CorrosionRADAR has launched its CR:SR sensor solution, a new short-range sensor technology that expands its corrosion under insulation (CUI) intelligence portfolio and helps to transform CUI management from a reactive inspection activity into a proactive intelligence-led approach.
The corrosion threat
Corrosion is an ever-present threat to asset integrity in the oil and gas industry, with industry studies estimating the global cost of corrosion exceeds $2.5 trillion annually.
CUI, which is a particularly insidious form of corrosion as it is difficult to detect at an early stage, occurs due to moisture build up on the external surface of insulated equipment and structures, and is prevalent in the onshore and offshore oil and gas industries.
Predictive corrosion monitoring
Predictive corrosion monitoring solutions facilitated by advances in AI and digital technologies can help operators proactively manage their corrosion challenges and protect their assets, allowing them to monitor and predict risk remotely and make data-driven decisions, saving time and money, while enhancing safety and ensuring the longevity of critical infrastructure.
CorrosionRADAR is using this approach to transform CUI management with continuous monitoring and intelligence-based analytics that save time, improve uptime and reduce the risk of catastrophic failures.
Remote sensor-enabled CUI monitoring programs help operators focus resources on the locations that matter most while reducing unnecessary inspection costs and operational disruption.
The new CR:SR sensor solution has been developed for targeted, localised (short-range) monitoring without the need to remove insulation. It complements CorrosionRADAR’s existing CR:LR solution, which delivers permanently installed, long-range monitoring across vessels, columns, tanks, and other complex assets.
The new sensor passes monitoring data to the AI-informed CR:CLARITY software for consolidation, analysis and reporting. The launch strengthens CorrosionRADAR's end-to-end CUI Intelligence offering, giving operators proven options to understand where CUI risk is developing, how it is evolving, and what action to take next.
Together, the CR:LR and CR:SR sensors address the challenges of traditional inspection programs by providing continuous visibility between inspection campaigns. CUI data is constantly collected and analysed by the CR:CLARITY software, enabling operators to prioritise inspection activity based on changing risk conditions rather than fixed inspection intervals.
Dr. Chiraz Ennaceur, Chief Executive Officer at CorrosionRADAR, said, "At CorrosionRADAR, we recognise that every asset presents a different CUI challenge. Some assets require broad coverage across large areas, while others benefit from targeted monitoring of specific high-risk locations. By expanding our portfolio to include the CR:SR sensor solution and bringing all monitoring data together through CR:CLARITY, operators gain greater flexibility in how they monitor CUI while maintaining a single view of risk across their assets."
As Shell Offshore Inc gives up 50% non-operated working interest in the Na Kika platform and associated fields in the Gulf of America, buyers Talos Energy and Ridgewood Energy will be required to assume certain decommissioning obligations with security coverage.
Approximately US$1.7bn transaction, it will also include the Coulomb tieback, which belonged entirely to Shell.
In Shell's outlook, Na Kika and Coulomb can be considered rapidly declining assets, which may reach end of life over the next few years. Last year, the assets generated around 37,000 barrels of oil equivalent per day for Shell. Its proven reserves generated from Na Kika by the end of 2025 were 4.3 million barrels of oil equivalent (boe) while from Coulomb it were 7.2 million boe. The major is now reshaping its deepwater asset portfolio with a focus on attaining scale, efficiency and infrastructure.
“The Gulf of America is one of our highest-value basins, and we are actively shaping our portfolio to ensure our Upstream business continues to be resilient and increasingly competitive,” said Peter Costello, Shell’s Upstream President. “We remain focused on sustaining our material liquids production into the next decade.”
The Na Kika semi-submersible platform is Shell’s only non-operated platform in the Gulf of America, which began producing in 2003. bp, as operator of the platform, holds the remaining 50% working interest. The Coulomb tieback has been producing since 2005.
The United States remain a key market for Shell, with operations and interests in all 50 states. The company is one of the frontrunners in the Gulf of America as deepwaters operator, with significant presence in the region as an oil and gas producer and US LNG buyer.
As part of portfolio optimisation and growth strategy, Baker Hughes Company's acquisition of Chart Industries comes as a value addition for the industrialised energy solutions company.
