Innovative new adaptive gas lift system

Enables operators to maximise oil production without costly and challenging well interventions.

Emerson and Interwell, a global leader in well intervention and integrity solutions, have announced the launch of the Adaptive Gas Lift System (AGLS), the world’s first retrievable electric gas lift system designed to meet internationally recognised safety and performance standards. The AGLS enables continuous optimisation of oil production without the need for invasive and costly well interventions, and its unique retrievable design reduces operational downtime while enhancing both the safety and sustainability of gas lift operations.

“We designed the AGLS to meet the most rigorous industry standards,” said Jan Inge Ellingsen, vice president and general manager for Roxar products at Emerson’s measurement solutions business. “This innovative technology will help unlock the full potential of assets in the field while eliminating the need for extensive interventions, improving safety, and supporting the transition toward net-zero energy production.”

Conventional gas lift systems typically optimise production during the early life of a well, when tubing pressure is high. However, as reservoir conditions evolve, drawdown efficiency decreases and oil output can decline, often leading to over-injection or under-injection of lift gas. Traditional injection pressure operated (IPO) valves require reducing casing pressure to close, which limits injection depth and production.

Manipulating casing pressure and managing temperature-related uncertainties in valve behaviour also frequently causes multi-pointing, where gas is injected at unintended depths, leading to inefficiencies and lost production. Addressing these challenges usually necessitates complex and costly well interventions to adjust valve port sizes or change injection depths.

The Adaptive Gas Lift System transforms gas lift operations by providing real-time remote control of valve port sizes, gas injection rates, injection depths and drawdown, without interrupting production. Because valve closure does not rely on reducing casing pressure, deeper injection is achievable, improving lifting efficiency over the life of the well.

The ability to make continuous data-based online adjustments eliminates the need for traditional intervention-based modifications, increasing uptime, maximising production, enhancing safety and reducing project payback time. The unique retrievable design of AGLS allows for the complete replacement of entire valve assemblies using standard wireline techniques, without the need for costly workover operations.

The system is powered and controlled by Emerson’s Roxar™ Integrated Downhole Network – a permanent monitoring and control system that provides real-time data on pressure, temperature and flow to optimise reservoir management and production – and utilises Interwell’s field-proven Side Pocket Mandrels and barrier-rated Gas Lift Valve.

AGLS is designed and qualified to the American Petroleum Institute’s API 19G1 (V1), 19G2 (V0) and Advanced Well Equipment Standards Group’s AWES 3362-36 standards.

By minimising the number of interventions – which typically involve equipment mobilisation, energy consumption, and associated emissions – the system also reduces the carbon footprint of gas lift operations. Additionally, by improving production efficiency, the AGLS lowers CO₂ emissions per barrel of oil produced, contributing to more sustainable and responsible energy production.

“The oil and gas industry has long required a more dynamic and resilient approach to electric gas lift,” said Thormod Langballe, chief executive officer of Interwell. “Combining Emerson’s industry-leading digital automation expertise with Interwell’s specialised gas lift technology and know-how, we have developed a robust, real-time controllable gas lift solution that tackles these challenges head-on.”

---

@EmersonExchange @Emerson_News @EMR_Automation @HHC_Lewis #PAuto #Petroleum

Ai, IoT, and Cybersecurity drive digital transformation in oil/gas.

A recent report, by GlobalData, on key technologies in the oil and gas industry was commissioned by Rockwell Automation. According to the Oil and Gas Technology Outlook for 2030 and Beyond, oil and gas companies are undergoing a seismic shift, driven by rapid digitalization and the integration of advanced technologies. 

The report reveals that artificial intelligence (Ai), the Internet of Things (IoT), and cybersecurity are at the forefront of this transformation, reshaping operations from exploration to refinement.

The report outlines five critical findings:

1. Digitalization is Now a Strategic Imperative: Companies are moving beyond isolated tech deployments to fully integrated digital ecosystems. Over 50% of industry leaders report that technologies like cloud computing, cybersecurity, and Ai are already disrupting their operations.
2. Key Drivers Fueling Adoption: Technological innovation, environmental compliance, supply chain resilience, and workforce challenges are accelerating the need for digital solutions. Predictive maintenance, remote monitoring, and automation are helping companies reduce downtime and improve safety.
3. Emerging Technologies Reshape Operations: Ai is being used to optimize drilling paths, forecast demand, and enhance refining processes. IoT sensors provide real-time data for equipment health and environmental monitoring. Electrification and smart motor systems are helping reduce emissions and energy costs.
4. Strategic Roadmap for Digital Success: The report emphasizes the importance of a clear digital strategy, choosing the right delivery model (e.g., SaaS or hybrid partnerships), and fostering a digital-first workforce. Companies must also stay ahead of evolving tech and data regulations.
5. Ai as the Central Innovation Engine: With projected spending in the energy sector reaching $18.5 (€1.97) billion by 2028, Ai is enabling smarter decision-making, immersive training, and autonomous operations. Its integration with digital twins, edge computing, and VR/AR is unlocking new efficiencies across the value chain.

“The convergence of information and operational technology is redefining how energy companies operate,” said Fabio Mielli, strategic business developer, Rockwell Automation. “By aligning advanced digital tools with measurable production outcomes, we’re helping the industry build resilience and agility for the future.”

