Shell Offshore has taken a final investment decision on a waterflood project at the Kaikias field in the Gulf of America to aid in boosting production.
Water will be injected to displace additional oil in the reservoir formation which supplies production to Shell’s Ursa platform in the Mars Corridor.
The method acts as a secondary recovery where the injected water physically sweeps the displaced oil into adjacent production wells, while re-pressurising the reservoir. First injection is penned for 2028 and is anticipated to extend the production lifecycle of Ursa by several years.
Peter Costella, Shell’s Upstream President, said, “Following our decision to increase our stake in Ursa earlier this year, this additional investment continues to maximise the value of the asset. It also contributes to our aim of maximising high-margin production and longevity in a core basin to maintain liquids production.”
ExxonMobil Australia Chair, Simon Younger, outlined the state of play in the company’s decommissioning efforts in the Gippsland Basin during a recent industry event.
He said the company is committed to “responsibly decommissioning” a number of offshore facilities that are no longer producing oil and gas, highlighting the global significance of the project off the coast of Victoria.
“You may be surprised to learn that Victoria is home to Australia’s largest decommissioning project, and ExxonMobil’s largest decommissioning project globally, a multi-year, multi-billion dollar programme of works,” he noted.
Younger was speaking at an event to mark ExxonMobil Australia’s 130 years in the country.
From humble beginnings as the Vacuum Oil Company (later known as Mobil Oil Australia) selling a barrel of cylinder oil to a Bendigo Goldmine from its Melbourne office back in 1895, 130 years later it has grown to become one of Australia’s most critical energy suppliers.
The event also celebrated 60 years of its membership to the Committee for Economic Development of Australia (CEDA), an independent, member-based public policy think tank.
“So far we’ve safely completed over $2.5 billion of early works across our offshore operations, including the permanent sealing of more than 200 wells,” said Younger.
All this work, he added, is in preparation for the arrival of the world’s largest construction vessel, the Allseas Pioneering Spirit, in 2027.
“This mammoth vessel, which is as long as almost 3 MCG fields laid end to end, will travel from Norway to start removal of the 12 retired offshore facilities in Bass Strait and deliver them to our Barry Beach Marine Terminal in Southeast Gippsland, where they will be safely dismantled and recycled.”
After that, the mega project entails a huge and coordinated recycling effort, he noted.
“We plan to maximise recycling of these facilities for a second life and minimise the number of materials processed as waste,” said Younger.
“In fact, our aim is to recycle more than 95% of the mostly steel material from our oil and gas structures. Most of the steel will either be sent offsite in trucks, or via ships for onward transportation to recycling facilities.”
At the same time, Younger noted that ExxonMobil Australia remains committed to supporting the reliable supply of gas from the Bass Strait into the 2030s.
Over the last decade, it has invested almost a billion dollars in the Gippsland Basin.
These investments include the Kipper 1B project, which started up last month, the Kipper Compression Project, and the West Barracouta project, which came online in 2021.
“And right now, in conjunction with our joint venture partner Woodside Energy, we are investing $350 million to develop the Turrum Phase 3 project, which will further bolster supplies of Gippsland gas to the east coast domestic market by 2027,” he said.
“Turrum Phase 3 will be one of the largest gas developments on the east coast and means our Gippsland operations are set to continue powering Australian homes and businesses well into the next decade.”
Earlier this month Subsea7 was awarded a sizeable contract by Ithaca Energy for work in the UKCS.
The contract outlines the provision of off-station decommissioning services for the Alba Floating Storage Unit and Greater Stella field FPF-1 production facility, located 230km east of Aberdeen.
The scope includes the flushing of the subsea pipelines, provision of diver support vessel services, and seabed clearance.
Project management and engineering will commence immediately, with offshore activities penned to begin from Q2 2026.
Hani El Kurd, Senior Vice President of UK and Global Inspection, Repair and Maintenance for Subsea7, said, “This award provides an excellent opportunity to further demonstrate the extent of our three decades of full-field proven decommissioning expertise and our capability in delivering complex, safe and effective solutions.