“Chart’s thermal management solutions bring complementary capabilities and aftermarket service offerings that accelerate our portfolio strategy,” said Baker Hughes Chairman and Chief Executive Officer, Lorenzo Simonelli. “Together, we will expand the solutions we deliver across a broader range of energy and industrial markets and create greater value for customers and shareholders. We welcome our new colleagues to Baker Hughes and look forward to working with them to deliver disciplined execution and maximise synergies as we move forward.”
Baker Hughes Chief Infrastructure & Performance Officer Jim Apostolides has been appointed senior vice president to lead the Chart segment.
“Congratulations to Jim on his well-deserved appointment as segment leader,” Simonelli added. “Jim’s business rigor, demonstrated through decades of global supply chain experience and operational leadership of large complex facilities around the world, makes him well-suited to lead implementation of the Baker Hughes Business System within Chart. We look forward to his leadership and continued success, quickly delivering value for our customers and shareholders as one company.”
Chart will be a new reporting segment within Baker Hughes, adding to the scale and strategic importance of its diverse services in air and gas handling, thermal management, and lifecycle services. For Chart, the acquisition means full integration and synergy capture across Baker Hughes while keeping its commercial and operational focus intact.
Baker Hughes is increasingly prioritising synergy capture in supply chain, functional support and manufacturing to achieve cost optimisation. Its signature Business System is supporting operational alignment as part of its newly launched comprehensive integration programme. The Chart acquisition will solidify Baker Hughes' industrial portfolio and enhanced recurring aftermarket services.
Decom Engineering has secured contracts worth an estimated £4.5mn during H1 2026, surpassing its original full-year target and placing the company in a strong position to mark a record annual revenue of £6mn.
The performance reflects the growing international demand for Decom’s specialist cold cutting technologies and engineering expertise, offshore and onshore, across decommissioning scopes as well as installation and commissioning projects.
Projects have been secured across North America, South America, Africa, the Middle East, Australia and the North Sea, ranging from chain cutting projects to large-scale subsea structural removal.
In Australia, Decom has completed a subsea flexible flowline removal campaign with Cyan Renewables over a five-month campaign, while in Canada, a summer-long East Coast installation campaign is underway using the C1-16 UL Chopsaw with follow-on campaigns scheduled for 2027 and 2028.
The ultra-light C1-16 Chopsaw is being utilised on a variety of projects – two are permanently deployed on mooring chain cutting scopes offshore Brazil, while in the UKCS another is engaged on a 60-day campaign cutting chains and risers on an FPSO.
Another chain cutting project for an FLNG operator offshore West Africa in underway, while in the Middle East, Decom has developed a custom-built TRACS-32 unit that will be ready to start work in Q4 2026.
Decom Engineering Managing Director, Nick McNally, said, “Decommissioning remains a core strength of the business, but installation work – supporting clients during the deployment of new subsea assets rather than only at the end of asset life – has become a significant part of our project pipeline. Changing market conditions and better market alignment is one factor behind this year’s growth but this sits alongside a major overhaul of our product design, and a change in engineering culture with a focus on innovation, which allows us to be more responsive to customer’s requirements.”
Chairman Keith McDermott added, “We set a target of £4.3mn for 2026 and we have already exceeded at the halfway stage, so expect to double our year-on-year revenue, and have a raft of work already secured for 2027. What is encouraging is that while our decommissioning legacy is a core element of our business, clients are increasingly recognising the value of engaging our technology and expertise much earlier in the lifecycle of an asset.”
Oceaneering International has announced that its Integrity Management and Digital Solutions (IMDS) segment has been awarded a five-year inspection and asset integrity services contract by a Qatar-based oil company.
The contract followed a competitive tender process and reinforces Oceaneering’s role in providing integrity management services in Qatar after operating in the country for more than 20 years.
Under the contract, Oceaneering will deliver non-destructive testing, inspection services and value engineering, utilising its established local workforce and leveraging Inform, its digital inspection software. The scope may also include deploying Vision, a data visualisation platform.
Leo Granato, Senior Vice President of IMDS, said, “This award underscores our ability to deliver reliable, digitally enabled integrity solutions that enhance production reliability and asset uptime while supporting regulatory compliance. Our established team in Qatar enables safe and consistent execution of our innovative solutions, while deepening the development of local talent.”
