Europe's first commercial-scale floating offshore windfarm.

Project to support the decarbonization of the British energy system by supplying 1.5 TWh renewable power annually to the grid.

Aker Solutions has awarded ABB a front-end engineering and design (FEED) contract for the 560 MW Green Volt floating offshore wind project, led by Vårgrønn and Flotation Energy. Green Volt, located 80km off the coast of Peterhead in northeast Scotland, aims to become the first commercial-scale floating wind farm in Europe and will contribute to the decarbonizsation of the country's energy system.

When fully operational in 2029, the project is expected to supply 1.5 TWh of renewable power to the grid annually - enough to supply approximately 555,000 homes a year - contributing to both the British Government’s commitment to reach net zero by 2050 and Scotland’s target for net zero by 2045.

As part of FEED Phase 1, ABB will work alongside Aker Solutions on the complete electrical study for the facility, including system design and high voltage equipment. ABB will lead the electrical infrastructure development, including integrated automation and telecommunications systems for the offshore platform and onshore substation. ABB will also manage the integration of renewable energy into the grid, deploying advanced power and energy management systems to optimize operations.

“Our partnership with Vårgrønn, Flotation Energy and ABB underscores our dedication to contribute to Europe’s vision for accelerating the deployment of offshore wind,” said Henrik Inadomi, Executive Vice President for New Energies at Aker Solutions. “This collaboration will also make a significant contribution to our shared commitment to building profitable value chains for the European offshore wind industry.”

ABB is actively involved in seven offshore wind projects across Britain, which collectively represent 9 GW of capacity. These include Dogger Bank, currently the world’s largest offshore wind farm. By leveraging its advanced automation, electrification and digital solutions, ABB helps offshore wind projects minimise operational costs, optimise energy production and ensure the safe, reliable integration of renewable power into the grid.

“We are proud to partner with Aker Solutions on the Green Volt project and deploy our technologies to help accelerate progress towards the UK’s 60 GW offshore wind capacity target,” said Per Erik Holsten, President of ABB Energy Industries. “Wind power currently accounts for almost 30 percent of the UK’s total electricity generation, with a record daily amount of 21.8 GW generated last year, and projects like Green Volt are important to sustaining this momentum.”

Developed under Crown Estate Scotland’s Innovation and Targeted Oil and Gas (INTOG) leasing round, the project will also bolster the Scottish and overall UK supply chains for floating offshore wind technology.

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@ABBgroupnews @ABB_Energy @ABBMeasurement @abb_automation @admiralpr #PAuto #Energy

Extended switch product range for port technology.

An extended range of switchgear products is being launched by steute with DNV approvals. These switching devices have been developed for applications often involving exposure to damp and wet (including saltwater). Their key features also include a wide temperature range (down to -60oC, depending on the series). The DNV approval certifies that they are mechanically robust and able to withstand shocks, impacts and vibrations up to 4 g – a combination frequently, but not exclusively demanded by the maritime industry, e.g. in shipbuilding or on oil rigs.

To date, the steute range of DNV-approved switchgear comprised magnetic sensors and safety sensors, as well as foot switches in "Extreme" variants. This range has now been extended to include the three universally applicable position switch series Ex 97, Ex 98 and Ex 99. All three series are compact and robust, and can be adapted to the individual case in question by selecting different actuators. A high protection class (IP 66/67) is a matter of course, as is certification for Ex zones 1 and 21 (gas Ex and dust Ex).

Additional features of these position switches include compact and standard dimensions to EN 50047 (Ex 97) and EN 50041 (Ex 98 and 99), metal enclosures (Ex 98) and universal mounting options. All three series are also available as non-Ex variants.

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@mepaxIntPR #steute #Marine #Pauto #Automation

Downhole monitoring.

Technology to help Norwegian energy company develop the largest untapped oil field in the North Sea.

Altera Infrastructure

Norwegian energy producer Equinor has chosen Emerson to provide advanced well completion monitoring systems for its Rosebank oil and gas field development offshore in Great Britain.

Emerson’s suite of Roxar™ downhole monitoring tools will empower Equinor to use advanced oil recovery techniques, optimize reservoir performance and verify well integrity in real time. The Rosebank field is a key asset in Britain’s effort to provide energy security for its citizens. The Rosebank field is estimated to contain over 300 million barrels of recoverable oil resources. The first phase of development will utilise a refurbished, electrification-ready floating production storage and offloading vessel connected to a subsea production system.

Continuous access to pressure and temperature data from active wells is a critical requirement to operate safely, optimize production, and maintain well integrity. Collecting this data is challenging, however, due to the harsh environment, limited onsite staff, and safety risks associated with active wells.

To address this, Emerson is providing Equinor with its unique Roxar Integrated Downhole Network technology, in close cooperation with its local partners in Britain and Norway. The system will provide operational insight needed to assist Equinor in maintaining high production levels, manage risk, and meet regulatory requirements.

Startup of the Rosebank field’s first phase is planned for 2026-2027.

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@EmersonExchange @EMR_Automation @Emerson_News  @Equinor @HHC_Lewis #PAuto #Britain #Norway #Offshore

Protection from catastrophic actuator failure.

Severe injury or death can be caused by the explosive forces released if a high-pressure spring-loaded actuator device fails, along with significant damage to equipment and facilities. However, there is often a lack of regular inspection and maintenance, and the risks have attracted little attention in terms of technology or regulation. A pioneering new energy containment safety device designed to reduce these risks has been launched by Survitec.

David Montgomery, Head of Sales at Survitec, asserts: “The introduction of the Gauntlet is a testament to our proactive stance on safety enhancement. The absence of detailed regulatory control pertaining to valve actuator failures or maintenance of this critical component is a pressing issue that demands immediate attention. We urge regulators to initiate further discussions and ask operators to act promptly to safeguard their personnel and critical plants in the event of an uncontained failure of an actuator.”

Compatible with all valve actuator types, the Survitec Gauntlet is a protective sleeve constructed from lightweight “bullet-proof” para-aramid armouring, ten times as strong as steel, and designed to contain the unpredictable forces of failure.

Technically qualified by the classification society Lloyd’s Register, the Survitec Gauntlet provides immediate containment protection, enhancing safety measures and minimising potential hazards. It is of minimal weight, placing no additional stress on the actuator, and protects the workings of the actuator from further corrosion and component degradation.

Survitec has supplied its Gauntlets to a majority of operators, including super-majors in the North Sea, and has recently received an order from a Spanish oil and gas operator.

Valve actuator failures offshore are often due to corrosion and the age of the units, with hundreds of actuators in service on each offshore installation.

Paul Gwynne, Sales & Contracts Manager at Survitec, said: “The valve return spring sits in a pre-loaded or loaded condition and is powerful enough to close down the valve even during full operation. However, far too many of these actuators have been left to degrade. We are now seeing hundreds in an unsafe or unknown condition – which may be intensified by pneumatic and/or hydraulic control pressures and, therefore, a huge issue and possible danger to equipment and personnel.