“Subsea7 is proud of its longstanding relationship with Ithaca Energy, which began in 2008, and looks forward to collaborating closely throughout this project to combine our expertise and ensure its successful delivery.”
Australia faces a major offshore oil and gas decommissioning challenge, with costs estimated at US$40.5bn over the next 50 years, covering more than 1,000 wells as well as related infrastructure.
This is estimated by the Centre of Decommissioning Australia (CODA) to involve the dismantling and disposal of topsides and substructures equivalent to 75 Eiffel towers.
Recent guidance issued by the UK’s Net Zero Technology Centre, in partnership with engineering consultancy Astrima, could help energy companies globally speed up the rollout of improved technologies for decommissioning oil and gas wells, thereby helping to cut costs as well as reducing the environmental impact of ageing energy assets.
The Aberdeen-based centre said the current pace of deployment “remains incredibly slow” as the scale of the challenge grows.
The first guidance is focused specifically on well plug and abandonment (P&A), given that well abandonment is one of the most costly aspects of decommissioning.
It sets out a clear, evidence-based process to assess whether materials can safely and permanently seal wells that are no longer in use. The six-step framework supports safe and confident use through a structured qualification process, helping users identify risks, build a strong evidence base, and streamline approvals to accelerate the safe deployment of new solutions.
Long-term safety and environmental protection are critical as the industry moves away from traditional cement-based barriers. New technologies using low melting point alloys, resins, polymers and epoxies are emerging, but face challenges demonstrating their effectiveness and reliability.
The framework incorporates input from operators, regulators and technology developers, and draws on international guidelines and standards such as DNV RP A203 and API RP 17Q, which are widely used across the energy sector.
Lewis Harper, Programme Manager at NZTC, said,“Well decommissioning is an increasingly urgent global issue as maturing basins seek ways to cut costs, reduce emissions and improve efficiency. The only way to achieve that is through new technology, but the pace of developing and deploying new solutions remains incredibly slow.
“This guidance will help speed up the safe adoption of innovative technologies, giving operators and regulators the confidence to move faster. By managing performance to stringent standards, the adoption of new materials should become easier and more reliable. This framework gives the industry the tools to tackle well decommissioning challenges with greater confidence.”
To reach optimised production results, Vaalco Energy has begun the spudding of the ET-15 infill well on the Etame platform as part of Phase Three Drilling Programme offshore Gabon.
This infill well is anticipated to significantly add to the production generation capacity of the floating storage and offloading vessel (FSO) that is operational on the Etame Block since 2022 following an extensive transition and field reconfiguration process. While a low cost solution, the FSO boasts of a high storage capacity and improved operational performance. It has helped Vaalco reach operational excellence, and production uptime and enhancement.
George Maxwell, Vaalco’s Chief Executive Officer, commented, “We are excited to commence our drilling campaign in offshore Gabon and are beginning the near-term series of value creation catalysts that we outlined to the market in our Capital Markets Day presentation this past May. The drilling rig arrived in late November, and we have spud our first well, the ET-15. We are initiating the programme at the Etame platform with this infill well and the pilot holes. After drilling at the Etame platform, we expect to move the rig to the SEENT and Ebouri platforms where we have several wells and workovers planned to enhance production, lower costs and potentially add reserves. As we enter 2026, with major projects underway in both Gabon and Côte d’Ivoire, we are looking to drive meaningful growth that we believe will translate into value for our shareholders for the remainder of the decade.”
As previously announced, the Company secured a drilling rig in December 2024 in conjunction with its Phase Three Drilling Programme, with an affiliate of Borr Drilling.
ADES Holding has secured a new contract for its Compact Driller standard jack-up through its Shelf Drilling subsidiary for work offshore Brunei.
The contract, awarded with Brunei Shell Petroleum, covers plug and abandonment operations offshore, and is expected to commence in Q4 2026. The contract has a two-year term and is worth approximately US$63mn.
