Wood, the engineering and consulting firm acquired by Sidara in March 2026, has outlined its role in maintenance and shutdown support in Australia’s Gippsland Basin, a region that supplies a large chunk of the country’s south-eastern gas demand.
For more than a year, it has provided services across the Gippsland Basin Joint Venture’s (JV) offshore assets in the Bass Strait and the Longford and Long Island Point facilities.
On July 1st, 2026, Woodside assumed operatorship of the Gippsland Basin assets from Esso Australia — Wood’s contract was first announced in January 2025.
In a recent article posted to its website — but drafted prior to completion of the Woodside operatorship — the consulting firm highlighted how a “strong alliance model” with Esso Australia was ensuring “reliable, value-driven maintenance across critical late-life assets.
”Every day in the Gippsland Basin, hundreds of Wood’s people – technicians, operators, planners, engineers and support staff — play a quiet but critical role in keeping Australia’s energy supply secure, it noted.
“The success of the Gippsland contract is grounded in an alliance model that brings Wood and the Gippsland Basin JV together as one team.”
Since 2020, it has also upgraded and modified key infrastructure through a diverse portfolio of onshore and offshore minor modification and major enhancement work.
Asset integrity management
Over 330 of Wood’s people — around 230 blue-collar and 100 white-collar — have become the engine room of safe and reliable operations, supporting the broader Esso Australia team across Gippsland’s mature assets.Focused on optimising operational performance, local personnel are responsible for planning and executing maintenance programmes with continuous improvement, the Wood article noted.
“Enhancing reliability, production and uptime are core drivers that guide our teams every day — and they work hard to do that while continually reducing risk, learning from experience and supporting Esso Australia’s expectations.
“From day one in January 2025, we ensured a seamless transition into the contract, completing all planned shutdowns safely and continuing to deliver value without operational disruption.”
Smarter maintenance strategies
With decades of production and thousands of hours of ongoing maintenance behind it, Gippsland is a basin with history.
According to Wood, a challenging mindset is needed to uncover optimal maintenance strategies that deliver reliability, and at pace.
“Our teams focus on compliance, prioritisation of critical maintenance and elimination of unnecessary work to strengthen operational performance, without compromising on safety,” the article added.
“Every improvement is driven by the people closest to the job — those identifying smarter ways to work, tightening processes and making sure that what gets done is what truly matters.
"By embracing rope access techniques to replace scaffold-heavy tasks, exploring drones for quick, efficient inspection and continuously challenging the status quo, we’re focused on finding better, safer, more efficient pathways forward."
As the JV’s assets move closer to eventual decommissioning, Wood concluded that its focus is to keep supporting the Gippsland assets with optimised, late-life maintenance that enhances production.
Offshore energy infrastructure across Australian waters is hurtling towards an unprecedented environmental and financial reckoning, yet regulatory safety nets appear ill-equipped to handle the fallout.
In a landmark ruling, the Federal Court has determined that fossil fuel giant Santos is not legally required to prove its financial capacity to clean up its ageing Reindeer gas infrastructure off Western Australia's Pilbara coast. The outcome of the legal challenge, brought against the National Offshore Petroleum Safety and Environmental Management Authority (NOPSEMA) and Santos by the Wilderness Society, has sparked fierce condemnation from conservationists and exposed severe regulatory gaps in national decommissioning frameworks.
Broken regulations and corporate liability
The Conservation Council of WA (CCWA) has labelled the court's decision a failure of process that leaves coastal ecosystems and public finances in acute jeopardy. Assessing the ruling, CCWA Executive Director Matt Roberts described the outcome as "of grave concern".
"This decision clearly shows that when it comes to regulating oil and gas corporations, Australia's laws are broken," Mr Roberts said. "In a judgement released on Friday, the Federal Court found that NOPSEMA was not legally required to be satisfied Santos had the financial capacity to clean up its ageing Reindeer gas field off the Pilbara coast."
Without statutory requirements demanding upfront financial guarantees before production concludes, operators can sidestep the monumental expenses of marine remediation.
“Our laws fail when they don't require multinational oil and gas corporations to take responsibility for cleaning up after themselves in our oceans. We've seen the failures of Australia's oil and gas decommissioning laws play out multiple times now," Mr Roberts stated.
A legacy of stranded maritime assets
The Reindeer verdict is not an isolated breakdown; it reflects a persistent pattern of abandoned liabilities across Australian waters, where corporate insolvency has repeatedly threatened public funds.
“Just last month, two companies, Pilot Energy and Triangle Energy both ceased trading, leaving a stranded asset sitting off the coast of Dongara in WA's Mid West, leaving a $200 million clean-up bill," Mr Roberts noted.