“What is known is that many actuators have suffered significant corrosion of the unit's internal workings, not only the exterior weather shield, which is visible. The problem can be compounded when these actuators are tagged as non-operational or decommissioned, no longer serviced but in place, but still containing a pre-load force in the spring, which can be equivalent to several tonnes depending on the size of the actuator.

“There have been a lot of occasions where the spring has eroded to the point of failure, then failed catastrophically, or the retaining bolt and end cap have failed and been ejected. So much so that the UK Health and Safety Executive has advised all operators to enforce action in this area. The force and impact of an actuator failure can be violent and often potentially fatal, impacting people, critical plants and even pipelines.”

The concept of the safety device was developed due to issues identified in the North Sea oil and gas sector, oil rigs, platforms, and floating installations, such as FPSOs and FSRUs. The Survitec Gauntlet can be applied to any facility that operates actuator valves and where risks need to be mitigated.

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@survitec @SCLPatrik #PAuto #Safety

Reliable network infrastructures for oil and gas industry.

Rugged networking devices combined with simplified management software are indispensable in strengthening the competitiveness of companies in the oil and gas industry  - Alvis Chen, Integrated Marketing Manager,  Moxa.

The oil and gas sector needs network infrastructures that satisfy the highest reliability standards to survive its challenging working conditions. In this industry, network failures can have costly repercussions, such as decreased operational efficiency, jeopardized on-site safety, and diminished organizational competitiveness.

Companies in the oil and gas industry understand that to guarantee precise process automation and real-time monitoring for operations that run around the clock, they need robust, effective, and future-proof network solutions. Two real-world examples that demonstrate network reliability to these operations are provided below.

Application 1: Reliability on the Seas—Offshore Oil Drilling.
The hostile atmosphere of offshore oil fields presents serious risks and difficulties for network devices. To successfully monitor a drilling platform remotely, the entire network infrastructure needs to be extremely reliable and available. In addition to redundant wired or wireless network systems with failover capability, the network equipment must comply with industrial standards that certify its ability to operate in an environment with varying temperatures, corrosion, and vibration.

A robust network architecture incorporating redundancy will prevent disruptions that create downtime and reduce operational effectiveness. Moreover, devices that meet rigorous DNV GL maritime certification are required to ensure reliability in the face of marine hazards while Class I Division 2 (CID2), IECEx or ATEX Zone 2 hazardous area certifications must be installed in explosive gas environments. Implementing these measures enables offshore oil-drilling operations to function effectively despite rapid temperature changes, harsh corrosive conditions, and continuous vibrations.

An example of this type of industrial device is the Moxa EDS-G4012 managed Ethernet switch. Certified for use in C1D2 environments and compliant with IEC 62443-4-2 industrial cybersecurity standards, the switches come equipped with 12 Gigabit Ethernet ports with PoE and up to four 1 Gbps or 2.5 Gbps fiber-optic ports, making EDS-G4012 switches ideal for upgrading an existing network to Gigabit speed or building a new full Gigabit backbone. Redundant Ethernet technologies such as Turbo Ring, Turbo Chain, and RSTP/STP increase the reliability and availability of the offshore network backbone.

Application 2: Monitoring the Lifeblood—Oil Pipelines.
The role of oil pipelines is to distribute crude oil from drilling rigs to oil storage tanks and then to refineries. Typically, pipelines span several thousand miles over harsh terrain and require a central SCADA system based on Synchronous Digital Hierarchy (SDH) and microwave architecture to measure, monitor, and control the status of field instruments across the entire oil flow. Multiple pumping stations, such as block valve stations and compressor stations, keep the pressure in the pipeline constant.

Pipeline operators can quickly detect, locate, and prevent or resolve leaks, damages, and breaks by deploying a rugged, extendable fiber-optic Ethernet network. Fiber networks are robust, highly available, and extremely fast. This network will include an integrated remote monitoring and surveillance service for pipeline operations to improve safety and reduce the total cost of pipeline maintenance.

Overseeing a pipeline network requires a responsive visualization tool. Moxa MXview network management software is optimized for networking device configuration, monitoring, and diagnosis in pipeline applications. It is an integrated management platform that can discover up to 2,000 Moxa networking devices and SNMP/IP devices installed on subnets. Selected network components can be managed via a web browser from local and remote sites—anytime, anywhere. Visualization is possible of redundant link status and device roles, security status of network devices, third-party device icons, network traffic loading, and power consumption of managed PoE devices.

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@Moxa_Europe @OConnellPR #Energy #PAuto #Oil_Gas

The blue economy.

Leagan Gaeilge

A conference on the Blue Economy will be held in Údarás na Gaeltachta’s head office in Na Forbacha,(Gaillimh IRL) on the 29th November 2022, as part of Asia Business Week. This conference, focussing on Marine Innovation and Offshore Wind Energy, will examine developments in the Blue Economy in Ireland and internationally.

Among the speakers on wind energy at next week’s conference will be Martin Murray, CEO of Asia Matters, Séamus Mc Cabe, senior development director with Corio Generation, Jayasurya Francis, India Director with the Global Council of Wind Energy and Dr. Edel O’ Connor, Business Development Director with the IMDO, the Irish Marine Development Office.

Seán Mulvany, senior investment manager with the Irish Strategic Investment Fund, will take part in the panel discussion on marine innovation, along with Máire Ní Éinniú, Blue Economy specialist with Údarás na Gaeltachta, Caroline Bocquel, Interim Chief Executive with Bord Iascaigh Mhara (Sea Fisheries) agus Dr. Colin Hannon, Senior Research Fellow at ATU.

Through their participation in Asia Business Week, Údarás na Gaeltachta aims to develop and strengthen connections between Asian countries and the west of Ireland, attract Asian investors to invest in businesses in the Gaeltacht and develop new markets for Gaeltacht companies.

Martin Murray, CEO of Asia Matters siad “The Asia marketplace is responsible for half the world’s GDP, and that’s where Irish businesses should be focusing their energies on. Business across Asia is relationship-based, rather than the transactional way of doing things we are used to in the West. Any business wanting to expand in Asia, especially businesses in the west of Ireland, would benefit enormously from the invaluable knowledge and experience that our speakers will be sharing.”

“This conference in Údarás na Gaeltachta is a great opportunity to examine the potential of the Blue Economy in the west of Ireland and to see that potential in an international context," according to Colm Ó Coisdealbha, Interim CEO of Údarás na Gaeltachta. “Údarás na Gaeltachta has a deep understanding of the importance of strategic connections with organisations and companies all over the world. We welcome the opportunity to be involved with Asia Matters for Asia Business Week; speakers with a wealth of experience will share their knowledge and insights, and participants will certainly benefit from their attendance at the events throughout the week.”

• Those wishing to attend virtually should register here.

