycling of end-of-life polyurethane products in collaboration with the value chain. •
Schlumberger and Microsoft Expand Partnership Partnership introduces industry first, AI-enhanced cloud native solution for the OSDU™ Data Platform optimized for Microsoft Azure. Schlumberger and Microsoft announced an expanded strategic partnership to accelerate new technologies for the energy industry. The first offering, the Schlumberger Enterprise Data Management Solution for the OSDU Data Platform—a new industry standard for energy data—is available today. Energy companies will now benefit from an OSDU-compliant solution, and the ability to seamlessly connect to the DELFI* cognitive E&P environment from Schlumberger. The Enterprise Data Management Solution is ready for global customers to deploy on Microsoft Azure, Schlumberger’s preferred global public cloud platform for OSDU-compatible solutions.
he companies’ mutual contributions to the first commercial release of the OSDU Data Platform establish the foundation of the Schlumberger Enterprise Data Management Solution. Through this partnership they will enhance the Enterprise Data Management Solution, tighten integration with OSDU and develop new scalable data ingestion capabilities, unified AI templates and domain services. These new joint solutions will be built using industry focused cloud, data and AI innovations and domain expertise from Microsoft and Schlumberger. The companies will work together to bring these new products to market, including sales, service and support. “Introducing a global cloud-based data solution, built by Schlumberger and Microsoft, means the energy industry can fully embrace their digital transformation with confidence. By working together, we have opened access to data and AI, unlocking significant potential for productivity increases and performance gains across all domains,” comments Hinda Gharbi, executive vice president Services and Equipment, Schlumberger. “These new possibilities and opportunities have become a reality today; our joint solution is available for deployment on Azure across the globe. Our industry can now quicken the pace of innovation to accelerate the digital future of energy.” “Our expanded partnership with Schlumberger underscores the vision we share to help the energy industry’s digital transformation,” said Scott Guthrie, executive vice president, Cloud + AI, Microsoft. “By harnessing AI technologies, companies can simplify their data to gain valuable insights and streamline workflows. Built on Azure, and open and interoperable by design, these new solutions and platforms will enable every customer and partner in the energy industry to compete and thrive.” More detail about the current Enterprise Data Management Solution can be found here. Additional information about the future joint solution will come at a later date. •
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Hi Ve n t Ai r Re l e a s e Va l v e s Desi g n ed F o r T h e O n / O f f sh o r e P et r o ch emi cal I n d u st r y
Air vent - Air release - Vacuum Relief valves
Introduction GA Valves Sales Limited has established itself in the supply of Engineered solutions in a wide range of exotic materials. We meet the diverse demands of the oil industry with the venting or admission of air into or out of pipelines and vertical risers, both wet and dry. We have supplied valves to a wide range of customers and countries throughout the world. Many of which revert back to GA after the valves reach their specified ‘life cycle’ for a new unit to be supplied, these life cycles are determined by the oil companies and can vary widely. All consumable spare parts are stocked on site for despatch around the world.
Documentation The critical nature of fire-fighting systems in the oil industry demands high quality of both material and traceability of components used. Every order is supplied with a document handbook available as electronic and/or hard copy if required. The document includes an arrangement drawing detailing all parts, operation and maintenance Manual, spares recommendation and pressure test certificate. Additional documents are available on request to be added as an extra, this includes but not limited to: material certification, radiography results, ferrite determination, micro examination, G4S/G48A corrosion test, charpy test, integral test block, dye penetrant, pickle & passivation, all to international standards. Due to the diversity of required material specification documentation, these units are custom made for each client, offering an extremely flexible and adaptable supply chain. Specifications for the following materials are available: Aluminium bronze, super duplex, titanium, lnconel, gunmetal and various grades of stainless steel.
GA Valves Sales Ltd Johnstone House, Birds Royd Lane, Brighouse, HD6 1LQ Tel: 01484 711983 Fax 01484 719848 Email: firstname.lastname@example.org Web: www.gavalves.co.uk
Hi Ve n t Ai r Re l e a s e Va l v e s Desi g n ed F o r T h e O n / O f f sh o r e P et r o ch emi cal I n d u st r y
Air vent - Air release - Vacuum Relief valves
References Many of our clients require that the details of supply are confidential so we are limited in the specific information we can release, end users include:British Petroleum, Exxon Mobil, Shell, Woodside Petroleum, Nexan Petroleum, Conoco Phillips, Total, Wartsila Oil and Gas.
Available configurations We offer an extensive range of configurations including custom request to suite your deign needs. We can offer the following: - All international or custom flange drilling’s - Threaded or flanged connection on inlet of the valve - Threaded or flanged connection on the outlet of the valve - Cowled outlet - Surge arresters - Inflow/outflow checks - Adjustable Throttled outlet - to control surge created by converging columns
Coatings Where required we can offer a wide range of both decorative and protective coatings with relevant certification, please ensure this is specified at time of enquiry.
GA Valves Sales Ltd Johnstone House, Birds Royd Lane, Brighouse, HD6 1LQ Tel: 01484 711983 Fax 01484 719848 Email: email@example.com Web: www.gavalves.co.uk
HEALTH & SAFETY
A Textile Legacy That Goes Back Over a Century For Carrington Textiles and their main production facility in the United Kingdom, Pincroft Dyeing and Printing, celebrating their 130th anniversary this year is a great milestone that reflects not only their strength and commitment, but also their capability to adapt to the different changes and challenges that the textile industry has gone through in the last century.