---

@ROKAutomation @ROKAutoEMEA #PAuto #Oil_Gas

Manufacturing of sensors for detecting toxic and combustible gases in KSA.

A new 699 m² manufacturing facility is being established in Dammam (KSA) by Teledyne GFD and  partners Industrial Detection Solutions (IDS). This partnership will enable the local production of high-precision sensors for detecting toxic and combustible gases, helping to protect workers and assets at oil and gas production/drilling facilities, LNG/CNG plants, and refining and petrochemical sites. A grand opening ceremony on (insert date) will officially declare the plant open 19th June 2025.

Gas detection is an essential safety aspect throughout the oil and gas industry. With so much activity in the Middle East, Teledyne GFD wanted to bring the production of key gas detection solutions closer to their point of use. This strategy also aligns with the IKTVA (In-Kingdom Total Value Add) programme that promotes local manufacturing in KSA.

IKTVA is an initiative to increase economic diversification and create a sustainable ecosystem in KSA’s oil and gas industry. The programme aims to increase the use of in-Kingdom suppliers, expand local supply chain capabilities and capacities, and drive industry collaboration through supplier development.

By partnering with Industrial Detection Solutions, Teledyne GFD will help to meet the ambitions of the IKTVA via the local manufacture of popular products like its DM-700 toxic gas sensor, and FP-700 and IR-700 combustible gas sensors.

“Our new partnership with Industrial Detection Solutions ensures that manufacturing is closer to both customers and suppliers, enabling even faster delivery of class-leading gas detection products in support of more efficient supply chains,” says Thomas Moeller, VP Sales & Marketing at Teledyne GFD. “The proven solutions manufactured in KSA will better serve a vast regional industry that recognises the importance of a robust and prevalent safety culture. We are proud to be part of KSA’s remarkable ongoing journey of economic and industrial growth, and we look forward to a successful future together.”

The DM-700 is a non-intrusive ‘smart’ sensor that detects and monitors oxygen and toxic gases in the air using electrochemical sensor technology. The intelligent, plug-in, field-replaceable cell automatically recognises gas type and range. Teledyne GFD’s FP-700 is also a non-intrusive ‘smart’ sensor, this time for the detection and monitoring of combustible gases over the range of 0-100% LEL using catalytic bead sensor technology. The IR-700 is a similar solution for combustible hydrocarbon gases. It uses miniature non-dispersive infrared (NDIR) optical sensor technology to detect and monitor gases over the range of 0-100% LEL.

All of these gas detectors support maximum safety with an innovative design that virtually eliminates sensor failure due to water ingress, corrosion, vibration or transient spikes.

---

@interdsys1 @GasMarcom @mepaxIntPR #TeledyneGFD #PAuto #KSA

High Integrity Pressure Protection System in gas wellheads.

Upstream gas wellheads can experience extremely high pressure and surges. In order to protect personnel and equipment, wellhead casing pressure is often monitored in case there is a situation where the wellhead needs to be shutdown. Traditionally standalone pressure switches were used but today companies are required to implement more advanced and effective safety systems. This illustration shows the Moore Industries SLA installed in a remote oil and gas wellhead application using 2oo3 voting logic to ensure pressure protection.

In this application, to protect personnel and the process from high pressure spikes, the three separate pressure transmitters are wired to the SLA where it can perform a 2oo3 safety voting architecture to shut down the well when dangerous conditions exist. The SLA’s built in loop power supply on each of its three input channels provides operating power to all three smart HART pressure transmitters. The HART signal from the three pressure transmitters is passed-through to each of the SLA’s corresponding analog outputs so the RTU/PLC has direct access to all HART programming, variables, and diagnostics of each connected transmitter.

The retransmission of these three pressure transmitters by the SLA, versus wiring in series with the RTU/PLC input cards, provides higher availability to the safety function since a catastrophic failure in the analog input cards or the RTU/PLC itself doesn’t affect the 2oo3 logic shutdown function of the SLA.

Additional relay outputs of the SLA also keep the RTU/PLC informed of shutdown status and any input faults experienced by the SLA. A digital contact input allows any alarm or relay configured as latching to be manually reset. Finally, all inputs, outputs, internal equations, variables, alarms, relay status and more are digitally transmitted to the RTU/PLC via a read-only MODBUS RTU signal.

Key attributes of the SLA: • Simple to configure 2oo3 voting alarm with checkboxes and pull-down menus • SIL 2/3 capable exida® approved to IEC 61508:2010 standard • HART pass-through of pressure transmitter diagnostics to RTU/PLC • SLA provides 24Vdc power to all three pressure transmitters for ease of wiring • -40 to 85 degrees Celsius ambient temperature operating range • Standard MODBUS RTU protocol sends all process and diagnostic data to RTU/PLC

---

@MII_Worldwide #PAuto #Oil_Gas

Rugged RTUs.

Red Lion has launched two new programmable Remote Terminal Units (RTUs), VT-MIPM-138-D and VT-MIPM-248-D. Equipped with onboard I/O and designed for uncompromising performance in extreme environments, these industrial controllers are ideal for a wide range of rugged, process-oriented applications in water and wastewater processing, oil and gas production and other advanced automation settings.