@UdarasnaG @asiamatters_biz #Marine, #Offshore #Energy

An eacnamaíocht ghorm.

Mar chuid de sheachtain ghnó Asia Matters, beidh Údarás na Gaeltachta ag reáchtáil seimineár ar na Forbacha (Gaillimh) ar an Eacnamaíocht Ghorm ar an 29 Samhain 2022, ag díriú ar an Nuálaíocht Mhara agus ar Fhuinneamh Eischósta, comhdháil ag a mbeifear ag tabhairt léargais ar staid na heacnamaíochta goirm in Éirinn agus ar fud na cruinne. 

Ina measc siúd a bheas ag labhairt faoi cheist an fhuinnimh eischósta, beidh Martin Murray, Príomhfheidhmeannach Asia Matters, Séamus Mc Cabe, stiúrthóir forbartha sinsireach leis an gcomhlacht Corio Generation, Jayasurya Francis, Stiúrthóir na hIndia sa gComhairle Domhanda d’Fhuinneamh Gaoithe agus an Dr. Edel O’ Connor, Bainisteoir Forbartha Gnó leis an IMDO, Oifig Forbartha Muirí na hÉireann.

Beidh Seán Mulvany, bainisteoir sinsireach infheistíochta le Ciste Straitéiseach Infheistíochta na hÉireann ag glacadh páirt sa díospóireacht faoin nuálaíocht mhara, maraon le Máire Ní Éinniú, speisialtóir san eacnamaíocht ghorm le hÚdarás na Gaeltachta, Caroline Bocquel, Príomhfheidhmeannach Eatramhach Bhord Iascaigh Mhara agus an Dr. Colin Hannon, ó Ollscoil Theicneolaíochta an Atlantaigh.

Trí rannpháirtíocht in Asia Matters, tá sé mar aidhm ag Údarás na Gaeltachta teagmhálacha a fhorbairt agus a chothú idir iarthar na hÉireann agus tíortha na hÁise, infheisteoirí as an Áis a mhealladh chun infheistíocht a dhéanamh i ngnólachtaí Gaeltachta, agus margaí nua san Áis a aimsiú do chomhlachtaí sa nGaeltacht.

“Tá margadh na hÁise freagrach as leath de Olltáirge Intíre (GDP) an domhain agus ba chóir go mbeadh gnólachtaí na hÉireann ag féachaint i dtreo na dtíortha sin," arsa Martin Murray, Príomhfheidhmeannach Asia Matters. "Tá cúrsaí gnó san Áis bunaithe ar chaidreamh pearsanta agus ar theagmhálacha – bheadh an t-eolas agus an taithí atá le roinnt ag ár gcainteoirí le linn na seachtaine seo ina bhuntáiste d’aon chomhlacht atá ag iarraidh forbairt a dhéanamh i dtreo na hÁise, go háirithe gnóanna san iarthar."

Dúirt Príomhfheidhmeannach Eatramhach Údarás na Gaeltachta, Colm Ó Coisdealbha “Is iontach an deis í an chomhdháil seo in Údarás na Gaeltachta le féachaint ar na féidearthachtaí a bhaineann leis an Eacnamaíocht Ghorm in iarthar na hÉireann agus é sin a chur i gcothéacs idirnáisiúnta. Tá an-tuiscint ag Údarás na Gaeltachta ar an tábhacht atá le nascanna straitéiseacha le heagraíochtaí agus comhlachtaí ar fud an domhain. Sa gcomhthéacs sin, tá muid thar a bheith sásta bheith rannpháirteach in imeachtaí Asia Business Week i dtaca le Asia Matters; beidh cainteoirí a bhfuil taithí den scoth acu ag roinnt a gcuid saineolais agus is cinnte go mbeidh an-tairbhe le baint ag na rannpháirtithe as imeachtaí uile na seachtaine.“

• Is féidir freastail go fíorúil ach clárú anseo.

@UdarasnaG @asiamatters_biz #Marine, #Offshore #Energy

Carbon-efficient production offshore!

Operational support services to optimise oil and gas production efficiency, reduce energy consumption and emissions.

A five-year framework agreement with Equinor to provide operational support services to ensure continued safe and optimised oil and gas production from its pioneering Martin Linge platform in the Norwegian North Sea has been signed by Emerson. The service agreement, which includes options for three additional five-year periods, covers maintenance and upgrades of the control technology, software and instrumentation. These technologies are helping to accelerate carbon-efficient production and empower remote operation from onshore for increased worker safety and reduced operating costs.

Photo: Jan Arne Wold & Øyvind Gravås/Equinor.

Martin Linge is a significant development for Norwegian oil and gas production, with expected recoverable resources of around 260 million barrels of oil equivalent. Emerson’s technology, project expertise and global resources were crucial in helping achieve first oil safely, and with the award of this service contract, Equinor gains continued support to optimise production, reduce energy consumption and emissions, and maximise the potential of the Martin Linge development.

This development is situated 42 kilometres west of Oseberg, was the first platform on the Norwegian continental shelf to be started up from shore. The 63 billion Norwegian krone (USD 7.3 billion) mega-project includes a production platform and a permanently anchored floating storage and offloading (FSO) vessel. These facilities are powered from onshore via the world’s longest alternating-current sea cable, helping to reduce CO2 emissions by 200,000 tonnes per year. Oil is processed on the FSO vessel before being transported in shuttle tankers to the global market, while gas is transported via pipeline to St. Fergus, Scotland.

“With proven automation technologies, collaborative work practices and extensive experience, Emerson is the ideal choice for a trusted partner on energy industry projects of this scale and magnitude,” said Mark Bulanda, executive president of Emerson’s Automation Solutions business. “With this service agreement, we look forward to helping Equinor achieve continued safe and carbon efficient production.”

The award of the service agreement follows Emerson’s implementation of a complete automation solution for the project, which incorporates the company’s DeltaV™ distributed control system; advanced wired and wireless measurement instrumentation; critical control, emergency shutdown and isolation valves; metering technology and asset management software. This technology enables both the platform and the FSO vessel to be mainly operated from an onshore control room in Stavanger, with offshore operators able to access the control system interface via mobile handheld devices, resulting in increased worker flexibility and efficiency. Controlling the production facilities in this manner enables three shifts of operators to work from onshore rather than offshore, reducing risk to personnel and minimising costs.

Emerson’s cloud engineering services and digital twin technology, played a crucial role in the successful delivery of the project and first oil being safely achieved. The company’s Remote Virtual Office (RVO) platform enabled project personnel around the world to collaborate securely in a virtual engineering, commissioning and testing environment, regardless of their location. This not only reduced travel requirements – which was vital due to COVID-19 restrictions – but also had a significant impact on project schedule, risk and costs. Emerson’s digital twin technology also enabled significant project and operational benefits such as streamlining commissioning of the control system, helping Equinor train its operators to experience real-life scenarios before the control system went live, and make continued improvements that help to optimise production, and reduce energy consumption and emissions.