he story of Pincroft dates back to the 19th century, right in the peak of the textile boom, when Benjamin Davies from Adlington and brother in law James Eckersley from Duxbury after buying together the Huyton Bleachworks in 1848, started operations of the mill across the road under the name of Pincroft Dyeing and Printing company for the bleaching and finishing of fabrics in 1891. Davies and Eckersley were experienced businessmen and fabric bleachers and back in April 1885 they had invented a ‘washing and rinsing machine’ used in bleachworks with a more efficient use of energy and water. A century later, Carrington Textiles is born In 1998 Carrington Textiles is created to be the commercial arm for Pincroft, giving the factory a wider reach to global markets and a bigger platform to progress in terms of research and development, as well as marketing. Since its creation and working jointly both companies have seen a considerable increase in turnover from €50 million in 1999 to €104 million in 2019, as well as growing their export business extensively breaking into new geographical markets including Europe, Middle East, Asia and Africa. Investment and development have been a key factor for the companies’ success, with over €45 million invested in new machinery, processes, laboratories, warehousing and sustainable energy projects. This in turn has driven Carrington Textiles and Pincroft into becoming one of the largest suppliers of workwear, flame retardant, waterproof, defence and sustainable fabrics to some of the biggest companies in the world with increased production of over 15 million metres in 1999 to 55 million metres in 2019. Achieving the highest standards By enhancing fabric performance through continuous development in advanced technologies that are carefully implemented with respect to the environment as a priority, Carrington Textiles and Pincroft have achieved standards including ISO 50001, ISO 9001 and ISO 14001 for energy, quality and environmental management respectively. Other important certifications also include Oeko Tex that certifies fabrics meet humanecological requirements, and Bluesign that sets and controls standards for environmentally
friendly and safe production. Global presence Over the years Carrington Textiles has developed a strong and reliable infrastructure that promotes our presence in key markets. For that reason they have offices in France and Germany, sales representatives in a number of European countries, and a solid network of agents worldwide. Additionally, the textile manufacturer has production facilities in the UK, Portugal, Germany, Russia and Pakistan as well as their strategically located warehouses. But their global presence is also the result of decades of presence in trade shows globally. For more than 20 years Carrington Textiles has understood the importance of expo shows as a great opportunity to create new connections, strengthen relationships but most of all to learn about what’s happening in the market to be able to drive our research and development efforts. Since the late 90s the company has exhibited on five different continents, in countries that include Australia, China, France, Germany, Peru, United Arab Emirates and the United States of America, to name a few. The company’s very first exhibition after joining forces with Pincroft Dyeing and Printing, was the A+A Trade Fair in Germany back in 1999. Since then we have committed
Aerial view of Carrington Textiles and Pincroft in Adlington, United Kingdom. to regularly participating in more and more expo events every year as we constantly reach new geographical markets. Proud legacy Carrington Textiles and Pincroft have not only supplied millions of metres of fabric to armed forces around the world including the UK’s and Dutch Ministries of Defence, the Finnish and Estonian armies and the Royal Oman Police, but also have been a key player during the coronavirus pandemic by supplying more than 4 million metres (and counting) of specialised fabric to the healthcare sector in the UK and mainland Europe. Helping the community is also crucial, that’s why in the last 5 years alone over £100,000 have been given to support sports clubs and individuals, hospices, youth centres and students. Group CEO John Vareldzis, says: “Celebrating 130 years in textile manufacturing is not only a testament to our contributions to the UK’s textile movement since the late 1800s, but also to our commitment to continue providing the best quality workwear fabrics.” • For more information please visit carrington.co.uk or email firstname.lastname@example.org
Egypt to Seek Over $1 Billion in Compensation for Suez Blockage Aker BP Obtains Safety Consents for Vessel Operations
orwegian oil and gas company Aker BP has received two consents related to vessels operations from the country’s offshore safety regulator, the Petroleum Safety Authority (PSA). The first consent is for the use of two mobile drilling vessels, the Island Constructor and Island Wellserver, for light well intervention on three offshore fields, Alvheim, Skarv, and Ærfugl. The consent applies to several field/production licences until 31 December 2025. The Alvheim field is located in the North Sea while Skarv and Ærfugl fields are located in the Norwegian Sea. The Alvheim field has been developed with subsea templates tied to a production ship (FPSO). Production started in 2008. The development concept for the Skarv field is an FPSO vessel with five subsea templates with fifteen wells. The first production started in 2013. The Ærfugl field is also tied to the Skarv FPSO. Aker BP changing ERRV vessel on Ula. Furthermore, Aker BP has been given consent from the PSA for a change of use of the emergency response and rescue vessel on the Ula field. The Stril Mariner vessel currently operates as an emergency response and rescue vessel for Ula and Tambar fields, undertaking both emergency response and operational tasks. The vessel was awarded a new contract for ERRV services by Aker BP in November 2020. It has been in service for Aker BP and its predecessor BP Norge for 11 years.
Egypt will ask for over $1 billion in compensation for damages caused by the grounding of Ever Given and the resulting blockage of the Suez Canal last week, Reuters reports citing Suez Canal Authority (SCA) Chairman Osama Rabie as saying to local reporters. The compensation is also expected to cover the costs incurred for the massive salvage operation in the Suez Canal that finally managed to free the ill-fated container vessel on March 29. The amount does not cover the losses suffered by numerous shipowners whose vessels ended up queuing in the waterway for days due to the logjam. Therefore, the final bill for the incident is yet to be finalized. The owner of the ship, Japanese shipping company Shoei Kisen Kaisha, which is expected to pay for the majority of the damages, has reportedly declared general average in connection with the grounding. Meanwhile, the vessel remains anchored in the Bitter Lakes area where it is undergoing technical inspection. Aside from the ship’s seaworthiness, Egyptian inspectors have also boarded the vessel to talk to its captain and the crew to determine the potential causes of the grounding, Reuters said. The investigation is looking into the potential role of a human error in the incident. According to Rabie, Ever Given will remain in the lakes area until the investigations are complete, without specifying when could that be. The Panama Maritime Authority, the ship’s flag country, has also launched an investigation into the accident. As informed, Panama is examining preliminary reports that Ever Given suffered mechanical problems that affected its maneuverability. •
HEALTH & SAFETY
Rystad: Vaccination Hiccups Could Prevent the Recovery The vaccine distribution cycle was not expected to be perfect, but the recent spike in cases in Europe, which some are calling the third wave, is not being met with a brigade of vaccines, but with vaccine skepticism instead. Rystad Energy has modeled the impact of the possibility of extended vaccination campaign hiccups and has found that the recovery of up to 1 million barrels per day (bpd) of oil demand is at risk in 2021, depending on the duration of the setbacks.