The new RTUs deliver maximum standalone control over today’s toughest industrial processes. Automatic datalogging and timestamping, as well as logging of trends, alarms and sequences of events, give operators full visibility on their applications. A robust IEC 61131 programming and configuration environment in Red Lion Workbench provides extensive programming and troubleshooting capability. The unit also supports ISaGRAF for backward compatibility and has a true open system design, with Ethernet TCP, Modbus, Linux® and more.

An ideal platform for water, wastewater and oil and gas processing facilities, the VT RTUs come pre-certified, letting operators add applications as desired, program and configure as needed and scale up easily, from 1 to 1000+ stations. Multi-user connectivity is enabled via 10/100 Ethernet ports, RS232 and RS485 and up to 4 communications ports. Onboard I/O is a mixture of DI, DO, AI and AO. Advanced communication capabilities include report on exception, store and forward and peer-to-peer networking.

“The VT-MIPM-138-D and VT-MIPM-248-D units represent the ultimate RTU upgrade for extreme industrial settings,” said Jacob Colegrove, Product Manager. “For operators moving from an existing Sixnet series, it’s the obvious choice. They share the same footprint, has equivalent I/O count, offer comprehensive data logging and networking functionality, plus programmable features for full flexibility.”

Suitable for hazardous areas and extreme temperatures, the controllers are rated for operating temperatures of -40°C to 70°C and have UL Class I, Division 2, CE, and ABS Type certifications.

---

• Red Lion products are marketed in Ireland through Instrument Technology.  

@redlioncontrols @mepaxIntPR #PAuto #Communications

Detect and locate methane leaks.

Delivering 24/7 Coverage of Methane Production, Transmission and Storage Infrastructure

ADGiLE is a fixed-mounted methane monitoring solution just unveiled by FLIR. Featuring optical gas imaging (OGI) with comprehensive edge detection analytics, ADGiLE is the oil and gas industry’s solution to meeting environmental stewardship and efficiency goals. The system, featuring a pan-tilt gas imaging camera, edge computing device, connectivity, and FLIR United VMS software within a ruggedized package, can help companies address the ever-evolving requirements for reducing methane gas leaks within oil and gas production, transmission, and storage infrastructure.

Designed for wide-scale site video monitoring and continuous leak detection applied to storage tanks, compressors, separators and many other equipment in the oil and gas industry, ADGiLE offers an industry-first, end-to-end fixed methane detection solution that leverages FLIR’s uncooled GF77a OGI technology, and is consequential to industry demands concerning methane mitigation.

This pairs the GF77a with platform analytics processed at the edge to detect emissions through automatic early detection, quickly pinpointing the leak source. It provides the critical situational awareness on the emission event that isn’t possible with other methane detection technologies, such as satellite and aerial-based detection methods. Data is displayed via the FLIR United VMS software back at the control room, which can be configured with custom alerts, areas of interest, and pre-set imaging pathways for a truly automated experience.

The solution primarily focuses on midstream and high-concentration methane upstream applications. It works to detect and prevent high volume emission events, compared to the company's existing cooled handheld OGI technology, leveraging their edge detection analytics built upon decades of detection data and experience to deliver consistent, accurate results. The system increases both site efficiency and safety, as it operates equally well during the day and in total darkness at safe distances, pending atmospheric and site conditions.

“The industry knows FLIR as the world leader in handheld OGI detection, and now they can access lower cost technology via a completely automated, fixed solution with ADGiLE, featuring everything they need out of the box to quickly pinpoint and then fix large methane leaks,” said Craig O’Neill, Business Development Director, FLIR. “ADGiLE is purpose-built for mid- and upstream methane operations to deliver game-changing results to achieve methane mitigation demands along with internal emission reduction goals. This makes ADGiLE a market leading solution for well site operators, compressor stations, and storage facilities that must invest in methane detection and monitoring technologies.”

FLIR ADGiLE uniquely meets the most serious methane leak detection challenges while providing operational insight to understand emissions that are a part of routine industry processes versus fugitive emission events. The system can also help prevent false readings, saving time and resources by avoiding the need to manually investigate and confirm specific leaks. At the same time, it can still detect intermittent leaks that happen and are too often missed by deployed aerial detection technologies using a wider temporal frequency. It can generate situational awareness that addresses the full range of challenges stemming from various methane emission scenarios.

---

@flir @mepaxIntPR  #PAuto

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.

---

@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.

---

@survitec @SCLPatrik #PAuto #Safety

Partnership strengthens custody transfer capability.

Ensuring the timely and safe delivery of oil and gas, helping to avoid shutdowns of primary infrastructure

Danny Knoop, ABB Flow-X Computers and
Berry van Hoek ,ODS Metering Systems

ABB has announced a partnership with ODS Metering Systems, an independent manufacturer of custody transfer flow measurement solutions, that will see ABB’s Flow-X computers support an increasing number of oil and gas customers with an accurate and reliable automation platform for custody transfer.

The partnership will see the two companies combining their respective strengths: ABB with their flow computers and ODS Metering Systems with the skills to help customers transition to new solutions through further digitalization and with minimum disruption. Through their expertise, global service and maintenance capacity, ODS Metering Systems will secure the seamlesst integration of ABB flow computers in newly built systems as well as refurbishment projects.

Custody transfer is a critical part of oil and gas logistical and commercial operations and is central to risk mitigation, inventory management, quality control and regulatory compliance. The ABB Flow-X series play a crucial role within these operations by accurately measuring and recording the quantity of the oil and gas being transferred from one party to another, protecting the interests of both buyers and sellers.