@EMR_Automation @Emerson_News @EmersonExchange @Equinor @HHC_Lewis #PAuto #Oil #Norway

Automotion for first offshore green hydrogen production process.

Emerson is helping accelerate technology development for large-scale offshore green hydrogen production. The company is developing software and systems to enable safe and efficient operation of the world’s first offshore green hydrogen production process on an operational gas platform.

The PosHYdon project is a pilot that aims to validate the integration of offshore wind power and offshore natural gas and hydrogen production at sea – generating renewable fuels by harnessing a green energy source. The Neptune Energy-operated platform Q13a-A in the Dutch North Sea will host the project, which will provide insight into electrolyser efficiency from a variable power supply and the cost of installing and maintaining a green hydrogen production plant on an offshore platform.

Green electricity will be used to simulate the fluctuating supply from wind turbines and power the production process, which will convert sea water into demineralised water and then safely produce hydrogen via electrolysis. The hydrogen is then blended with the natural gas and transported to the coast, via the existing gas pipeline, and fed into the national gas grid. The 1 MW electrolyser is expected to produce up to three tons of hydrogen per week.

“Hydrogen is regarded as the ‘fuel of the future’, but with ambitious decarbonisation and net zero emission targets, it is essential to expand production capacity and accelerate the transition to hydrogen produced using sustainable energy,” said Mark Bulanda, executive president of Emerson’s Automation Solutions business. “Through the PosHYdon project, we – together with the consortium partners – hope to provide a pathway to large-scale offshore green hydrogen production and make a significant contribution to the energy transition process.”

The DeltaV™ distributed control system, DeltaV safety instrumented system and DeltaV Live operator interface software will manage the desalination and electrolyser units, gas blending and balance of plant equipment. By meeting the unique application challenges, including variable desalinated water feedstock and power supply, DeltaV software and systems will provide enhanced safety, process uptime and operational efficiency. The solution will ensure the existing natural gas operations remain unaffected and blended gas meets its required specification. Integration with the existing offshore systems and communication with onshore operations will maximise process visibility and prevent unforeseen issues.

“The PosHYdon project creates a unique opportunity to develop the steps required to ensure safe, large-scale green hydrogen production at sea,” said Bulanda. “Emerson’s experience across the hydrogen value chain, wind power and offshore energy industries will help achieve successful project execution, and our proven technology will ensure safe and efficient operations in this first-of-a-kind application.”

PosHYdon is being developed by consortium partners Nexstep, TNO, Neptune Energy, Gasunie, Noordgastransport, NOGAT, DEME Offshore, TAQA, Eneco, Nel Hydrogen, InVesta, Hatenboer, Iv-Offshore & Energy and Emerson. The project has been awarded a €3.6 million grant from The Netherlands Enterprise Agency (RVO) under the agency’s Demonstration Energy and Climate Innovation scheme, which invests in renewable energy developments, including hydrogen pilots.

@Emerson_News @EMR_Automation @HHC_Lewis #PAuto #PosHYdon #Netherlands

Hazardous location luminaires.

A new solution for the oil and gas industry to easily and safely illuminate land-based drilling rigs has been unveiled by Emerson. The Appleton™ Rigmaster LED linear luminaire streamlines the cumbersome and time-consuming task of installing and maintaining bright, energy-efficient lighting in hazardous areas on drilling rigs.

“Rig maintenance workers require linear luminaires that are rugged and long-lasting yet compact and easy-to-install, which can be a difficult solution to find for the engineers responsible for designing rig electrical systems,” said Mustafa Bengali, lighting product manager for Emerson Automation Solutions. “The Appleton Rigmaster solves these challenges by integrating LED technology into a lightweight, low-profile package that performs durably, is resistant to harsh conditions and damaging vibrations, yet allows faster, safer installations throughout the drilling rig.”

Minimal weight is a top priority for rig hands who must climb a derrick hundreds of feet high to install or change a fixture. The Appleton Rigmaster LED weighs a mere 4.5kg, making it significantly lighter than similar fixtures that can weigh as much as 13.5kg. Although compact, it delivers 8000 lumens of uniform lighting to promote a safer working environment. Even when used under a canopy or inside an analyser house, the diffused lens option makes the Rigmaster LED an ideal solution for comfortable, no-glare illumination. Moreover, the Rigmaster LED’s wide distribution of light translates into fewer fixtures being needed in the rig’s mud pit, shaker, cellar and derrick. High-efficiency LED drivers consume less than half the energy of standard T8 fluorescent fixtures, further lowering direct cost of operations and minimising strain on the diesel generators that typically power drilling rigs.

Along with being lightweight, the Appleton Rigmaster LED provides installation flexibility in hazardous locations by offering a variety of mounting options that are well suited for retrofits as well as new rig builds. An easy-to-access hinged wiring compartment with captive hardware makes the installation experience smooth and safe. A wide operating temperature range of -40° to 65° C, and NPT (National Pipe Thread Tapered) hubs on each end for through wiring make this fixture a user-centric solution. To complete the package, an LED life of 60,000+ hours means years of maintenance-free operation, unlike fluorescents that may fail in six months or less and require constant maintenance.

Given safety concerns due to round-the-clock, high vibration boring, secondary retention of a light fixture on drilling rigs is critical to prevent it from plunging from a high-rise mast. To help create a safer workplace environment, the Appleton Rigmaster LED features a looping safety cable through the fixture and around the mounting structure which helps secure the fixture. In addition, while some manufacturers screw on eyebolts, the Appleton Rigmaster LED provides five casted-in openings for safety cable retention points. The yoke bracket is also designed to ensure the bracket will stay in position regardless of heavy vibration and maintain its structural integrity. To take it a step further, captive hardware eliminates the possibility of a screw coming loose and falling out.

Built with a high degree of corrosion resistance, the Appleton Rigmaster LED features a gasketed, copper-free aluminium housing, plus a thermal shock and impact-resistant polycarbonate lens. It is certified for Class I, Division 2 hazardous locations, National Electrical Manufacturers Association (NEMA) Type 3R, 4 and 4X wet and marine type areas. The fixture also meets IP66 rating requirements of being ‘dust tight’ and protected against powerful jets of water.

@EMR_Automation  #PAuto #Oil @Emerson_News @HHC_Lewis 

Support for North Sea platforms.

Following safe start-up of Clair Ridge, Emerson to enable remote monitoring and provide real-time data to maximise production for UK offshore assets

A five-year contract with BP to provide predictive maintenance and operational support services has been awarded to Emerson. This is to ensure safe, optimised production from its Clair Ridge platform and Glen Lyon floating production, storage and offloading (FPSO) vessel in the North Sea.

As main automation contractor for the Clair Ridge project, which achieved first oil at the end of 2018, Emerson was responsible for implementing its advanced integrated control and safety systems, and measurement and control devices to ensure safe, efficient operation of the two bridge-linked platforms. BP used Emerson’s Project Certainty methodology and consulting to define project goals that would eliminate costs, reduce complexity and risk, and accommodate late-stage changes.