he latest pandemic hurdle in Europe is the temporary ban of the AstraZeneca vaccine in several EU and now a handful of Asian countries, which puts the recovery of economic activity and oil demand at risk. In Rystad Energy’s Covid-19 research, we have forecasted that the AstraZeneca vaccine would make up 2.6 billion of the total global 11 billion global vaccine doses (1 inoculation is 1 dose) produced in 2021. At the moment, we estimate Western Europe boasts a near 8.5% vaccinated rate, which is forecast to reach 50% by June 2021. A ban or delay in vaccine distribution in Europe could likely be filled by other vaccine producers, but we still estimate that the associated logistical and bureaucratic obstacles would trigger a delay of Europe reaching the threshold by between one and three months. Rystad Energy currently forecasts global oil demand in 2021 at 95.2 million bpd, but under a slow vaccination scenario, caused by the AstraZeneca debacle and other possible future setbacks, oil demand in 2021 could only average at as low as 94.2 million bpd. The extent of the recovery loss will depend on the duration of the delays and consequently on how quickly vaccination campaigns progress. “We estimate that each country’s oil demand recovery will speed up after at least half of its population has been vaccinated, driven by
road fuels demand. It’s too soon to tell if the AstraZeneca hiccup will momentously dent demand or not. A complete ban of the AstraZeneca vaccine could delay reaching the
50% threshold by two months, but this scenario is a bit extreme,“ says Sofia Guidi Di Sante, oil markets analyst at Rystad Energy. “As of now, the 50% vaccination threshold may be postponed by a few weeks in some countries with negligible effects on oil demand, but again we need to wait on further developments,” adds Guidi Di Sante. Rystad Energy’s Slow Vaccine scenario accounts for a slower rate in production and distribution of the vaccines than what is officially announced. The model considers potential production or distribution stops, which can be related to capacity but also safety issues. The most serious theoretical snafu would be an issue with insufficient storage routines for the vaccines, which would trigger a potential delay in vaccination campaigns on a global scale. For more analysis, insights and reports, clients and non-clients can apply for access to Rystad Energy’s Free Solutions and get a taste of our data and analytics universe. •
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Mercedes-Benz and Siemens Launch Strategic Partnership Mercedes-Benz and Siemens plan to cooperate on advancing digitalization and automation in the automotive industry, supported by the State of Berlin. Mercedes-Benz AG aims to digitize its production processes. Siemens, a leading supplier in the field of automation, industrial software and smart infrastructure, will bring its expertise and technologies to the partnership to develop highly flexible, efficient and sustainable automotive production together with Mercedes-Benz.
örg Burzer, Member of the Board of Management of Mercedes-Benz AG, Production and Supply Chain Management: “Mercedes-Benz takes digitalization to the next level in the global Mercedes-Benz Cars production network. Together with Siemens, we are driving forward the development of sustainable future technologies - from Berlin for the whole world.” In this context, the Mercedes-Benz BerlinMarienfelde site in Germany will be transformed into a competence centre for digitalization with a focus on the development and implementation of the digital Mercedes-Benz Cars ecosystem MO360 (http://mb4.me/UWbRz2GR), in addition to the redesign of production activities. In the future, e-mobility components will also be assembled in Berlin. The company wants to secure the future for the Berlin plant, which is the oldest site in the Mercedes-Benz global powertrain production network. The MercedesBenz Digital Factory Campus in Berlin is the technological and digital nucleus for the whole Mercedes-Benz Cars production network. Its objective is to roll out the new developments that have been tested in Berlin at the MercedesBenz plants worldwide and to provide the users with the required qualifications. With the Werner-von-Siemens Centre for Industry and Science in the Siemensstadt in Berlin, there is already an excellent wealth of experience that can be incorporated into the cooperation. With the synergies of the
Siemensstadt2 and the Mercedes-Benz Digital Factory Campus Berlin, plants that represent the origin of industrialization in Germany, will be transformed into two modern digital sites. Cedrik Neike, Member of the Managing Board of Siemens AG and CEO Digital Industries: “We are further expanding our decades-long successful cooperation with Mercedes-Benz in the field of engineering and production. Together, we want to take the next big step towards sustainable and evenmore competitive automotive production. To achieve this, both partners rely on end-to-end digital technologies to connect technology, sustainability and new working environments more closely than ever before.” Siemens leading automation and software
solutions lay the foundation for the digital transformation of automotive production. The physical and virtual worlds as well as operational technology (OT) and IT can be combined with them. This opens up new possibilities for gathering, understanding and using the huge amounts of data generated in engineering and production. With innovative IoT applications, for example, production processes can be made much more flexible and energy efficient. Michael Müller, Governing Mayor of Berlin: “Today’s agreement is a clear commitment by Mercedes-Benz and Siemens to Berlin as a location for innovation and production. Both companies have long established and close ties to Berlin. With their strategic partnership, they are strengthening Berlin’s leading scientific and research location and can secure jobs and training places. We are very pleased that Siemens and Mercedes-Benz want to jointly advance the digitalization of production processes from here - and we are very happy to support networking and cooperation with potential partners from science, research and business who are working here in the capital on future-oriented digital solutions for industrial applications and production.” The State Government of Berlin welcomes and supports both the clear commitment to the production and innovation location, the transformation and the cooperation between the two companies. The State of Berlin will support the partnership, which is part of the excellent science and start-up landscape in Berlin. Against this background, the Governing Mayor of Berlin will sponsor the cooperation. •
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HEALTH & SAFETY
Equinor and Sustainability “2020 was an extraordinary year with the pandemic causing human suffering and market turmoil. I am impressed by our employees’ hard work during this year, to keep people safe and operations running. We delivered solid operational performance during this demanding year, but our results were heavily impacted by the low prices for oil and gas,” says Anders Opedal, President and CEO of Equinor ASA.