The Flow-X computer systems have an unmatched accuracy of 0.008 percent over a wide ambient temperature range as well as reliable performance, with the mean time between failures longer than 100 years.

“ABB’s Flow-X computers are not only exceptionally accurate and reliable, but they offer one of the most versatile and cost-effective automation platforms for custody transfer on the market,” said Danny Knoop, General Manager, Flow-X Computers, ABB. “This partnership is really good news for customers as it will help enhance service and technical support throughout the commissioning and operations process.”

“ODS has over 40 years of experience with flow computer integration and metering automation projects. By using ABB’s state-of-the-art Flow-X flow computers we will enable customers around the world to achieve more reliable measurement and digitalization of their metering assets,” said Berry van Hoek, COO of ODS Metering Systems. “With this partnership, we are pleased to offer clients the best of both worlds”.

The partnership will extend ABB’s expertise and increase the reach of its Flow-X computers, ensuring the timely and safe delivery of energy across the globe. It will also see the two companies support customers who have faced long delays and other inconveniences due to a disturbed supply chain in recent years, helping to avoid shutdowns of primary infrastructure that can leave homes and industies without energy.

ABB’s Flow-X series works in synergy with ABB’s range of Coriolis flowmeters, pressure and temperature sensors, and its award-winning gas chromatographs, making measurement easy across industries.

---

@abb_automation @ABBgroupnews @ABBMeasurement @AdmiralPR #PAuto #OilGas

Topside and hullside electrical system automation.

ABB has won a large order from Sembcorp Marine Ltd, a global provider of innovative engineering solutions to the offshore, marine and energy industries with headquarters in Singapore, to deliver the complete electrical system automation for a floating production storage and offloading (FPSO) facility for Brazilian oil and gas producer Petróleo Brasileiro S.A. (Petrobras). 

The P-82 FPSO will be one of the largest vessels to be deployed in the Búzios field, an ultra-deepwater oil and gas field covering an area of 853 square kilometers in the Santos Basin, around 180 kilometers off the coast of Rio de Janeiro, Brazil.

Petrobras plans to deploy 18 FPSO vessels offshore Brazil in the next four years[1] – making up nearly half of all global FPSOs. These new-generation vessels, of which P-82 is one of the first, will be characterized by high production capability and emission-reduction solutions, such as carbon capture, utilization and storage (CCUS). Collectively, these vessels are expected to have the production capacity of approximately 2.8 million barrels per day.

ABB is supplying both the topside and hullside electrical systems for P-82, providing seamless project integration. The topside systems will be installed in an ABB eHouse solution – a prefabricated, modular substation that reduces costs, risk exposure and on-site work because all components are wired, tested and commissioned before shipment to the yard.

Once operational, the facility – which receives fluids from a subsea reservoir before separating them into crude oil, natural gas and water within topside facilities onboard – will have the capacity to produce 225,000 barrels of oil per day and process 12 million cubic meters of gas per day.

“We are delighted to be collaborating with Sembcorp Marine to deliver this integrated solutions order,” said Brandon Spencer, President of ABB Energy Industries. “We have a proven record in electrical and automation solutions for FPSOs both in Brazil and worldwide. This project aligns with our own commitment to reduce the emissions footprint of existing hydrocarbon infrastructures as we balance the needs of the energy transition with rising consumption demands, especially in developing economies.”

@ABBgroupnews @ABBMeasurement @abb_automation @petrobras #PAuto #Marine #Oil_Gas

Identifying orphan well.

ABB’s emissions monitoring technology which is typically used for gas leak detection by oil and gas companies and natural gas utilities is now employed to identify and monitor orphan wells in the United States.

With the help of ABB technology, organizations such as The Well Done Foundation, the nonprofit organization that works to plug orphan oil and gas wells in the country, can detect leaking wells and, once the wells are capped, continue to monitor the sites to ensure they no longer emit harmful greenhouse gases.

Orphan wells are oil or gas wells that have been deactivated and no longer have legal owners responsible for their care. Due to their age and deteriorated condition, the wells can leak methane and other harmful greenhouse gases through their “plugs”.

The United States Environmental Protection Agency estimates that methane emissions from over 2 million inactive, unplugged wells, of which orphan wells are a subset, range from a CO2 equivalent of 7 to 20 million metric tons per year (approximately the emissions of 2 to 5 million cars). Methane has more than 80 times the warming power of carbon dioxide over the first 20 years after it reaches the atmosphere, according to the Environment Defense Fund.

Many wells are situated on farmland, and could contaminate land, air and water, potentially harming ecosystems, wildlife, livestock, and people.

In some parts of the United States where towns are growing, housing has been built where oil and gas wells once stood. The Environment Defense Fund estimates that 14 million Americans live within a mile of an orphan well.

“It is extremely rewarding to see our technologies employed in the endeavor of fixing such a pressing environmental problem. We remain focused on accelerating the pace of environmental programs that reduce emissions, especially in the oil and gas industry. Our work on this initiative is a great example of how technology can benefit the environment and help countries achieve their sustainability goals,” says Jacques Mulbert, Division President, ABB Measurement & Analytics.

What can be measured can be improved.

Together with channel partner Winn-Marion, ABB worked to create a comprehensive approach that enables the identification, on-site qualification, and monitoring of orphan wells. At the heart of the solution are ABB’s gas leak detection products as well as a suite of flow computers, both used in tens of thousands of industrial plants worldwide to measure and report on emissions.