Stressing on the urgency to incentivise energy production instead of relying on imported oil and gas, Offshore Energies UK (OEUK) has expressed the need for early implementation of the government’s proposed Oil and Gas Price Mechanism as it can potentially unlock an additional £50 billion in oil and gas investment.
The body has urged a priority visit by Prime Minister Andy Burnham so that the North Sea's offshore industry stakeholders from operators to supply chain players can expect a positive shift in government attitudes towards the sector.
“The UK will still need oil and gas for decades to come. The question is whether we produce as much of that energy as possible here — supporting our own jobs, communities and economy — or rely increasingly on imports while exporting investment and economic value overseas. Government policy should back North Sea production as part of a secure and managed energy transition.
“Energy policy cannot be made in Westminster alone without listening to the people and communities who have powered this country for the last 50 years. For too long, offshore workers, engineers, technicians and those across the energy supply chain have been talked about rather than listened to. A visit to meet the North Sea workforce would demonstrate that the new Government intends to build a different relationship with the people and communities at the heart of Britain’s energy system.
"The new Prime Minister must now turn listening into action. Words of support for projects such as Jackdaw and Rosebank cannot be a substitute for the policy reset our country needs. The new Government must back North Sea oil and gas over increased reliance on imports — delivering the fiscal and regulatory reforms required to unlock investment, protect domestic jobs, strengthen energy security and support the energy transition,” said David Whitehouse, Chief Executive of OEUK.
North Sea's decades-long legacy of offshore exploration needs digital innovations to continue thriving in the current era of sustainability. The recently concluded OWI EU 2026 in Stavanger, Norway, celebrated the rich legacy of the North Sea, by fostering crossborder collaboration, digital innovation, and exchanging ideas on sustainable interventions.
Keeping up with production goals from the largely declining North Sea assets will inevitably require rapid digitalisation of the sector. As operators are now having to work under dynamic conditions, requiring fast yet accurate decisionmaking, they need the support of integrated digital platforms that combine real-time data, historical well information and advanced analytics to improve visibility across their assets. Tools, such as digital well barrier schematics, are helping reduce manual effort and enabling more consistent, standardised approaches to integrity management.
Offshore Netwrok has recently released a report reflecting North Sea's stronghold in the global well intervention industry. The region's well intervention scene is way past the stage of new innovations and is just a few steps away from becoming an established norm. Click here to download the report.
Aquaterra Energy has highlighted growing confidence in Australia's offshore decommissioning sector following this year's Decommissioning & Abandonment Australia 2026 conference.
In a blog published on the company's website, Head of Engineering Matt Marcantino said the industry is placing greater emphasis on early planning, collaboration and long-term investment as it prepares for an increasing volume of decommissioning work.
"Decommissioning has changed significantly over the last 10 to 15 years, but it certainly hasn't become any easier," he wrote, noting that end-of-life projects are now being considered much earlier in the asset lifecycle.
Reflecting on discussions at the event, hosted by the Centre of Decommissioning Australia (CODA) together with Offshore Network, Marcantino said operators, regulators and contractors openly discussed challenges including regulatory complexity, supply chain investment and workforce capability.
“What impressed me was that none of these felt like uncomfortable topics,” he said.
“Operators, regulators and contractors were raising them in the same conversations, with the same level of candour.”
The blog also pointed to a shift away from one-off projects towards longer-term programmes, with operators increasingly engaging contractors earlier in the planning process to reduce risk and improve project outcomes.
Marcantino said regulators appeared focused on supporting progress while maintaining safety and environmental standards, adding that early engineering and planning work is becoming increasingly important in reducing uncertainty before project execution.
Looking ahead, he noted that Australia is building momentum as a decommissioning market despite the challenges that remain.
“At a time when parts of the global decommissioning sector feel uncertain, Australia is building real momentum," he added.
“If that collaborative mindset continues, I believe it has every chance of becoming one of the world’s leading decommissioning markets over the coming decades.”
Expro, a global energy services provider, has showcased through a recent case study how advanced subsea technology enabled safe, efficient well abandonment
Operating in some of the world's most challenging offshore environments demands technologies that can maintain safety, reliability and operational efficiency even when weather conditions deteriorate. A recent case study from Expro demonstrates how the company successfully supported a complex subsea well abandonment campaign in the harsh waters north-east of Shetland, delivering consistent performance despite repeated weather-related disruptions.
