Norwegian operator Aker BP has received approval from the country’s offshore safety regulator to deploy two of Island Offshore’s mobile offshore units across its operated fields on the Norwegian Continental Shelf.
According to the Norwegian Ocean Industry Authority (Havtil), the consent covers the use of the Island Constructor and Island Wellserver vessels for riserless light well intervention (RLWI) activities on all of Aker BP’s production licences, as mention in Offshore Energy.
The Island Constructor, delivered in 2008 and built to the Ulstein SX 121 design, is a multi-purpose offshore vessel with accommodation for 90 personnel. The unit has been cleared for Norwegian operations since obtaining its Acknowledgement of Compliance (AoC) from the Petroleum Safety Authority in April 2010.
Its sister vessel, the Island Wellserver, also delivered in 2008, is equipped to carry out a wide range of subsea and intervention tasks. These include light well intervention, construction and installation work, well securing, trenching, tower and module handling, plug and abandonment (P&A), crane operations, inspection, maintenance and repair (IMR), supply duties and X-tree installation. The 116-metre vessel remains a core asset for Island Offshore’s well intervention campaigns.
Island Offshore previously secured a two-year extension for Island Wellserver in May 2023 for continued light well intervention work on the NCS, with additional options for further activity. The Island Constructor received a separate consent in 2023 allowing RLWI operations without risers on production licences 359, 338 C and 028 B.
The company is also enhancing its fleet to support future demand. VARD recently marked the keel-laying of Island Offshore’s second hybrid-powered ocean energy construction vessel, underscoring the firm’s ongoing investment in next-generation offshore capabilities.
The Bouri Gas Utilisation Project development in Libya that aims valourising the associated gas from the Bouri field will involve work class ROVs performing offshore touch down monitoring.
Specialised vessels by Next Geosolutions called NG Worker and NG Surveyor will be deployed for the operations in line with around €8.5mn-worth survey and support-to-installation contract awarded by Saipem.
A significant project including complex construction and pipelines delivery, Saipem will be handling the installation of a new Gas Recovery Module, along with a series of upgrades and enhancements to the existing infrastructure. Its contract with Next Geosolutions include optional extensions following operations in Q4 2025.
NextGeo, which mainly deals in renewables and subsea power cables, is excited to have stepped into the oil & gas segment with this significant project from North Africa. It is an addition to another major contract from the same project that was landed last July by the company's affiliate Rana Subsea. Valued at approximately €62.6mn, the contract mandates Rana Subsea to provide specialised subsea services and installation support operations, extending through Q2 2026.
Giovanni Ranieri, CEO of Next Geosolutions, said, “The award of these new contracts with Saipem marks a significant step forward in the growth path of our Group. The joint presence of NextGeo and Rana Subsea in the same project clearly demonstrates the full complementarity of our expertise and our ability to operate in synergy across different yet closely integrated activities, positioning ourselves as a single, trusted partner for the development of complex projects. This is a collective achievement that strengthens our Group identity and represents a natural evolution towards an increasingly integrated, competitive, and operationally excellent model.”
TechnipFMC has secured a major integrated EPCI contract from Italian energy company Eni for the deepwater Maha development offshore Indonesia, marking another significant step in their long-standing collaboration.
This project is particularly notable as it will be the first time Eni deploys TechnipFMC’s Subsea 2.0 configure-to-order technology in Indonesia, signalling a shift towards more standardised and efficient subsea solutions in the region.
Building on the companies’ previous successes at Jangkrik and Merakes, the new Maha facilities will be connected to the existing Jangkrik floating production unit (FPU). Under the scope of work, TechnipFMC will handle the design and manufacture of subsea tree systems, flexible flowlines, a manifold and associated control systems, and will also oversee the installation of the full subsea production package.
Although the precise contract value has not been disclosed, it is classified as a substantial award, indicating a worth in the region of US$250mn to US$500mn.
Jonathan Landes, president of subsea at TechnipFMC, said, “The Maha development provides a significant opportunity to strengthen our relationship with Eni and deliver greater timeline certainty through the application of Subsea 2.0 technologies and integrated delivery.
The offshore drilling industry is entering a period of vigorous growth as operators worldwide accelerate exploration and production to meet rising energy demand, according to The Business Research Company.