Initially, ABB’s gas leak detection system is used to find the orphan wells. Depending on their location, the high sensitivity analyzers using OA-ICOS™ technology are transported by vehicle (using ABB Ability™ MobileGuard™), drone (HoverGuard™), or backpack (MicroGuard™) to the site. The system can detect methane emissions down to 1 part per billion (ppb).

Once on-site, it measures methane concentration and flow with a measuring range as low as 180kg/h. The flow from the thermal mass is logged and visualized on ABB’s gas flow computers, the control devices known in the industry for their extreme accuracy and reliability. In the post-plugging phase, methane emissions continue to be monitored.

A key advantage of ABB’s emissions monitoring technology is that it is fully audited by the Bureau of Land Management, which manages the Federal government’s onshore oil and gas program in the United States.

@ABBgroupnews @ABBMeasurement @abb_automation @EPA  #PAuto #Oil_Gas 

Building secure certified systems.

Moxa UC-8200 Series computers running on the Moxa Industrial Linux 3.0 (MIL3) platform offer a highly secured edge computing solution for IIoT environments in energy, industrial automation, and oil & gas applications.

In an IIoT environment, data is collected from a multitude of OT edge devices and transmitted to an enterprise IT cloud for analysis and storage. Insights gained from the processed data are then used by OT systems to implement appropriate actions. However, as cyberattacks are increasingly targeting cloud networks, more enterprises are looking for ways to secure the computing infrastructure that collects and processes data for their IIoT environments.

Industrial computers play a critical role in connecting industrial automation and control systems (IACS) to the cloud. Although this connectivity allows formerly private systems to be accessible from practically anywhere, transmitting confidential data over untrusted networks requires greater attention to network security and access to edge devices. Consequently, asset owners are becoming aware of the importance of cybersecurity and starting to adopt IEC 62443-3-3 system security practices to protect their IIoT applications from threats, such as unauthorized access, tampering, and data breaches.

UC-8200 Industrial Computers Features: Compact Arm-based computer for distributed IIoT applications  ISASecure SDLA (IEC 62443-4-1) and CSA (IEC 62443-4-2) SL2 certi-fied host device  Wi-Fi and LTE communication redundancy  Robust LTE Cat. 4 connectivity with RF and carrier approvals (Verizon, AT&T)  Rich set of communication interfaces including 2 serial, 2 Giga LAN, 1 USB, and 1 CAN ports and 4 DIs, 4 DOs

Certified for ISASecure SDLA (IEC 62443-4-1) and CSA (IEC 62443- 4-2) security level 2, Moxa UC-8200 computers feature the security functions and tools users need to easily redevelop and build a secure edge computing system, reduce unnecessary operational costs, and increase the usability and reliability of industrial assets to return higher profits. This bundled solution also provides a security diagnostic tool to help system integrators comply with IEC 62443-4-2 standards when any changes take place in the redevelopment process, as well as an accompanying hardening guide that instructs users on how to install, deploy, operate, and maintain their systems securely.

Moxa Industrial Linux 3.0.
Device availability is often the most critical aspect of an IACS. MIL3 provides UC-8200 computers with a system failback function, enabling automatic system recovery in case of a failure to ensure system data integrity. MIL3 also offers system snapshot and backup functions, ensuring that the UC-8200 can roll back to a designated secured backup when the system fails to boot due to a power outage during critical updates or under other circumstances, such as a security breach.

For comprehensive protection of system data from cyberthreats, the UC-8200 computers come with an NXP i.MX7 processor and OTP (one-time programmable) fuse, which acts as the Root of Trust and initiates a chain of validation sequences during bootup to ensure the authenticity and integrity of the bootloader and kernel before allowing them to decrypt the root file system with sensitive data using the password stored in the Trusted Platform Module (TPM) 2.0. System integrators can further extend the chain of trust to validate the integrity and authenticity of their deployed applications on the UC-8200.

@MoxaInc @OConnellPR #Pauto #IIoT #Cybersecurity

Process data and diagnostics from many field radar level transmitters.

Gathering and communicating critical measurement and diagnostic data in oil and gas applications can be extremely challenging due to the harsh and remote conditions associated with these operations. A company in Kuwait recently needed a way to acquire data from dozens of radar LEVEL transmitters in the field, and in addition, provide power to these transmitters because there were limited power sources available at the site. Moore Industries HES HART to Ethernet Gateway System was able to fulfill both of these requirements.

The client multi-dropped six output loop-powered radar level transmitters to each single-channel HES for data acquisition, and utilized the HES transmitter excitation power supply feature to power the transmitters. The gathered process and diagnostic data was then sent over MODBUS/TCP from the HES back to the client’s BPCS (MODBUS/TCP Host) for higher level control, data acquisition and monitoring functions.

The HES offers a flexible and economical way to gather process data and instrument diagnostics from smart HART instruments and share it over an Ethernet infrastructure via its embedded web server or with MODBUS/TCP and HART-IP hosts. This enables fast and seamless connectivity for advanced monitoring of critical process variables and parameters. In addition to the single channel configuration outlined above, the HES is also available in a four channel configuration supporting up to 64 HART devices. The HES communicates with all HART 5, 6 and 7 devices including smart valves, multivariable flowmeters, pressure, pH, level, and temperature transmitters and more.