Mohamed Farouk, CEO of ADES Holding, said, “We are delighted to announce our first contract award following the successful acquisition of Shelf Drilling, a milestone that reinforces our strategic vision and solidifies our presence in Southeast Asia, a region of immense opportunity and growth. This award reflects Shelf Drilling’s proven track record of safety and operational excellence, particularly its unique experience delivering P&A services in the region.
“This track record underscores the rationale behind our acquisition. We are pleased to begin our partnership with BSP and remain committed to delivering safe and efficient operations in support of their activities in Brunei. It is a testament to the dedication of the combined teams and the strength of our integrated platform. We look forward to building on this momentum and continuing to deliver exceptional results for our clients and partners.”
Malaysian well interventions specialist, United Asiapac Energy Bhd, has launched an initial public offering (IPO) on the ACE Market of the local stock exchange.
According to filings lodged with Bursa Malaysia, the company aims to use the IPO to bolster its services and operational capabilities to take advantage of emerging opportunities in Malaysia’s upstream sector.
Specifically, that includes plans to strengthen its technical capabilities by acquiring new well intervention tools and equipment.
“To support future business growth, it is essential that our group has available well intervention tools, equipment and DNV-certified cargo baskets that we can mobilise
simultaneously in order to meet our project deadlines,” its stock market prospectus notes.
In line with this goal, the company plans to acquire a break-out unit for installation at its Kemaman base, to be used for the assembly and testing of well intervention tools.
Presently, the group’s tools and equipment are transported to a third-party facility within the Kemaman base for assembly, testing and inspection, which requires careful planning to ensure project timelines are met and incurs additional logistical costs.
“We also intend to purchase DNV-certified cargo baskets, which are used to transport tools during every mobilisation,” the company added.
The group boasts strategic locations in Kemaman and Labuan, which it claims give it a competitive edge over other industry players, which are predominantly international firms.
United Asiapac Energy added that it also intends to introduce new well intervention solutions to broaden its service offering.
“We plan to introduce e-line, slickline and wireline recovery services, particularly for small hole fishing,” its prospectus notes.
“In addition, we plan to offer hydrocarbon well cleanout services to remove obstructions and debris through the procurement of specialised tools. This expansion is a direct response to increasing market demand and enquiries from existing and prospective clients seeking for well intervention solutions under a single service provider.”
The company also said that it intends to expand its services in Sabah, as well as acquire a new corporate office in the Kuala Lumpur area.
Sarawak expansion is also in its sights.
“We aim to expand our market presence in well intervention solutions within Sarawak,” it notes in the Bursa Malaysia filings.
“The state presents significant opportunities for growth, driven by the anticipated increase in greenfield exploration activities and the maturing of existing hydrocarbon fields. With new fields being explored and developed, and mature fields nearing the end of their productive life, the resulting demand for well intervention, particularly P&A services, appears promising.”
Pantheon Resources has been conducting well clean-up operations on the Dubhe-1 well with an aim to determine a representative oil flow rate.
The clean up profile might need alteration to suit the well's multiple fracked stages, each differing from the previous single zone completion and requiring clean up at different points in time.
While the company's budget for well completion was set at approximately US$15mn, well planning and data gathering led to modified final costs. As clean-up continues alongside flow-back and well testing activities, these costs will be determined at the end of the programme.
Production from the Dubhe-1 well is dominated by previously injected stimulation fluids. After intermittent production, consistent small oil volumes have been visible, with boosted gas production throughout the period. Till now, approximately 40% of the injected water volume has been produced with steady gas production along with the modest production of light oil. The company's closest analog to this well is the SMD-B interval in Alkaid-2 which was flow tested in 2023 and first measured oil production when a water volume equivalent to approximately 50% of the injected water volume had been produced.
The company recorded approximately US$33mn in drilling and completion costs, a marked increase over the original budget, as it had to drill a pilot hole to allow core samples to be collected, to better refine the target landing zone and to penetrate the deeper Slope Fan System (SFS) as well as the shallower SMD-C reservoir target.