Using the latest technology, Emerson’s cloud engineering services enabled global project personnel to remotely collaborate on design, development and testing in a common virtualised environment. This allowed project changes and testing to be managed efficiently and remotely, reducing travel, time, costs and project risk.

Emerson trained BP operators using its new, high-fidelity dynamic simulation model, enabling them to experience real-world scenarios before the system went live. This prepared them to effectively handle abnormal situations and resolve any operational issues that might have delayed reaching first oil.

“This is another example of our collaboration with BP and commitment to combining proven technologies and the best expertise to help ensure safe, optimised production for many years to come,” said Lal Karsanbhai, executive president of Emerson’s Automation Solutions business.

Emerson’s ongoing operational support, remote monitoring and predictive maintenance for Clair Ridge and Glen Lyon rely on Emerson’s Plantweb™ digital ecosystem technologies, software and services which equip plant personnel with relevant, real-time production data and analytics. This includes its DeltaV™ integrated control and safety systems, AMS asset management software, and measurement and control devices, all helping BP locally control operations, while remotely monitoring production and asset health from an onshore location.

Clair Ridge is a multi-billion-pound investment developed by BP and its co-venture partners ConocoPhillips, Chevron and Shell. Construction of the platforms was completed in 2016, with first oil announced on November 23, 2018. Clair Ridge is designed for 40 years of production. The development is targeting 640 million barrels of oil reserves, with peak production expected to be around 120,000 barrels of oil per day.

@EMR_Automation  #PAuto #Oil #Britain @HHC_Lewis 

Gas detector for offshore platform operations.

United Electric Controls, a leading producer of safety, alarm and shutdown technology, is demonstrating the latest version of its Vanguard WirelessHART gas detector, with new features of value for offshore platforms.

Magnetic mounting and adjustable pipe clamp options enable offshore operations teams to increase detection of toxic and combustible gases. High stability and high-resolution offerings improve reliability and accuracy of detection and the addition of carbon monoxide (CO) detection to existing wireless hydrogen sulfide (H2S) and methane CH4 detection reduces cost of compliance with air pollution regulations.

"By eliminating the need to install and locate wiring, wireless technology reduces installation cost by as much as 90 percent and preserves valuable platform space. The new capabilities of the Vanguard WirelessHART detector make it even easier for platforms to benefit from wireless gas detection by giving them more flexibility to locate detectors on the platform, and the CO detection capability helps control one of the largest sources of offshore air pollution,” said Andrew Liptak, United Electric Controls Product Manager for Gas Detection.

The new Vanguard WirelessHART gas detector version also features its new FLEXmountTM installation, which augments Vanguard standard mounting with magnetic and universal options. The magnetic option enables installation on I-beams without drilling. The universal option uses adjustable clamps that enable installation on pipes from 3” to 12” in diameter, without a hot work permit.

Among the locations in which gas detection might be located on a platform are mud logging units, mud pit room, drilling derrick and mud gas separator, and well-test areas, or wellheads, where H2S is prevalent. Locating near gas flaring locations, venting storage tanks, dehydrators, and pig launchers can detect CH4 releases, and locating near burners can detect CO emissions.

Vanguard WirelessHART version 1.2 also includes the following new features:

• New WiHART communication accessories, which enable users to extend system range, get more out of their installed HART instruments by receiving WirelessHART data via 4-20 mA inputs, and further extend range with powered repeaters.
• A new touchscreen configurator, which streamlines onboarding of the gas monitor to a WirelessHART network.
• Upgraded diagnostic software, which detects and pre-warns of system faults, providing more visibility into sensor messages, more ways to code the status of the signals and fewer false alarms.

The Vanguard WirelessHART Gas Detector version 1.2 is available immediately, supporting interchangeable detection heads for hydrogen sulfide (H2S) and methane (CH4) as well as carbon monoxide (CO). Beta testing is now underway for ammonia (NH3) detection heads.

Flow assurance for oil & gas production.

Yokogawa has announced that it has introduced an on-demand hydrate risk management solution that helps offshore oil platform operators to maintain production levels, protect plant assets, and minimise operating expenses and downtime by optimising pipeline chemical injection. The new solution integrates industry-leading simulation software from KBC, a wholly-owned subsidiary, with Yokogawa’s flexible supervisory control & data acquisition (SCADA) software to deliver a dashboard that enables consolidated, on-demand monitoring. Automated chemical injection metering valve technology can also be integrated as required.

The formation of gas hydrates that block pipelines is, together with other flow assurance issues such as waxes, asphaltenes, and scales, a major concern in the oil and gas industry for maintaining integrity of pipeline flow. The threat is particularly high in offshore oil platforms, which are increasingly moving to deepwater operations, as the fluid may cool to low temperatures in the flowline or in the production facilities. Hydrates form rapidly at certain temperature and pressure conditions, and can result in serious decreases in production levels, equipment damage, safety issues, and even emergency shutdown of equipment. To mitigate this risk, operators generally inject chemical inhibitors into the hydrocarbon flow to prevent the formation of hydrates or other threats to production.

During the plant design phase of oil and gas offshore platforms, modeling and simulation software and pre- operation field test data is utilised to optimise the pipeline network design and calculate the amount of inhibitor required to prevent hydrate formation. During operations too, field operators use the simulation results to calculate the amount of inhibitor to be injected into the flow. Injection rates are regularly reviewed by field experts, but without real-time visibility into the actual state of the pipeline, operators tend to overdose the inhibitor to provide a sufficient buffer for daily operational conditions and to compensate for changes in field properties over time. This can result in excessive chemical use and increased operating expenses. With the aim of enabling more efficient hydrate risk management, Yokogawa has developed a common dashboard for KBC’s two advanced, complementary simulation software solutions, Maximus® and Multiflash®, and Yokogawa’s own FAST/TOOLS™ SCADA system, making on-demand flow assurance a possibility for the first time.

KBC’s Maximus is a purpose-built tool for compositional thermal hydraulic steady state simulations of pipeline networks, including wells, choke valves, flowlines and a wide range of processing equipment. It can be used as both a production forecaster and flow assurance tool by predicting physical conditions of the network. Multiflash is the de facto standard pressure-volume-temperature (PVT) modeling solution for hydrocarbon flow assurance and production modeling due to its scope and accuracy. It is used to evaluate the phase behavior and physical and transport properties of complex mixtures and pure substances, and excels in modeling multi-phase hydrocarbon mixtures.