@MII_Worldwide #PAuto #Oil_Gas #Kuwait

Basics of metering systems, flow computers and instrument validation software.

Phoenix Contact and Krohne are presenting the webinar series “Basics of metering systems, flow computers and instrument validation software” from June 19 to July 3. It is aimed at planners, engineers and operators in the oil and gas industry.

In a series of 8 webinars hosted by the Krohne Academy online, the basics behind (custody transfer) metering systems and associated processes such as flow computing, proving and master metering will be outlined. Furthermore, wet gas wellhead measurement and instrument validation software processes will be explained.

More information on the webinars can be found HERE. Participation is free of charge.

@krohnegroup @PhoenixContactV @PhoenixContactU  #PAuto #Oil_Gas 

Enabling advanced analytics and faster data-based decision making.

The availability of Seeq connectors to CygNet enterprise SCADA and WITSML data storage systems has been announced by Seeq Corporation. Their comprehensive set of applications for analyzing process manufacturing data include Workbench for easy to use advanced analytics, Organizer for publishing insights in reports and dashboards, and Data Lab for accessing Python libraries. Seeq applications empower engineers and subject matter experts to rapidly investigate, collaborate, and share insights to improve operations and business outcomes.

According to CygNet, their SCADA platform is designed specifically for the oil & gas industry, provides a quick launch that collapses deployment time, saves millions of dollars in implementation costs, reduces IT project risk, and delivers the industry’s fastest time to value. Customers using Seeq together with CygNet will be able to achieve faster insights with predictive, diagnostic, and descriptive analytics.

Wellsite Information Transfer Markup Language (WITSML) is an industry initiative to provide open, non-proprietary standard interfaces for data transmission from rig sites to the offices of operators, oilfield service companies, and integrators. It is also used to share information among partners, vendors, and government agencies.

“Seeq connectivity to these oil & gas industry data sources will help companies tap advanced analytics for data-based decision making at a critical time in the industry,” says Will Knight, Global Lead for Seeq Partner Programs. “The need for innovation is tremendous, so we appreciate the efforts of our system integrator partners, such as TIGA, to assist customers in unlocking the value in their data.”

TIGA, based in Houston (TX USA), is a system integrator with a deep understanding of the specific challenges of oil & gas customers seeking insights in untapped silos of data. “We help our clients use CygNet and Seeq to capitalize on their data to drive innovation, transformation and cost savings in their organizations,” says John Miller, President of TIGA. “Furthermore, the WITSML connector will enable access to the operational data landscape, driving value and savings for our clients.”

The opportunity for operators using Seeq with WITSML systems is extending the value initially gained from initiatives to aggregate and visualize well data. Seeq support for WITSML empowers end users by overcoming the lack of time and tools for engineers to complete more advanced investigation and analytics initiatives. Process engineers and subject matter experts will now be able to analyze current and past drilling, completions and well intervention campaigns, for example to perform root cause analysis on equipment failure and optimize performance

All of the browser-based Seeq applications—Organizer, Workbench, and Data Lab—connect to a shared Seeq server to enable collaboration, access connected data sources, and enable administrative control. For example, graphics created in Data Lab may be viewed in Organizer Topics, data modeled in Workbench may be accessed by Data Lab users, and Data Lab algorithm results are available for use in the other Seeq applications.

"Seeq continues to release compelling analytics solutions for customers in process manufacturing and Industry 4.0 engagements," comments Janice Abel, Principal Analyst at ARC Advisory Group. "The need for the faster and better insights provided by Seeq is a consistent requirement for customers investing in IIoT and Smart Manufacturing."

@SeeqCorporation #PAuto #SCADA #TIGA #WITSML

Monitoring Technology in North Sea.

Wellhead pressure monitoring used as safety measure during the installation of replacement platforms and topsides during two-year redevelopment

Tyra field - North Sea.

Total E&P Denmark A/S has awarded Emerson a contract to provide wellhead pressure monitoring technology to enhance safety during the multi-year redevelopment project to extend the life of Denmark’s biggest gas field.

“Emerson’s wireless technology has been successfully deployed within offshore applications around the world, helping improve the safety of people and operations,” said Roel van Doren, president of Emerson Automation Solutions in Europe. “The ability to offer a complete solution capable of providing real-time measurement and awareness to help Total monitor and respond to pressure changes safely was a key factor in the use of Emerson technology.”

The Tyra field in the Danish part of the North Sea has been in production for more than 30 years but is today suffering from seabed subsidence. Since production started in the 1980s, the seabed has subsided by more than five metres, reducing the air gap between the sea level and the bottom of the platforms. In order to keep the Tyra field in production, Total E&P Denmark is replacing the existing wellhead platforms with new and elevated topsides. The 13-metre-high jacket extensions and new topsides will be installed on top of the existing jacket structures.

The Tyra redevelopment project will ensure continuous production from Denmark’s biggest gas field, while safeguarding Danish North Sea infrastructure. The $3.3 billion investment in the redevelopment is the biggest ever in the Danish North Sea. Once completed, Tyra is expected to produce more than 200 million barrels of oil equivalent. The current Tyra field has two production complexes, Tyra East and Tyra West, which are linked to satellite fields Harald, Roar, Svend, Tyra Southeast and Valdemar.