The project involved the safe re-entry into five subsea wells as part of a well abandonment programme. Conducted from a floating Mobile Offshore Drilling Unit (MODU), the campaign faced demanding operating conditions characterised by frequent storms, heavy swells and rapidly changing sea states. These conditions increased the risk of non-productive time (NPT), making dependable well integrity systems and robust disconnect capability critical to maintaining safe operations.
Expro was selected for the campaign based on its established expertise in subsea well integrity, proven control barrier technologies and reliable disconnect systems. Building on an ongoing relationship with the operator, the company was chosen for its technical capabilities, field-proven equipment and operational performance in extreme offshore environments.
Throughout the campaign, Expro's Subsea Safety Tree (SSTT) system played a central role in maintaining operational continuity. Adverse weather conditions required the primary SSTT system to be unlatched on five separate occasions to allow safe disconnection from the well. Despite these interruptions, every unlatch and subsequent relatch operation was completed successfully on the first attempt without incident.
The extended campaign also demonstrated the durability of the equipment. During operations, the SSTT system completed 1,114 valve functions and accumulated 2,490 operating hours while maintaining full operational integrity. Even after extensive use, the system continued to perform reliably, highlighting its resilience in one of the industry's most demanding offshore environments.
A key factor behind the project's success was the combination of reliable technology and experienced offshore personnel. The SSTT's dependable unlatching capability enabled safe disconnection during severe weather, while its high-performance latch mechanism ensured repeatable, reliable reconnection each time conditions improved. Careful planning and close coordination by Expro's offshore team further supported the seamless execution of the campaign.
According to the case study, the solution enabled the operator to complete all required completion intervention activities for the well abandonment programme without experiencing non-productive time. The combination of proven equipment reliability, first-time operational success and effective collaboration between offshore personnel and technology helped deliver safe and efficient operations throughout the project.
The campaign also demonstrated the importance of robust subsea intervention systems as offshore operators continue to prioritise safe and cost-effective well decommissioning. By maintaining continuous performance under challenging conditions, the project illustrates how advanced well integrity technologies can reduce operational risk while supporting efficient abandonment programmes in increasingly demanding offshore environments.
The offshore oil and gas sector in Australia operates within one of the most demanding physical environments in the world.
As facilities mature and production demands shift, the necessity for robust asset integrity management has never been more critical. Overseeing this high-stakes domain is the National Offshore Petroleum Safety and Environmental Management Authority (NOPSEMA), Australia's independent expert regulator. Tasked with ensuring health, safety, environmental management, and structural and well integrity in Commonwealth waters, NOPSEMA drives the regulatory landscape that governs the lifecycle of every offshore facility.
At the core of Australia’s offshore regulatory framework is the Offshore Petroleum and Greenhouse Gas Storage Act 2006 (OPGGS Act), alongside a comprehensive suite of associated regulations. This legislative foundation dictates that no offshore petroleum activity can commence until NOPSEMA has strictly assessed and accepted a detailed risk management plan. The fundamental standard for these plans is the demonstration that an organisation will manage risks to structural and well integrity to a level that is "as low as reasonably practicable" (ALARP).
Recent Legislative Updates and Risk Management
Recently, the regulatory regime has seen significant updates, including the implementation of the Offshore Petroleum and Greenhouse Gas Storage (Safety) Regulations 2024. These legislative revisions reflect a modernised, highly risk-based approach to oversight, ensuring that regulatory resources are precisely targeted toward the industry's most pressing vulnerabilities. NOPSEMA expects duty holders to continuously evaluate their control of work systems, from detailed job task analyses to robust permit-to-work processes. By aligning these operational protocols with evolving international best practices, operators can eliminate or drastically reduce the inherent risks associated with complex offshore activities.
NOPSEMA’s National Priorities
To provide clear strategic direction, NOPSEMA has identified key areas requiring sustained regulatory attention through its Five National Priorities. Foremost among these is structural integrity, ensuring offshore assets remain inherently safe, efficient, and fully compliant throughout their operational lives. A continuous lifecycle approach is essential, particularly as operators must proactively combat the severe risks associated with long-term marine operations, such as relentless corrosion, fatigue, and environmental stress.