Overall, this cost outcome, inclusive of full appraisal scope, contingency measures (e.g. standby drilling rig and coil tubing unit based on the experience at Alkaid-2), and inflationary pressures, does not detract from a solid operating performance. In addition, the construction of the new Dubhe pad, which will also be available for the drilling of future wells, cost $2.5 million. Clean-up, flow-back and well testing operational costs will be determined at the end of the programme.
Max Easley, Chief Executive Officer, said, "I continue to be pleased with the ongoing safe and efficient execution of our operations to date and look forward to sharing more about Dubhe-1 results when we have them."
Petrobras and Shell Brasil Petróleo Ltda. (Shell Brasil), a subsidiary of Shell plc, have together secured additional equity in Brazil’s pre-salt oil projects following an auction led by Pré-Sal Petróleo.
Petrobras increased its stake in the shared Mero field from 38.6% to 41.4%, and increased its stake in the shared Atapu field from 65.687% to 66.38%. Shell Brasil increased its participating interest from 16.663% to 16.917% in Atapu and from 19.3% to 20% in Mero.
Both projects are located in the offshore Santos Basin. In the Mero field, the four FPSOs and an Early Production System (EPS) have a combined gross installed production capacity of 770,000 barrels of oil per day. the P-70 Floating, Production, Storage and Offloading unit (FPSO), which has the capacity to produce 150,000 barrels of oil per day. To support future growth, a second FPSO (P-84), with a production capacity of 225,000 barrels of oil per day, is currently under construction.
This auction was supported by Law No. 15,164, of July 14, 2025, which amended Law No. 12,351, of December 22, 2010, authorising the Union to sell its rights and obligations arising from production individualisation agreements in non-granted or non-shared areas in the pre-salt area.
Petrobras' participation in the PPSA Uncontracted Areas Auction is aligned with the company's long-term strategy, reaffirmed in the 2026-30 Business Plan, which foresees the replenishment of its oil and gas reserves with economic and environmental resilience.
In Shell’s case, the investment strengthens Shell’s position in areas where it has existing assets and supports the company’s aim to sustain material liquids production of 1.4 million barrels per day through 2030.
“Today’s winning bid reinforces our disciplined approach to grow Shell’s high margin portfolio in Brazil,” said Peter Costello, Shell’s Upstream President. “Our assets in Brazil are among the most competitive in our global portfolio, combining strong performance with a low carbon footprint.”
The International Well Control Forum (IWCF) has introduced a new assurance framework designed to ensure that non-accredited training adheres to the highest standards, establishing a benchmark to enhance safety across the global oil and gas sector
Quality Assured provides a flexible, independent endorsement for well control training outside IWCF’s accreditation scope, offering providers and employers confidence in the quality, structure, and relevance of their programmes.
Zdenek Sehnal, CEO of IWCF, said: “Through Quality Assured, we’re committed to ensuring the highest standards in well control training, providing consistency and empowering professionals. This goes beyond compliance; it’s about giving the sector confidence in the training they are investing in and supports a culture of continuous development and accountability across the oil and gas industry, where well control incidents can have far reaching impact on life and reputation.”
The framework consists of nine standards, covering all aspects from course design and delivery to assessment, digital learning, and on-the-job training. Each standard includes defined criteria that providers must satisfy to achieve Quality Assured status.
IWCF will initially roll out Quality Assured in four categories:
The Well Academy, based in Apeldoorn, The Netherlands, participated in the Quality Assured trial. Jan Willem Flamma, Director of Training, said: “We were thoroughly impressed with the Quality Assured feedback from IWCF. The report on our Stuck Pipe Prevention & Recovery course went far beyond a simple evaluation, providing a true partnership in quality.
“The detailed strengths and constructive recommendations will be invaluable in helping us elevate our course materials and delivery, reinforcing our commitment to delivering high quality training and supporting continuous improvement for our learners.”
Training providers and employers will receive a 12-month endorsement, with the possibility of renewal if Quality Assured standards continue to be met. This initiative will support vital risk reduction across the sector.
Pentarch Offshore Solutions, which provides marine logistics for offshore energy, heavy industry and decommissioning, is bolstering its bunkering capabilities.