Highlighting earlier precedents, he added: “We've been here before, when Woodside offloaded its Northern Endeavour decommissioning liabilities to a company that went broke. After that debacle, the federal government said it would reform Australia's decommissioning laws, yet here we are, still waiting."
“By delaying these reforms any further, the government runs the risk of more unfunded liabilities and more stranded assets," he warned.
The scope of decommissioning by 2030
The volume of obsolete fossil fuel assets in Australian waters presents a critical logistical and ecological challenge as offshore infrastructure reaches operational retirement.
Mr Roberts pointed to official projections detailing the sheer magnitude of the work ahead:
"We have billions of dollars of oil and gas decommissioning work which will need to begin by 2030, according to the Department of Industry, Science and Resources."
“More than 5.7 million tonnes of material will need to be removed from our oceans nationally, with 89% of that infrastructure located in WA waters."
Urgent calls for legislative reform
To prevent the financial burden from shifting onto the public, environmental organisations are demanding comprehensive statutory overhauls and dedicated funding pools.
“We're calling on oil and gas companies to report on their liabilities project-by-project, to increase accountability and improve accuracy on cost estimates for decommissioning," Mr Roberts urged. "Oil and gas companies must be legally required to set aside dedicated, upfront clean-up funds now - not after they've already left, collapsed, or offloaded the liability onto a smaller player."
Leaving these obligations unaddressed carries severe ecological dangers. As Mr Roberts stressed, “Australian taxpayers and the marine life we all cherish are left vulnerable when corporations are allowed to leave toxic oil and gas assets to rot in our oceans."
"This disappointing legal outcome is yet another example of this process failing our communities, nature and the environment," he concluded. “This level of decommissioning work is a massive liability, and it's up to the government to make sure gas companies, not taxpayers, are the ones paying for the clean-up and the loopholes are closed to prevent the offloading of liabilities or delays.”
Zenith Energy Australia Pty Ltd has been selected to lead phase two of the Northern Endeavour decommissioning programme, Australia’s Department of Industry, Science and Resources confirmed in an 18th August, 2026 update.
“We have engaged Zenith to conduct planning, engineering and regulatory activities to plug and abandon the Laminaria and Corallina wells,” it noted.
Zenith is an independent well engineering and project management firm which has delivered offshore projects in the North West Shelf, Timor Sea, Perth Basin, Otway Basin and Bass Strait.
Phase two of the Northern Endeavour decommissioning focuses on six wells in the Laminaria field and two oil wells and one gas injection well at Corallina.
The Department said the programme would be conducted in two stages, to “help us complete works safely, efficiently and in compliance with regulatory requirements and industry best practice.”
Stage 1 will involve working with Zenith on:
• detailed project planning
• understanding and designing the engineering needs
• gaining regulatory approvals.The outcome of stage one will then determine whether to proceed with stage two, the Department said.
Stage 2 would involve plugging and abandoning the nine wells in line with regulatory approvals, including:
• installing permanent cement barriers at different depths in the wells
• pressure testing the barriers to make sure no fluid can flow to the surface
• removing well infrastructure above the seabed.
Separately, the Department also reported that Xodus Group would provide environmental services for phases two and three of the Northern Endeavour decommissioning programme.
It builds on the company’s experience providing technical assurance and advisory support during phase one work.
The company had confirmed its role in an earlier statement released on 3rd August.
The Department stated that Xodus Group will support environmental approvals for the next phases of the programme by providing technical assurance and advisory services; assisting to gain approvals under the Environment Protection and Biodiversity Conservation Act 1999; developing regulatory approval documents and plans; supporting engagement with regulators; and providing implementation advice.
Xodus has partnered with Elemental Consulting Services who supported environmental approvals during phase one of the programme, the statement added.
Origin Energy has signed a multi-year deal that will see Pointerra’s cloud-based digital twin technology used to monitor approximately 750 km of gas transmission pipeline in Queensland — demonstrating how remote sensing and automated analytics can reshape the management of linear infrastructure.
The project was outlined in a blog written by Matthew James, VP of Business Development - Resources at Pointerra, and posted recently to the company’s website.
Pipeline operators have long faced a fundamental challenge: how to efficiently monitor hundreds or thousands of kilometres of geographically dispersed assets while maintaining visibility of changing conditions along the corridor, James noted in the blog.
“Reality capture technologies such as drones and LiDAR are making it possible to capture those environments in increasing detail. But capturing the data is only part of the equation. Turning large, repeated surveys into timely and consistent information that asset managers and engineers can use is where the operational value lies,” he said.
“That is the challenge Pointerra is addressing with its cloud-native digital twin platform, Pointerra3D.”
Pointerra commenced its multi-year programme with Origin Energy in July, which will deploy Pointerra3D as an enterprise pipeline monitoring and analytics solution across approximately 750km of Origin's gas transmission pipeline network.