Used as an integrated SCADA system within and between plants, FAST/TOOLS offers the ability to work with and present information from various data sources and applications on a single dashboard. In this solution, data from temperature and pressure sensors in the subsea wellhead, pipeline(s) and offshore platform are collected by FAST/TOOLS and sent to KBC’s simulation software continuously or when operators require up-to-date hydrate formation risk information. Based on the results, FAST/TOOLS then displays the level and specific location of hydrate risk, and provides operators with the current hydrate formation curve and key performance indicators in one unified dashboard. In addition, the solution calculates the recommended level of inhibitor injection that enables them to balance risk and cost with a given margin. Integrating the KBC simulation and modelling technology with Yokogawa’s flexible SCADA platform enables operators to quickly make informed decisions about inhibitor injection volumes by getting the information they need on demand, without having to rely on periodic engineer analysis. Customers also have the option of leveraging the precise, automated FluidComTM chemical injection metering valve technology of subsidiary Yokogawa TechInvent AS to achieve an end-to-end hydrate risk management solution.

  @YokogawaIA  #PAuto #Oil @kbc_at

Control and Estimation!

Yokogawa and Shell have jointly developed a platform for Advanced Control and Estimation R5.02.

The platform for Advanced Control and Estimation is a software suite that brings together advanced plant process control technology developed by Shell and the real-time control technology that Yokogawa has developed in its role as a control system supplier. This upgrade from version R5.01 provides enhanced functionality that will help customers optimise the control of operations throughout their plants, maintain high system availability, reduce operator workload, and improve productivity. The Platform for Advanced Control and Estimation suite is positioned as a solution in Yokogawa’s OpreXTM Asset Operations and Optimisation family.

Advanced process control systems improve product yield and reduce energy consumption by maintaining temperature, flow rate, pressure, and other process values within a set range and keeping them as close as possible to their optimal set points. Such systems are increasingly used in facilities such as oil refineries, petrochemical plants, chemical plants, and natural gas liquefaction trains. Advanced control solutions are attracting considerable interest due to their ability to improve productivity.

Yokogawa’s platform for Advanced Control and Estimation suite delivers the following functionality:
• Multivariable model predictive control (the control of multiple variables based on predictions made using models of the dynamic characteristics of plant responses)
• Soft sensing for estimating quality in real time based on temperature, flow rate, pressure, and other process values
• Customisation of calculations

Yokogawa has continued to enhance this suite in response to changing customer requirements, and the release of version R5.02 meets the need for solutions that can optimise the control of operations throughout a plant, ensure high availability, and alleviate problems with high workload caused by reductions in the number of plant operators and expansion in the range of items that must be monitored and controlled.

1. Plant-wide optimisation of control with large-scale applications.
With large-scale applications, advanced control systems need to be able to quickly process huge amounts of data. Version 5.01 of this software suite is suitable for small to medium-size applications and can optimise the control of individual processes. With the enhancements made to R5.02, this software suite now offers significantly greater processing speed. As a result, it can now handle large-scale applications involving multiple processes and is thus capable of optimising the control of operations throughout a plant.

General and utility processes in plants can have an effect on or be affected by those processes that are subject to advanced control. Previously, operators had to view data on separate screens for the production control system and the advanced control system. With R5.02, operators can now view lists of all the measurement data on a single screen. By being able to access all this data in one place, they can respond more quickly to any changes.

2. Maintaining high system availability regardless of changes in operational conditions or aging of facilities.
With this software, a trend line showing the predicted values when advanced control is active (closed loop prediction trend) can be superimposed over a trend line that is based on the actual measured values. By comparing them, it is possible to easily identify errors in a dynamic response model. Such errors are the result of a deterioration in advanced control performance caused by changes in operational conditions or the aging of facilities. System availability can be maintained by rebuilding the dynamic response model whenever these errors become significant.

R5.02 has been enhanced to enable the display of a trend line that predicts plant behaviour when advanced control is inactive (open loop trend). This enables operators to know in advance what impact this will have on a process.

3. Improved operability for efficient operation and monitoring.
With a single press of a key, operators can call up items from a list of recently displayed screens. Frequently used screens can also be accessed quickly by registering them as favourites.

@YokogawaIA  #Pauto #Oil

Efficient connections for the Ex zone.

In environments where there is a high explosion risk (known as Ex zones), connectors must fulfil special safety requirements. Here Howard Forryan of Harting discusses how these challenges may be met.

Harting offers a range of connectors - the Han® Ex series - that meet the safety requirements for ignition protection in Ex zones 1 and 2. The use of such connectors, featuring innovative termination techniques supporting unskilled assembly and flexible hood and housing mating solutions, allows end users and installers more installed site flexibility and keeps costs down through time saving in various hazardous application areas including process automation in the petrochemical, chemical and mining sectors.

Condition monitoring
Operators of oil and gas platforms need to continuously monitor their sites’ ambient condition status through parameters such as gas concentration levels, differential pressures and temperatures. Mobile explosion-proof detectors and transmitters allow such measurements to be made at various different key locations on the platform and then be re-positioned as required. The readings from these instruments are switched and recorded via an explosion-proof central controller. These pre-existing detectors and central controller enclosures will typically already have glanded conduit access points. Because of the stringent requirements of explosion-proof equipment, users need to avoid making any modifications to such certified equipment.

In order to save valuable installation time and to maximise location flexibility of such a mobile detection system onto an oil or gas platform installation, Harting offers an exposion-proof connection solution with the compact Han® Ex 4A cable-to-cable connector system, a product that can be retrofitted without compromising the equipment’s Ex certification compliance. Because all detectors are provided with pre-fitted connector cable ends, they are supplied to site fully pre-tested, which ensures fast pluggable installation.

For the links to the central controller enclosure already located on site, cables can be wired through existing glands and conduits, leaving free ends for cable-to-cable connector termination. Harting provides its mating cable-to-cable connector with tool-less quick-lock termination connector inserts, allowing for quick and simple non-specialist wiring on-site installation.

The application of the Han® Ex 4A cable-to-cable connector system allows the connection between the controller and the detectors to be made outside the explosion-proof enclosure, hence ensuring that there is no modification done to the enclosure and no need for re-certification of equipment.

Lifting cranes
Another offshore oil and gas platform related application where connectors offer significant benefits over hard-wiring is on mobile heavy lifting cranes, which may need to be frequently removed and re-installed at different locations. While the crane platform and operator cabin are installed in the so called “safe zone”, the boom is operating in the hazardous zone, thus making it mandatory to use ATEX approved components. The boom carries a number of different sensors (for detecting angle and load, for example) and a light bar at its tip; near the cabin various connectors are used at a panel where all the sensors are wired up.

Across the general “Ex” sector, the replacement of defective loads such as low-voltage switchgear, generators or pumps is complex: the power has to be switched off before the defective equipment can be uninstalled and replaced. With a hard-wired installation, all cores would have to be screwed or connected individually. Connectors, on the other hand, reduce downtime and support modern and flexible machine configuration through modularisation in hazardous areas. Harting’s Han® Ex series connectors are available in different tool-less contact wiring termination designs, so that no specialist skilled personnel are needed for initial assembly and replacement of components. Similarly, the installers require no special tools, thereby accelerating the switch-out operation while maintaining all safety functions. Crimp termination is also an option for the volume OEM manufacturing producer.