During the two-year shut-in, Emerson technology will monitor wellhead casing pressures as a safety measure. With power and cable infrastructure unavailable, a wireless and battery-powered solution is required. Emerson will provide more than 200 Rosemount™ wireless pressure transmitters to be installed on the four riser platforms. The devices will transmit data to two standalone Emerson DeltaV™ PK Controllers, to be installed on the offshore accommodation platforms. Data will be presented to construction workers locally on human machine interfaces and relayed to an onshore monitoring point and data historian.

#PAuto #Denmark @EMR_Automation @Emerson_News

Flexible and scalable SCADA.

Yokogawa has released FAST/TOOLS R10.04, the latest version of its real-time operations management and visualisation software*, and has released it for sale this month as part of its OpreXTM Control and Safety System family. A highly flexible and scalable supervisory control and data acquisition (SCADA) solution suitable for use in everything from smart IoT-enabled applications to enterprise-wide integrated operations spanning multiple sites and subsystems, FAST/TOOLS R10.04 will help customers derive maximum value from their investments over the entire system lifecycle.

Driven by the rising importance of factors such as the IoT, big data analytics, and the cloud, a digital transformation is underway that is leading to the convergence of information, operational, and engineering technologies (IT, OT, and ET) in unmanned, remote-controlled, and enterprise-wide operations. To benefit from near real-time transaction processing and other capabilities that already are well established in the IT domain, a growing effort is being made to achieve seamless integration and convergence with the OT domain.

As production and delivery cycles shorten and require greater flexibility, the real-time sharing of data on operational capacity/conditions and its use in production/maintenance planning and forecasting become critically important factors in improving a company’s bottom line results. A modern open SCADA platform should be able to bridge the legacy gaps between the IT and OT domains by leveraging OPC Unified Architecture (OPC UA), upcoming IoT standards, and open database interfaces. By simplifying operations, automating activities, and enhancing user insights, operating expenditure (OPEX) can be reduced.

Recognising that most enterprises will take a profit-driven approach and seek to reduce risk with their management and control solutions, Yokogawa continues to pursue innovations that will ensure its customers are able to transform their data into meaningful information and get the most out of their investments.

FAST/TOOLS R10.04 supports the digital industrial ecosystem with information models that simplify and enhance sub-system integration with the CENTUM VP integrated production control system.

1. Improved system integration capability
For improved integration with CENTUM VP, the graphics integration tool that is provided with FAST/TOOLS has been enhanced. Along with the FAST/TOOLS portfolio of supported industry standard interfaces and protocols which has the addition of support for Mitsubishi MELSEC iQ-R series controllers and the FINS protocol used by Omron programmable controllers.

2. Improved security and integrity
To make it easier to incorporate FAST/TOOLS into an existing IT infrastructure, authentication and authorisation services are now handled as one centralised process for all system users. One benefit of this is that all logged-on/off activities will be visible in one window, allowing for improved audit trailing and user management. In addition, when making use of an Active Directory (AD) for the single sign on (SSO) mapping function, users with profiles in multiple AD domains can have a merged user profile in FAST/TOOLS, in accordance with authentications and authorisation credentials. The FAST/TOOLS encryption process has also been improved to provide more secure communication between server and clients.

3. Improved engineering environment for HTML5-based visualisation
The FAST/TOOLS graphics editor is able to generate native displays to the HTML5 standard for both information-rich PC-based applications and light-view tablet and smartphone applications. An enhanced graphics editor simplifies the task of creating screens that deliver exactly the data operators require.

The main tagets markets include oil and gas upstream, midstream gas and (multi-product) liquid pipelines (for which the standard EPMS applications suite is available), petrochemicals, chemicals, renewable energy, power, pulp and paper, pharmaceuticals, food, mining, iron and steel, water distribution and wastewater treatment.

It is envisiged for use in monitoring, operation, control, data collection, and data storage for geographically distributed facilities.

*Outline of FAST/TOOLS Over the past decades FAST/TOOLS has evolved from centralised SCADA/MES and HMI software to an enterprise automation environment. This state-of-the-art IIoT enabled industrial SCADA software benefits our customers through improved visualisation, collaboration, decision support, configuration, communication, security, deployment, connectivity, operational alarm management/analysis, and history data storage/management. For added reliability, FAST/TOOLS can be set up to run on systems that employ Yokogawa’s advanced dual-redundant technology, enabling automatic switch-over to a backup system in the event of a hardware failure.

#SCADA @YokogawaIA #PAuto

Potential for Unconventional Oil and Gas Operators.

By adopting advanced automation technologies and new processes, unconventional oil and gas operators can move from average to top quartile performance, capturing up to $7 billion (€5.8b) in profits annually, according to a recent study conducted by Emerson and industry benchmarking firms of onshore producers in the lower 48 US states. The study consists of data and analysis compiled from publicly available industry benchmarking, financial and operational data supplied by industry producers.

In a ‘lower for longer’ oil price environment, many companies are turning to Industrial Internet of Things (IIoT) technologies and the promise of digital transformation to help embed expertise in work processes, improve production and begin the path to operational excellence. Emerson’s Operational Certainty™ programme helps oil and gas operators confidently deploy a digital transformation strategy in a targeted, scalable and measurable manner. Emerson estimates an average operator that adopts a comprehensive improvement programme could see profitability improve by as much as 10 percent.