Another critical priority is the responsible management and permanent decommissioning of redundant offshore wells. Timely and effective well plugging and abandonment are treated as essential for long-term risk management and environmental protection, effectively minimising the potential for any disastrous loss of well control. The remaining national priorities focus heavily on protecting worker psychosocial health, improving the overall control of work to prevent recurring incidents, and emphasising how executive leadership decision-making directly impacts offshore safety outcomes.
Managing Ageing Offshore Infrastructure
A central challenge currently shaping the regulatory landscape is the complex management of mature offshore infrastructure. NOPSEMA has provided dedicated guidance on ageing assets and life extension, urging duty holders to rigorously review their existing management systems. Crucially, the regulator clarifies that asset degradation is a condition-based, rather than strictly time-based, phenomenon. As NOPSEMA’s official guidance notes: "Ageing is not about how old your equipment is; it is about its condition, and how that is changing over time."
This vital distinction means that operators cannot rely solely on predetermined chronological milestones to dictate their maintenance schedules. Instead, they must deploy advanced monitoring techniques to continuously assess for material deterioration, damage, and any increasing likelihood of failure. It is imperative that offshore operators implement robust inspection, maintenance, and repair programmes tailored to the actual physical condition of the plant. If an asset's condition unexpectedly deteriorates, operators are legally required to instigate comprehensive recovery plans to promptly restore integrity and bring the associated risks back down to the ALARP threshold.
Successfully navigating the evolving regulatory landscape for asset integrity management in Australia’s offshore oil and gas sector demands far more than basic compliance. It requires a proactive, strategic commitment to continuous operational improvement. By integrating structural integrity, responsible decommissioning, and dynamic asset management into their core strategies, operators can ensure they meet NOPSEMA’s rigorous standards while safeguarding their workforce and the marine environment.
With the offshore industry largely prioritising brownfield over greenfield projects to advance optimisation and sustainability, digitalisation has been a primary driver of the transition journey.
It has facilitated complex data and process integration, eliminating hours of menial tasks so that operators are free to make prompter decisions and can attend to areas where it really matters. When the focus is set straight, complex intervention processes become simplified with quicker turnarounds at half the cost of traditional approaches.
With an ideal setup of digital asset integrity management in place, operators can remotely monitor risks at the most inaccessible parts of gigantic offshore platforms and take timely action.
Offshore environments can be accessed without arranging for ropes or scaffolding when aerial drones can reach the targeted area and click high definition images with inbuilt thermal and optical cameras. These are equipped to clearly capture splash zones, flare tips and under-deck structures.
Without diving into the ocean, everything from subsea manifolds or wellheads to pipelines can be scanned to check for leaks with the help of remotely operated or autonomous underwater vehicles. This is made easy with machine-vision artificial intelligence (AI) driving these vehicles.
AI can also detect and track minute shifts in temperature and vibration in critical offshore turbomachinery. This helps to flag failures way ahead in time, avoiding emergency downtime situations. Non-intrusive wireless sensors, for example, can raise alarm in cases of internal sand erosion or chemical corrosion in subsea and topside pipes. When clamped to the right zones, these sensors come alive to feed consistent, real-time information on pipe wall thickness.
One of the most innovative solutions that digital asset integrity management has seen is digital twins or virtual 3D replicas of complex platforms placed deep offshore. These replicas can combine hull structural models with real-time wave, wind and mooring line tension data. They consistently update the fatigue life calculation of floating production storage and offloading (FPSO) units or tension-leg platforms.
Digital twin providers, FutureOn and SteelTrace, have collaborated to bring a one stop shop to operators, where all disconnected systems and archived documentation can be accessed in one place.
“A digital twin only delivers real value when it gives engineers immediate access to the information behind the asset. As offshore infrastructure matures, operators need trusted material information to extend asset life, support maintenance and plan for decommissioning.
“Bringing SteelTrace's verified material records directly into FieldTwin enables operations teams to quickly access the documentation they need to support maintenance, in-field repairs and decommissioning without searching across multiple systems,” said Filip Valica, vice president – corporate development at FutureOn.
Once SteelTrace’s Smart Manufacturing Records is integrated into FutureOn’s FieldTwin, a digital twin platform for offshore energy projects, operators can easily locate quality documentation, allowing faster maintenance and integrity decisions while maintaining a complete audit trail.