The company, a partner of the Centre of Decommissioning Australia (Coda), has signed a Memorandum of Understanding (MoU) with Integr8 Fuels to help meet growing Australian maritime refuelling needs at the Port of Edrom, Eden, New South Wales (NSW).
The agreement marks a key step in enhancing bunker fuel provision and operational support for expanding offshore energy, maritime, and defence activities in the region, according to William Kanavan, Managing Director of Pentarch Offshore Solutions.
“The signing of this MOU marks a significant milestone for Pentarch Offshore Solutions, firmly positioning our region on the global map as a growing hub for marine and offshore energy operations,” said Kanavan.
“Our developing partnership with a world-leading fuel provider like Integr8 Fuels demonstrates the scale of opportunity this regional port can deliver – for industry, and for Australia.”
The collaboration means the two partners, alongside regional stakeholders, will be contributing to the ongoing transformation of the Port of Edrom into a multi-functional marine and energy terminal.
The MOU builds on existing fuel supply commitments to a range of Australian and international marine contractors, including allied defence and naval refuelling operations.
“This partnership strengthens Integr8 Fuels’ presence in the Australian market, demonstrating our commitment to supporting critical marine and offshore operations,” said Christopher Seidel, Integr8 Fuels’ Business Manager.
“We look forward to collaborating with Pentarch Offshore Solutions and contributing to the growth and capability of the Port of Edrom and the Far South Coast community of New South Wales.”
HEA Energy, a fast-growing offshore services provider based in the UAE, has officially expanded its fleet with the addition of HEA Survey, a highly versatile subsea support and survey vessel designed to meet the evolving demands of modern offshore operations.
The ABS-classed, Panamanian-flagged vessel represents a major step forward for the company as it continues to strengthen its capabilities across the Middle East’s offshore oil, gas, and renewable energy markets.
Built by Jiangsu Islands Shipbuilding in China, HEA Survey was conceived as a multi-role offshore workhorse capable of undertaking a wide spectrum of subsea activities. These include high-precision survey work, ROV support, subsea inspection campaigns, light well intervention, dive support, heavy lifting, firefighting duties, and anchor-handling operations. Although the vessel’s construction began in 2013 and was significantly delayed, with completion only achieved in late 2024, she emerges with a thoroughly modern design tailored to today’s offshore requirements.
Measuring 59.25 metres in length with a beam of 15 metres, the vessel features a robust diesel-electric propulsion system engineered for operational flexibility. Two 2,100hp engines, paired with multiple generators and controllable-pitch propellers, deliver up to 12 knots while enabling dynamic load management. This configuration allows the vessel to operate efficiently during low-speed survey work or station-keeping a critical capability for precision subsea tasks. An electrically driven bow thruster further enhances lateral manoeuvrability, making the vessel suitable for operations in both shallow and deepwater environments.
A considerable 350-square-metre aft working deck, reinforced to handle seven tonnes per square metre, gives HEA Survey the capacity to support modular mission packages such as ROV hangars, geotechnical equipment, and ISO container-based systems. With a maximum payload of up to 500 tonnes and a 25-tonne SWL crane, the vessel is well-equipped for heavy offshore logistics and deployment work.
Despite not being DP-classed, the combination of controllable-pitch propellers, bow thrusters, and a diesel-electric system ensures reliable station-keeping for a broad range of survey and subsea activities. The vessel also features a complete suite of modern navigation and communication electronics, including S- and X-band radars, AIS, echosounder, GPS, Doppler log, and MF/HF radio equipment.
Accommodation onboard is fully air-conditioned and compliant with ILO standards, providing comfortable living quarters for up to 48 crew members across a mix of single, double, and quad cabins. Safety provisions are SOLAS-compliant, with liferafts, immersion suits, fire monitors, and a dedicated MOB boat with davit launch capability.
Entering service in the UAE, HEA Survey positions HEA Energy to meet growing regional demand for multi-role offshore support vessels particularly within subsea construction, well intervention, offshore survey campaigns, and the expanding clean-energy marine sector.
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