Meeting protection requirements
Intrinsically safe explosion protection is based on the limitation of the power circulating in intrinsic circuits, permitting electrical devices to be operated safely even in an explosive environment. Han® Ex connectors meet the standards for materials that are permitted to be used in potentially explosive atmospheres (DIN EN 60 079-0). Air clearance and material creepage distances are in accordance with the intrinsically safe circuit requirements for zones 1 and 2. Their blue colour provides easy identification of inherently safe circuits and they ensure protection class IP65 when mated or unmated in conjunction with appropriate lanyard attachable loose covers (plastic for Han® Ex B and powder coated blue zinc die-cast for Han® Ex 3A series).

 @HARTING_Group #PAuto #EX #Offshore

Automation technologies & ongoing support in North Sea oil.

Emerson has completed its multi-year, $90 million (€73 million) automation project for BP’s Glen Lyon floating production, storage and offloading (FPSO) vessel west of Shetland (GB).

The company is now providing ongoing operational support services to help BP achieve its goal of producing 200,000 barrels a day from the North Sea by 2020.

Photo courtesy of BP

Emerson has served as the main automation contractor (MAC) for the Glen Lyon, which is expected to produce 130,000 barrels of oil a day at plateau.

“By leveraging our project certainty model through expert partnering, we collaborated to achieve a truly world-class mega project that will help BP remain a North Sea energy leader,” said Mike Train, Emerson Automation Solutions executive president. “With first oil from the Glen Lyon accomplished, our focus now turns to helping BP achieve operational certainty, with maximum asset reliability and uptime, reduced risk of safety incidents and optimised production.”

Its construction and commissioning were central to BP’s multi-billion-dollar Quad 204 project, which involved the redevelopment of the Schiehallion and Loyal fields to target 450 million barrels of oil and allow production from the hub to be extended to at least 2035.

As part of an additional five-year contract, Emerson will provide ongoing operational support services, remote monitoring and predictive maintenance technologies for the Glen Lyon and BP’s other North Sea mega project Clair Ridge, which is due to come on stream this year.

Emerson’s lifecycle services will help BP ensure ongoing safety, improve reliability, maximise availability and reduce operating costs.

BP uses Emerson’s automation technologies including the DeltaV™ and DeltaV SIS integrated control and safety systems to help optimise production and yield, avoid environmental impact and operate safely.

BP also uses the Emerson high-fidelity dynamic simulator to train its operators and engineers in real-world scenarios before system changes go live.

In addition, BP has selected Emerson to manage its fiscal metering systems on all North Sea assets, which is essential for fiscal accounting, custody transfer and taxation purposes.

Their metering consultants, engineers and specialist metering experts will validate and report measurement data, sampling, analytical and test equipment, as well as plan and carry out offshore metering maintenance and verification activities. In addition, the company will provide comprehensive auditing services for BP’s North Sea pipeline operations.

#Oil @EMR_Automation #PAuto @BP_plc

IIoT-enabled artificial lift optimisation software.

Energy producers seeking to maximise production from proven reserves now have access to next-generation artificial lift optimisation solutions from Emerson.

The Dynamic Lift Optimization (DLO) software allows producers to extract greater value from existing assets and reduce field decline rates by ensuring a field or platform is producing at maximum efficiency given current production constraints. Using the DLO software, a typical site operating multiple wells can experience a 10 percent production improvement because it responds immediately to changes in the field operation, continually reallocating available lift resources. DLO software is one of the technologies featured by Emerson at this year’s Offshore Technology Conference, this week (Houston, TX USA).

DLO software can impact the industry at a critical time. Energy producers seek to maximise the productivity of existing wells and offset the natural decrease in production from an oil well over time. As decline rates increase and wells produce less oil, energy producers are forced to find alternative methods to meet production targets, preferably without the added cost of drilling new wells.

DLO software dynamically adjusts lift gas flows or electric submersible pump (ESP) speed based on the most recent well test curves. Once configured, the application optimally allocates the available lifting power to the wells to maximise production, at the same time adjusting to changing conditions such as wells coming on or off or compressor trips. By contrast, traditional gas lift adjustments are typically handled manually and infrequently, resulting in missed opportunities and lower field performance.

Earlier versions of the software have helped oil and gas producers generate millions of dollars per year in increased production throughout the last decade. The new version is easier to implement and comes IIoT-ready allowing cloud-based infrastructure. The new graphical user interface enables production engineers to safely and securely access crucial field optimisation data from any location with an internet connection.

In addition to a new user-friendly web interface, the DLO software now uses the OSIsoft PI System - a highly scalable open data infrastructure and historian that provides a common data architecture from the plant floor to the enterprise level - making information available wherever needed for better business decisions.

“Emerson’s Dynamic Lift Optimization software is the first of its kind that helps production teams dynamically adjust lift rates closed-loop based on current conditions, ensuring efficient, high-yield recovery,” said Jose Jimenez, director for Emerson Automation Solutions’ global O&G industry business. “It is critical to direct lift resources precisely to the highest value wells, and Emerson’s optimisation solution has proven to increase oil recovery rates and slow well decline rates. The new software platform lowers implementation cost significantly.”

Since DLO utilises well test curves to determine how to allocate lift resources, it’s important that these curves are updated as the well declines. For maximum benefit, oil producers have the option of pairing DLO technology with Emerson’s integrated well testing solution, which allows for more frequent updating of well curves – information that is fed to DLO software to ensure field production is continuously maximised.

The integrated well testing solution consists of a multi-port flow selector, a 3-phase flow meter and a full-featured remote terminal unit that is delivered as pre-engineered and fabricated on a skid. This improves the quality and frequency of well test data with a significantly reduced footprint and weight as compared to a traditional test separator and manifold. Each skid can handle up to seven wells, significantly eliminating piping, valves and vessels. The 3-phase flow meter provides instantaneous readings for the oil, gas and water from that well, eliminating the settling time required for a traditional test separator. The well test schedule can be programmed in advance and can occur without manual intervention, eliminating the need for an operator to manually line up valves.

Together, DLO software and integrated well testing solutions offer producers enhanced capabilities for gathering real-time data from the field, automating the well test procedures and closed-loop optimisation of lift rates based on current field conditions and operating constraints. This solution automatically allocates available lift resources, where they have the most potential to drive additional profit.

 @EMR_Automation #PAuto @OTCHouston #OTC2017

AC/DC Drives for oil rig cranes!

A US-based specialist in the supply of complete electrical packages for oil rig cranes is using Control Techniques AC and DC drives as part of a landmark $500,000+ order involving the upgrade of 10 LeTourneau cranes. Three cranes have already been completed with no reported down-time in the first 18 months of operation, whereas prior to the upgrade, maintenance would be required on a weekly or even daily basis in some instances. The financial benefits for the oil rig operator are proving substantial.