here was unprecedented volatility and decline in prices during the year, caused by the Covid-19 pandemic especially during the first half. In March, Equinor launched a 3-billion-dollar action plan to strengthen financial resilience. Delivery on the plan resulted in savings of USD 3.7 billion, including a reduction in fixed operating costs of around USD 1 billion. Equinor is positioning itself to create value and be a leading company in the energy transition and took major steps in 2020 to shape the future of the company. “We are preparing for a future that will be different from the past. Equinor aims to be a leading company in the energy transition and to build the energy industry of tomorrow,” says Opedal. Annual report In the Annual report for 2020, a new outline of the report and a table with more information on a country-by-country basis are added to facilitate a better overview of key events and results for 2020. IFRS net operating income was negative USD 3.42 billion and the IFRS net income was negative USD 5.50 billion. The results are impacted by lower prices and impairments mainly due to reduced future price assumptions. Equinor delivered adjusted earnings(1) of USD 3.49 billion before tax and USD 0.92 billion after tax, mainly adjusted for net impairments. In 2020, the cash flow from operations after tax amounted to USD 10.9 billion.
As a reaction to the market uncertainty, and to further strengthen financial resilience, Equinor reduced its cash dividend significantly and suspended share buy backs under the share buy-back programme in the spring of 2020. Total capital distribution to shareholders for the year was USD 3.39 billion. For the full year, the serious incident frequency was 0.5, down from 0.6 in 2019. The total recordable injury frequency was at 2.3, down from 2.5 in the previous year. “Although we observed a positive trend in some of our safety indicators, serious incidents at our onshore plants are a stark reminder that we need to further improve our safety performance. Together with our suppliers and partners, we must ensure implementation of existing safety initiatives and focus on extracting learnings from
previous incidents,” Opedal writes in the letter. Equinor’s management and external auditors have in accordance with requirements for SEC reporting companies assessed and concluded that Equinor’s internal control over financial reporting as of 31 December 2020 was not effective due to control deficiencies related to two specific areas. Equinor is actively undertaking remediation efforts to address the two material weaknesses. The auditors have provided an unqualified audit report on the consolidated financial statements. Sustainability report The 2020 Sustainability Report offers an overview of how Equinor works with its most material sustainability impacts. Sustainability is embedded in Equinor’s strategy, and the company is committed to long term value creation inspired and guided by the United Nations’ Sustainable Development Goals. “Society has to move towards net-zero emissions, and we aim to be a committed partner on that journey. Equinor has set clear ambitions for the future and we are delivering strong progress to achieve them,” says Opedal. In 2020, Equinor’s (scope 1 & 2) greenhouse gas emissions were 1.4 million tonnes lower than in 2019, due to energy efficiency projects, changes in the portfolio and lower activity level.
The average CO2 intensity of Equinor’s operated portfolio was 8.0 kg CO2 per barrel of oil equivalent (boe), down from 9.5 kg per boe in 2019. Going forward, Equinor expects fluctuations in the upstream carbon intensity from year to year, but the long-term direction towards lower emission intensity is clear. •
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ASIA PACIFIC - NEWS PetroChina Achieved Better-than-Expected Annual Results
n March 25, PetroChina Company Limited released its 2020 annual results. In 2020, despite challenges brought by COVID-19 and plummeted international oil price, the Company adhered to quality development and coordinated efforts on all fronts including COVID-19 prevention and control, work and production resumption, as well as reform and innovation. It vigorously implemented green and lowcarbon transition and maintained a stable production and operation. The Company’s oil and natural gas equivalent output was 1,409.7 million barrels, representing an increase of 4.8% year-on-year; with marketable natural gas output reaching 3,993.8 billion cubic feet, an increase of 9.9% year-on-year. The proportion of natural gas output continued to grow, further optimized the oil and gas production mix and led to major progress in green and low-carbon transition. The Company successfully completed the spin-off of its pipeline assets based on market principles winning high recognition from the capital market. The transaction was approved in the General Meeting, with 99.99% votes in favor. Seizing the opportunity of China being the first major economy with positive economic growth and giving full play to the synergy along the oil and gas industrial chain, the Company vigorously implemented measures to enhance quality and profitability and achieved better-thanexpected operating results with extraordinary efforts combating the pandemic and low oil price. Under the International Financial Reporting Standards, PetroChina registered a revenue of RMB 1,933.84 billion and the net profit attributable to parent company was RMB 19.01 billion. The oil and gas lifting cost was US$11.1 per barrel, representing a decrease of 8.3% year-on-year. The financial status remained healthy with asset-liability ratio down by 2.1 percentage points year-on-year. The Company’s cash flow is sound with net cash flow generated from operating activities amounting to RMB 318.58 billion, and free cash flow RMB 70.2 billion, representing an increase of 75.8% year-on-year. As the Company attaches great importance to shareholder’s return, the Board of Directors recommended a final dividend of RMB 0.08742 per share, totaling RMB 16 billion. The total amount of dividend payout for the full year will be RMB 32 billion, representing an increase of 21.7% year-on-year. PetroChina Company Limited is a joint stock limited company incorporated on November 5, 1999, upon the restructuring of China National Petroleum Corporation (CNPC). •