The integration will address a common challenge across offshore projects. Extensive data output from manufacturing and construction phase such as material test records (MTRs), weld records, coating documentation, non-destructive examination (NDE) results and fabrication sign-offs often ends up separated from the engineering models and operational systems used to manage offshore assets. The integrated solution will take care of this lack, ensuring easy access for operators.
Engineers will now be able to move directly from an asset in FieldTwin to the certificates, inspection records and manufacturing data that verify how it was manufactured, inspected and installed.
SteelTrace’s blockchain-backed Smart Manufacturing Records (SMRs) replace static PDF certificates with structured digital records that provide a verified audit trail from raw material through fabrication and installation. The integration will bring these records directly into FieldTwin, improving traceability without changing existing engineering workflows.
“Every offshore asset has a history. From the steel mill through fabrication and installation, thousands of records are created to demonstrate quality and compliance. The challenge isn't creating that information, it's making sure engineers can easily access it years later when they need it most.
“By connecting SteelTrace with FieldTwin, we're making verified material records available alongside the asset itself,” said Tom Meulendijks, CEO and founder of SteelTrace.
Australia’s offshore energy sector stands at a monumental crossroads.
Beneath the churning waves, an industrial transformation of unprecedented scale is underway. Australian operators and regulatory bodies face an incredibly complex dual mandate as the world pivots away from fossil fuels towards a sustainable future. They must safely decommission a sprawling network of ageing petroleum assets whilst simultaneously accelerating the deployment of new offshore renewable energy infrastructure.
The Burden of Ageing Maritime Infrastructure
To grasp the magnitude of this transition, one must look at the physical footprint of Australia's legacy installations. The condition of this infrastructure is defined by its advancing age. Today, more than half of the nation's offshore petroleum assets have been operating for over twenty years, with several facilities exceeding half a century. This aging architecture encompasses over 1,000 wells, various floating and fixed facilities, and nearly 5,000 kilometres of subsea pipelines. As these stalwarts of the fossil fuel era reach the end of their productive lives, the sector faces a colossal wave of decommissioning. The financial liability for safely dismantling these structures over the next fifty years is staggering, estimated between US$30bn and US$50bn.
The Renewable Energy Dawn
As traditional oil and gas strongholds like the Gippsland Basin grapple with declining reserves, a dynamic new era of offshore production is taking shape. To facilitate this, the Australian Government implemented a forward-thinking regulatory framework via the Offshore Electricity Infrastructure Act 2021. This legislation paves the way for the construction, operation, and maintenance of modern marine energy projects. The sector's focus is shifting rapidly towards large-scale commercial offshore wind farms, designated in specific zones to underpin the national energy transition. Feasibility licences are also being explored for alternative marine energies, including offshore solar and wave energy plants. For operators, this creates a delicate balancing act: winding down legacy infrastructure whilst applying deep-sea expertise to construct sustainable energy hubs.
Managing these ocean-bound assets through such a profound transition introduces severe integrity challenges. One pressing risk occurs when production ceases but physical dismantling has not yet begun. During this precarious timeframe, assets enter a highly vulnerable "twilight period." Stripped of human presence, uncrewed platforms and dormant pipelines become exceptionally susceptible to inadvertent damage from routine maritime traffic, such as commercial fishing trawlers. These undetected collisions frequently result in dangerous "silent incidents". Furthermore, recent data reveals that nearly 25 per cent of all offshore wells suffer from some form of well integrity issue. If not rigorously monitored and remediated, these abandoned wells pose a severe hazard to the marine ecosystem.
Compounding these physical risks is a lack of local decommissioning precedent. Unlike the mature markets in the North Sea or the Gulf of Mexico, Australia's decommissioning industry remains in its infancy. This lack of regional experience, exacerbated by specialised equipmencanvat shortages and a fragile supply chain, inflates the risk of budget overruns and safety breaches. Crucially, human factors are taking centre stage. Regulators like NOPSEMA have elevated psychosocial health to a national priority, placing it on par with physical safety protocols. The rationale is clear: effective decision-making under immense pressure is vital for preventing technical failures in these hostile environments.
Forging a Future-Proof Strategy
To safely navigate these risks, operators must urgently adopt dynamic, technology-driven asset integrity management strategies. This approach demands enhanced maritime intelligence, utilising real-time vessel tracking to monitor behavioural patterns around unattended, late-life installations. By anticipating maritime traffic, operators can actively prevent costly collisions. Additionally, integrity strategies must mandate rigorous post-production monitoring for plugged and abandoned subsea wells, extending strict oversight through the entire asset lifecycle.