Headquartered in League City, Texas, JC’s Marine Oilfield Services was established in 1992. The company’s Power & Distribution Division specialises in a variety of motor control solutions that are customised to match the needs of oil rig cranes, as well as drilling barges, supply vessels and land rigs.

When a Texas/Louisiana-based customer was seeking an electrical contractor to help upgrade the drive systems on 10 LeTourneau oilfield cranes, JC’s Marine Power & Distribution was in prime position to secure the order thanks to its technical support and AC/DC capabilities. As a long-standing advocate and user of drive technologies from Control Techniques, the company proposed the use of a Unidrive SP AC variable speed drive for the boom, and two Control Techniques Mentor MP series DC regenerative drives for the swing and hoist.

“The technical advice offered by Control Techniques is one their best selling points,” stated John Costanza, President at ‎ JC's Marine Oilfield Services. “Their technicians always address problems quickly and comprehensively, which means a lot to a business such as ours, and is certainly better than we have experienced elsewhere. We exclusively use Control Techniques drives on our projects, ranging from 75 to 750kW, both AC and DC.”

Around 1600 LeTourneau cranes are currently in service on oil and gas rigs around the world. Although they were originally fitted with large motor-generator sets, these do not offer variable speed, meaning there is total reliance on the skill of the boom operator to lower heavy loads.

“By changing to a Control Techniques variable speed drive for the boom we can ensure complete control over the speed and rate at which the boom moves, so that loads up to 50 tons are ‘feathered’ rather than ‘banged’ to the ground,” said Mr Costanza.

The boom motor drive system comprises an SP5402 Unidrive variable speed AC drive rated at 210 Amps continuous, while the hook motor drive system features a Mentor MP420A4R DC drive rated at 420 Amps continuous. A Mentor MP210A4R, rated at 210 Amps continuous, is fitted to the swing motor drive system. All of the drives are purposely sized for twice the normal power required, which means the system never runs at its maximum capacity.

“I’ve been operating with the new system for 12 months and have not had one issue,” said Justin Hillard, LeTourneau crane operator on Atlantic 7 rig. “The controls are user friendly, very smooth and have a wide variable speed in hook, swing and boom. In my opinion the boom is the biggest operating improvement. With its variable speed you can ease into boom and keep the load stable and personnel safe on deck.”

Jason also praised the increased safety afforded as a result of the new system: “The crane is also much quieter without the motor-generator sets running; you can hear what the crane is doing and what’s going on around you. I’ve also noticed that if you’re in a position where you cannot see the hook, you can actually hear the hook motor running and know how fast the hook is travelling. I highly recommend this system, it’s safer, smoother, quieter and virtually maintenance-free.”

David Powers, fellow LeTourneau crane operator on Atlantic 7 rig, also likes the new control system, which carries a Certificate of Design Conformance from the American Bureau of Shipping (ABS): “The new system gives the crane a better parameter of operation and is more responsive. Most importantly, these changes have made a much safer work environment.”

“Braking is automated, which promotes safety and takes responsibility away from the operator,” added Mr Costanza. “Also, there is better reliability as the load is not being ‘snatched’.”

Further benefits delivered to the end user as a result of AC and DC drive technologies from Control Techniques include conformal coating on the PCBs, which helps impart protection in marine environments, while the large working temperature range is also advantageous.

The project to complete the upgrade of the 10 LeTourneau cranes will continue through to the end of 2017.

@EmersonIndAuto #PAuto #ControlTechniques #Oil

Non-intrusive wireless corrosion monitoring added to portfolio!

Emerson has agreed to acquire the British company Permasense Limited, a leading provider of non-intrusive corrosion monitoring technologies for the offshore and onshore oil production, refining, chemical, power, pipelines, metals and mining and other industries. Permasense® monitoring systems use unique sensor technology, wireless data delivery and advanced analytics to continuously monitor for metal loss from corrosion or erosion in pipes, pipelines or vessels, and reliably deliver high-integrity data from even the harshest environments.

The acquisition represents another step forward in Emerson’s strategy to invest in its core business platforms and expand in markets that hold significant long-term growth opportunity.

“Corrosion and erosion can significantly impact the safe and reliable operation of our industrial customers’ infrastructure, which can have dire consequences. Wireless non-intrusive corrosion monitoring is a transformational shift that helps customers immediately understand the health and integrity of their infrastructure in real-time and enables them to fully optimise their operations while maximising safety,” said Mike Train, president, Emerson Automation Solutions. “For example, with the increasing complexity of the types of crude oil coming into a refinery, corrosion is becoming a significant issue in the uptime and profitability of a refinery. Now refinery infrastructure can be monitored and controlled using this non-intrusive technology.”

The Permasense product line will become part of Emerson’s Rosemount™ portfolio of measurement and analytical technologies. Permasense technologies complement Emerson’s Roxar™ intrusive corrosion monitoring and non-intrusive sand management systems and strengthen the company’s Pervasive Sensing applications that provide customers a more complete view of their operations and facilities. With Permasense and Roxar technologies in its portfolio, Emerson will be the largest provider of integrity and corrosion management solutions in the marketplace.

Lal Karsanbhai, group vice president, measurement and analytical technologies, Emerson Automation Solutions, added: “The addition of patented Permasense technologies along with our existing Roxar technologies enables Emerson to provide customers with a more complete corrosion monitoring solution and a clearer picture into the performance of their infrastructure based on what they’re demanding of it and the strategies needed to optimise production.”

Central to Permasense corrosion monitoring systems are sensors that employ proven ultrasonic wall thickness measurement principles. The sensors are battery powered and communicate wirelessly, which minimises the cost of installation and enables use in remote areas and on a large scale. The sensors are also designed so they can be deployed in hazardous areas.

@EmersonProcess @Permasense_ltd #PAuto #Oil #offshore

Metering management services contract for offshore facilities.

Nexen Petroleum U.K. Limited, the wholly-owned subsidiary of CNOOC Limited, has awarded Emerson a new five-year contract to provide metering management services for Nexen’s British operations. The work will be managed from Emerson’s new Solutions Centre in Aberdeen.

Roel van Doren

Emerson will provide onshore metering engineers and offshore metering and analyser technicians for their offshore facilities. The Emerson experts will be responsible for validating and reporting measurement data and metering, sampling, analytical and test equipment, as well as supporting all offshore metering maintenance and verification activities.

“For oil and gas companies, the accuracy and integrity of their fiscal and custody transfer metering systems are critical for customer confidence,” said Roel van Doren, president of Emerson Process Management Europe. “This contract builds on our proven success in helping companies achieve those objectives – while also continually reducing their metering costs.”

Metering systems provide accurate, reliable measurements essential for fiscal accounting, custody transfer and taxation purposes. Emerson’s metering management services help increase confidence in the accuracy of measurement equipment so oil companies can maximise production revenues.

@EmersonProcess  #PAuto #Oil #Gas # Britain @HHC_Lewis