Valued at US$33.53bn in 2024, the sector is projected to climb to US$36.28bn in 2025. This reflects a compound annual growth rate of 8.2%.
The expansion follows a decade shaped by strategic discoveries of deepwater reserves, improvements in offshore infrastructure, and increasing global energy consumption. The depletion of easily accessible onshore resources and the availability of specialised offshore expertise have further reinforced activity across major basins.
Looking ahead, the offshore drilling market is forecast to reach US$49.67bn by 2029, maintaining the same growth trajectory of 8.2%.
This forward momentum is driven by renewed investment aimed at strengthening energy security, securing supply chains, and expanding access to capital. Governments and operators alike are also responding to evolving climate regulations and rising expectations around safety, prompting upgrades to equipment and operational standards.
Technological transformation is set to become a defining feature of the forecast period. Operators are expected to increase the use of digital tools, integrate drilling operations into hybrid renewable energy systems, and push further into ultra deepwater territories. Advances in seismic imaging and the adoption of digital twin technology will play a central role in improving accuracy, reducing risk, and optimising asset performance.
A primary force behind the market’s expansion is the steady rise in global consumption of oil and natural gas. These fuels remain vital to heating, power generation, and transport, making them central to energy systems around the world. Economic growth, increasing populations, and the continued shift toward cleaner burning fuels in power and transport sectors are amplifying demand.
Offshore drilling offers the ability to tap large reserves beneath the seabed, thereby ensuring continued supply. Data from the United States Energy Information Administration illustrates this trend. By the end of 2022, proven US crude oil and lease condensate reserves rose by 9% to reach 48.3 billion barrels. Natural gas reserves increased by 10%, climbing to 691 trillion cubic feet. Such figures highlight the sustained appetite for exploration and the vital role offshore assets will continue to play.
Across Europe, leading operators are pursuing competitive advantage through robotics and artificial intelligence. A notable example emerged in 2024 when Schlumberger and Equinor achieved a milestone in autonomous drilling on the Peregrino C platform. Using cloud based applications and AI driven planning tools, the partners succeeded in autonomously drilling 99 per cent of a 2.6 km section. The project demonstrated not only improved efficiency and lower operational costs but also meaningful reductions in carbon emissions.
Asia Pacific remained the world’s largest offshore drilling region in 2024, followed by Western and Eastern Europe, North America, South America, the Middle East, and Africa.
Ocean services provider DeepOcean has been awarded a contract by Equinor to provide various subsea construction and installation activities as part of the Snorre Export and Import Gas Project (SNEIG) for offshore execution in 2026
The SNEIG project is part of the broader Snorre Expansion Project, which aims to extend the production life of the Snorre oil and gas field – originally discovered in 1979 and operational since 1992 – beyond 2040. The Snorre field is located in the Tampen area of the northern North Sea, in water depths of 300–350 meters.
DeepOcean’s scope of work includes installation of a subsea safety isolation valve (SSIV), a subsea umbilical, and tie-in to the existing pipeline using connectors and associated tooling from the Pipeline Repair and Subsea Intervention (PRSI) pool.
DeepOcean will also provide preparatory subsea construction activities include isolation pig tracking, pipeline coating removal and cutting operations. Suitable crossings for the new umbilical will also be prepared and installed at the field before various mechanical completion and commissioning activities are performed.
“This is a complex subsea project that underlines Equinor’s dedication to responsible resource utilisation through life-of-field extensions. Through our in-depth knowledge of the specialised tooling from the PRSI pool, matched with our highly capable construction vessel fleet, I am confident that our skilled project team will ensure a safe and successful project execution in close cooperation with Equinor,” says Olaf A. Hansen, managing director of DeepOcean’s European operation
The award also includes the provision of onshore engineering, procurement and project management services. DeepOcean will manage the project out of its office in Haugesund, Norway.
Offshore operations will be executed during the summer season of 2026 using a subsea construction vessel from DeepOcean’s chartered fleet.
Promethean has announced its Q4 Gulf of Mexico mobilisation, marking the beginning of a new operational phase dedicated to safe and complaint decommissioning.
Committed to operational excellence and continuous improvement, Promethean has embedded integrated data management and innovative technologies into its work processes after recognising that a significant number of safety incidents go unnoticed until they result in workplace incidents.