Aquaterra Energy Inks Multi-Million-Dollar Riser Deal
quaterra Energy, a leader in global offshore engineering solutions, has secured a multi-million-dollar (USD) riser contract with a marine vessel owner and operator, for deeper water well intervention projects mainly in the Asia Pacific region. Aquaterra Energy will deliver a large-bore (7 3/8”) AQC-CW completions and workover riser system with automated handling package that will operate in water depths of up to 1,500m. The system has been designed to withstand repeat make and breaks, whilst offering a gas tight metal-to-metal seal. The solution can be operated from a lightweight intervention vessel, semisubmersible or from a jack-up rig as a surface riser, open water subsea riser or as a landing string. The NACE compliant technology and unique pipe to connector attachment eliminates welding – making the riser lighter offering enhanced water depth deployment capacity. In addition, the ability to pressure test each connection upon make up provides enhanced environmental reassurance against well bore fluid discharge. James Larnder, Managing Director of Aquaterra Energy said: “This project marks a key milestone in our Asia Pacific success story, whilst also diversifying our AQC riser offering into deeper water operations. All our systems are intelligently engineered to be efficient with no wasted materials and a focus on quick connection to reduce operational time whilst assuring integrity. Importantly, these efficiencies also support our own and our customers’ decarbonisation efforts.” Aquaterra Energy will manage the entire project scope via its in-house engineering and project management teams. Throughout the project, Aquaterra Energy will provide fatigue utilisation and management through riser monitoring hardware to extend asset life, as well as automated hands-off connector makeup and umbilical handling equipment to improve safety and enhance offshore efficiency. •
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Total to Develop Singapore Into a Major LNG Maritime Hub for Asia
he Maritime and Port Authority of Singapore (MPA) has awarded a third Liquefied Natural Gas (LNG) bunker supplier license to Total’s subsidiary in charge of worldwide bunkering activities, Total Marine Fuels Private Limited, for a five-year term starting January 1st, 2022. This achievement follows a 10-year agreement signed by Total back in 2019, to develop an LNG bunker supply chain in the port of Singapore. It reaffirms the Company’s commitment to contribute to the country’s ambition in becoming a key LNG bunkering hub for Asia. It also underscores Total’s confidence in the role of natural gas for the global maritime industry’s energy transition and in its potential to further reduce carbon emissions from ships, through the development and future introduction of carbon-neutral bioLNG. “We are proud to be awarded by the Maritime and Port Authority of Singapore the licence to supply LNG. Singapore, as the world’s largest conventional bunkering hub with a market share of 20 percent, is well positioned to become a major hub for LNG as a marine fuel,” underlined Alexis Vovk, President, Marketing & Services at Total. “Asia’s demand for LNG bunkering is growing and the contribution of Singapore is of essence for the development of a global LNG bunkering market. Moving forward, Total will continue to step up investments to bring greater value of our integrated natural gas supply chain to customers serving this important region, ultimately contributing to our target of serving more than 10% of the global LNG bunker market.” Total has actively invested in LNG infrastructure, critical to support its shipping customers’ uptake of LNG as a marine fuel. Since November 2020, Total has been operating the world’s largest LNG bunker vessel, the “Gas Agility”, at the Port of Rotterdam. By 2022, the Company will launch another newly built LNG bunker vessel in Marseille (France), while serving the port of Singapore through a third one. As part of its strategy to reduce greenhouse gases emissions in maritime transportation, Total has in parallel chartered two VLCCs (Very Large Crude Carriers) and four Aframax-type vessels, all equipped with LNG propulsion, which will be delivered in 2022 and 2023 respectively. Total’s active efforts to develop LNG bunkering for maritime transport are in line with the Company’s climate ambition to get to net-zero emissions by 2050, together with society. Furthermore, it embodies Total’s broader marketing strategy towards the industries it serves, focusing on solutions to reduce the carbon intensity of the energy products used by its customers worldwide. Total is the world’s second largest privately owned LNG player, with a global portfolio of nearly 50 Mtpa by 2025 and a global market share of around 10%. The Group benefits from strong and diversified positions throughout the LNG value chain: gas production and liquefaction, LNG transportation and trading, and contribution to the development of the LNG industry for maritime transport. Through its interests in liquefaction plants in Qatar, Nigeria, Russia, Norway, Oman, Egypt, the United Arab Emirates, the United States, Australia and Angola, the Company markets LNG on all world markets. •
Total Partners With Shenergy Group to Jointly Market LNG in China