The agreement followed a paid Proof of Concept that demonstrated how drone-acquired LiDAR and imagery could be processed and analysed through Pointerra3D to automate pipeline inspection workflows traditionally reliant on manual review and field-based processes.
Under the programme, Origin's pipeline network will be surveyed quarterly by drone, with Pointerra3D providing the digital environment connecting capture partners with Origin's asset managers and engineers, according to James.
Rather than treating each survey as an isolated dataset, the platform enables successive captures to form part of an evolving digital twin of the pipeline corridor.
This allows teams to identify and quantify changes between surveys and focus attention on areas requiring further investigation.
“Pointerra3D's Pipeline Monitoring Analytics Package provides automated data ingestion and QA/QC alongside analytics including terrain, vegetation and surface change detection; third-party interference detection; erosion volume quantification; depth of cover analysis; vegetation segmentation; encroachment analysis; and automated generation of points of interest,” said James.
“Analytics are targeted for delivery within 24 hours of receipt and validation of drone survey data, giving teams access to actionable information through a secure browser-based environment.”
This approach changes the role of reality capture from simply providing a record of asset condition to supporting repeatable monitoring and decision-making, he added.
“For owners of long linear assets, that distinction is significant. A pipeline corridor can extend across hundreds of kilometres of changing terrain, vegetation and land use. Manually reviewing large volumes of imagery and point cloud data is difficult to scale, particularly when surveys are repeated regularly.
“Automating that analysis allows asset teams to concentrate on identified changes, threats and exceptions rather than manually searching datasets for them.”
For Pointerra CEO and Co-Founder Ian Olson, the move from Proof of Concept into business-as-usual operations is an important demonstration of how automated spatial analytics can be applied to critical infrastructure.
“The Origin Energy contract is a significant milestone for the Company,” said Olson.
“It demonstrates the power of our disciplined PoC-to-BAU engagement model and validates the market demand for automated, cloud-native infrastructure asset monitoring solutions that reduce field exposure, improve compliance outcomes, and deliver actionable insights at scale.”
Australia's offshore oil and gas infrastructure is ageing, with many assets approaching or exceeding their original design life, creating significant asset integrity management (AIM) challenges. Operators must address corrosion, fatigue, structural degradation and evolving production conditions while maintaining safety, environmental protection and regulatory compliance. At the same time, they must sustain output and keep projects viable.
Offshore Network has issued a new report addressing how operators can respond to this unique and increasingly complex set of challenges The report looks at:
To download the report, go to https://offsnet.com/reports
Australia’s Department of Industry, Science and Resources has issued a request for tender (RFT) for a lead contractor to deliver Phase 3a of the Northern Endeavour Decommissioning Program.
Published on 14 August 2026, the tender covers the recovery, transport and offloading of subsea infrastructure from the Laminaria and Corallina oil fields to a nominated Australian port. Submissions close on 23 October 2026.
The work will be carried out in two stages.
The first stage will focus on planning and preparation for offshore operations. This includes project, engineering and logistics planning, procurement and subcontractor management, project planning, regulatory approvals, permits and other required authorisations.
The contractor will also be required to submit a Stage Gate Review Pack for approval. Stage 2 can begin once the department approves the pack.
The second stage will involve removing subsea equipment from the Laminaria and Corallina seabed, transporting the recovered infrastructure to a nominated Australian port and offloading it for transfer to the Phase 3b contractor.
The successful contractor will also undertake the project management, engineering, logistics and procurement activities required to complete the work.
The programme requires the successful contractor to meet several priorities, including:
Collaboration will be integral to the success of Australia’s decommissioning efforts, according to Dr Francis Norman, CEO of the Centre of Decommissioning Australia (CODA).
Reflecting on a recent workshop in Jakarta for Indonesian government officials and operators, Norman underlined the power of partnership and the need for knowledge sharing across the industry and across different territories.
“Time and time again, we hear at industry conferences and forums that collaboration will be critical to addressing the challenges of offshore decommissioning,” he said.
“This workshop was a great example of that in practice, bringing together Australian and Indonesian stakeholders to share experiences, discuss different approaches and build a stronger understanding of the opportunities and challenges ahead.”
The two-day CODA workshop was held in collaboration with Australia’s Department of Industry, Science and Resources (DISR) and the National Offshore Petroleum Safety and Environmental Management Authority (NOPSEMA).
Held in July, it brought together 40 participants to support knowledge exchange between Australian and Indonesian stakeholders and build capability in managing the challenges associated with offshore oil and gas decommissioning.
“As countries across the region prepare for increasing decommissioning activity, continued knowledge exchange and cooperation will be an important part of supporting safe, sustainable and effective outcomes,” said Norman.