To address this critical gap, Promethean has partnered with Detect Technologies to implement an innovative visual AI monitoring system, T-Pulse, on decommissioning projects. The technology enhances HSER practices by integrating visual data sources, including fixed cameras and robotic systems to analyse imagery and extract actionable insights on safety compliance and risk mitigation.
Danny Turner, SVP Projects, said, “The meticulous planning over the last three months reflects Promethean Energy’s steadfast commitment to doing decommissioning the right way, with safety, environmental stewardship, a technical excellence, and cost efficiency at the forefront. Our structured approach ensures that every stage, from platform preparation to post-plugging verification, delivers long-term integrity and measurable value to our stakeholders.”
The scope of work is organised under five key operational phases:
This milestone underscores the operator’s continued leadership in delivering efficient and technically robust decommissioning programmes across the Gulf.
Two substantial platforms in the Gulf of America were subjected to comprehensive full-cycle offshore decommissioning campaigns by MC Offshore Petroleum, which also advanced environmental stewardship.
A multi-asset operation, the campaign involved the retirement of the Jolliet Tension Leg Well Platform (TLWP) in Green Canyon Block 184 and the fixed production infrastructure at Marquette comprising a production platform, GC52A, and a processing platform, GC52CPP, in Green Canyon Block 52. These will be further converted into an artificial reef in Green Canyon Block 52.
When installed as the first TLWP in the Gulf of America, Jolliet came to be known as the world's deepest floating production unit at the time of installation. The current campaign honours the platform's legacy while establishing a model for the next generation of offshore decommissioning excellence.
Right from the planning stage in 2022, MCOP has followed a strategy to execute the removals ahead of the peak months of hurricane season. The final decision to begin decommissioning operation was made in the first quarter of 2024. Decommissioning operations, along with the plug and abandonment of all wells on GC 52-A (Marquette) and GC 184 (Jolliet), were set to begin with an execution team in place by the second quarter of 2024.
With the well P&A work underway, pipeline abandonment operations begun as three pipelines were flushed and abandoned. The project team also abandoned another 24-mile pipeline belonging to a midstream operator that originated at GC52.
The decommissioning of the Jolliet TLWP and removal of GC52A and GCS2CPP was made possible with high-level engineering work. Disconnecting the TLWP tendons from the template, ballasting the JOLLIET TLWP during tendon removals and towing the platform to Port Aransas were backed by extensive planning.
The Institute for Energy Economics and Financial Analysis (IEEFA) has published its responses to the Victorian Legislative Council Environment and Planning Committee and its inquiry into the decommissioning of oil and gas infrastructure.
IEEFA is an independent energy finance think tank that examines issues related to energy markets, trends and policies.
The Institute’s mission is to accelerate the transition to a diverse, sustainable and profitable energy economy.
In a statement published on its website, IEEFA noted that Victoria is in a “unique position” to establish a decommissioning industry, given the state has some of the oldest oil and gas extraction infrastructure in Australia “and therefore has a greater proportion of its property and equipment ready for decommissioning.”
It also called on the Victorian government to ensure decommissioning work is undertaken in an orderly and transparent manner.
“This will help to keep cost downs and provide opportunities for the state’s oil and gas workforce and contractors to move into the next phase of oil and gas lifecycle, decommissioning.
Victoria’s decommissioning asset profile includes 22 platforms, over 2,000 km of pipelines and umbilicals, as well as around 460 wells to be plugged and abandoned, according to the National Offshore Petroleum Safety and Environmental Management Authority (Nopsema).
The infrastructure earmarked for decommissioning offshore Victoria is owned and operated by a handful of companies.
Historically, the largest oil and gas producing complex is the Gippsland Basin Joint Venture (GBJV), also known as the Bass Strait project. This year, Woodside took over as operator of the venture from ExxonMobil, which had operated the project since 1969.
Other companies with decommissioning liabilities offshore Victoria include Beach Energy and Amplitude Energy.
Last week the industry’s finest gathered in Aberdeen to see who will be crowned this year’s well intervention champions!
The annual celebration saw a panel of expert judges acknowledge the very best in global well intervention excellence.
This year’s winners included:
A huge congratulations to all the winners and nominees, and a big thank you to everybody who attended! We look forward to another year of seeing this industry push boundaries and drive the wider offshore community into the future.