otal and Shenergy Group, the leading energy player in Shanghai, have signed binding agreements for the supply of up to 1.4 million tons per annum of Liquefied Natural Gas (LNG) from Total, as well as the creation of a joint venture to expand LNG marketing in China. The joint venture (Total 49%, Shenergy Group 51%) will sell LNG, supplied by Total, to customers in Shanghai and throughout the neighboring Yangtze River Delta regions, one of the main LNG markets in China. Additionally, Total will supply LNG to Shanghai Gas, the natural gas subsidiary of Shenergy Group, for its distribution business. “This deal with Shenergy Group is a great opportunity to partner with an experienced Gas & LNG player with strong ambitions, as well as a unique entry point into the downstream LNG market in China. This partnership is in line with our strategy to grow along the entire gas value chain,” said Stéphane Michel, President Gas, Renewables & Power at Total. “LNG is playing a key role in meeting the growing demand for natural gas, especially in China where we are pleased to contribute to the diversification of the energy mix.” “The Shenergy Group is very pleased to sign this partnership agreement with Total, which secures a long-term, reliable supply of LNG for the Yangtze River Delta. The Joint Venture with Total will develop the LNG downstream market and support the objective of Shenergy Group to improve the air quality and reduce emissions in the region,” said Mr. Wang Zhehong, Vice President of Shenergy Group and Chairman of Shanghai Gas. The LNG supply to the JV and Shanghai gas distribution business will be sourced from global LNG portfolio of Total through a long-term LNG Sale and Purchase agreement ramping up to 1.4 million tons per annum for a term of twenty years. It will be delivered to Shenergy’s Chinese LNG terminals. •
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ASIA PACIFIC - NEWS PTTEP Strikes Another Oil and Gas Discovery Offshore Malaysia
TT Exploration and Production Public Company Limited (PTTEP) announced a successful oil and gas discovery from the first exploration well, Sirung-1, in Block SK405B, off the coast of Sarawak, offshore Malaysia. The achievement is the latest outcome of PTTEP’s ‘Execute strategy’ which focuses on adding reserves for long-term growth. Mr. Phongsthorn Thavisin, PTTEP Chief Executive Officer, disclosed that PTTEP, through its subsidiary PTTEP Sarawak Oil Limited, commenced the drilling of Sirung-1 wildcat well in Block SK405B in January 2021. The well was drilled to a total depth of 2,538 metres where it encountered a significant oil and gas column of more than 100 metres, in the clastic reservoirs. An appraisal well is scheduled in near future to assess the upside resources. “The Sirung-1 exploration well marks PTTEP’s third discovery offshore Malaysia following SK410B’s Lang Lebah and SK417’s Dokong. PTTEP also plans to explore nearby prospects in this PSC next year. The achievements have strengthened our investment base as we continue to expand our exploration horizon in Malaysia,” said PTTEP CEO. Block SK 405B is located in the shallow waters, approximately 137 kilometres off the coast of Sarawak (Bintulu). PTTEP Sarawak Oil Limited is the operator with 59.5 per cent participating interest. MOECO Oil (SARAWAK) SDN.BHD. and PETRONAS Carigali Sdn. Bhd. holds 25.5 and 15 per cent interest respectively. Apart from the Sarawak SK405B, there are also SK410B, SK314A, SK438, SK417, PM407 and PM415, all still in the exploration stage. Major projects in PTTEP’s portfolio in Malaysia include the producing assets in Block K, SK309, SK311, the Rotan-Buloh field in Block H and the jointly operated gas fields with PETRONAS Carigali in the Malaysia–Thailand Joint Development Area. PTTEP is also a joint investor with PTT, through the PTT Global LNG Company, in the MLNG Train 9 Project, an LNG liquefaction plant in Sarawak. •
PTTEP Discovers High-Quality Gas Offshore Malaysia
TT Exploration and Production Public Company Limited (PTTEP), through its wholly-owned subsidiary PTTEP HK Offshore Limited (Malaysia Branch) or PTTEP HKO, announced a successful gas discovery from the first exploration well, Dokong-1 in Block SK417, off the coast of Sarawak, offshore Malaysia. The drilling of Dokong-1 exploration well commenced in November 2020, targeting gas in the sandstone reservoir. The well was drilled to a total depth of 3,810 metres and encountered more than 80 metres of gas column. The second exploration well will be drilled in the middle of this year as part of the exploration campaign. Mr. Phongsthorn Thavisin, PTTEP Chief Executive Officer, said “The finding of potential high-quality gas at Dokong-1 exploration well is PTTEP’s latest achievement in Malaysia following first gas production from Block H and a major gas discovery at SK410B’s Lang Lebah field. This drilling result paves the way for exploration of nearby prospects that have similar geological structures. It also presents opportunity for PTTEP to synergize future development and production of SK417 with the adjacent areas and leverage on our strong expertise in cluster development.” Block SK417 is located in the shallow waters, approximately 90 kilometres off the coast of Sarawak. PTTEP HKO is the operator with 80 percent participating interest and PETRONAS Carigali Sdn. Bhd. holds the rest. Apart from SK417 PSC, PTTEP’s portfolio in Malaysia include Block H, Block K, SK309 and SK311 PSCs and the Malaysia–Thailand Joint Development Area (MTJDA) which are producing assets; and SK410B, SK314A, SK438, SK405B, PM407 and PM415 PSCs which are under exploration. PTTEP through PTT Global LNG Company also holds a 10 percent equity in LNG Train 9 as part of the larger Malaysia LNG Complex in Bintulu. •
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RUSSIA & CIS - NEWS Gazprom Adds Over 480 Billion Cubic Meters to Its Gas Reserves in 2020
he Gazprom Board of Directors took note of the information about the ongoing work for resource base support, geological surveys, and geological exploration performed by the Company. It was highlighted that Gazprom, which has the largest reserves and output of natural gas in the world, is effectively expanding its mineral and raw material base, primarily through geological exploration.
Debt for Gas Supplies Reduced in Most Russian Regions in 2020
According to preliminary data, the year 2020 saw the Company perform 3D seismic surveys covering more than 5,000 square kilometers and drill over 57,000 meters of rock formations in Russia, including technically challenging wells with depths reaching 4,500 meters. This resulted in reserve additions exceeding 480 billion cubic meters, which is substantially higher than the production volume (452.6 billion cubic meters). Therefore, Gazprom’s reserve replacement ratio has been exceeding 1 for as many as 16 consecutive years.