Risk profiles must remain highly adaptive, ensuring protocols guarantee that risks are maintained "As Low As Reasonably Practicable" (ALARP), heavily relying on remote monitoring and automated alert systems. Success hinges upon collaborative knowledge sharing. By working intimately with NOPSEMA, the Offshore Infrastructure Regulator, and adopting international best practices, Australia can protect its marine environments whilst ensuring commercial viability in a radically transformed energy landscape.
Australia's industrial and energy sectors face immense pressure to maintain ageing infrastructure while managing complex modern operational environments.
At the absolute core of these modern industrial challenges is workforce capability and human factors. In the high-stakes realm of Australian Asset Integrity Management, balancing technical demands with human limitations is no longer just an optional enhancement; it is a fundamental strategic necessity. To ensure long-term sustainability, operators must intentionally "Overcome workforce, budgetary and logistical constraints by building high-performing teams capable of identifying, mitigating and managing critical asset integrity risks."
The Pressures of Workforce and Budgetary Constraints
The Australian industrial landscape is currently grappling with a severe skills shortage, compounded by the realities of an ageing workforce. A substantial proportion of seasoned integrity engineers and specialised inspectors are rapidly approaching retirement age. Their departure represents a profound loss of tacit knowledge, the vital ability to recognise subtle indication patterns or failure precursors that is incredibly difficult to replace with automated technology alone.
Furthermore, stringent budgetary constraints and complex logistical hurdles mean that maintaining safe operations in remote or harsh environments has never been more difficult. Without highly skilled workers available to operate and implement asset integrity strategies, routine maintenance and inspection tasks become prohibitively expensive and practically unachievable. The stakes are remarkably high; poor asset documentation and work-related incidents cost the Australian economy an estimated $28.6 billion annually. Consequently, executives must find innovative ways to do more with less, without compromising on stringent safety standards.
Understanding Human Factors in Asset Management
To effectively counteract these compounding constraints, organisations are increasingly pivoting towards a much deeper understanding of human factors. The National Offshore Petroleum Safety and Environmental Management Authority (NOPSEMA) defines human factors directly as 'the ways in which the organisation, the job, and the individual interact to influence human reliability in hazardous event causation'.
Historically, research has demonstrated that between 75 and 80 per cent of accidents across high-risk sectors involve deficiencies in human performance, rather than purely mechanical or technical failures. Even within highly controlled maintenance environments, human error is a significant vulnerability; for instance, between 12 and 20 per cent of aviation accidents involve maintenance-related human factors. Errors typically manifest as slips, lapses, or mistakes. Slips and lapses occur at the point of task execution—such as accidentally skipping a vital step in an isolation sequence, or loosening a valve when intending to tighten it. By deeply understanding these cognitive and physical interactions, responsible parties can implement robust barriers that dramatically improve human reliability and mitigate potential errors.
Building High-Performing, Resilient Teams
How do organisations overcome these layered challenges and prevent critical errors? The solution lies in building high-performing teams that are technically competent and actively empowered to communicate risk. Modern operators increasingly require multi-skilled personnel who possess cross-disciplinary capabilities spanning condition monitoring and non-destructive testing.
Organisations must minimise operational mistakes through robust competency assurance processes, comprehensive task-based training, and proactive supervision. To build authentic workforce capability, management must foster an open, fair reporting culture where co-workers feel entirely comfortable observing and challenging one another regarding safety practices. Additionally, fatigue risk management, the reduction of external distractions, and proactive resource allocation play a significant role in mitigating human error on the front lines.
As Australian facilities increasingly operate well beyond their original design life, asset integrity has transitioned from a basic maintenance function into a highly strategic risk discipline. While digital transformation and advanced inspection platforms provide essential diagnostic data, they cannot function effectively without a competent, highly accountable workforce to interpret that data. Looking ahead, the future resilience of Australia's industrial sector will depend entirely on these interlocking pillars: robust methodologies, digital tools, and human expertise. Ultimately, investing heavily in the human element is the most robust defence against catastrophic infrastructure failure. By rigorously prioritising human factors and continuous competency development, Australian industries can successfully navigate their current constraints and guarantee the long-term safety of their critical assets.