The analysis shows higher production rates, lower lease operating expenses (LOE) and a reduction in safety risks have the greatest impact on overall operational improvements. Improvement in these areas matters most to liquids-weighted unconventional oil and gas operators and helps them achieve top quartile performance. Top quartile is defined as achieving operations and capital performance in the top 25 percent of peer companies and requires changing historic work processes across multiple functions.

For unconventional oil and gas operators, Emerson identified key technologies to quickly improve operations in a scalable way:

• Optimising production with automated production surveillance, modelling and analytics and implementing produced fluids management techniques to reduce lost and unaccounted-for production.
• Improving equipment reliability by leveraging analytics and automation diagnostics to lower LOE, providing greater visibility of costs per well.
• Using prescriptive instead of reactive maintenance to improve health, safety, security and environmental compliance (HSSE) and reduce personnel exposure.

By harnessing the power of the IIoT and other transformation technologies, advanced automation systems can optimise operations with real-time information from a pervasive sensing layer and securely feed that data to robust standard analytics applications. With this data, experts – anywhere in the world – have better insight to respond quickly and confidently to changing conditions. This provides oil and gas operators the diagnostic capabilities and data insights to predict instead of react to issues, make better decisions and reduce risks.

“There’s broad knowledge among operators about improving production, yet understanding how to consistently achieve real, sustainable savings is not as clear,” said Chris Amstutz, vice president, oil and gas industry programmes, Emerson Automation Solutions. “For example, we have the software now to help production meet targets by leveraging the latest reservoir model data that shows what’s going on in the field to avoid drilling the wrong wells.”

The digital transformation of exploration and production means higher production rates, lower LOE and reduced safety risks, among other benefits. Emerson’s Operational Certainty Consulting Group advises operators to start their digital transformation by developing a practical blueprint that leads to higher production with more actionable and timely insight into the performance of the field, minimising HSSE risk by enabling the workforce with remote field intelligence and reducing LOE by optimising work processes and logistics.

@EMR_Automation #PAuto #Oil_Gas @Emerson_News @HHC_Lewis 

Progressing the digital oilfield!

Endress+Hauser has aligned partnerships with Angus Measurement Services,  TechnipFMC and its Authorized Service Provider, Vector Controls. The automation companies will collaborate to bring added value to the oil and gas industry, assisting customers with transition to the digital oilfield.

“Endress+Hauser is excited to work alongside Angus Measurement, TechnipFMC and Vector Controls,” said Brian Hoover, Business Development Manager, Endress+Hauser. “Together we deliver real-time information on product quality, quantity and value for our customers in the oil and gas industry.”

The partnership alignment between the automation companies is to inform and better prepare the oil and gas industry and customers for Industry 4.0. The oil and gas industry has played a pivotal role in the economic transformation of the world. Today the industry has the opportunity to set new parameters and direction through digitalization.

The companies’ combined strengths and expertise will provide oil and gas customers measurement certainty, better operational performance to enhance revenue, improved safety of operations, regulatory compliance and predictive maintenance, lowering the total cost of operations and optimizing the measurement and management of our customer’s gas, oil and water resources.

“It’s the people that make the difference. Their understanding and years of experience are enablers that generate revenue and create value for our oil and gas customers and their shareholders,” said Hoover.

The technology will be brought to the field by a dedicated team of oil and gas experts. Each partner will contribute focused areas of expertise, including best-in-class products and/or services to oil and gas customers:

• Endress+Hauser’s intelligent field instruments and digital communication expertise captures and transmits product quality, quantity and value
• Angus’ systems fabrication and technology consultants helps customers optimize the performance of gas, oil and water assets
• TechnipFMC’s oil and gas measurement technology and design capabilities deploy best-in-class technology and develop modularized systems
• Vector’s expertise in gas analytics, measurement and control provides the opportunity to deploy best-in-class solutions.

“With this partnership, we bring preeminent value, that transcends that of any other technology provider,” said Hoover. “We deliver industry expertise that is unparalleled and systems capabilities that can digitalize the oilfield of the future - delivering Industry 4.0 to the oil and gas industry today.”

@Endress_US  #PAuto #Oil @TechnipFMC

Wirelessly-monitored storage tank emergency vents.

Emerson has introduced wirelessly-monitored Enardo 2000 emergency pressure relief vents (EPRVs) that provide safety control by managing abnormally high storage tank pressures in the oil and gas, chemical, petrochemical and pharmaceutical industries.

Under normal operating conditions, an EPRV remains closed. The immediate knowledge of an open position can be vital and should warrant quick investigation. However, because these EPRVs are located on top of storage tanks, they are difficult to monitor. Site managers are increasingly looking for ways to increase safety and efficiencies.

“Though EPRVs represent the last line of defence against tank overpressure, they have largely remained unmonitored,” said Steve Attri, product manager for Emerson Process Management. “Along with the recent introduction of wirelessly-monitored pressure vacuum relief vents (PVRVs), more information is now available to quickly identify and resolve pressure issues that can impact safety and emissions.”

The new product design consists of a proximity indicator and wireless transmitter integrated with an EPRV. The proximity indicator senses movement of the emergency vent. ‘Open’ or ‘closed’ signals are received by the wireless transmitter and can be sent to a control room via a WirelessHART® gateway.

@EmersonProcess #PAuto #Pharma #Oil