The bulk of geological exploration carried out by the Company takes place near the Yamal Peninsula, in the east of Russia, and on the continental shelf. Specifically, the Yamal gas production center expanded its resource base in 2020 thanks to the discovery of the 75 Years of Victory field (202.4 billion cubic meters of gas reserves) on the Yamal shelf of the Kara Sea. Moreover, new data obtained in the course of drilling an exploration well proved that the productivity of the Leningradskoye field is much higher than anticipated. The Company is also conducting follow-up exploration at Bovanenkovskoye and Kharasaveyskoye, which are the key fields of the Yamal center, and studying the Tambeyskoye field. As part of developing the Yakutia gas production center and shaping the Irkutsk gas production center, Gazprom is performing geological exploration at the Chayandinskoye and Kovyktinskoye fields. In order to improve the efficiency of geological surveys, the Company employs cutting-edge technologies, including digital ones, thereby obtaining better data and optimizing production processes. To that end, the Company is developing an integrated information environment for geological, geophysical and field data, which allows the specialists of Gazprom and its subsidiaries to monitor and analyze the ongoing surveying and development of fields across their entire lifecycles in a comprehensive manner. •
he Gazprom Board of Directors took note of the information on improving the payment discipline with regard to domestic gas supplies, as well as on the measures being taken to settle the debt for the gas supplied, including the interaction with government authorities to perfect the current legislation that regulates the procedure of paying for gas. It was highlighted that Gazprom is fulfilling its obligations on providing reliable and timely gas supplies to its consumers. At the same time, the overdue consumer debt for gas supplies remains a pressing issue in the development of the domestic gas market. The Company is making systematic efforts to settle the issue of non-payment. In 2019, the overdue debt was reduced to RUB 174.3 billion. The debt spiked in the first half of 2020 amid the restrictions imposed to fight the spread of the coronavirus, but the situation stabilized in the second half of the year. At the end of 2020, the overdue debt totaled RUB 178.4 billion, an increase of 2.3 per cent from the previous year. Nevertheless, Gazprom followed the decision made by the Russian Government and did not put restrictions on gas supplies as a disciplinary action against the owners and tenants of residential properties in the period from April through December. One of the key trends of 2020 was the growing number of constituent entities of the Russian Federation that managed to lower their debt. This number rose from 34 to 49, and the leaders in debt reduction included the Moscow, Ulyanovsk and Volgograd Regions, the Republic of Tatarstan, and the Astrakhan Region. Heat suppliers continue increasing the level of their payments and reducing their debt. Thanks to the responsible efforts made by regional authorities in cooperation with this category of consumers, heat suppliers in St. Petersburg and in the Leningrad and Kaliningrad Regions have practically no debt owed for gas. The Company is implementing a set of measures to improve the payment discipline among consumers. As a result of legal claims and cooperation with law enforcement and supervisory authorities, a total of RUB 117.1 billion was collected last year. Another RUB 8.7 billion was paid to Gazprom under the debt repayment schedules signed with 30 constituent entities of the Russian Federation. In the course of collaboration with regional administrations, subsidies in the amount of RUB 37.4 billion were allocated in 2020 to cover lost revenues for heat suppliers. The Company continues to take stock of its subscriber bases, including those in the North Caucasus Federal District, and to correct inaccuracies in the Federal Information Address System. Consistent development of the online digital service that allows consumers to pay for gas remotely in a quick and convenient manner is also yielding good results. The user base of the Subscriber Account service grew by 24 per cent to 4.1 million people in 2020. The amount of payments collected last year was RUB 6.5 billion, an improvement of 31 per cent against 2019. In addition, the Company is taking part in streamlining the current legislation regarding gas supplies in conjunction with relevant ministries and agencies. The Management Committee was tasked with continuing the work on settling the receivables for the gas supplied, improving the gas consumption discipline, and interacting with government authorities to perfect the current legislation of the Russian Federation that regulates the procedure of paying for gas. •
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NEWS - RUSSIA & CIS SOCAR-Equinor Exploration Project Delivers Encouraging Initial Results
n March, SOCAR President Rovnag Abdullayev met a delegation led by Al Cook, Executive Vice President for Development and Production International of Equinor. The meeting focused on the development of Karabakh field and the exploration of prospective structures, carried out jointly by SOCAR and Equinor on equal sharing basis. The participants discussed the results of preliminary exploration work on Dan Ulduzu - Ashrafi - Aypara prospects and possible scenarios for next steps. The Exploration of Dan Ulduzu - Ashrafi - Aypara was launched in the second half of 2018, 2D and 3D seismic exploration was completed in 2019. The results were processed in 2020, and their interpretation is currently underway. Preliminary results of interpretation demonstrated that oil and gas reserves in these prospects are higher than previously expected. Exploration drilling may be carried out in the future to prove the reserves. The encouraging results from the new prospects could necessitate the reconsideration of development plan of the Karabakh field. In the coming weeks, a joint working group of SOCAR and Equinor shall consider various options for the continuation of Karabakh project and explore opportunities for synergy between the development of Karabakh field and prospective new fields. In the meeting, the importance of Azerbaijan for Equinor was emphasized and the intention to grow in this country was expressed. The parties aim to reach the highest levels of production on the jointly exploited fields during this decade, when oil and gas prices are expected to peak. From this viewpoint, it is important to accelerate the exploration and drilling on these structures. The Norway’s Equinor (formerly Statoil) and SOCAR are cooperating in Azerbaijan on the development of the Karabakh field and on the exploration and production at the prospects Ashrafi-Dan UlduzuAypara. Both companies participate in the Azeri-Chirag-Deepwater Gunashli (ACG) oil field development project. In May 2018, SOCAR Karabakh and Equinor signed a Risk Service Agreement for the development of the Karabakh oil field in the Azerbaijani sector of the Caspian Sea. •
Gazprom and YaNAA Agree to Extend Cooperation to 2021–2023