Archer Limited will be delivering a P&A unit, which is much lighter than usual, for the Fulmar platform in North Sea.
The unit will be deployed as part of an additional contract linked to a five-year agreement with Neo Next Energy.
While the P&A unit will be replacing one of Archer’s modular drilling rigs, the expanded scope of the new contract will cover platform drilling, facilities engineering, coil tubing, wireline services, and downhole well service technologies across Neo Next’s offshore portfolio. This portfolio includes integrated drilling and well services for late-life operations and P&A activities for approximately 130 wells, requiring safe and cost-effective project delivery.
Alexander Olsson, EVP Platform Operations Archer, said, “We are very pleased with this contract award as this anchors our strategic focus on late life and P&A operations. This amendment reflects our ability to grow long-term client relationships by delivering value through operational excellence and innovative solutions. Archer’s capabilities to offer lighter, leaner and more cost-efficient P&A units, is a competitive advantage as the demand for cost efficient P&A programmes grow. We are proud to extend our collaboration with NEO NEXT in this area.”
In an article on the ASCO website, John Davidson, Operations Manager – Environmental Services, ASCO discusses how the UK’s experience of building a system to deal with Naturally Occurring Radioactive Material (NORM) can benefit Australia.
Davidson points out that as Australia faces a massive decommissioning wave, dealing with NORM will be one of the challenges it will need to address. This residue, which builds up in pipework, tanks and separators over years of oil and gas production, carries radiological risks and requires expert handling, treatment and disposal.
In the UK, the oil and gas sector has been dealing with NORM for decades, although the early years were challenging, he notes. “But through trial and error, the UK built a system that now works,” he says.
“NORM processing was centralised. Long-distance, highly regulated transport systems were developed. Experienced specialists were embedded into local teams. Most importantly, collaboration gradually replaced competition. Today, the UK has one of the most mature decommissioning supply chains in the world.”
Australia has a chance to avoiding years of inefficiency and unnecessary cost by learning lessons from the UK experience, he suggests. ASCO, which has built and operated one of the world’s most advanced NORM facilities in the North Sea, can now transfer that knowledge directly into Australia.
He goes on to suggest that a logistics strategy to deal with the long distances of offshore assets from disposal sites needs to be put in place; the expertise of experienced specialists should be leveraged at an early stage; and collaboration between companies should be encouraged, with shared infrastructure, expertise and logistics creating efficiencies and helping to address gaps in local capabilities.
On the questions of regulation, he notes that UK authorities engaged closely with industry to co-develop standards and best practice. “The UK’s lesson is clear: proactive engagement builds trust, accelerates approvals and avoids gridlock.”
“If Australia can absorb the lessons above now, rather than repeat the UK’s early missteps, it has the opportunity to build one of the world’s most resilient and effective decommissioning supply chains,” he concludes.
In a strategic move to strengthen the energy export network of the US Gulf of Mexico, Shell and Chevron have joined forces once again through their Amberjack Pipeline Company joint venture.
The partnership has awarded offshore contractor Allseas a major contract to install the Rome Pipeline, a 150-km, 24-inch trunk line designed to boost oil transport capacity from Shell’s Green Canyon 19 platform to the Louisiana coast.
This vital new link will expand Shell’s extensive Gulf of America pipeline system, enhancing export efficiency and operational flexibility across the region’s offshore network. The project underscores Shell and Chevron’s ongoing commitment to modernising and optimising oil transport infrastructure in one of the world’s most productive offshore basins.
Installation will be executed in two main phases. The nearshore section, scheduled for 2027, will be handled by Allseas’ automatically positioned anchor barge Sandpiper. Following that, the dynamically positioned pipelay vessel Solitaire—one of the most advanced ships of its kind will take on the deepwater installation in 2028. Together, these operations will form a critical artery within the Gulf’s subsea network, ensuring smooth and secure flow of hydrocarbons to shore.
The Rome Pipeline builds on the long-standing collaboration between Shell, Chevron, and Allseas, following the successful completion of previous ventures such as the Amberjack Debottleneck Project in 2016.
With an impressive record of more than 8,000 km of subsea pipelines safely installed in the US Gulf, Allseas continues to play a key role in shaping the region’s energy infrastructure. This new project not only reinforces its technical excellence but also represents a significant milestone in sustaining the Gulf’s vital oil and gas exports for years to come.
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