CODA reported on the workshop in a 5 August statement posted to its website.
“Australia and Indonesia share a common interest in effective offshore decommissioning outcomes, with both countries preparing for significant decommissioning activity in the coming decades,” it noted.
“Building understanding between regulators and government officials provides an opportunity to share experiences, compare approaches and strengthen collaboration across the region.”
CODA said the workshop was developed to provide practical insights across the offshore decommissioning lifecycle, from regulatory frameworks and planning through to execution, environmental management and sustainability considerations.
Sessions covered topics including international and Australian regulatory frameworks, Indonesia’s regulatory approach, well decommissioning, facility and subsea decommissioning, late-life asset management, platform reutilisation, cost estimation, hazardous materials management and environmental assessment.
The programme also included contributions from Australian and Indonesian government representatives, including NOPSEMA, DISR’s Northern Endeavour branch, and Indonesia’s Ministry of Energy and Mineral Resources (ESDM), providing perspectives from both jurisdictions.
As part of a broader capability-building initiative, CODA also developed a version of its recently released online well plug and abandonment training module, adding Bahasa Indonesia subtitles.
The module provides an additional resource for Indonesian officials to continue building their understanding of key decommissioning concepts beyond the workshop.
According to CODA, the Jakarta workshop marked the latest step in ongoing Australia–Indonesia collaboration on offshore decommissioning, supporting greater understanding of the technical, regulatory and operational considerations involved in managing offshore assets through their end-of-life phase.
Testing and quality assurance specialist Intertek is now getting to grips with a contract to provide essential asset integrity and non-destructive testing solutions to operator Santos.
The company announced a multi-year contract back in May for the provision of inspection, non-destructive testing (NDT) and asset integrity management support services across the Santos portfolio of Australian assets.
Its work means delivering expert technical services to help ensure asset quality and safety.
Asset integrity management and NDT services are critical for ensuring the safe and efficient operation of equipment and assets, an essential requirement in industry environments such as oil and gas.
Early detection of defects and irregularities, combined with ongoing asset management services such as risk-based inspection and corrosion management, help owners and operators make informed decisions that minimise risks associated with asset damage, operating inefficiencies, and in-service failure.
The latest contract award deepened Intertek’s long-standing relationship with Santos, which operates multiple producing assets and upstream projects throughout Australia.
Intertek also highlighted the strength of the group’s network of Australian-based inspectors and technicians, as well as its global asset integrity management expertise and fully digitised inspection solution platform, Intertek AWARE.
As the company starts work on its newest assignment, it underlines a broader industry requirement for asset integrity management services, both in Australia and elsewhere.
“This contract award reflects Intertek’s position as a leading provider of asset integrity inspection and testing solutions for the Australian market,” said Simon Mortimore, General Manager Intertek Asset Integrity Management (AIM) Australia, at the time of the contract announcement.
“It also showcases the strength of Intertek AWARE and our capability to support Santos in operating assets safely and effectively across Australia.”
Global Maritime Australia has outlined its role in the recent decommissioning of the Harriet Alpha platform in a recent update posted on its website.
The consultancy provides a suite of decommissioning services, spanning Marine Warranty Survey, engineering and design, FEED studies, marine assurance, marine operations and project management.
It supported Santos as Independent Verification Body (IVB) for the removal and transportation of the platform, marking a new milestone in Australia’s offshore decommissioning sector.
The project saw the removal of a 1,600-tonne topsides and 1,480-tonne jacket, representing a significant full-scale offshore platform removal.Installed in 1985 and ceasing production in 2013, Harriet Alpha was a flagship development for Western Australia’s offshore oil and gas industry and is now a key component of the region’s expanding decommissioning programme.
Engaged from the early planning stages in 2022 through to offshore execution in 2026, Global Maritime (GM) utilised access to a global pool of expert resources in decommissioning to support the project, ensuring that extensive lessons learnt were transferred to the local Australian project teams and the contractor team.
The Harriet Alpha removal campaign stands as the largest offshore platform removal undertaken in Australia to date, encompassing the safe extraction and onshore processing of key structures, including the topsides, jacket and associated infrastructure.
“The decommissioning of the Harriet Alpha Platform was a flagship project, GM pooled local and international technical experts to support our client and ensure that the assets were timely removed and safely transported onshore,” said said Bianca Bevan, Country Manager – Australia of Global Maritime.
“Projects executed with this degree of precision, timeliness and success takes patience, competence and collaboration between all parties. Global Maritime was proud to be a part of such a flagship and successful project.”
In its update, GM added: “Delivered safely and efficiently, the project establishes a new benchmark for offshore asset removal in Australia, demonstrating the increasing capability and maturity of the domestic decommissioning market and setting a precedent for future large-scale programmes.”
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."
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.”
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.
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