working meeting between Alexey Miller, Chairman of the Gazprom Management Committee, and Dmitry Artyukhov, Governor of the Yamal-Nenets Autonomous Area (YaNAA), took place today via a video link. The parties discussed relevant issues of cooperation. The Company is developing a major gas production center on the basis of the Bovanenkovskoye field in the Yamal Peninsula. Pre-development of the second key field in the region, Kharasaveyskoye, is underway, and geological exploration is being carried out on the Yamal shelf of the Kara Sea. Efforts are in progress to expand the regional network of compressed natural gas (CNG) filling stations where consumers can refuel vehicles with natural gas – the most eco-friendly and cost-efficient type of fuel. Currently, three CNG stations of Gazprom are active in the YaNAA, namely in Nadym, Novy Urengoy, and Yagelny. In 2021, the Company started to design another station in Noyabrsk. Particular attention at the meeting was paid to the implementation of the 2021–2025 regional program for gas supply and gas infrastructure expansion. In the course of the meeting, Alexey Miller and Dmitry Artyukhov signed a new Agreement of Cooperation for 2021–2023. This is the first three-year agreement of this kind with the YaNAA. Previously, the parties used to document their arrangements on an annual basis. The document outlines a set of top-priority areas for further interactions. Gazprom is going to, inter alia, continue its investment activities in the region. As before, the Company will reliably provide local consumers with energy resources, make payments to the regional budget in line with Russian legislation, and help settle issues of social significance. In its turn, the YaNAA Government will go on facilitating the implementation of Gazprom’s investment projects through, among other things, assisting the Company in addressing land issues and obtaining permits for the projects. The main document regulating the cooperation between Gazprom and the YaNAA is the General Agreement. Agreements of cooperation are signed as a follow-up to this document. The parties have also signed the Memorandum of Cooperation within the Yamal project and the Agreement on wider use of natural gas as a vehicle fuel. Gazprom will channel RUB 561.9 million into the 2021–2025 regional program for gas supply and gas infrastructure expansion. The gas pipeline branch to Labytnangi, Salekhard and Kharp will undergo a renovation, and a gas distribution station will be built to bring gas to the village of Kharsaim.•
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NEWS - RUSSIA & CIS NOVATEK Reports Preliminary Operating Data
n the first quarter 2021, NOVATEK’s hydrocarbon production totaled 158.1 million barrels of oil equivalent (boe), including 20.15 billion cubic meters (bcm) of natural gas and 3,129 thousand tons of liquids (gas condensate and crude oil), resulting in an increase in total hydrocarbons produced by 7.9 million boe, or by 5.3% as compared with the first quarter 2020. Preliminary natural gas volumes sold in the Russian Federation were 19.56 bcm, representing an increase of 7.2% as compared with the prior year period, whereas LNG volumes sold on international markets amounted to 1.87 bcm. The total natural gas sales volumes, including volumes of LNG sold, aggregated 21.43 bcm, representing an increase of 3.6% as compared with the first quarter 2020. The decrease attributable to volumes sold on international markets was mainly due to the decrease of Yamal LNG shareholders’ share, including NOVATEK’s share, of LNG volumes sold on the spot market, and a corresponding increase in Yamal LNG direct sales under long-term contracts. The Company processed 3,127 thousand tons of unstable gas condensate at the Purovsky Processing Plant, representing an increase of 10.8% as compared with the corresponding volumes processed in the prior reporting period. NOVATEK processed 1,772 thousand tons of stable gas condensate at the Ust-Luga Complex, representing a decrease of 0.8% in volumes processed at the facility in the first quarter 2021. According to preliminary data, petroleum product sales volumes aggregated 1,613 thousand tons, including 1,022 thousand tons of naphtha, 252 thousand tons of jet fuel, and 339 thousand tons of fuel oil and gasoil. NOVATEK sold 1,020 thousand tons of crude oil and 548 thousand tons of stable gas condensate. As at 31 March 2021, NOVATEK had 0.1 bcm of natural gas, including LNG, and 713 thousand tons of stable gas condensate and petroleum products in storage or transit and recognized as inventory. •
RMC, TT-Line Finalize Deal for Ferry Duo
innish shipbuilder Rauma Marine Constructions and Australian shipping company TT-Line Company have finalised an agreement for the construction of two car and passenger ferries after the deal was cancelled last year due to the COVID-19 crisis. As informed, the construction of TT-Line’s vessel pair will begin in spring 2022. Last summer, TT-Line had to withdraw from a previous memorandum of understanding due to the coronavirus pandemic. Negotiations resumed in March this year, initiated by the Tasmanian government. Jyrki Heinimaa, CEO of Rauma Marine Constructions, said he is happy with how the two parties reached the agreement despite a very challenging situation worldwide. “We eagerly await these three years of fruitful collaboration with RMC. The vessels will also make extensive use of the expertise of Tasmanian companies,” Bernard Dwyer, CEO of TT-Line Company, commented. The first vessel is planned to be delivered to TT-Line in late 2023 and the second one in late 2024. Once completed, the vessels will operate in challenging conditions on the Geelong–Devonport route running between mainland Australia and the island State of Tasmania. The ferries will accommodate 1,800 passengers and will have an approximate gross tonnage of 48,000. The vessels will replace the Spirit of Tasmania I and II, both built in Finland in 1998. According to RMC, the agreement with TT-Line is a positive signal for the shipbuilder’s financial outlook for 2021, as it raises the company’s orderbook to approximately EUR 1.6 billion and increases the number of ship projects at the shipyard to four. RMC also achieved a good financial result last year despite the global coronavirus pandemic. In 2020, the company’s net sales more than quintupled from EUR 38.1 million in the previous year to EUR 220.1 million. Operating profit, on the other hand, increased from EUR 1.9 million in the previous year to EUR 6.7 million. “We will continue on our set growth path to build car and passenger ferries in Rauma, which also means stable growth in the shipbuilding industry in Finland. Last year, we strengthened our personnel by almost 50 per cent, meaning our organisation is more than ready for a new 3,500-person-year project,” says Heinimaa. •
IMPORTANT EVENTS CALENDAR
SPE/IADC Virtual International Drilling Conference and Exhibition 08.03.2021 - 12.03.2021 Virtual http://www.drillingconference.org AntwerpXL 2021 10.03.2021 - 12.03.2021 Antwerp https://www.antwerpxl.com The 18th Asian Oil, Gas & Petrochemical Engineering Exhibition 08.06.2021 - 10.06.2021 Kuala Lumpur Convention Centre https://www.oilandgas-asia.com/ The 28th World Gas Conference (WGC 2021) 21.06.2021 - 25.06.2021 Daegu, Korea https://www.wgc2021.org/ ADIPEC 2021 08.11.2021 - 11.11.2021 Abu Dhabi, UAE https://www.adipec.com/ CIPPE Beijing March 30th - April 1st 2021 https://en.cippe.com.cn/ European Gas Virtual 2021 26 January 2021 - 28 January 2021 Virtual https://www.energycouncil.com/event-events/european-gas-conference/ 23rd World Petroleum Congress Dec 5-9th 2021 Houston, Texas, USA https://www.23wpchouston.com/ Offshore Technology Conference 16-19 Aug 2021 Houston, Texas, USA http://2020.otcnet.org/ The 28th World Gas Conference (WGC 2021) 21.06.2021 - 25.06.2021 130 Gongpyeong-dong, Jung-gu, Daegu, South Korea https://www.wgc2021.org/